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Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. T41223PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Lau, Jack J (OGC) To:Oliver Sternicki Subject:RE: [EXTERNAL] RE: 15-43 (PTD# 196083) P&A sundry 325-359 added SL step Date:Thursday, November 20, 2025 2:12:38 PM Attachments:image001.png Good afternoon Oliver, Approved to eliminate the plug at 8610’ and use the fill as the hard bottom for cementing. Jack From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Thursday, November 20, 2025 1:54 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: 15-43 (PTD# 196083) P&A sundry 325-359 added SL step Jack, Coil tubing completed the FCO of the cretaceous sand down to 8660’ MD on 15-43 yesterday and fullbore executed a passing MIT-T against the fill top this morning. MIT-T max applied pressure was 2020 psi, lost 68 psi 1st 15 min & 25 psi 2nd 15 min. We would like to eliminate the plug setting step seen below in the eline operation as the fill is a sufficiently hard bottom to execute the subsequent coil cementing operations. Let me know if you agree with this change, eline is scheduled to be on the well tomorrow (11/21). Thanks, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, November 14, 2025 11:34 AM To: Oliver Sternicki <oliver.sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: 15-43 (PTD# 196083) P&A sundry 325-359 added SL step Thanks for the update Oliver. Have a great weekend. Jack From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Friday, November 14, 2025 10:56 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: 15-43 (PTD# 196083) P&A sundry 325-359 added SL step Jack, Wanted to give you a heads up on a couple minor changes to the 15-43 P&A eline steps upcoming after the coil FCO. Step 6-1: They are going to start off with the CBL to try to narrow down where the top of IA fill is prior to running the gravel pack log, may not even need to run the gravel pack log depending on how the CBL looks. Step 6-2: We are going to us a Neo high expansion plug and dump bail 10’ of cement on top of it instead of using the 4.5” ER CIBP. The follow up PT to 2000 psi max applied will be the same. Let me know if you have any questions. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, November 3, 2025 10:40 AM To: Oliver Sternicki <oliver.sternicki@hilcorp.com> Subject: [EXTERNAL] RE: 15-43 (PTD# 196083) P&A sundry 325-359 added SL step 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Thanks for the update Oliver. Jack From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Monday, November 3, 2025 9:58 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: 15-43 (PTD# 196083) P&A sundry 325-359 added SL step Jack, Coil began the P&A work on 15-43 yesterday (11/2/25) by milling through the CBP at 7739’ MD. They were unable to recover the plug remnants from the top of fill so we are going to add in a SL step to see if they can recover it prior to EL setting the patch. If SL is unable to recover the plug remnants we will plan to set the patch and then have coil break up whatever is left as they are do the FCO in step 5. Let me know if you have any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor 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 youare 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 strictlyprohibited. 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 andpermanently 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 useof this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carryout 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 youare 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 strictlyprohibited. 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 andpermanently 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 useof this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carryout 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 youare 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 strictlyprohibited. 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 andpermanently 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 useof this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carryout such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 15-43 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 196-083 50-029-22676-00-00 ADL 0028306 11043 Conductor Surface Intermediate Production Liner 8847 80 3518 8572 2591 7739 20" 9-5/8" 7" 4-1/2" 7496 36 - 116 35 - 3553 33 - 8605 8452 - 11043 2504 36 - 116 35 - 3541 33 - 8299 8156 - 8847 10840, 10949 470 4760 5410 7500 7739, 10225 1490 6870 7240 8430 9672 - 10940 4-1/2" 12.6# 13cr80, L80 31 - 84538851 - 8841 Structural 4-1/2" Baker S3 Packer 4-1/2" Baker S3 Packer 8326, 8039 8418, 8124 Date: Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com (907) 564 4891 PRUDHOE BAY 9/16/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:54 pm, Sep 02, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.02 11:32:12 - 08'00' Torin Roschinger (4662) 325-538 X DSR-9/9/25JJL 9/9/25 A.Dewhurst 09SEP25 10-407 X AOGCC witness tag TOC and MIT and CMIT-TxIA to 2250 psi. AOGCC witness casing cuts before any top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut JLC 9/10/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.10 14:06:15 -08'00'09/10/25 RBDMS JSB 091125 P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Well Name:15-43 Permit to Drill Number:196083 Well Type P API Number:50-029-22676-00-00 Job Scope:P&A Reg.Approval Req’d?Yes Current Status:Not Operable, Offline Date Reg. Approval Rec’vd: Estimated Start Date:9/16/2025 Estimated Duration:20 days Regulatory Contact:Abbie Barker 907-564-4915 First Call Engineer:Oliver Sternicki 907-564-4891 Second Call Engineer:Jerry Lau Current Bottom Hole Pressure:3384 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2504 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:562 psi Min ID:3.813” TRSV @ 2183’ MD Max Angle:95 deg @ 9939’ MD Top of Sag:8547’ MD Well History: 15-43 was originally completed as an Ivishak producer in 1996 and a RWO replaced the tubing in 2004. The well then went Not Operable in late 2008 for a surface casing leak which was not successfully repaired until 2015 when a Wellock conductor top job was executed. The well again went Not Operable in late 2018 when a Cretaceous production casing leak was discovered at 5380’ MD. Due to the Cretaceous leak, formation sand was found to be blocking the tubing at ~7800’ MD and GLM #3 at 5334’ MD was found to be washed out, creating TxIA communication. A WRP was set at 6983’ on 10/22/18 to isolate crossflow between the Cretaceous and the Ivishak. This WRP was removed and replaced with a composite bridge plug at 7739’ MD on 11/4/19. Both Cretaceous leak and TxIA liquid leak rate are ~2 BPM at 600 psi. The confining interval above the Sag is from 8034’- 8547’ MD. Current Status: 15-43 is currently not operable and offline. Objectives: The intent of this program is to fully abandon the well as part of the 2025 PBU P&A program. The CBP at 7739’ MD will be milled and retrieved after which a patch will be placed across leaking GLM#3 to isolate the tubing from the cretaceous leak. An FCO will then be executed to near the 7” casing shoe depth. Tubing punches will then be shot into the 4.5”x 7” annulus above the liner top and between the production packers and coil will lay in cement from the top of fill in the tubing to ~8250’ MD creating a lateral plug from 8342-8452’ MD. Cretaceous sand fill in the 4.5”x 7” annulus is unknown so a gravel pack log will be executed to determine where to punch the 4.5” tubing and a tubing, IA cement plug will be placed from below the cretaceous leak depth, up to ~4500’ MD. The tubing and production casing will then be perforated at ~2920’ MD and the tubing, IA and OA will be cemented to surface. A variance to the plugging requirements under 20 AAC 25.112(c)(1) is requested. A lateral plug will be placed across the confining interval from 8342-8452’ MD, providing isolation of the reservoir and preventing vertical movement of fluid within the wellbore. A variance to theplugging requirements under 20 AAC 25.112(c)(1) is requested P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Current Schematic P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. 1. Coiled Tubing Mill CBP 1. MU 3.80” venturi burnshoe assembly, RIH and mill CBP at ~7739’ MD. 2. Mill/ push CBP parts to top of fill, remove remaining pieces from top of fill.. Reference SL AWGRS from 10/22/2018 as last top of fill tag at 7769’ MD. 2. Fullbore: 1. Circ out IA with 360 bbls diesel, pumping down tubing, through washed out GLM #3 at 5334’ MD and out IA to clean out potential solids in the IA from the cretaceous leak. 3. Eline: 1. Set 4.5” X-Span patch across GLM#3 leak from 5326-5346’ MD. Patch ID= 3.375” A.Tie into Halliburton LDL dated 10/23/2018 (Up/Down Overlay- Pumping 2 bpm down tubing) P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Halliburton LDL- 10/23/2018 P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 4. Fullbore: 1. MIT-T to 2000psi max applied pressure to determine if patch is holding. Uncertain if fill will hold pressure, monitor IA for any pressure change if unable to hold pressure on the tubing. ***If MIT-T doesn’t pass, notify OE of results*** 5a. Test Separator FCO of Cretaceous sand- coordinate with Coiled Tubing . 5b. Coiled Tubing FCO to ~8650’ MD 1. MU slim CTC with 1.75” disco, 1.25” motor and 3.30” mill to clean out cretaceous sand. ***High gas rate well prior to cretaceous leak, potential high gas rate below sand bridges. Reference SL AWGRS from 10/22/2018 as last top of fill tag at 7769’ MD. Approx fill volume to 8650’ MD= 14 bbls. Well test prior to Cretaceous leak: P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Proposed Schematic- post tubing patch and FCO P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 6. Eline/ Fullbore: 1. Log TMD3D gravel pack log from ~8326’ MD to 4000’ MD to determine cretaceous sand fill top in 4.5”x 7” annulus. If gravel pack log is inconclusive run CBL Log with same objective. A.Tie into 4.5” Tubing Summary dated 3/15/2004. B. Contact OE (907-350-0759) with log results. 2. Set special clearance 4.5” ER CIBP at 8610’ MD. A.Tie into Halliburton Coil Flag dated 6/15/2018 (Main Pass) 3. MIT-T to 2000 psi max applied pressure to determine if CIBP is holding. Contact OE if PT fails. 4. Punch tubing at each of the following depths: A. 8447- 8452’ MD, 8412-8432’ MD, 8342-8347’ MD B.Tie into Halliburton Coil Flag dated 6/15/2018 (Main Pass) C. Use 0° phase, decentralized, oriented to low side, rated for 4.5”, 12.6#, 13CR tubing. 5. MIT-T to 2000 psi max applied pressure to determine if tubing punches changed PT results. Contact OE if PT fails. 6. Punch tubing w/ 5’ of punches across collar ~50’ above top of fill based on gravel pack/ CBL log,but not higher than 5380’ MD. A.Tie into TM3D gravel pack log or CBL previously run. B. Use 0° phase, decentralized, oriented to low side, rated for 4.5”, 12.6#, 13CR tubing. 7. Verify communication TxIA through punch holes with 20 bbls diesel pumped down IA and then 20 bbls diesel pumped down tubing. P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Tubing Summary (3/15/2004) P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Halliburton Coil Flag (6/15/2018) Main pass- plug set and tubing punch P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Proposed Schematic- post plug set and tubing punch P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 7. Coiled Tubing: Reservoir plug and cretaceous leak isolation 1. Circ out tubing with 140 bbls diesel. a. Max circulating pressure= 2500 psi. 2. Bullhead IA to cret leak at 5380’ MD with 120 bbls diesel. a. Max pressure= 2500 psi. 3. Cement tubing and IA: a. Pump 20 bbls inhibited surfactant wash. b. Pump 10 bbls FW spacer. c. Lay in 50 bbls of 14-16 ppg cement, taking returns from coil backside. Cement should be at 5500’ MD after this initial volume. Open IA and coil backside taking 1:1 returns, laying in additional minimum of 32 bbls cement (based on punch depth) up to 4500’ MD allowing cement to u-tube. If Cret leak is taking cement and unable to get 1:1 returns, attempt to squeeze 20 bbls cement into Cret leak. d. Displace with 5 bbls FW spacer followed by diesel. Max circ pressure= 2500 psi. Estimated TOC in tubing and IA = 4500’ MD. Cement Volumes: x 4.5” x 7” annulus from 8342-8452’ MD: 110’ x 0.0186= 2 bbls x 4.5” x7” annulus from 4500’ MD- (punch holes above IA fill). Highest planned depth of punch holes is 5380’ MD: >880’ x 0.0186= >17 bbls x 4.5” tubing from 4500- 8610’ MD: 360’ x 0.0152= 63 bbls Total cement: minimum 82 bbls. Additional 20 bbls may be needed to squeeze into Cret leak. Cement Type/weight:Class G 14-16 ppg Bottom hole static temp:~180°F at base of cement (8570’ MD) Fluid Loss:20-200 cc/30 min Thickening Time:Minimum 6 hours P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Proposed Schematic- Reservoir cement plug and Cretaceous leak isolation P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 8. Fullbore 1. WOC 5 days, MIT-T, CMIT-TxIA to 2500 psi max applied pressure, 2250 psi target pressure – AOGCC Witnessed 9. Slickline 1. WOC 5 days, Drift and tag TOC –AOGCC Witnessed 10. Well Support: 1. Nipple down tree, install dry hole tree for cementing if required. 11. DHD: 1. Remove plug in SSSV C/B line penetration from WH. Cement control and balance lines with microfine cement if C/B lines are present. 12. Eline: 1. Perforate 4.5” tubing and 7” casing at 2920’-2930’ MD. Perf gun to be determined from HES model. A. Perforate 4.5” tubing and 7” casing at 2920’-2930’ MD to establish circulation point for IA and OA cementing. B. Tie into Halliburton LDL dated 10/23/2018 (Main Pass) C. Apply 500 psi to 4.5” prior to perforating, record before/after pressures. D. Note any pressure changes. P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Halliburton LDL- 10/23/2018 P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 13. Fullbore : ***Arctic Pack in OA. History of intermittent SC leak. Have vac truck on location.*** Surface-2930’ MD volumes: Tubing= 45 bbls, IA= 55 bbls, OA= 75 bbls 1. Verify circulation from tubing to IA and tubing to OA. 20 bbls diesel each, max pressure= 2500 psi. 2. ***If unable to circulate up OA, circulate hot brine down IA to loosen up AP***. 3. Circulate the following down the tubing and up the 7” x 9.625”” annulus to prep for cement. A. 5 bbls MeOH B. 25 bbls hot diesel (min 120 degF) C. 80 bbls hot (160degF) fresh water + surfactant. D. 140 bbls (20 bbls excess) of 9.8 brine (80-100 degF) Ensure reasonably clean returns. (can skip this freeze protecting step if immediately going to cementing) E. Max pressure 2500 psi. 4. Circulate the following down the tubing and up the 7” annulus to prep for cement. A. 5 bbls MeOH B. 25 bbls hot diesel (min 120 degF) C. 80 bbls hot (160degF) fresh water + surfactant. D. 120 bbls (20 bbls excess) of 9.8 brine (80-100 degF) Ensure reasonably clean returns. (can skip this freeze protecting step if immediately going to cementing) E. Max pressure 2500 psi. 14-Fullbore Cement: 1. Circulate the following down the tubing to cement the 4.5” tubing, 4.5”x 7” and 7”x 9.625” annulus from surface to 2930' MD. MIT-OAs have passed historically except for intermittent SC leaks, OA shoe should hold pressure. 2. Pump down the tubing, taking returns from the OA at surface. A. 5 bbls MeOH B. 10 bbls fresh water C. 130 bbls (10 bbls over calculated volume) 14- 16 ppg Arctic Set (or similar) cement or until uncontaminated cement is seen at surface. a. Max pressure while pumping 2500 psi. 2. Shut-in OA and open IA for cement returns to surface while pumping down the tubing. A. Pump 65 bbls (10 bbls over calculated volume) 14- 16 ppg Arctic Set (or similar) cement or until uncontaminated cement is seen at surface. a. Max pressure while pumping 2500 psi. Cement Type/weight:Arctic Set or similar 14-16 ppg Bottom Hole Temp:10°F Fluid Loss:20-200cc/30 min Thickening Time:Minimum 8 hours Cement Volumes: x 4.5” tubing from surface to 2930’ MD: 2930’ x 0.0152 bpf= 45 bbls x 4.5” x 7” annulus volume= 0-2930’ MD= 2930’ MD: 2930’ x 0.0186= 55 bbls x 7” x 9-5/8” annulus from surface to 2930’ MD: 2930’ x 0.0256 bpf= 75 bbls Total cement: 175 bbls + 20 bbls excess P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Displacement: x No displacement P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 Proposed Schematic- Surface abandonment plug P&A Sundry Well: 15-43 PTD: 196083 API: 50-029-22676-00 22. DHD: 1. Bleed all wellhead pressures to 0 psi. 2. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. 23. Well Support: 1. Excavate and cut off all casings and wellhead 3’ below original tundra level. 2.AOGCC witness of cut-off casings before any top job commences. 3.AOGCC witness cement tops in all annuli. Top off with cement as needed. 4. Bead weld ¼” thick steel marker cap on outermost casing string. Photo document all steps and AOGCC witness of installed cap. Marker cap to read as follows: Hilcorp North Slope, LLC PTD # 196083 Well: PBU 15-43 API # 50-029-22676-00 5. Remove shoring box, backfill excavation. Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: September 2, 2025Subject: Changes to Approved Sundry Procedure for Well 15-43Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:196-083 6.50-029-22676-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11043 7739 7496 8333 , 8418 7496 , 10840 7739 8045 , 8126 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 3518 9-5/8" 35 - 3553 35 - 3541 6870 4760 Intermediate 8572 7" 33 - 8605 33 - 8299 7240 5410 Production Perforation Depth: Measured depth: 9672 - 10940 feet True vertical depth:8851 - 8841 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 #31 - 8453 31 - 8156 8333 , 8418 8045 , 8126Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Packer (2) Liner 2591 4-1/2" 8452 - 11043 8156 - 8847 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 48506328166 00 0 2881 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8847 Sundry Number or N/A if C.O. Exempt: 319-223 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 pull WRP, set CBP Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028306 PBU 15-43 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:15 pm, May 26, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.26 14:30:10 -08'00' Bo York RBDMS HEW 6/9/2021 SFD 6/16/2021MGR30JUL2021DSR-5/26/21 ACTIVITYDATE SUMMARY 11/3/2019 ***WELL S/I ON ARRIVAL*** (Cement Squeeze) DRIFTED WI/ 3.805" CENT & 2.50" SAMPLE BAILER TO WRP AT 6973' SLM. ***JOB CONTINUED ON 04-NOV-2019*** 11/4/2019 ***JOB CONTINUED FROM 03-NOV-2019*** (Cement Squeeze) PULLED 4-1/2" WFD WRP FROM 6983' MD (slips and elements intact). TAGGED FILL AT 7767' SLM WITH 3.805" CENT & 2.50" S-BLR. RAN 4 1/2" BL-BRUSH & 3.80" G-RING TO TIGHT SPOT AT 6951' SLM. SET 4-1/2" WFD CBP @ 7739' MD. CONFIRMED PLUG SET DEPTH W/ 3.68" CENT, TAGGED CBP @ 7729' SLM/ 7739' MD. ***JOB COMPLETE ON 04-NOV-2019*** 11/12/2019 T/I/O=562/565/15 Temp=SI (LRS Unit 76 - Establish Tubing & IA LLR) Establish TBG LLR of 2 BPM @ approx. 580 psi w/ 20 bbls crude. Establish IA LLR of 2 BPM @ approx. 611 psi w/ 20 bbls crude. FWHP=545/568/17 5/11/2021 FS3 team decided to not move forward with legacy BP IA cement squeeze job on 15-43 under sundry # 319-223. Daily Report of Well Operations PBU 15-43 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Joshua Tempel Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 15-43 Permit to Drill Number: 196-083 Sundry Number: 319-223 Dear Mr. Tempel: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ww .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner,,` DATED this 1 day of June, 2019. �BDMS�'' 1UN 0 51019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® MAY 0 1 9ma 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0' Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change'•'Pk` JLgk Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other IA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: 1 Exploratory ❑ Development D 5. Permit to Drill Number: 196-083 ' 3_ Address: P.O. Box 196612 Anchorage, AK 9951841612 Stretigrephic ❑ Service ❑ 6. API Number: 50-029-22676-00-00 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No El PBU 1543 9. Property Designation (Lease Number): 10. Field/Pools: 1 ADL 028306 PRUDHOE BAY. PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth lVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MO): Junk (MD): 11043 8847 6983 1 6795 I 8983.10225 10840,10949 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 36-116 36-115 1490 470 Surface 3518 9-5/8" 35-3553 35-3541 6870 4760 Intermediate 1 8574 1 7" 33-8605 33-8299 7240 5410 Production Liner 2591 4-1/2" 8452- 11043 8156-8847 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9672-10940 8851-8841 4-1/2" 12.6# 13Cr80 / L-80 31 -8453 Packers and SSSV Type: 4-12^ Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 8333/8045 41/2" Baker S-3 Packer 8418 / 8124 12. Attachments: Proposal Summary ® Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic ❑ Development ® Service ❑ 14. Estimated Date for Commencing Operations: June 1, 2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel, Joshua be deviated from without prior written approval. Contact Email: Joshua.Tempelabp.com Authorized Name: Tempel, Joshua Contact Phone: 170:1 - 89 1 -5930 Authorized Title: Well Integrity Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ^ I i✓` G G 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 15r- Location Clearance ❑ Other: Aacr-- R8'-itE 6F sL'' T g��6Q-�0� ? RPPROVE) IO - LESS Tt ),J 1&Z6T%10 MOOSE 06GCNAS'h1-eP 1L>4tviefoL Ca E 4�fi¢.?Gb�Ll Uo4diKeABOJLTCEM6gM SE'rSVRrfBc�ati�,Sb10L� Post Initial Injection MIT Req'd? Yes ❑ No If ''ll LLL�/ Spacing Exception Required? Yes ❑ No W Subsequent Form Required: X --4 / !!'' APPROVED BYTHE / / Approved by. COMMISSIONER COMMISSION Date: (� Form 10-403 Revised 04/2017 ORIGINAL RIMMS.,�-IJUN052019 M(1LRQ4"Ilt Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate °e aW -5/3 /1 q Lip 0 15-43 IA Cement Sundry AN #: 50-029-22676-00 Expected Start Date: 7/1/19 Intervention Engineer Josh Tempel (907) 891-5930 Production Engineer Paulina Meixueiro (907) 546-5971 �Maxl a�-3uNE-/i Well: 15-43 History 15-43 is a 4-1/2" monobore drilled in 1996 and completed in Z1A. The well had a tubing swap (13Cr80) in 2004. In December 2008, a SC leak was discovered and the well was shut in. The SC leak was repaired with WellLock in 2015 and brought online until 7/29/2017 when it was shut in due to high gas cut. In June 2018, a profile modification was performed and on 9/17/18 the well was brought online. The well was shut in again on 9/21/18 due to a suspected cretaceous leak based on a substantial unexpected increase in water cut. After setting a WRP at 6983' MD, the PC leak was confirmed at 5380' MD based off an LDL (10/23/2018) with a 2bpm/-630psi bullhead rate down the IA, additionally, the LDL confirmed a tubing leak in GLM #3 at 5334' MD. The leak rate while pumping down the tubing was 2bpm/-630psi which is similar to the IA leak rate. Current Status Well is shut in with a WRP set at 6983' MD. Plug was set 10/22/18. Objective The objective of this job is to repair the cretaceous leak and tubing leak by squeezing cement into the IA. CO 736 Information Sheet BP requests a waiver from CO 736 requirements for this well as per below: Analysis: By repairing this well with an IA cement squeeze an estimated 150 mbo will be produced over the next several years. Without an IA remedial squeeze, the well has no utility in the foreseeable future. Rig Workover Alternative Considered: A Rig Workover option for fixing this well is available, and complies with CO 736; however, a Rig Workover option is not economic because of the high cost. Based on the above production estimate, a non -rig IA squeeze is currently the only economic option to fix this well. If this well is not remediated in a way justified by production then it will become a P&A candidate. CO736 Cement Height Information The proposed TOC in the IA (4334' MD / -4248' tvdss) is -351' MD above the top of the UG4 marker (4685' MD / - 4590' tvdss) and 775' tvd deeper than the surface casing shoe (3553' MD / -3473 tvdss). CO 736 Waiver Request: CO 736 requires TOC to be max 1500' tvd below the surface casing shoe. Placing TOC within this requirement would require TOC to be 288' and above the PC leak and 242' and above the tubing leak. Based on prior jobs, it is generally believed a minimum of 500'md of cement is needed to reliably repair a small leak in a relatively vertical well. Given past cement height requirements and 15-43's relatively large PC leak (LLR of 2bpm/-630psi), it is likely that an IA squeeze within CO 736 requirements would fail. This sundry requests a TOC -1000'md above the Tubing leak (1046'md above PC leak) with the expectation that, after losses to formation are accounted for, final TOC will be at least 500'md above the Tubing leak (546' and above the PC leak). Comparison of 15-431A Squeeze to Similar Wells Post CO 736 Implementation Currently, as shown below, 2 wells with production casing leaks and a well with tubing leaks have been repaired since the implementation of CO 736. Other wells relating to CO 736, and not shown below, include repairs for packer leaks and cement placed in preparation to perforate above a mechanical packer. Cement above leak 817' 530' 1000' Planned 1550' 03-25 pt 18.16 pt 15.43 pt and ffiQ E-31 tbg Job Sequence 1 S Pull WRP. Set and tag CBP. 2 F Obtain LLRs on Tubing and IA 3 E Punch above Top of Fill and set Retainer 4 C Circulate IA. Cement IA through Retainer 5 D MIT -IA prior to fill cleanout 6 S Replace DGLV at ST#4 (3212') with a LGLV 7 T Rig up in preparation for CT fill cleanout. High gas well. 8 C Mill out retainer and CBP. Coordinate with Well Testers and perform fill cleanout. 9 S Set TTP. MIT -T to 2500psi. Pull TTP. 10 E Run SCMT 11 WIE Add Biennial MIT -Ts and MIT-IAs to AKIMS Post -Job Evaluation • CMIT TxlA and MITT • SCMT to locate TOC Long -Tenn Integrity Monitoring • Record WHPs daily. • Biennial CMIT-TxIA and MIT -T. Key Risks, Critical Issues Mitigation Plan Cement locks up and can not be pumped If at some point the cement locks up and cannot be pumped into the IA, then cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1. Reverse the remaining cement out of the tubing. Freezable fluids in the IA Carefully consider the fluid pumping sequence. Fluid above the cement will remain in the IA, it is important to keep freezable fluid below—2500tvd. Bleeding cement into the tubing The tubing has a leak at GLM#3. Allow tubing pressure to equalize with the IA after unstinging from the cement and don't bleed tubing down below the equalization pressure. DPZ Crossflow: Cretaceous to Ivishak crossflow has both regulatory Pull the WRP and set the CBP in the same job and reservoir impacts. to minimize the amount of time DPZs are open to each other. Cement Design and Volumes Cement Type/weight: SLB Cemfit-Heal. Batch mixed. Field blend to be =lab ppg +/- 0.1 ppg Contingency Cement: 5bbls additional (69bbl total) Disposal Plan: Cleanup to truck with contam pill Expected Pump Rate: 2.5bpm Static Setting Temp 141 ° F at base of cement column (6953' MD) Fluid Loss: 40-200cc(20-100cc/30 min) Compressive Strength: 2000 psi in 36 hrs. Thickening Time: Minimum 5 hours Location Volume IA cement volume 7669' MD to 4380' MD 62 bbls —70' between CBP and Retainer 1 bbls 1 bbl of excess cement 1 bbls Total Cement to Pump 64 bbis Contingent Excess in Callout 5bbis Procedural Steps (1) Slickline: Pull DGLV, Pull WRP, Set CBP Note 1: Setting the CBP in this step is to minimize the amount of time the cretaceous is open to the formation. Please do not separate pulling WRP and setting the CBP into 2 separate jobs. (See Risks) a. Drift. b. Pull WRP from 6983' MD c. Drift and tag top of fill. Top of fill was previously tagged at 7,769' SLM during the same job the WRP was set. d. Set CBP (HES Obsidian Bridge Plug) 3040' above top of fill. e. Tag CBP after setting to verify it will stay in place. Note: Tubing will not pressure test, leak at GLM #3 takes 2bpm at—630psi. (2) Fullbore: a. Obtain LLR by pumping down the IA: LLR is expected to be 2bpm at —630psi. Verify fullbore LLR from prior step has not increased since performing the LDL in 10/2018. If rate has changed discuss the situation with engineer prior to proceeding. A higher LLR rate may indicate the CBP is not holding. (3) Eline a. Tag CBP and referencing the 4-1/2" tubing tally (3/15/04), record the CBP depth in AWGRS. b. Punch tubing w/ 5' of punches, positioning mid punch across the first available collar above the CBP. (If 15' available collar is within 15' of the CBP then move up to the next collar). c. RIH and set HES Fasdrill SVB Squeeze Packer (composite cement retainer) in the middle (+/- 5') of the first full tubing joint above the top punch. Note 2: Please write a clear and detailed AWGRS entry on this job so that coil will have a good reference to work from when stinging into the cement retainer. 3 (4) Coiled Tubing Job Prep Please contact engineer and discuss plan prior to performing work. Coordinate Red Dye Plan a needle valve location downstream of return MM to offtake samples for KCI with red dye returns. 40bbl Open Top Note: Hole in tubing at GLM #3 (5,334' MD) and in the Production Casing at —5,380' MD, cement stringers are expected in the tubing after the job is complete. CT Rigup a. Rig up a micromotion with bypass to monitor returns from the IA, this will help determine if the PC leak is taking cement and it will help in placing the cement top per plan. Sting Into Retainer b. RIH with stinger assembly for HES Fasdrill SVB Squeeze Packer and sting into the retainer rolling pumps at 0.25bpm and watching pressure response to verify coil is stung in. c. Pump a Coil + IA volume of KCI w/ red dye taking samples from the needle valve installed downstream of the return MM. If stinger is not fully in the retainer then red dye will be seen early. Circulate IA Note: This step is to help ensure the IA is clear of fill. Crossflow from the PC leak deposited significant fill in the tubing. Fullbore has circulated the IA prior to this step; however, there may still be FII in the IA. d. Pump the below fluid schedule taking returns from IA to an open top tank. Target choke for 1 to 1 returns if PC leak rate allows Fluid: Diesel Target Rate: 5bpm Target Returns Volume: Minimum of 1.5x IA Volume (-215bbis) + CT volume, continue pumping until pressures are stable. Max Pressure at Stinger: 2500psi (unlikely to achieve considering size of cretaceous leak). 6 Cement IA e. Pump the below fluid schedule taking returns from IA to a 40bbl open top tank. Target pressures and rates to achieve 1 to 1 returns if PC leak rate allows. Some losses to PC leak may occur, please note losses in AWGRS. I. 20bbl inhibited surfactant wash (inhibitor in 160°F FW + 2gpt of F103 and 2 gpt of U067) ii. 64bbl cement (per above design): (Unsting from retainer with lbbl remaining in coil and est. -1bbl between retainer and CBP) iii. 5bbl FW spacer iv. Displace with Diesel: Displacement Volume= (CT Volume - 1 bbl cement - FW Spacer) Note: 62bbls of cement in annulus places TOC at -4334' MD and 20bbls of FW puts top of FW at -3300' MD / 3289'tvd. f. Pullout of retainer with 1bbl of cement remaining in coil. g. After unstinging from the retainer lay in remaining 1 bbl of cement 1:1. Please note the T and IA pressure in AWGRS immediately before unstinging. Keep in mind the tubing has a leak at GLM #3, therefor please do not bleed the tubing as this may cause cement to flow in from the IA. h. POOH. i. Rig down and move off well. (5) DHD a. Wait on cement at least 3 days from cement in place. b. MIT -IA to 2500psi. Contact Engineer if test does not pass. (6) Slickline a. Verify MIT -IA passed prior to performing work. b. Drift. Set Catcher. (WSL discretion on how to set catcher.) Please do not attempt job without a catcher as fishing a GLV may be very difficult in this situation. The well may have cement stringers below -5300' MD, and the drift/catcher may not make it down to the retainer. A slipstop catcher may be a good primary plan. c. Pull ST #4 DGLV (3212') and replace with LGLV/SO based of GL engineer recommendation. Note: This step is so that gas lift can be used to assist the fill cleanout. GL Engineer modelling estimates top valve will provide a 612psi drawdown. (7) Test Separator a. Coordinate job timing with CT. Discuss job prep with CT and rig up to perform a fill cleanout. b. WSL please coordinate with Coil WSL to collect fill sample from top perf depth. Plan to have lab perform rush testing. Plan to re -pert well will be partially based on these samples. The perfjob is currently a contingent step on the fill cleanout. PEs are looking for Barium content of fill. Fi (8) Coil Job Prep Rig up gaslift from a neighboring well to assist in cleanout. Gas lift from GLM #4 is estimated to provide a 612psi drawdown. Have a contingency plan in place to use nitrogen for the fill cleanout if gas lift and formation gas cannot provide enough lift. Initial formation gas quantities are unclear. a. Rig up micromotion with bypass. b. MU 3.80" OD junk mill to milling assembly. RIH and tag TOC c. Mill through cement retainer and CBP. d. Mill/push CBP/retainer remnants near top of fill. (Top of fill at —7,769' SLM based on SL tag 10-22-18) e. Coordinate with Well Testers to begin fill cleanout. Note: Program is written to use motor and mill for fill cleanout; however, WSL discretion on alternative assembly to attempt to venturi/fish the CBP components or WSL discretion on alternative fill cleanout assembly once the CBP components are milled up or removed. Cleanout Note 1: Consider mill size vs. coil size and take small bites. Consider coming out for a slim nozzle assembly once CBP components seem to not be causing motor work. Note 2: This well made significant gas prior to cretaceous water choking it off and there is potential for gas to be beneath a sand bridge, please plan bites accordingly. f. Line up returns to the test separator. Plan to eventually see significant amounts of formation gas (see below). Estimate of fill quantity: 38bbls (4-1/2" monobore: 0.0152bpf) Top of fill = 7,769'. CIBP = 10,225 Formation Gas: Estimated at —55MCF/day when increased watercut shut off production from the liner. It is unknown what the gas rate will initially be as fill is cleaned out, or if significant gas volumes will be below a bridge. g. RIH and clean out per the RP. i. Coordinate with well testers and take sample of fill that came from —9675' MD (A few feet past the top pert depth, if fill has a high Barium content then plan to perform contingent perforating steps.) ***Please coordinate with lab ahead of time to rush the processing of the samples so that the perforating can be done in the same coil rigup if needed.*** h. Attempt to flow well with GL. If well does not flow then plan to perform contingent perforating steps. Contingent Perforating a. If perforations are required, RESDEV will provide a perf sheet in a timely manner. Please have a plan in place to make 6 x 20' pert runs with 2-3/4" Millennium Guns, 6 SPF, 60° phasing. Note: The decision to perforate or not to perforate is contingent upon both the sample results and the well's ability to flow after the fill cleanout. There is a high probability cretaceous water containing barium dump flooded into the Ivishak and formed barium scale. Barium scale cannot be chemically removed and will require reperforations. (9) Slickline a. Drift with 3.80" drift. b. Set tubing tail plug in X -nipple at 8350' MD (verify good set) c. MIT -T to 2500psi d. Pull TTP (10) Eline: a. Run SCMT to identify top of cement per AOGCC requirement in CO736. Note: Job may be run on SL memory to accommodate equipment needs, but please send engineer a note if this change is made. (11) Well Integrity Engineer a. Add Biennial (every 2 years) MIT -Ts and MIT-IAs to AKIMS. b. Josh Tempel will review SCMT with AOGCC and obtain approval to make well Operable. Current Wellbore: TREE= aw WHIIEAD- cm ACItYITM= BAKH(1: 0103. HEV = 67.8' 9F. HPI = 9572-9846 KOP= 4349 M1a Angle - 95'a 9939' Oabm NO- WA &"n1VD= SOOT 9-SM'CSC, 470. 1461)91.8681' - Minimum ID -- 3.813" 0 2183' 4.112" HES X NIPPLE I 12- TOG, 12.69, 13CRAO VAM IOP. 152 bpf. D = 3 958' 14 112' IKG. 12 60, 180, 01 S: bpf, 13 = 3 9h9' 276' 8370' PEWORATICNSLKMRY REFLOG. BFPON05M701) AHiFAI1(WF`H* 9'T689617 NOW. Pifer b Aaductw M for Ki "cal peri ddb WE SFIF I MEWAL I O rkg SHOT SO2 2.V4' 4 9572-9846 O 05124196 KnG-7 23N' 4 9576 - 9974 O 0524!98 5334 2314' 4 IDD03 - 10206 O 0524196 0 2314" 4 10296 - 10322 C 0524106 IWG 2 2-314" 4 10422 - I061M C 054456 8236 2314' 4 10755- 10782 G OW4116 0 7.314' 4 10962. 10MG G 0 r'4RJ6 15-43 Current SAFE tY NO TES: W ELL ANGLE a 70" @ 9295'. 15-43 MAX OLS: 32.2'@ 9876. CHROME TBG 14 12-H5 X NP. D=3.813' 1 GASLFTMANORELS Sr MJ TVD DEV TYPE VLV LATCHFORT DATE 1 3217 3701 G KnG-7 my Px0 - 0926H8 3 5334 5285 I 22 KBG-2 OdY 6K 0 0128!18 2 W53 6761 21 IWG 2 CNN SK 0 0WlGfD4 1 8236 7957 22 KBG 2 OM BK 0 0311v 4 n ra 8326'__j 1TXd IfrbKNS3WKD=38f5- H9 X NP, D=361' ELMD TT NOT LOGGW 14 1rz WPI CRP((XF15mo—) I IO' CTYI {RIl wit 1016$ - ----i-gym I I -1� uQ #44X0401- PAY TINT WELL 1543 960 FEFWT fb,1003 AR W. 50-0232267600 SEC 22, T11 K R14E 574' F L 8 100' FWL DATE mvilyl TXIWNIS I I]AIF lwvlivl 00M TMS KOM 614 0FOG 110HLOMALCOMPL 0420.115 oSIA60 Comm=mc OWN04 M)MIrAl FM 06//8116 101-1441) MILL CORC13P, SET CIDPS FSH 0322104 JLAKAK GLV 00 07117116 LTVJMD GLV 00 (0711010) 1210409 V SET FX F3LUS ( ) 10f01fi0 JM3dJ GLV 010 (09W18) 08107/HO I�INIM 13V TAT ((W31ry0) 10r1811R,IM(VJM %I WF0Wf8(/02N78) BID rxpbrMiaa (Alaska) OV010 GTWP PILL PX R W 100!05110) - uQ 6EY.57R : = O 4 4318nya - I 95• a owvw- 4 NMA TVD=- --amass a 919'COO. 470,M60.O=999P 1553• N9nimum 10 m 3,813" ! 2183' 4-112" HES X NIPPLE 0152 Spf, O.3 958• IU- 6 2/6' FFR40 MT0NSLR MRV IU LOG 5WON05007NO ANOL.E A7 IOPRW 92.09677 4 9878-9974 O 4 10003 19298 0 4 10298 10322 C 4 10422 IONS C 4 IOJSS 10782 C 4 10882 10940 C 15-43 Proposed M�=a," ;°'sa;APPOLE .',w70;;; z.`' OAS Lsr AADS 9T 1� rvo wv� Trl-vLv uTw IVF 1 13212 132011 5 NBG2 DM BK 0 3 5334 5258 22 KM 0141' BK 0 2 1853 6767 21 KBG 2 OETI BK 0 1 8238 7487 22 KM2 L75H 8K 0 f� LSAo n Nrn L000R) q'INC 1l aa,i 0a, 01 SJ CPLD=]B5a' MIT" WAY IM WELL. 1547 P624n w 1960w All 1b 50 019 176 16 00 SK: zJ, ulN Hut, SI4'iH 81061w, DATE FWV BY COMEW5 WE my BY OOA4ENI5 ari-9 DH ONONOIBZOWALCOYPL OU21YIS 087J/D COIWAE1®TBG mom im9oki FM 0&18118 JCF/JC LLL CBRCOP. S& CBPS FISH 0302)04 AJKAK Q V 00 O7H7H6 LOIJM) OI V 99 O/64/18 1 ( 1 17 l 06O 60 MBMPX GLV C/O (05'3VIO) 10'29118 Ard SE7MFUVVW(ta2N181 UP Rplw&4 JALoaaa) _ O9Ga10 M4.LPXFLUG(08ANIO) TUBING SUMMARY RIG _ WELL # TUBING TBG WT. 200 JTS ON RACK 8390.35 FT ON RACK ITEM Description Includes: SIZE, TYPE, CONNECTION (JTS 04l Nabors 2ES 16.43 RWO 4.5" 12.60 JTS RAN FT RAN Date 3/1512004 13 Chrome Vern Top 26.00 2ES KB TO BF ITEM ID OD LENGTH TOP BOTTOM 4.5" Unique Machine Overshot 6' over tubingstub 3.910 5.990 4.02 8369.98 8374.00 4.5" 12.6#, 13CRBO TC-11 in X Vam To box 3.958 5.000 9.87 8360.11 8369.98 4.5" 12.6#, 13CR80 TC-11 box X Vam To In 3.958 4.950 9.10 8351.01 8360.11 'X' Nipple HES 9-Cr 3.813" bora w/ RHC-M PI 3.813 5.030 1.21 8349.80 8351.01 4.5" 12.60 13CROO VAM TOP BOX X TC-11 PIN 3.958 5.000 9.86 8339.94 8349.80 4.5" 12.6# 13CR80 VAM ACE BOX X VAM TOP PIN 4A00 4.980 9.90 8330.04 8339.94 Baker "S-3" 7" x 4 112" Packer VAM ACE B X P 3.875 5.968 3.72 8326.32 8330.04 4.5" 12.6# 13CR80 VAM TOP BOX X VAM ACE PIN 3.920 4.960 9.76 8316.56 8326.32 4.5" 12.6# 13CROO TC-11 BOX X VAM TOP PIN 3.958 4.9501 9.15 6307.41 6316.56 'X' Nipple. HES 9-Cr 3.813 Pkg. Bore 3.813 5.030 1.24 8306.17 8307.41 4.5" 12.6# 13CR80 VAM TOP BOX X TC-1 i PIN 3.958 5.000 9.85 6296.32 8306.17 1 JT Jt #114.5- 13CR80 12.60 VAM TOP Tbg 3.958 4.961 41.96 8254.36 8296.32 4.5" 12.6# 13CR80 TC-11 BOX X VAM TOP PIN 3.958 4.950 9.22 8245.14 8254.36 GLM 01 4.5"x1" KBG-2 9cr, DV wl SK latch 1938 5.984 6.95 8238.19 8245.14 4.5" 12.6# 13CR80 VAM TOP BOX X TC-11 PIN 3.958 5.000 9.84 8228.35 6238.19 30 JTS Jts 02431 4.5" 13CRBO 12.6# VAM TOP Tbg 1958 4.961 1259.11 6969.24 8228.35 4.5' 12.60 13CR80 TC-11 BOX X VAM TOP PIN 3.958 4.950 9.21 6960.03 6969.24 GLM 02 4.5"x1" KBG-2 9cr, DV wl BK latch 3-938 5.9841 6.95 6953.08 6960.03 4.5" 12.60 13CRSD VAM TOP BOX X TC-11 PIN 3.958 5.000 9.88 6943.20 6953.08 38 JTS jJt3 032469 4.5" 13CR80 12.60 YAM TOP Tbg 3.958 4.961 1592.97 5350.23 6943.20 4.5" 12.60 13CRBD TC-11 BOX X VAM TOP PIN 3.958 4.950 9.65 5340.58 5350.23 GLM #3 4.5"x1" KBG-2 ger, DV wl BK latch 3.938 5.984 6.95 5333.63 5340.58 4.5" 12.6# 13CRBO VAM TOP BOX X TC-11 PIN 3.958 5.000 9.85 5323.78 5333.63 50 JTS Jts #70-0119 4.5" 13CRBD 12.6# VAM TOP Tbg 3.958 4.961 2095.59 3228.19 5323.78 4.5" 12.6# 13CROO TC-11 BOX X VAM TOP PIN 3.958 4.950 9.68 3218.51 3228.19 GLM #d 4.5"xt" KBG-2 ger, DCK SV wl BEK latch 3.938 5.984 6.95 3211.56 3218.51 4.5" 12.6# 13CRBO VAM TOP BOX X TC-11 PIN 3.958 5.0001 9.75 3201.81 3211.56 24 JTS Jts #1204143 4.5" 13CRBO 12.6# VAM TOP Tbg 3.958 4.961 1007.91 2193.90 3201.81 4.5" 12.60 13CR80 TC-11 BOX X VAM TOP PIN 3.958 4.950 9.74 2184.16 2193.90 WNIpple. HES 9-Cr 3.813 Pkg. Bore 3.813 5.030 1.24 2182.92 2184.16 4.5" 12.6# 13CROO VAM TOP BOX X TC-11 PIN 3.958 5.000 9.86 2173.06 2182.92 50 JTS Jts #1444193 4.5" 13CROO 12.6# VAM TOP Thil 3.958 4.961 2099.05 74.01 2173.06 4.5" Space Out Pups 3.958 4.961 2.07 71.94 74.01 1 JT Jt #194 4.5" 13CRBO 12.60 VAM TOP Tbg 3.958 4.961 41.91 30.03 71.94 4-5" 13CR XO VAM ACE box X VAM TOP pin 3.958 4.961 3.17 26.86 30.03 4.5" 13CR XO VAM ACE pin X NSCT pin 3.9681 4.5001 2.34 24.52 26.86 FMC Tbg Hn r 4.112" NSCT Lifting Threads 3.958 13.687 .72 23.80 24.52 Nabors Rig 2ES RT To Lock Down Studs 23.80 23.80 PUW - 127k; SOW - 11 Ok Pullin Tools: Balll Rod = 2" RB RHC-M Plug =4.5 GS GLM 1 Thru 3 wl BK Latch = 1 114" JDC GLM 4 wl BEK Latch = 11/4" JDC RHC-M Plu Install In Lower "X" Nipple 11718" Ball/Rod Assy In RHC-M Plug -1 318" neck jAssembly below packer Is Baker-Locked 12 15-43 P&A .es•csg,l:r.x10,o=est• asz• -� A![iEATn Rw-- sto9 IUeftlabRad�orOB WrhokmApeddib !6 EFF] WaIRVAL CO.BW 3a: am 234 4 967.2 -SM O 0NAM zw 4 sm-saw O 097493 2-31 4 :0003-10®8 O 092193 2- 3f 4 7OW-UM G 0924M air 1 10VJ 10M c 0921AB 231` :0795 :O7S G 0WW" 2 W 4 11062- 70910 c 0924M 15-43 � 1-WIBRNR ffaix-m NY LM WELL 1547 f6 Nm 199003O AHMr 9002W.7M7&W 10`Fpbn- lAb." 13 �m �LLa..'Js:L.i' 0 .®' .... I - A � Iw0 °0"' rW-,�M ..�° 0=4:11 M �- ffaix-m NY LM WELL 1547 f6 Nm 199003O AHMr 9002W.7M7&W 10`Fpbn- lAb." 13 15-43 IA Cement Sundry API #: 50-029-22676-00 Expected Start Date: 6/1/19 Intervention Engineer Josh Tempel (907) 891-5930 Production Engineer Pauline Meixueiro (907) 546-5971 Well: 15-43 V -J 12J b�"X' e, Y" b History 15-43 is a 4-1/2" monobore drilled in 1996 and c/.The 1A. The well had a tubing swap (13Cr80) in 2004. In December 2008, a SC leak was discovered and thut in. The SC leak was repaired with Welll-ock in 2015 and brought online until 7/29/2017 when it was shigh gas cut. In June 2018, a profile modification was performed and on 9/17/18 the well was brought ell was shut in again on 9/21/18 due to a suspected (cretaceous leak based on a substantial unexpecte water cut. After setting a WRP at 6983' MD, the PC leak was confirmed at 5360' MD based off an L (10/23/2018) with additionally, the LDL confirmed a tubing leak irybLM was 2bpm/-630psi which is similar to the IA leA rate. #3 at 5334' MD. a 2bpm/-630psi bullhead rate down the IA, The leak rate while pumping down the tubing Current Status Well is shut in with a WRP set /ean Plug was set 10/22/18. Objective The objective of this job is to reaceous leak and tubing leak by squeezing cement into the IA. By repairing this well with an IA cement squmated 140 mbo will be produced over the next several years. Without an IA remedial squeeze, the well h the foreseeable future. The proposed TOC in the IAj(3800' MD / 3719' tvdss) is -885' MD shallower than the top of the UG4 marker (4685' MD /4590' tvdss) and -246/TVD deeper than the surface casing shoe (3553' MD / 3473 tvdss). Job Seauence 1 S Pull 6GLV St#2. Pull WRP. Set and tag CBP. 2 F Obtain LLRs on Tubing and IA 3 E Punch above Top of Fill and set Retainer 4 C Circulate IA. Cement IA through Retainer 5 D MIT -(A prior to fill cleanout 6 S Replace DGLV at ST#4 (3212') with a LGLV 7 T Rig up in preparation for CT fill cleanout. High gas well. 8 C Mill out retainer and CBP. Coordinate with Well Testers and perform fill cleanout. 9 S Set TTP. MIT -T to 2500psi. Pull TTP. 10 E Run SCMT 11 WIE Add Biennial MIT -Ts and MIT-lAs to AKIMS Post -Job Evaluation • CMIT TxIA and MITT • SCMT to locate TOC Long -Term Integrity Monitoring • Record WHPs daily. • Biennial CMIT-TxIA and MIT -T. eb n d00 b3 Key Risks, Critical Issues Mitigation Plan Cement locks up and can not be pumped If at some point the cement locks up and Disposal Plan: cannot be pumped into the IA, then cut Expected Pump Rate: cement at surface, pull out of the retainer and Static Setting Temp lay cement in the tubing 1:1. Reverse the Fluid Loss: Compressive Strength: Thickening Time: remaining cement out of the tubing. Freezable fluids in the IA Carefully consider the fluid pumping sequence. Fluid above the cement will remain in the IA, it is important to keep freezable fluid below—2500tvd. Bleeding cement into the tubing The tubing has a leak at GLM#3. Allow tubing pressure to equalize with the IA after unstinging from the cement and don't bleed tubing down below the equalization pressure. DPZ Crossflow: Cretaceous to Ivishakcro flow has both regulatory Pull the WRP and set the CBP in the same job and reservoir impacts. to minimize the amount of time DPZs are open to each other. Cement Design and Volumes Cement Typetweight: SL Cemfit-Heal. Batch mixed. Field blend to be =lab ppg +/- 0.1 ppg Contingency Cement: 5 Is additional (81 bbl total) Disposal Plan: leanup to truck with contam pill Expected Pump Rate: P.5bpm Static Setting Temp 141 ° F at base of cement column (6953' MD) Fluid Loss: Compressive Strength: Thickening Time: 40-200cc(20-100cc/30 min) 2000 psi in 36 hrs. Minimum 5 hours Location Volume IA cement volume 6953' MD to 3800' MD 74 bbls —70' between CBP and Retainer 1 bbls 1 bbl of excess cement 1 bbls Total Cement to Pump 76 bbis Contingent Excess in Callout 5bbls Procedural Steps (1) Slickline: Pull DGLV, Pull WRP, Set CBP Note 1: Setting the CBP in this step is to minimize the amount of time the cretaceous is open_4o the formation. Please do not separate pulling WRP and setting the CBP into 2 separate jobs. (See Risks) a. Drift. b. Pull WRP from 6983' MD c. Drift and tag top of fill. Top of fill was previously tagged at 7,769' SLM d. Set CBP (HES Obsidian Bridge Plug) 30-40' above top of fill. e. Tag CBP after setting to verify it will stay in place. Note: Tubing w)N 2bpm at-630psi. (2) Fullbore: ���' C)) pe�SG V'Ae '571 o the same job the WRP was set. not pressure test, leak at GLM #3 takes a. Obtain LLR by pumping down the IA: LLR is expected to 2bpm at-630psi. Verify Fullbore LLR from prior step has not increasedsi a performing the LDL in 10/2018. If rate has changed discuss the situation with engineer prior to proceedin . A higher LLR rate may indicate the CBP is not holding. (3) Eline a. Tag CBP and referencing the 4-1/2" tubing tp(lly (3/15/04), record the CBP depth in AWGRS. b. Punch tubing w/ 5' of punches, positionirA mid punch across the first available collar above the CBP. (If 1s' available collar is within 15' of the CBP an move up to the next collar). c. RIH and set HES Fasdrill SVB Squee a Packer (composite cement retainer) in the middle (+/- 5') of the first full tubing joint above the top Note 2: Please write a clear and detfiiled AWGRS entry on this job so that coil will have a good reference to work from when stinging into the cemi 3 (4) Coiled Tubing '0 d f 9 Job Prep {s io��M� Please contact engineer and discuss plan prior to performing work. d 2J �U Coordinate Red Dye '-s-,J Plan a needle valve location downstream of return MM to offtake sample o KCI with red dye returns. 40bbl Open Top Note: Hole in tubing at GLM #3 (5,334' MD) and in the Production Ca ng at -5,380' MD, cement stringers are expected in the tubing after the job is complete. CT Rigup a. Rig up a micromotion with bypass to monitor returns fr m the IA, this will help determine if the PC leak is taking cement and it will help in placing the cement topper plan. Sting Into Retainer b. RIH with stinger assembly for HES Fasdrill SVS Squeeze Packer and sting into the retainer rolling pumps at 0.25bpm and watching pressure response toperify coil is stung in. c. Pump a Coil + IA volume of KCI w/ red dy taking samples from the needle valve installed downstream of the return MM. If stinger is not fully in the ret ner then red dye will be seen early. Circulate IA Note: This step is to help ensure the IA is Fullbore has circulated the IA prior to this d. Pump the below fluid leak rate allows. of fill. Crossflow from the PC leak deposited significant fill in the tubing. however, there may still be fill in the IA. returns from IA to an open top tank. Target choke for 1 to 1 returns if PC Fluid: Diesel Target Rate: 5bpm Target Returns Volume: Minimum of 1.5x IA Volume (-217bbls) + CT volume, continue pumping until pressures are stable. Max Pressure at Sting r: 2500psi (unlikely to achieve considering size of cretaceous leak). 4 Cement IA e. Pump the below fluid schedule taking returns from IA to a 40bbl open top tank. Target pressures and rates to achieve 1 to 1 returns if PC leak rate allows. Some losses to PC leak may occur, please note losses in AWGRS. L 20bbl inhibited surfactant wash (inhibitor in 160°F FW + 2gpt of F103 and 2 gpt of U067) ii. 76bbl cement (per above design): (Unsting from retainer with 1 bbl remaining in coil anddibl betwe4o retainer and CBP) ' In #, C uN 15 e VA £ iii. 5bbl FW spacer S ll(n � N �j� iv. Displace with Diesel: Displacement Volume= (CT Volume — 1 bbl cement—,F)1V/Spacelr) lf Note: 74bbls of cement in annulus places TOC at —3800'/20bblsuts top of FW at 2724' MD2715'tvd. f. Pull out of retainer with 1 bbl of cement remaining in coil. g. After unstinging from the retainer lay in remaining 1 bbl onote the T and IA pressure in AWGRS immediately before unstinging. Keep in mind theLM #3, therefor please do not bleed the tubing as this may cause cement to flow in frgrfi the IA. h. POOH. i. Rig down and move off well. (5) DHD a. Wait on cement at least 3 days from cem nt in place. b. MIT -IA to 2500psi. Contact Engineer if t st does not pass. (6) Slickline a. Verify MIT -IA passed prior to pe orming work. b. Drift. Set Catcher. (WSL discr ion on how to set catcher.) Please do not attempt job w' hout a catcher as fishing a GLV may be very difficult in this situation. The well may have cement stringer below ^5300' MD, and the drift/catcher may not make it down to the retainer. A slipstop catcher may be a ood primary plan. c. Pull ST #4 DGLV (, ')and replace with LGLV/SO based of GL engineer recommendation. Note: This step is so hat gas lift can be used to assist the fill cleanout. GL Engineer modelling estimates top valve will provide a (,/place (7) Test Separator I a. Coordinate job timing with CT. Discuss job prep with CT and rig up to perform a fill cleanout. b. WSL please coordinate with Coil WSL to collect fill sample from top pert depth. Plan to have lab perform rush testing. Plan to re -pert well will be partially based on these samples. The pert job is currently a contingent step on the fill cleanout. PEs are looking for Barium content of fill. 5 (8) Coil Job Prep Rig up gaslift from a neighboring well to assist in cleanout. Gas lift from GLM #4 is estimated to provide a 612psi drawdown. Have a contingency plan in place to use nitrogen for the fill cleanout if gas lift and formation g s c��/n not provide enough lift. Initial formation gas quantities are unclear. 1* iY a. Rig up micromotion with bypass. „1, C b. MU 3.80" OD junk mill to milling assembly. RIH and tag TOC I_ tttJJJ«< 3 c. Mill through cement retainer and CBP. P d. Mill/push CBP/retainer remnants near top of fill. (Top of fill at -7 9' SLM based on SL tag 10-22-18) e. Coordinate with Well Testers to begin fill cleanout. Note: Program is written to use motor and mill for fill cleano ; however, WSL discretion on alternative assembly to attempt to venturi/fish the CBP components or WSL scretion on alternative fill cleanout assembly once the CBP components are milled up or removed. Cleanout Note 1: Consider mill size vs. coil size and t e small bites. Consider coming out for a slim nozzle assembly once CBP components seem to not be causing otor work. Note 2: This well made significant ga prior to cretaceous water choking it off and there is potential for gas to be beneath a sand bridge, please plan ites accordingly. f. Line up returns to the tests parator. Plan to eventually see significant amounts of formation gas (see below) Estimate of fill quantity: 3bbls (4-1/2" monobore: 0.0152bpf) Top of fill = 7,769'. CIBP = 10,225 Formation Gas: Estima d at -55MCF/day when increased watercut shut off production from the liner. It is unknown what the gas r9fte will initially be as fill is cleaned out, or if significant gas volumes will be below a bridge. g. RIH and clean ouVper the RP. I. Coordinate th well testers and take sample of fill that came from -9675' MD (A few feet past the top pert depth, if fill as a high Barium content then plan to perform contingent perforating steps.) ***Please ordinate with lab ahead of time to rush the processing of the samples so that the perforating can bed a in the same coil rigup if needed.*** h. Attempt to fl well with GL. If well does not flow then plan to perform contingent perforating steps. Contingent Perfo ting a. If perforations are required, RESDEV will provide a perf sheet in a timely manner. Please have a plan in place to make 6 x 20' pert runs with 2-3/4" Millennium Guns, 6 SPF, 600 phasing. Note: The decision to perforate or not to perforate is contingent upon both the sample results and the well's ability to flow after the fill cleanout. There is a high probability cretaceous water containing barium dump flooded into the Ivishak and formed barium scale. Barium scale cannot be chemically removed and will require reperforations. (9) Slickline a. Drift with 3.80" drift. b. Set tubing tail plug in X -nipple at 8350' MD (verify good set) c. MIT -T to 2500psi d. Pull TTP (10) Eline: a. Run SCMT to identify top of cement per AOGCC requirement Note: Job may be run on SL memory to accommodate change is made. needs, but please send engineer a note if this (11) Well Integrity Engineer a. Add Biennial (every 2 years) MIT -Ts and MIT-As/tainl1approval S. b. Josh Tempel will review SCMT with AOGCC and to make well Operable. Current Wellbore: TREE = CAN VALLMAD= OW ACRXLTOR= RAOWC OKB E LEV = 67.8' RF 8. EV = 9672 - 9646 moo-- 4349 K&K Angk - 95' ® 98.38' M8 L4)- MA LLben TVO= so 3S rsc. L.rA - sno' Minimum ID = 3.813°' @ 2183' 1 4.112" HES X NIPPLE I TiSG, 1259, IMR-80 VAM fOP, J—L bpi. D = 3 958' Z%� F. ON 057 198 AP"f-AI TOP PFJT-. 9' Q�98l7 Mea. Wfe1 b Roducton M f Nawo- ',pert dale SQE SPF KERVAL 009&F HUT SO2 2-34' 4 9672 - 9646 O 052498 08130110 MNPK mil PJC mm tom9lo) 2-3N' 4 9878-9974 O 0512408 2-34' 4 10003 - 1 O 052496 2-14' 4 10296 - 1 C 05249E 2-774' 4 10422 - 1 C 05124Aw 2-34' 4 70155 - 10782 C W?496 2-Y4' 4 1®82 - 10040 C 05 AM 15-43 Current 15 3 SA(11V NOTE S. WR I Amu L, 70- Lb 9295' MAX DLS. 32.2' Q 9976. CHROME TBG `yC -FI—?S -X-NP U = 3.413 Q �j I -�-Pzo falx �SZWANDFELS 3 5934 22 KW -2 0M1' I BK0 0826118 2 6767 21 KBG2 01 &( D 03716/D4 1 7957 22 KBG-2 ().N &C 0 0011&0-4 6308' 417Y MES X NP, D=3.813' _vB326r YX41IV BKRSF3 R4 U=9.6%8' 09rA'-4417'ICCXM,D�]41]' 8419' 1-yP X fl2'pKRRM1peDi eU 3004' ( � BMT' 4.11Y IE9 X NP. D= 3_817 i SM2' -}- HR W 798' RCR D 1.931' x110 77 NDT LOOC�D 1Q' LfWi. 19 99, L 30. 0152 bpf. O a 3 95W f."_j2' WE,c& onnvla 0' &—m F79H L1k.uD HLS cBPB 3 F*G"40F BAY W f V'WM-L. 15-43 PEFUT W. '19605W ARM. -5440-22676-00 SEC 22. T11 K RUE. 574 R1 & 108FWL DAM RFV BY OE*A&MS DATE F&V BY ODWA T, 05021M D -M ORGHOW-ONTALCOYPL 042015 081J►D CoRFv=MTBG 0311 M4 )MMAP IdYO 08118110 JGF7AW M.L C8PIGOP. SETCEPS F&I OV22104 JLNKAK GLV CIO 07117716 LC1JM GLV OL7 (07114+16) � 1210909 F F(7SV SET PA PLUG (1 U28109) 10!01718 TiUj—Lc GLV ao (08!28118) D6102110 WkW [AV 00(MWi 0) 102418 JIICVJ SET VWD%&W(l 22118) 0E3eplorat)na (Alsaka) 08130110 MNPK mil PJC mm tom9lo) 3 7Tg= aw I ELEV - 15-43 Proposed SAFETY NOTES: WELL AMC LE 15-43 / MAX OLS: dt3• 9979. CHROME TSO J S� DATE REVSYJ COAM.Ei is LMIE I FwV BY I COMENIS GMIM9 DUI JORIOHOAMNTALCOUPL s OBfJLO00RRBCI�TBG 03MVH H01 RBNO 18/18 .ILF7 AIL.t BP, SET (>BPA FISH o3fi1.O1 A.LKAK GLV OT) 7117115 tOIJAp GLV Cb 0711m" v 00jawom) 08107/10 GLV CAD (OS711f10) 10/18 SET NFOVYFPIf0YYt119j OM=10 T=FUL PX FLUE (OSMSIIO) fKJOHOE SAY LM riAL 1543 R3vff M:1960830 ARM. 504M2267600 SEC 72. 11 IN. R14L 57! FTL A 108 I BPec;-' -' (Awlq 15-43 P&A 4SZ-A4 h�Qt�oc ,S FNMIMERY Uf VAMl' 1543 /AI. 500211�0 Wim•,. .gym....- - -ISIS i PFapbria 1ma" STATE OF ALASKA .SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon Li Repair Well U Plug Perforations U Perforate Lf Other U Wellock S C- Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2 Operator 4.Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development Exploratory ❑ 196-083-0 3 Address: P.O Box 196612 Stratigraphic❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-22676-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028306 PBU 15-43 9 Logs(List logs and submit electronic and printed data per 20AAC25.071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary E E 1'V E D Total Depth measured 11043 feet Plugs measured See Attachment feet true vertical 8846 92 feet Junk measured 10948 feet i�A O 2015 Effective Depth measured 10226 feet Packer measured See Attachment feet, ,OG CC true vertical 8847 11 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 35 9-115 9 35 9-115 9 1490 470 Surface 3519 31 9-5/8"47#N-80 35.4-3554 71 35 4-3542 22 6870 4760 Intermediate 1 63 7-5/8"29.7#L-80 32-33 63 32-33 63 6890 4790 Production 8572 76 7"26#L-80 33 63-8606 39 33 63-8300 39 7240 5410 Liner 2590.8 4-1/2"12 6#L-80 8453 7-11044.5 8157 16-8847 01 8430 7500 Perforation depth Measured depth 9672-9846 feet 9878-9974 feet 10003-10206 feet 10296-10322 feet 10422-10605 feet 10755-10782 feet 10862-10940 feet True Vertical depth 8851.22-8849.01 feet 8848 45-8841 61 feet 8840 56-8846 43 feet 8845 1-8843 45 feet 8837 63-8833 21 feet 8832 8-8833 5 feet 8837 76-8841 13 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment 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 SCANNED MAY 8 0015 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 0 0 0 14 Attachments '15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil U Gas ❑ WDSPLU 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 0 Exempt 315-143 Contact NitaSummerhays Email Nita.Summerha s• b•.com Printed Name Nita Summerhayyss Title Petrotechnical Data Engineer Aiii" Signature � /„_ , r,,��,A��_...__ Phone 564-4035 Date 5/4/2015 VrL- 5711115- RBDM MAY - 6 1015 ,ot J/0t 1 , [ Form 10-404 Revised 10/2012 I Submit OnIna!Only li l Daily Report of Well Operations ADL0028306 .,. ., ,_> T/I/O=SSV/515/35. Temp= SI. Eval. (Pre-Wellock). Conductor is between 2'1" to 2'3" deep around conductor(soft bottom, Mud?). No OA companion installed on well, OA flanges are not intruding into well cellar&OA flange is @ the 6 O'clock position pointing out WH front door. 3/20/2015 SV, WV& SSV= C. MV= 0. IA& OA= OTG. NOVP. 14:00 T/I/O = SSV/520/40. Temp = SI. Remove fill from conductor(pre Wellock). No AL. Conductor depth @ 57". Used Cusco&water(11 bbls) to remove 8"of gravel, Conductor depth @ 65". To the top of the collar is 24" below top of conductor& bottom of collar is 36" below top of conductor. Applied Musol & let soak. 4/2/2015 WSR continued on 4/3/15. WSR continued from 4/2/15. Remove gravel from conductor(pre Wellock). Filled Conductor w/water& let soak for 30 min &took returns w/Cusco. 4/3/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 0130. T/I/O = SSV/515/70. Temp = SI. Pump Wellock (SC repair). No AL. SC temp = 135*. Vac'd out-1 bbls of water from conductor. Halliburton pumped -70 gallons wellock into conductor. Heater in wellhouse, tree cap bled to 0 psi. Monitored for 3 hrs 15 min. WHPs unchanged. Job Complete. Final WHPs= SSV/515/70. 4/3/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 2400 T/I/O = SSV/520/70. Temp = SI. WHP's &conductor temp (post Wellock). No AL. Heater in well house, working properly. Conductor temp is 142° @ 12 o'clock position &96° @ the 6 o'clock position. Bled tree cap to 0 psi. SV, WV, SSV=C. MV=0. IA, OA=OTG. 2330. 4/4/2015 T/I/O = SSV/520/70. Temp = SI. WHP's &conductor temp (post Wellock). No AL. Heater in well house, working properly. Conductor is 150° @ the 12 o'clock position & 150° @ the 6 o'clock position (temp taken with a PTC magnet thermometer. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 15:15. 4/5/2015 T/1/O=SSV/120/70. Temp=Sl. WHPs (Well lock). No AL. IA has integral installed. Heater in well house, working properly. Conductor is 142° @ the 12 O'clock position & 151° @ the 6 O'clock position (temp taken - 1 foot below top of conductor). 4/5/2015 SV, WV, SSSV=C. MV=O. IA&OA=OTG. NOVP. 1950.. T/I/0= SSV/520/70. Temp= SI. WHP's &conductor temp (post Wellock). No AL. Heater in well house, working properly. Conductor is 140° @ the 12 o'clock position & 130° @ the 6 o'clock position. 4/5/2015 SV, WV& SSV=C. MV=0. IA& OA=OTG. 0920 hrs. T/I/O= SSV/520/70. Temp= SI. WHP's &conductor temp (post Wellock). No AL. Heater in well house, working properly. Conductor is 124° @ the 12 o'clock position & 176° @ the 6 o'clock position (heater blowing directly @ 6 o'clock position, temp taken with a Fluke IR meter). Redirected heater hose into cellar. 4/6/2015 SV, WV& SSV=C. MV= 0. IA&OA=OTG. 0845 hrs. i i !J Daily Report of Well Operations ADL0028306 T/I/O =SSV/520/70. Temp =SI. Clean cellar& conductor temp (wellock). No AL. Heater in well house working properly. IA has integral installed =inspection not current. Conductor is 98° ©the 12 o'clock& 90° © the 6 o'clock position. Cleaned 2 bags of cured wellock from cellar. See log for details. Job complete. Final WHP's = SSV/520/70. 4/7/2015 SV, WV, SSV=C. MV=0. IA, OA=OTG. 12:00. T/I/0= SSV/520/60. Temp= SI. WHPs (Wellock). No AL. Integral flange on IA =inspection NC. Upon arrival, heater in wellhouse not working properly. Installed new heater in WH. Conductor is 19* @ the 12 o'clock position and 18*@ the 6 o'clock position at the top of conductor. Temp taken w/Fluke meter. 4/9/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 2300 T/I/0 = SSV/520/60. Temp = SI. Pressure test OA w/ N2 **PASSED**to 500 psi (Post Wellock). No AL. Initial OA FL = near surface. Pressured up the OA w/ N2 to 500 psi w/ .5 bottles of N2. The OA lost 5 psi in 15 minutes and 3 psi in the second 15 minutes for a total 30 minute loss of 8 psi. No response seen at surface. 4-way gas meter readings were normal throughout the PT. PASS. Bled the OAP to 0+ psi (-3 minutes, mostly gas). Hung caution tag on the OA. Monitored the WHP's during RD (30 minutes), OAP increased 10 psi. FWP's = SSV/500/10. 4/10/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 0030 hrs. T/I/0=SSV/514/35. Temp=SI. MIT-OA PASS to 1200 psi (post well lock treatment). No AL. OA FL @ surface. Increased OAP to 1200 psi in 200 psi increments with 1.06 bbl diesel. OA lost 34 psi in 1st 15 min &4 psi in 2nd 15 min for a total of 38 psi in 30 min. Monitored OA pressure for 1 hr per WIE (see log for details). Bled OA to 0 psi. Final WHPs=SSV/415/0 4/21/2015 SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1550. Tags hung. T/I/0=SSV/515/50. Temp=SI. WHPs (Eval well lock repair). IA has integral installed =inspection not current. IAP increased 100 psi, OAP increased 50 psi over night. No signs of leaks in well lock in flutes. 4/22/2015 SV, WV, SSV=C. MV=0. IA&OA=OTG. NOVP. 1150. T/I/0 = SSV/515/62. Temp= SI. WHPs (Eval Wellock repair). No AL. IA has integral installed =inspection not current. OAP increased 4 psi since 4/24/15. No signs of leaking from Wellock repair inside flutes. SV, WV, SSV=C. MV=0. IA, OA=OTG. 13:00 4/25/2015 T/I/0 = SSV/515/65. Temp = SI. WHPs (eval wellock post bleed) No AL. Integral installed on IA=inspection not current. IAP unchanged, OAP increased 1 psi overnight. No signs of leaking from Wellock repair inside flutes. 5/1/2015 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 0945. T/I/0 = SSV/515/40. Temp= SI. WHPs (eval wellock post bleed) No AL. Integral installed on IA=inspection not current. IAP unchanged, OAP decreased 125 psi since 5/1/15. No signs of leaking from Wellock repair inside flutes. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 0500 hrs. 5/3/2015 FLUIDS PUMPED BBLS 1.06 DIESEL I �' Daily Report of Well Operations ADL0028306 1.06ITOTAL FLUIDS PUMPED GALS 70 WELLOCK 70 TOTAL Q o 0 0 0 0 0 0 0) 0 N- L0 N- 0o r- Ln v In In O N Ln N- N U y o 0 0 0 0 0 0 0) O) M V N- co co 7 V c V N CO V CO CO CO CO CO CO - CA N V M O) CO O CO N Cb N Ln N 4 (xi - M O ct O) Ln - CO CO CO LO CO CO CO CO O 0 I H CO O c— CO N U7 L1') Lf) co Ln MO CO M r CO M 01 O r CO CO Ln CO LC) N- LU cO O Ln CO LC) CO CO LO CO V - CO CO CO CO C-) Ca (G0 ate.+ O 2 co) CO O N LO V Ln N- CI) a) CV 0303 -4- 03C00301 C O co co .- � J �— Qo O O CO O co 0 - co M 00 Z d �$ CO J *k CO .N NO O 00 .- N M (Ni CO N ' - N N LO L - co O CO Cr)O0) N- — in CO C Co N Ln LO Ln M r- CV CO CO CO J e Q Z O w � 0 � jQC� 0 OCCC[ DLLZZ ° z w w O CCCOCO ;— z UZ � � (/) I- H f N L W O v <CL 4- O 2 U) Q� O L n W 002Y coCL ch Q 0 cn O- W w O m m N N N r E V co CO N N QO V1-0 Q • • In Ln •(O O � O CO •zr - N c) Cb 07, .`; O N O Q LO CO N- a) 0 C) O) C) () 00 a0 00 as a CC CC CC (1) www O. >+OOU Q Q Q 3- 3- d E co co co • v v L.0 L6 r r r cn li TREE= CJI W _LF€AD= aI 15TY NOTES: WELL ANGLE>70°c 9295'. ACTUATOR. BAKE —4 3 MAX C DLS:32.2°@ 9876. CHROME TBG OKB.ELEV= 67.8' BF.ELEV= KOP= 4348' Max Angle= 95°©9939 t ' 2183' 4-1/2"1- X MP,D=3.813" Datum MD= PYA Datum TV D= 8800'SS GAS LFT MANDRILS 9-5/8"CSG.47#,N-80. =8.681" 3663' C .-----._-- D ST MD IVO DEV TYPE VLV LATCH FORT DATE 4 3212 3201 5 KBG-2 DMY BK 0 05/31/10 L 3 5334 5265 22 KBG-2 DMY BK 0 05/31/10 2 6953 6767 21 KBG-2 DMY BK 0 03/16/04 1 8238 7957 22 KBG-2 DMY BK 0 03/16104 Minimum ID = 3.813" @ 2183' I I 8306' -H4-112"FES X NIP,D=3.813" 4-1/2" HES X NIPPLE X X- 8326' —7"X 4-1/2"BKR S-3 PKR,D=3.875" 1----1 8350' H4-1/2"HIM X Imo,D=3.813' 4-1/2'TBG,12.6#,13CR-80 VAMTOP, H 8370' , 8374' 4-1/2"UNDUE MACHIE OVERSHOT .0152 bpf,D=3.958' 7'X 4-1/2'BKR S-3D=3.875" 41/2'TBG STUB(03/14/04) 8374' 8418' PKR, I I 8441' —14-1/2"FES X NIP,D=3.813" 8452' 1—TBR W17.96°PKR, D=3. 881" 4-1/2"TBG,12.6#,L-80,.0152 bpf,0=3.958" H8453' -- / 8453' N4-i/2 WLEG,D_3.958" TOP OF 4-1/2'LM t H. 8462' { \ / I ELMD TT NOT LOGGED 7"CSG,26#,L-80,D=6.276" H 8605' i_Al PERMMA PERFORATION SURY REFLOG: BFPON 05/07/96 10226'CTM —PARTIALLY ML.LED FESS ANGLE AT TOP PERF: 920152 BRIDGE9672' ` FAST DRL.L PLUG(03/29/04) Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ ` 10250' -�4 h/2' BAKE32CBP 2-3/4" 4 9672-9846 0 05/24/96 �j `''10949' CBP PUSFFE)TO BTM 01/24/01 2-3/4" 4 9878 9974 O 05/24196 /f / ` PBTD 10949') 2-3/4" 4 10003-10206 O 05/24/96 2-3/4" 4 10296-10322 C 05/24/96 2-3/4" 4 10422-10605 C 05/24/96 -- 2-3/4" 4 10755-10782 C 05/24/96 • 2-3/4" 4 10862-10940 C 05/24/96 N1r 4-1/2"Llai,12.6#,L-80,.0152 bpf,D=3.958" H 11043' - DATE REV BY COMMENTS DATE REV BY COMMENTS FRIDHOEBAY INT 05/21/96 0.14 ORIG HORIZONTAL COM PL 04/20/15 OS/J1,13 CORRECTED TBG WELL 15-43 03/18/04 JDM/KAN RYYO PERA K No: 1960830 03/22/04 JLJIKAK GLV CIO AR No: 50-029-22676-00 12/09/09 RPCISV SET PX FLUG(11/28/09) SEC 22,T11 N,R14E,574'FNL&108'FYYL 06/02/10 1431WRIC GLV GO(05/31/10) h 08/30/10 GTi/W 'JC PULL PX PLUG(08/05/10) t; E 'Exploration(Alaska) r i (cOr 1�jsTHE STATE Alaska Oil and Gas � ofALASI�;A Conservation Commission ___= 'mitt _�y 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OA, �T , Main: 907.279.1433 ALA5a P Fax• 907 276 7542 www.aogcc.alaska.gov ti SCS► ►. Travis Montgomery Well Interventions Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 (^ f " Anchorage, AK 99519-6612 V Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU 15-43 Sundry Number: 315-143 Dear Mr. Montgomery: 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, 6get.e 7;ki.e. Cathy P. Foerster Chair DATED this /A-ay of March, 2015 Encl. RECEIVED STATE OF ALASKA MAR 113 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well Change Approved Program❑ Suspend El Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Well Lock Techndogy 3• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. SG 1 eck V' BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 ' 196-083-0 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: P.O Box 196612,Anchorage,AK 99519-6612 50-029-22676-00-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU 15-43 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028306 . PRUDHOE BAY, PRUDHOE OIL ' 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): 11043 8847 . 10250 8847 10250 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91 5#H-40 35.9-115.9 35.9-115.9 Surface 3519 9-5/8"47#N-80 35.4-3554.71 35.4-3542 22 6870 4760 Intermediate 2 7-5/8"29.7#L-80 32-33.63 32-33.63 6890 4790 Production 8573 7"26#L-80 33.63-8606.39 33.63-8300.39 7240 5410 Liner 2591 4-1/2"12.6#L-80 8453.7-11044 5 8157 16-8847.01 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade. Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed X12 Attachments: Description Summary of Proposal I=I13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14 Estimated Date for 15.Well Status after proposed work: Commencing Operations. Oil D - Gas ❑ WDSPL ❑ Suspended ❑ 16 Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative. GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessica Sayers Trav,•.t M444,,,,,i-ry Email Jessica.Sayers@BP.Com Printed Name S;gn1nJ for Jessica Sayers Title Well Intervetions Engineer Signature .•JJ Phone 564-4281 Date 3/I L/Of Prepared by Garry Catron 564-4424 /1Z7,1,4 .5-6,1-L1127 WO(lnie7've.ri4- .1j-tn.".,02r l COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 16 - I S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No u Subsequent Form Required: /0 - 464. APPROVED BY Approved by. ci-.1COMMISSIONER THE COMMISSION Date.3 -(c"f -/5-- V ri- /vTi- //8/ s R F464--- ,1`,1 •76-, ./s- Form 10-403 Revised 10/2012 0 ipevidNmicEs valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate /ilk 3•/9-&s RBDMS J MAR 2 0 2015 Perforation Attachment ADL0028306 Well Date Perf Code MD Top MD Base TVD Top TVD Base 15-43 5/24/96 PER 9672 9846 8851 8849 15-43 5/25/96 PER 9878 9974 8848 8842 15-43 5/25/96 PER 10003 10206 8841 8846 15-43 4/12/01 ' BPS 10296 10322 8845 8843 15-43 4/12/01 BPS 10422 10605 8838 8833 15-43 4/12/01 4 BPS 10755 10782 8833 8834 15-43 4/12/01 BPS 10862 10940 8838 8841 i AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF I,ol) u./`- n-I C?`vv'( -000000000 = oDaocc0? CO 0 a) Q 0 0 0 0 0 0 c0o0 N L N- LU L) o � Lnvr— N- U 0 0 0 0 0 0 0 L 0) 0) CO N- M co - CO N 00 V m r co co CD CO 00 a) 03• M O CA `— co c0 co co O Q 00 CO CO CO CO F- 0- 0 0 t� ~ O N Lo LO N— CO • M M (-0 CO CO O > CO CO CD C (D C O a) O LUcoInr� Ln cosY O O Ln co in `=^ M (fl Ln M '� vJ CIQ CO CO CO CO � p 2 C J •- (� Q H CO N LC) .- U Q M M -;r M M M M co 00 O CO O CO O CO CO b CO (_) CO J J C Z CO L`iLU C� N * CO N 0) -� D -e, 1 - N O 7 v- cr L_ CO CD CO ) O C) r— — LO CO NCO N Ln 1.0 LO CO h- a) CO CO CO W Q O 0-) H � w U U 0 t c a u. Z Z Z w w O fx m m O H Z D > O Z U) H H Packers and SSV's Attachment ADL0028306 Well Facility Type MD Top Description TVD Top 15-43 PACKER 8333 4-1/2" BAKER S-3 PERM PACKER 8045 15-43 PACKER 8420 4-1/2" Baker S-3 Hydro Set Packer 8125 15-43 PACKER 8464 4-1/2" TOP PACKER 8167 bp + To: Ken Bulloch / Dan Scarpella; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-12-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Travis Montgomery, Well Interventions Engineer (office: 564-4127, cell: 918-281-9663) Subject: 15-43 WeIlLock Conductor Treatment Objective This program is for treating surface casing response to pressure by external repair with WellLock. The well fails MIT-OA to 500 psi with nitrogen. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to place the WeIlLock between the conductor and surface casing to mitigate the leak. Approximately two days before treatment, apply heater trunks to warm well to aid in treatment/curing of resin. Please reference the waste management plan, at the end of this document for disposal practice and approval. Ensure the slop trailer is clean prior to arrival. Do not mix non-exempt hydrocarbons with WeIlLock (this is to avoid taking WeIlLock to the facility). Well Detail Current Status: Not Operable — P Previous Test: 1/10/2015 MIT-OA to 500 psi with nitrogen failed Integrity Issues: Surface casing leak at 42" 3 '2 Last H2S Reading: 8-28-2010 26 ppm Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WellLock at or above 85°F) Musol A: 7.5 ppg Diesel: 6.8 ppg Temperature: Maintain 75°-80° F throughout the entire job, leave heater trunks in well during cure period (one week) Relevant History: > 08/25/10: MIT-OA to 1200 psi passed on pressure but failed due to visible leak 1 of 3 Procedure 1 D Thoroughly clean the conductor by surface casing annulus to remove any deleterious material. This includes steam washing the annulus and cleaning with detergent. 2 D Run open bleed on OA during the entire job. 3 D ***Pump WellLock into conductor by casing annulus. 4 D Allow WeIlLock to cure for one week. 5 D MIT-OA to 500 psi. *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period and record temperature and observable viscosity of sample. 2 of 3 • Hitt WELL- L) 1 5-i1.3 SAFETY NOTES: HORIZONTAL WELL AC WA 4U3,.are' MJ'P 4348 Ms Ant* 9541;S1,41',141f I I I 2183' H4-.!z•HES 12 ":1;8,3," ai ' MU L)1 ?VD &kV St,i LW 1.1,414..4*,LI., ISW" ?=1- 6.9'" 3553' 1-41 /.,t; I LA 1q L11 It 4 ".1'.2'2 2'7.4 s < -2 LIMY 1:111 05,0 V10 `,3•34 UP& HOC 0 MC:1'UP° 2 695:2 2V..±14.,-- we 0 Will;6004 KtPC-2 OW 11,K T.; 03016004 Minimum ID=3813' ( ' 2183' 4-112"HES X NIPPLE 1 • I 8306 1_14_"12"HtS,X.NV,ID 3.P" ' -I 8326' 1_1,X 4-,..;.2^W.:KR , D 3,87.5r I r -- --j8350' H4- i-Esx Isc o ' I 8370' '.2"UNDUE PARCHtdf.-.. 8418' H,- ..±4p5.- I I I I 8441' 3413"1 13452, U eer 1.4-'72- L-80„0452'tcg.ID 191',F.7 H 8453 1-- / I 6453 I I 1.4'Lw-4 • LIWPI-I 84162* :1 ICY. LL,Lic...ii.Ell H sew 1-41 I tffit-CIPPA I UN-S,L11.41.4441•CP NB-1.4.; Crt405.07,645 PatIALLA r Pur4m:5,1-s sct 416,7 Pkte.htgrer finalkortawalita. :err dal 110226'civ—WAir 14..LL', ; t SIZE SIP,- rtifiVAL L N DA rt 4 9572-SSW 1.4fILL fi;fiLt 2104- 4 91578 ser4 ;::;5,;2410 ; '4111P 10256' 4t2' 4444thJ 2-144" 4 1114103,-Pet2CE, CP4a*PRE; PC005;-130322 C 05024AW: ioser RCMP'i'LLVP4e,- rc,tg1.4 2-141" 4 110122-POKI5 C 05024,,.% 1044111kKEE 10949. 2- 3 3,4" 4 P015,5-toraz C os,t2240i6 "'ill sip 2-14" 4 -4C840 C 05424.;% t:an' ear wr 4 Lt4H,P2434, .0t52,t',24 IiWAP;" H 11043' I 14141.1.1P4Utt43Alf;LAIR it'Sg-t9E, °RIG HO;FIZONT AL COM PL YdELL 01.18,64 J DK'KA 14 RWO idJT%b. 2:i,2117.4 W–INAK E.C._'Z., •" !,,E1, - ' 2V, J2 ; P-LL, E4P Expluratior,!Aka kal 3 of 3 XHVZE Pages NOT Scanned in this Well History File. This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I c/~ -O ~,_~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~incent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 January 6, 2012 1016— 0.4Z3 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ° Anchorage, Alaska 99501 1 - Subject: Corrosion Inhibitor Treatments of GPB DS 15 cIS" Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 907 - 659 -5102. Sincerely, StAtINED FEB 7 Z012- Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date: 11/09/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor . sealant date ft bbls ft gal _ 15-018 2042570 50029206960200 15-028 , 2060720 50029206970200 15-03 1820300 50029207220000 15-048 2071380 50029207260200 15-05A 1950340 50029207310100 15-06A 1982540 50029207420100 15-07C 2030970 50029211660300 15-08C 2050050 50029211800300 15-09A 1931380 50029212010100 15-10A 1880850 50029205010100 15-11B 2041460 50029206530200 15-123 2060870 50029206650200 15-13A 1991240 50029206450100 15-14A 2042220 50029206820100 15-15C 2081820 50029206910300 15-16B 2011920 50029211150100 15-17 1840890 50029211260000 15-18A 2080830 50029222740100 0.4 NA 0.4 NA 5.1 11/9/2011 Additional treatment 15-19A 1990990 50029218290100 Dust Cover NA NA NA 102 11/9/2011 15-20C 2050930 50029211330300 15-21A 1990290 50029205030100 15-22 1800970 50029205090000 15-23A 2031110 50029222250100 15-24 1911280 50029222230000 15-258 2080240 50029218420200 15-268 2041590 50029222350200 _ 15-27 1920060 50029222430000 15-28A 2031240 50029222470100 15-29B 2090380 50029222590200 0.1 NA 0.1 NA 3.4 11/9/2011 Additional treatment 15-30A 2020890 50029222820100 15-318 2050860 50029222850200 15-32A 2011840 50029224620100 15-338 2031940 50029224480200 15-34A 2001370 50029224740100 15-35 1940880 50029224880000 15-36B 2060730 50029224800200 15-37B 2040190 50029224850200 15-38A 2030160 50029224960100 Dust Cover , NA NA NA 3.4 11/5/2011 15-39A 2060860 50029225030100 0.3 NA 0.3 NA 3.4 11/5/2011 Additional treatment 15-40A 1980980 50029225110100 15-41B 2011460 50029224920200 15-42B 2090730 50029226240200 ---� 15-43 1960830 50029226760000 4 NA 4 NA 30.6 11/9/2011 15-44 1961100 50029226830000 15-458 2071790 50029226710200 15-46 2041030 50029226650000 15-47 1951740 50029226170000 15-488 2051660 50029226350200 15-49B 2090640 50029226510200 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q SEAL TITE Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-ente uspended Well ^ 2.Operator BP Exploration (Alaska), Ina 4. Well Class Before Work: Permit to Drill Number: Name: Development ~ Exploratory ^ 196-0830 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-22676-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~ ADLO-028306 PBU 15-43 10. Field/Pool(s): ~ PRUDHOE BAY FIELD ! PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11043 feet Plugs (measured) 10250 10226 feet true vertical 8846.92 feet Junk (measured) 10949 feet Effective Depth measured 10949 feet Packer (measured) 8326 8418 true vertical 8841.56 feet (true vertical) 8039 8124 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110 1490 470 Surface 3519 9-5/8" 47# N-80 SURFACE - 3553 SURFACE - 3541 6870 4760 Intermediate 8574 7" 26# L-80 SURFACE - 8605 SURFACE - 8299 7240 5410 Production Liner 2591 4-1/2" 12.6# L-80 8462 - 11043 8156 - 8847 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# L-80 29 -8453 29 - 8157 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer 8326 8039 4-1/2" Baker S-3 Perm Packer 841~~~_ „~ t, Y 12. Stimulation or cement squeeze summary: `~~~~~ ~~~?%' ~ `_" ~~~~ ~ `~"' ' Intervals treated measured : ( ) : J ~taSka ~i ~t Gs~ ~~tt~. ~~111'#I'i'tISSIOn ~tiGltvf;:~l8 Treatment descriptions including volumes used and final pressur e: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: ~ Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil r Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-166 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 8/2/2010 mini iv-•+v-'r~cviacu ~icvv~D~~~ O~ ~~~ ~ ~ `l /d 15-43 196-083 PFRF ATTA(_HMFNT • u Sw Name Operation Date Perf Operation Code - ---- - -- Meas Depth Top -- ----------- Meas Depth Base Tvd Depth Top Tvd Depth Base 15-43 5/24/96 PER 9,672. 9,846. 8,851.22 8,849.01 15-43 5/25/96 PER 10,755. 10,782. 8,832.8 8,833.5 15-43 5/25/96 PER 10,422. 10,605. 8,837.63 8,833.21 15-43 5/25/96 PER 10,862. 10,940. .8,837.76 8,841.13 15-43 5/25/96 PER 10,003. 10,206. 8,840.56 8,846.43 15-43 5/25/96 PER 9,878. 9,974. 8,848.45 8,841.61 15-43 5/25/96 PER 10,296. 10,322. 8,845.1 8,843.45 15-43 10/4/97 BPS 10,675. 10,685. 8,832.2 8,832.26 15-43 1/24/01 BPP 10,675. 10,685. 8,832.2 8,832.26 15-43 4/12/01 BPS 10,250. 10,940. 8,847.2 8,841.13 15-43 1/20/04 BPS 8,427. 10,226. 8,132.28 8,847.11 15-43 3/30/04 BPP 8,427. 10,226. 8,132.28 8,847.11 15-43 11/28/09 BPS 8,325. 10,940. 8,037.63 8,841.13 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i 15-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/26/2010 T/I/0=800/150/80. Temp=S1. Install Heater on starting head. (pre-Sealtite). Integral installed on IA, Heater installed on starting head & Katch Kan installed in t Icellar. Bled treecap to 0 psi & opened front and rear wellhouse doors. Job Complete. SV & WV = C. MV &SSV = O. IA & OA = OTG. NOVP. 7/29/2010!***SEAL-TITE TREATMENT FOR SURFACE CASING LEAK**" INITIAL T/I/O = 900/250/0. TEMP = SL Pump Gel Seal down OA to mitigate bubbling at 9 o'clock position on landing joint 'collar. Bubbling reduced but still there. Leave 700 psi on OA overnight. j FINAL T/I/O = 900/250/700. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. ***JOB CONTINUED 30-JUL-2010**" 7/29/2010 T/I/0=900/220/700.. Temp=S1. WHPs (post sealtite). No AL. Monitor WHPs and fluid level 3 times during 12 shift (see log for details). ISV=C WV,SSV,MV=O IA,OA=OTG NOVP ~ e..._. _._. _---~- _ ____ ._.~.._ _ _ 7/30/2010 **"SEAL TITE TREATMENT CONTINUED FROM 29-JUL-2010**" INITIAL T/I/O = 900/220/700. TEMP = SL OA still at 700,~si~ No bubbling activity. Pressure up to _1200_ps treatment pressure _ in 100 psi increments with Gel Seal ever 30 mins. Last 100 psi with diesel. Leave 1200- psi on OA and allow 48 hour cure. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. FINAL T/I/O = 900/250/1200. ***JOB COMPLETE -CONTINUE TO MONITOR OA PRESSURE**" 7/30/2010 T/I/0= 830/160/1100. Temp= SI. WHP's (post Sealtite). below flutes. Pressures read @ 19:30. **Job complete"" ,SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. FLUIDS PUMPED Fluid in conductor @ 38" ~ BBLS 2 SEAL TITE 1 DIESEL 3 Total TREE _ ~ CMi WELLHEAD = CMJ ACTUATOR = _ BAKER C KB. ELEV = 67.8' BF. ELEV = KOP = 4348' Max Angle = 95 @ 9939' Datum MD = N/A Datum TV D = 8800' SS 9-518" CSG, 47#, N-80, ID = 8.681" I~ 3553' Minimum ID = 3.813" @ 2183' 4-1/2" HES X NIPPLE (4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 8453' ~OPOF4-1/2"LNR -~ $462' SAFETY S: HORIZONTAL W ELL. 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3212 3201 5 KBG-2 DOME BK 16 03/22/04 3 5334 5266 22 KBG-2 SO BK 20 03/22!04 2 6953 6767 21 KBG-2 DMY BK 0 03/16/04 1 8238 7957 22 KBG-2 DMY BK 0 03/16/04 8306' ~- ~4-1/2" HES X NIP, ID = 3.813" 8326' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" $350' $350' 4-1 /2" PX PLUG (11 /28/09 4-1/2" HES X NIP, ID = 3.813" 8370' 4-112"UNIQUE MA CHINEOVERSHOT 841$' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" $441' 4-112" HES X NIP, ID = 3.813" 8452' TBR WI7.96" PKR, ID = 3.881" 8453 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGG 7" CSG, 26#, L-80, ID = 6.278" ~-~ $605' PERFORATION SUMMARY REF LOG: BHP ON 05/07/96 ANGLE AT TOP PERF: 92 @ 9672' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 9672 - 9846 O 05!24/98 2-314" 4 9878 - 9974 O 05/24/96 2-3/4" 4 10003 - 10206 O 05/24/96 2-3(4" 4 10298 - 10322 C 05/24/98 2-3/4" 4 10422 - 10605 C 05/24/96 2-3/4" 4 10755 - 10782 C 05/24/96 2-314" 4 10862 - 10940 C 05/24/96 10226' CTM ~ PARTIALLY MILLED HES FAST DRILL BRIDGE PLUG (03/29/04; 10250' 4-1/2" BAKER CIBP 10949' CIBP PUSHED TO BTM 01/24/01 PBTD 1-49' ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 05!21!96 ORIG HORIZONTAL COMPL 03(18!04 JDMtKA RWO 03/22/04 JLJ/KAK GLV CJO 12/09/09 RPCISV SET PX PLUG (11/28/09} PRUDHOE BAY UNIT WELL: 15-43 PERMIT No:1960830 API No: 50-029-22676-00 SEC 22, T11 N, R14E, 2750.94' FEL & 1754.84' FNL BP 6cploratian (Alaska} • • SEAN PARNELL, GOVERNOR Tim Lee Petroleum Engineering E~ ~~ BP Exploration (Alaska), Inc. Q (Q, J..f/j P.O. Box 196612 6'' Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 15-43 Sundry Number: 310-166 Dear Mr. Lee: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~{' ~ /.i Chair DATED this ~! day of June, 2010. Encl. ~~~ ~ ~,~ ALAS~L AND GAS CONSE VAT ON COMMISSI~ RECE11/ED ~~~ ` b,~ APPLICATION FOR SUNDRY APPROVALS 6-`~-/O 20 AAC 25.zso JUI~ 0 ~ 201Q 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well ay~ro ~~ ~3 1 O~ Sus end Plu Perforations Perforate Pull Tubin 8 p ^ g ^ ^ g • 0 8 An~harae Extension ^ Operation Shutdown ^ Reinter Susp. Well ^ Stimulate^ Alter Casing ^ ^ Other: SEAL TITE 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ , Exploratory ^ 196-0830 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22676-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU 15-43 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028306 PRUDHOE BAY Field / PRUDHOE 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): 11043 - 8846.92 - 10949 8841.56 8350' 10226' 10250' 10949' Casing Length Size MD ND Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE 110 SURFACE 110 1490 470 Surface 3519 9-5/8" 47# N-80 SURFACE 3553 SURFACE 3541 6870 4760 Intermediate 8574 7"26# L-80 SURFACE 8605 SURFACE 8299 7240 5410 Production Liner 2591 4-1/2" 12.6# L-80 8462 11043 8156 8847 8430 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 29 8453 Packers and SSSV Tvae: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD and ND (ft): 8326 8039 4-1/2" Baker S-3 Perm Packer 8418 8124 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^/ - Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/11/2010 Oil Q , Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact TIM LEE Printed Name TIM E Title P E Signature Phone Date / 564-4904 5/28/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of a roval: Notif resentative ma witness Sund Commission so that a re Number: 3~ DJI ry pp y p y Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~ • YU APPROVED BY Approved b : COMMISSIONER THE COMMISSION ~ 1 / Date: (O(' U y Form 10~Rev / 01~0~ ~ v ~O ~' ~ ~ ~~ ~ ~ ~ G • 7 ~a Submit in Duplicate 15-43 196-083 PFRF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-43 5/24/96 PER 9,672. 9,846. 8,851.22 8,849.01 15-43 5/25/96 PER 10,755. 10,782. 8,832.8 8,833.5 15-43 5/25/96 PER 10,422. 10,605. 8,837.63 8,833.21 15-43 5/25/96 PER 10,862. 10,940. 8,837.76 8,841.13 15-43 5/25/96 PER 10,003. 10,206. 8,840.56 8,846.43 15-43 5/25/96 PER 9,878. 9,974. 8,848.45 8,841.61 15-43 5/25/96 PER 10,296. 10,322. 8,845.1 8,843.45 15-43 10/4/97 BPS 10,675. 10,685. 8,832.2 8,832.26 15-43 1/24/01 BPP 10,675. 10,685. 8,832.2 8,832.26 15-43 4/12/01 BPS 10,250. 10,940. 8,847.2 8,841.13 15-43 1/20/04 BPS 8,427. 10,226. 8,132.28 8,847.11 15-43 3/30/04 BPP 8,427. 10,226. 8,132.28 8,847.11 15-43 11/28/09 BPS 8,325. 10,940. 8,037.63 8,841.13 AB ABANDONED PER PFRF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE L~ • • • To: J.Bixby&R.Liddelow, AK D&C Wireline Ops Team Leads May 27, 2010 C.Olsen&T.Norene, AK D&C Well Services Ops Leads From: Taylor Wellman & Tiffany Quy (cell 253-576-6153) Projects WIE (659-5098, Harm #2418) Subject: 15-43 Seal-Tite SC Repair Step Type Procedure 1 S Pull & Set DGLV in STA #3&4, MIT-IA to 3000 psi 2 WP Pump Seal-Tite (Pending MIT-IA results) 3 SP Pull TTP from 8350' to POP (Pending 4 day cure) Objective: This procedure is to confirm tubing integrity and to repair a surface casing leak located at a pup joint threaded connection ~4' below the casing hanger using Seal-Tite. Seal- Tite Gel-Seal will be pumped down the OA to mitigate the thread leak. Once the sealant is cured, the well will be unsecured and reclassified as Under Evaluation to put on production to monitor for continued thread leakage. Please call Tiffany Quy or Taylor Wellman (Projects WIE) with any questions on this work at 659-5098 or Harmony #2418. Cc: Well File AK, D&C Well Integrity Coordinator • Procedure: Slickline (S): 1. Pull LGLV's from STA #3 (5335' MD) and STA #4 (3213' MD). 2. Set DGLV's in STA #3&4. 3. Conduct an MIT-IA to 3000 psi, LLR if fails. a. If fails, trouble-shoot GLV's. b. If pass, RDMO. Wellhead (W): 4. Rig up Fireball pump to the OA and start injecting Gel-Seal into OA to achieve initial injection pressure. Maintain pressure on the OA until Gel-Seal is observed coming from leak location or leak has stopped. Allow sealant to cure for 1 hour. Increase OA pressure in 100 psi increments and hold for 30-60 minutes until maximum treatment pressure is reached. 5. With maximum treatment pressure on the OA allow the sealant to cure for 96 hours. Visit well daily and increase pressure back to maximum pressure during curing period. Monitor and record any leaks observed. Slickline post curing period (SP): 6. Pull 4-1/2" PX Plug from 8350' MD. DHD post Sealtite treatment (DP): 7. Reclassify well as Under Evaluation and POP well. Put well on production and monitor OA pressure for buildup as well heats up. ~. ~,~ ~ m n .Z~T1i474R a f~A% 1GJ ~i.E~! ~ ~ 7 ~~ a.. __ _ _. h4;J~ ao......_ _ .:_... _ 43~~3 1~ A'S1~ _ _ 65 3`~ _____.... t'~~+.D. ~fq .~.~.~ Minimum ID ~ 3.$13" 2183 4=112" HES X 1+IIPPL,E Capacity: OA = 0.0256 bpf IA = 0.0175 bpf Tbg = 0.0152 bpf Fluids: IA: Completed w/ 8.5 ppg inhibited seawater to 5334' MD and loaded w/ crude to surface Tbg: Loaded w/ dead crude 1 ~Sl'~Y {4f 1: t#CNi~"C?N'1'A1. W>E~l. ®~ 2f 83' N ~- a .~ 1~5 K tom! ~'l s 3 fia 3' Y VR, CA 3~'2 32~a ., K~C:,-~ ~ ~K t+S .~3.2?a!;4 ~ 533 }2+.3+5 ,~." Kii:.r2 ^a+© ~€ 24 ~~?A4 S 82'34 1x51 ~ 2 ~r 6 t16~4 ttx` FMS X NP, Iff +~ 3 843° ' ~ ~T X 4-7P2" S 3 ~sR [? ~ 3, 87 83.80' ~,'1' PX p„ t1G a a,~2~ ~~ 6350' !i2' -~5 x MF? IQ ~- 3.8'3' 8418' Txt-~,! X5-3 D~3&; 8441` 4- irC' FES l( s~MP !D m 3 9? 3" ~$,~' 1T3R W ~'7 !~5' GK R ~i R 3 d81" ' 4- 7.. 2' 4hkl ECi, C? m 3 Q.IU~ ~T N~'r CTBA ~~ ~.t.~ eASr ~ ~o~ ptu~ t A,:r aA~ os~ .~=~~~r ~_ ~~ nw~ -22sr~{x, 7 @~ Rt 4E 27~A_4~4' ~1. ~ 7 T y{ $1` F-~L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 67.8' 0 Suspend 181 Repair Well 181 Pull Tubing 8. Property Designation: ADL 028306 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 110' Surface 3519' Intermediate 8574' Production Liner 2591' 11043 8847 10250 8847 Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New PaolO Re-Enter Suspended Well 4. Current Well Class: IBI Development 0 Exploratory 0 Stratigraphic Test 0 Service 0 Waiver 0 Time Extension 0 Annular Disposal 5. Permit To Drill Number 196-083 6. API Number: 50-029-22676-00-00 0 Other 9. Well Name and Number: PBU 15-43 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 10226' & 10250' feet Junk (measured) 10226' & 10949' feet Size MD TVD Burst 20" 110' 110' 1490 9-5/8" 3553' 3541' 6870 7" 8605' 8299' 7240 4-1/2" 8452' - 11043' 8156' - 8847' 8430 Collapse 470 4760 5410 7500 RECEIVED APR 1 6 2004 Alaska Oil & Gas Cons Conrn; . 4-1/2", 12.6#, L-80 8453' Anchor~ SSlon 7" x 4-1/2" Baker 'S-3' packer at 8418'; 7" x 4-1/2" Baker 4-1/2" HES 'X' Nipple at 'S-3' packer at 8326' 2184' 9672' - 10206' 8851' - 8846' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ftBDh\S Sf L. WR 1 \) lUU'\ Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casina Pressure 18,700 -0- 1,400 11,848 71 600 15. Well Class after proposed work: 0 Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Rob Tirpack, 564-4166 N/A 13. Oil-Bbl Prior to well operation: 774 Subsequent to operation: 694 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations 0 Well Schematic Diagram Printed Name Terrie Hubble Signature ~ ~ Form 10-404 Revised 12/2003 Tubina Pressure 1,176 543 Title Technical Assistant Phone Date (jJ. ~/(;!,..,c¡ Prepared By Name/Number: I j /(." Terrie Hubble, 564-4628 564-4628 Accept: Spud: Release: Ri~: 03/12/04 NIA 03/16/04 Nabors 2ES Well: Field: API: Permit: 15-43 RWO Prudhoe Bay Unit 50-029-22676-00-00 196-083 PRE-RIG WORK 11/21/03 TIIIO = 320/6010. PPPOT-IC = PASSED AT 3000 PSI, LDS = OK. PPPOT-T = PASSED AT 5000 PSI, LDS = OK. 11/28/03 EQUAILIZE XX PLUG @ 8425' (SLM). 11/29/03 PULLED XX PLUG @ 8421' (SLM). (PLUG WILL SERVE AS DRIFT FOR CHEM. CUT). WELL TURNED OVER TO DSO, WELL LEFT SHUT IN. 01/20/04 SET 4.5" HES FASDRILL COMPOSITE BRIDGE PLUG IN FIRST FULL JOINT BELOW PACKER WI CENTER ELEMENT AT 8427' MD (REF. TUBING TALLY DATED MAY-96) AND PUNCHED TUBING FROM 8374'-8376' MD IN PREPARATION FOR CHEMICAL CUT. NEW TD ON TOP OF PLUG IS 8426' MD. 01/24/04 ATTEMPT STRING-SHOT, CHEMICAL CUT. RIG UP AND ATTEMPT TO RUN A PRE-CHEM CUT STRING-SHOT AND UNABLE TO GET BELOW MASTER VALVE. CYCLE MASTER VALVE AND FIND SHORT 3 TURNS FROM CLOSING. APPLY HEAT AND PUMP METHANOL BY VALVE WITH TRIPLEX AND EVENTUALLY CYCLE TO 21.5 TURNS (1.5 SHORT). STILL UNABLE TO GET BELOW MASTER, PULL UP HOLE AND START PULLING OVER TENSION. TOOLSTRING THEN NOT DROPPING FREELY, THOUGHT TO BE ICING IN FLOW TUBES AND APPLY TANNER TO TUBES. CLOSE SWAB AND BLEED DOWN LUBE. UNSTAB TO FIND BOTTOM OF STRING SHOT BOTTOM BENT 90 DEGS APPROX l' ABOVE BOTTOM NOSE AND HAVING TO PULL HARD ON STRING BOTTOM TO GET TO MOVE DOWN. FIND KINK IN CABLE 20' ABOVE HEAD. CUT LINE AND RE-HEAD. ABLE TO CYCLE MASTER TO 22 TURNS. RESTAB WITH 22.125" WT BARS AND DROP RIGHT BY MASTER DOWN TO 100' CHECKING FOR OBSTRUCTIONS, NONE FOUND. POOH. RIG DOWN. 01/26/04 CHEMICAL CUT 4.5" TUBING IN MIDDLE OF FIRST FULL JOINT ABOVE PACKER (CUT AT 8389' MD REF. TUBING TALLY). FIRED 12-FOOT BY 1 STRAND STRINGSHOT PRIOR TO CUTTING. NO PROBLEMS ON FIRST RIH, BUT SECOND RIH SEVERING HEAD WAS BEING HELD UP IN MASTER VALVE. HAD TO HEAT, GREASE AND WORK MASTER TO BE ABLE TO FALL PAST WI 3.625" SEVERING HEAD. TAGGED TD 8426' MD. 01/28/04 TIO=300/70010. CIRC-OUT WELL BORE WI 470 BBLS SEAWATER. FEEZE PROTECT IAXTBG WI 85 BBLS DIESEL. FREEZE PROTECT FLOWLINE WI 10 BBLS DIESEL. FINAL WHP'S= 01010. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-43 15-43 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 1/31/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 5/611996 End: 3/11/2004 16:00 - 00:00 8.00 MOB P PRE 3/12/2004 00:00 - 03:30 3.50 MOB P PRE 03:30 - 06:30 3.00 RIGU P PRE 06:30 - 13:30 7.00 RIGU P PRE 13:30 - 14:30 1.00 RIGU P PRE 14:30 - 15:00 0.50 RIGU P PRE 15:00 - 16:30 1.50 WHSUR P DECOMP 16:30 - 20:00 3.50 KILL P DECOMP 20:00 - 21 :00 1.00 WHSUR P DECOMP 21 :00 - 00:00 3.00 WHSUR P DECOMP 3/13/2004 00:00 - 03:30 3.50 BOPSUF P DECOMP 03:30 - 08:00 4.50 BOPSUF P DECOMP 08:00 - 09:00 1.00 WHSUR P DECOMP 09:00 - 10:30 1.50 PULL P DECOMP 10:30 - 12:30 2.00 PULL P DECOMP 12:30 - 15:30 3.00 PULL P DECOMP 15:30 - 16:00 0.50 PULL P DECOMP 16:00 - 21:00 5.00 PULL P DECOMP 21 :00 - 22:00 1.00 PULL P DECOMP 3/14/2004 22:00 - 00:00 00:00 - 03:30 DECOMP DECOMP 2.00 PULL 3.50 PULL P P 03:30 - 04:00 0.50 CLEAN P DECOMP 04:00 - 05:00 1.00 CLEAN P DECOMP 05:00 - 08:00 3.00 CLEAN P DECOMP 08:00 - 14:00 6.00 CLEAN P DECOMP 14:00 - 14:30 0.50 CLEAN P DECOMP 14:30 - 17:30 3.00 CLEAN P DECOMP Move rig from 18-14B. Camp, Pits and Truck shop on location @ 2100 hrs. Sub left DS 18 @ 2300 hrs. Move Sub from DS 18-14B and line up DS 15-43. Rig on location @ 0230 Pin up side cellar doors. Lay herculite. Spot sub on well. Secure doors. Prep sub. Spot Pits, Camp, Shop and Cuttings Tank. Raise and bridle down Derrick. RU Rig Floor. Hold Prespud meeting with rig team. Rig accepted 3/12/2004 @ 1330 hours. Install secondary annulus valve. RU DSM and pull BPV with Lubricator. Annulus Pressure - 0 psi. Tubing was on a vacuum. RD Lubricator. RU circulating lines taking returns to the cuttings tank. Test lines and circulate out diesel freeze protection fluid from the well with seawater. Circulate Dirt Magnet sweep around. 4 bpm @ 350 psi. Blow down circulating lines. Dry rod FMC TWC and test from below to 1,000 psi. ND Tree and Adapter Flange. Remove tree and adapter flange. Check hanger threads. NU BOPE's. Test BOP's w/4" and 4-1/2" test joints - 250 psi low/3,500 psi high. Witness of BOP test waived by AOGCC. RU Lubricator and pull TWC. RD Lubricator. Well Static. PJSM. MU 4-1/2" NSCT XO on DP and thread into hanger. BOLDS and pull hanger to the floor - PU - 130K. Breakout and LD hanger. RU tubing handling equipment. Changeout elevators. RU control line spooling unit. LD 4-1/2" tubing from tubing cut at 8,399' (WLM) to 7,444'. Pull up to 15K over in some spots. Level rig. LD 4-1/2" tubing from 7,444' to 6,158'. Pulled tight several times - 20K over. Work pipe at tight spots. 3 bird's nests of control lines and missing bands from 6,281' to 6,158' (SSSV). Recovered 52 of 60 bands. RD control line spooling unit and clear the floor. Pump Hi Visc sweep - 9 bpm @ 1,000 psi. LD 4-1/2" tubing from 6,158' to 3,864'. LD 4-1/2" tubing from 3,864' to tubing cut. Clear Floor. 3 GLM's,1 SSSV, 210 jts + 20.06' cut joint of 4-1/2" tubing removed from well. Good, clean cut. Holes were seen on some of the joints in the pin and box ends of the tubulars. No holes were seen in the body of the joints. Install Wear Ring. RU and test 7" 26# casing to 3,500 psi for 30 minutes. RU power tongs and changeout handling equipment. MU Milling BHA to 295'. Break circulation - 3 bpm. 250 psi. PU 4" DP singles from 295' to 8,352'. Fill Pipe every 3,000'. RIH and tag up on bridge plug @ 8,409' (top of tubing stub @ 8,370'). PU - 167K, SO - 150K, ROT - 160K, 3.5 bpm @ 390 psi. Mill on Fastdrill plug @ 8,409', WOB - 2,000#,20 RPM. Mill Printed- 3/22/2004 8.04 54 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-43 15-43 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 1/31/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 5/611996 End: .~e 3/14/2004 3.00 CLEAN P 1.00 CLEAN P DECOMP and push plug down to 8,454'. DECOMP CBU. 9.5 bpm, 2,450 psi. Monitor well- 14 bph static loss rate. Blow down Top Drive. 14:30 - 17:30 17:30 - 18:30 18:30 - 21:30 21 :30 - 23:00 3.00 CLEAN P 1.50 CLEAN P Losses from starting to mill - 127 bbls DECOMP POH w/4" DP from 8,454' to 295'. DECOMP Changeout handling equipment. LD Milling BHA from 295' to 110'. RU 2-7/8" handling equipment. LD BHA from 110'. 23:00 - 00:00 1.00 CLEAN P Losses on Trip out - 70 bbls DECOMP Clear rig floor. Prep for running Baker Overshot and Scraper BHA. 3/15/2004 2.00 CLEAN P 2.00 CLEAN P DECOMP DECOMP 00:00 . 02:00 02:00 - 04:00 04:00 - 06:00 2.00 CLEAN P DECOMP 06:00 - 07:00 1.00 CLEAN P DECOMP 07:00 - 10:00 3.00 CLEAN P DECOMP 10:00 - 11 :30 1.50 CLEAN P DECOMP 11 :30 - 13:00 1.50 CLEAN P DECOMP 13:00 - 15:30 2.50 CLEAN P DECOMP 15:30 - 17:00 1.50 RUNCO~ COMP 17:00 - 18:00 1.00 RUNCO~ COMP 18:00 - 00:00 6.00 RUNCO~ COMP 3/16/2004 00:00 - 07:00 7.00 RUNCO~ COMP 07:00 - 10:00 3.00 RUNCO~ COMP 10:00 - 12:00 2.00 RUNCO~ COMP 12:00 - 13:00 1.00 WHSUR P COMP Total Losses for the day- 208 bbls PJSM. MU Overshot and Scraper BHA to 234' RIH with Overshot and Scraper BHA on 4" DP from 234' to 8,260'. PU single and 5' pup and RIH to the top of the tubing stub @ 8,374' DPM, 3 bpm @ 200 psi. Swallow stub, see pressure increase to 400 psi when packoff engaged and tagged up at 8,386'. PU - 170K, SO - 150K, ROT - 165K. 80 bbls lost since midnight. PU above top of tubing stump. Pump sweep - 11.5 bpm. Pump dry job and blow down top drive. LDDP from 8,386' to 2,700' Slip and cut 75' of drilling line. Service top drive. LDDP from 2,700' to 233'. Change out handling equipment. LD BHA from 233'. Clear the floor and remove saver sub. Pull wear ring. RU 4-1/2" 13Cr tubing handling equipment. PJSM. MU Unique Machine Overshot and Baker S-3 Packer. MU 4-1/2",12.6#, 13Cr, Yam Top tubing to 4,653'. Total Losses for the last 24 hours: 252 bbls. MU 4-1/2",12.6#, 13Cr, Yam Top tubing from 4,653' to 8,374'. PU - 127K, SO. 11 OK. Tag up on stump. Pull above stump. Wash down. Saw pressure increase at same spot. Spaceout Tubing. Land Hanger w/4" DP landing joint and run in lock down screws. LD Landing joint. RU circulation hoses and reverse circulate 145 bbls 140 degree seawater and 223 bbls 140 degree seawater w/ corrosion inhibitor - Displace to upper GLM @ 3,213' @ 3 bpm, 210 psi. MU Landing joint and drop 1-7/8" ball/rod. LD Landing joint. Close blind rams and set packer w/ 3,500 psi and hold for 30 minutes - good test. Bleed tubing to 1,500 psi. Pressure test annulus to 3,500 psi for 30 minutes - good test. Bleed tubing pressure and observe DCK in upper GLM shear. Bleed off annulus pressure. Total fluid loss - 112 bbls since midnight and 572 bbls for the well. Dry rod install TWC. Test from below to 1,000 psi. Blow down surface equipment and rig down hoses. Prlnled. 3/22/2004 8.04.54 AM Påge30f 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-43 15-43 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 1/31/2004 Rig Release: 3/16/2004 Rig Number: Spud Date: 5/611996 End: , , [)eSèripJj~h~f'.bRera tidti~~: 3/16/2004 13:00 - 18:00 5.00 WHSUR P 18:00 - 19:00 1.00 WHSUA P 19:00 - 21:00 2.00 WHSUR P 21 :00 - 22:00 1.00 WHSUA P 22:00 - 23:00 1.00 WHSUA P 23:00 - 00:00 1.00 RIGO P CaMP NO BOPE. NU Tree and adapter flange. Test tree to 5,000 psi - good test. Pull TWC with lubricator. PJSM. RU Little Red Hot Oil Service. Circulate 75 bbls diesel freeze protection fluid down annulus @ 2.5 bpm, 2,000 psi. U-tube diesel from annulus to tubing. Dry rod install BPV and test from below to 1,000 psi. AD circulation lines Remove secondary annulus valve and secure well. Rig released 3/16/2004 @ 2400 hours. COMP COMP COMP COMP COMP Printed' 3/22/2004 8:04'54 AM 15-43 RWO Prudhoe Bay Unit 50-029-22676-00-00 196-083 Accept: Spud: Release: 03/12/04 NIA 03/16/04 Nabors 2ES POST RIG WORK 03/22/04 PULL B & R @ 8321' SLM. PULL DGLV (BK) @ 5315' SLM. PULL DCK (BEK) @ 3193' SLM. SET GENERIC (1/4, TRO 1500#) STA # 1. SET SIO (5/16) STA # 2. PULL RHC PLUG BODY. DRIFT WI 3.27 CENT SAMPLE BAILER 9322' (SLM) + 20', CORRECTED DEPTH OF 9342' MD. (NO SAMPLE, HAW) 03/29/04 PUMP 1.25" BALL THROUGH NEW COIL. MU BHA WI 2-7/8 MTR, 3.70" 6-BLADED MILL. TAG PIS, MIN ID TOO SMALL FOR MILL. MU BHA WI 2-3/8" MTR, 2.75" 5-BLADED MILL. PUSH FBP TO EST 10226'. POH FREEZE PROTECT WELL TO 2500' AND FLOW LlNE.RDMO. NOTIFY DSO WELL FP AND LEFT SHUT IN. JOB COMPLETE. - ~, "~, 15~43 As 2 ES Completed _,_,m 1& '<__'-_-">L,j ~. 21M' H'~'fE;: X NI?,JD" 3.813U N-80,[)" 8,68.1~Ji 35~:__~ l' '$T NID 3213 2 5335 :) 6954 4 8239 'u "^,' , GAS LIFT MANDRELS WD:!JEV TYPE v'uj- LATCH' PORi DATE- 3200 5-nV' Ö3l16!04' 5256' 21 - KBG2 DV EK 1" ,03116/04- 21 KeG2 DV, EK 1" ~ 03J16fO4i 7960: 22 KBG;? DV - EK 1H 03116104, , , .- "_u.,,' ," , " , Minimum 10 :: 3.813" @ 8441' 4~112" HES X NIPPLE .. I' 8301' 8321' over top ,'""~ '----"-, I TOPÒf 4.1/2" 8442' " I ,~ (w . -~ ' ø- ...---1 F l¡-'j-- I I, " "m~'I1- ---.-.. I ~ _.. ~~_~"H o;3.§ii'] '~~2: ,JiTBR Wrr:9ß"~~, fO'" 3,SfWl á453' !D ;;. 3J.~5í?l , c' ,,'~C L.aO"O152bpf,IO" I-{ ELMI? NO! LOG(35D I r 1~ Ç$G, L-BO, ö."a,Ú6", Ii 8605' PartlaHy milled Fastdrill BrIDge Rug J Note: , s¡i'Êr~ PERFORA TON SUI\1MARY REF lOG: BHPONO6JO7!96 ANGLE AT TOP PERF: 92 @ 9672' to Production 00 fOf hístoric..1 perf data , IÍlífE:Rv A L DA TE 961~f:'~t)' 05/24196 9878.9974 0 OS/24196' 1000$. 10200 0 05124196 10296" 10322 C 05124/96 10422 - 10005 C 05124/96 10155 - 10782 C 05124/96 10862, 10940 C 05124196 . J. rô1 !} I I 1Ci250'-1-f4-1/2" BAKæœp1 / ,. .., ' . "U ,. /10949' HëiPR]$H!Ð TÇI aiM 0112410"1- "") mTD 10949' .1 4 2.314". 4 . 2-314" 4 f 2£.3!4" , 4 , 2<~í4'" 4 . 2-.3!4" 4 I 2<314" ~ 4 r4.1/2" LNR:12,6#.l-ao, ,0152 bpf, [)" 3.958" 1-1 11043', .. ...,.".......-.,.----.... , "'~r~'-'. .. DATE REV BY CO!'v1MENTS 0512119'6 :ORIG HORtZONTA~.C~.~1.. 05/ool01 RWKAKREDRAW û2í26tÒ3 CJlKAK PERF CORRB.-ìl0NS OEd 3/0:3 , CWfflP Kí3 E!..Ë\I A TION CORRECTJON û9/12103 CMOfflP ÓA'TUM'~'CORRB...jKJN 0911'4/03 JCM.'TlP GLV ClO DATE REV BY coMMÊNT$ , . PRUC>HC.ìE SA Y UNrr WELL 15.43 PERt-,¡\IT No: 1960830 APt No: 50-029--22616-00 SEC 22, T11N, R14E. 2750,94' FE!.. &. 1754.84' FM. u , ,...... 6P Exploration (Alaska) ---",-,",..~..-u, '"",,¡, " "n., --. .. --"' " " ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION · REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _ Pull tubing _ Alter casing_ Repair well _ Other_X (ClBP) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 573' FNL, 5170' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 232' FNL, 3599' FEL, Sec. 22, T11N, R14E, UM At effective depth At total depth 1755' FNL, 2751' FEL, Sec. 22, T11N, R14E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 676023, 5960909) (asp's 677588, 5961288) (asp's 678471, 5959785) 6. Datum elevation (DF or KB feet) RKB 67.8 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-43 9. Permit number / approval number 1 96-083 10. APl number 50-029-22676 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 3485' Production 8537' Liner 2591' 11043 feet Plugs (measured) Set ClBP @ 10250' MD on 4/12/2001. 8847 feet 10250 feet Junk (measured) Milled up CIBP pushed to 10933' MD (1/24/2001). 8847 feet Size Cemented Measured Depth True Vertical Depth 20" 260 sx AS 110' 110' 9-5/8" 17oo sx CS III & 336 sx cs II 3553' 3541' 7" 215 Sx Class G 8605' 8299' 4-1/2" 31o sx C~ass G 11043' 8847' Perforation depth: measured 9672' - 9846'; 9878' - 9974'; 10003' - 10206'; (Isolated below CIBP 10296'- 10322'; 10422'- 10605'; 10755'- 10782'; 10862'- 10940'). true vertica18851' - 8849'; 8848'-8841'; 8840'-8846'; RECEIVED (Isolated below CIBP 8845' - 8843'; 8837' - 8833'; 8833' - 8833'; 8838' - 8841') Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8453' MD. 7" X 4-1/2" BAKER S-3 PACKER @ 8418' MD. 4-1/2" HES HXO SVLN SSSV @ 2219' MD. 13. Stimulation or cement squeeze summary APR OH & Gas Cons. Commission Anchorage Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl 1223 36718 0 1346 7982 0 Casing Pressure Tubing Pressure 920 382 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certi~.t~at /.,/ Preston Evans y ' the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Title: DS 15 Surveillance Engineer Date April 27, 2001 Prepared by Paul Rauf 564-579~~ SUBMIT IN DUPLICATE 15-43 DESCRIPTION OF WORK COMPLETED SET CIBP FOR GSO Date Event Summa~ 1/24/2001- 2/24/2001. 4/06/2001. 4/12/2001' MIRU CTU. PT'd equip. RIH w/milling BHA & tagged CIBP @ 10676' MD. Milled CIBP & pushed it downhole to 10933'. POOH w/BHA. Loaded well w/Crude. RD CTU. TIFL passed. RIH & drifted to 9327' (HAW). A ClBP placement f/GSO was performed as follows: MIRU CTU. PT'd equip. Pumped 63 bbls of 2% KCL Water. RIH & set Baker ClBP in the 4-1/2" liner @ 10250' MD to isolate the following Zone 1 perforations: 10296' - 10322' MD Reference Log: BHP 5/07/1996. 10422' - 10605' MD 10755' - 10782' MD 10862' - 10940' MD Retagged ClBP & POOH w/Baker setting tool. RD CTU. Placed well BOL & obtained a representative production test. Page 1 bp April 5, 2001 oNLY - t DF ~FLUR~'I'IUIN BP Exploration (Alaska) lnc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-66 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA_, Pt. Mac, & Lisbume Well Work: , This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for April 2 - 9, 2001; Well Work Planned 02-19 ADD PERFORATION 02-21 05-17B 06-21A 07-08A 11-22A . 16-05Ai ADD PERFORATION ADD PERFORATION CTE PERF'ORATION CT REMOVE 2-3/8" GL COIL ADD PERFORATION SET CIBP W/CT CT REPERFORATION / ACID STIMULATION 18-04A CT REMOVE 2-3/8" GL COIL 18-13A CT SET CIBP FOR GSO 18-18A SET CIBP W/CT Starting next week, I will be including WOA, Milne Pt, & Endicott wellwork. If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. Sincerely, Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS -- Page: 1 Date: 05/13/98 RUN DATE RECVD -- 96-083 DIFL 96-083 BHP 96-083 SS~rD 96-083 DLL/GR 96-083 CN/GR 96-083 DAC/GR 96-083 SSVD 96-083 DIR SURV 96-083 GR/RES - MD 96-083 GR/RES - TVD 96-083 7154 96-083 7452 96-083 7458 96-083 GR/PDC 96-083 TDTP/B ~'~SEDIA ~SEPIA SEPIA s zmY DT /BO 1 06/03/96 1 06/03/96 1 06/03/96 2 06/03/96 2 06/03/96 2 06/03/96 2 06/03/96 06/17/96 FINAL 06/21/96 FINAL 06/21/96 1 09/11/96 7-13 09/10/96 ~ATLAS DLL/DIFL/4CAL/DAC/CN/GR 1,2 09/10/96 ~'~000-9320 FINAL 09/20/96 L~000-10920 FINAL 09/20/96 10-407 ~0MPLETION DATE ~/~i-/ ~/ DAILY WELL OPS ~- §-/ IA / ~/ TO ~/,? ~,/¥~/ Are dry ditch samples required? yes ~_And received? Was the well cored? yes n~_~Analysis & description received? Are well tests required?~s ~ Received? y.e.e----ner--~-~ Well is in compliance Initial COMMENTS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSI, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Per[orate _ Pull tubing Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 68' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service _ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 4706' NSL, 5172' WEL, Sec 22, T11N, R14E, UM. 15-43 At top of productive interval: 9. Permit number/apRrovaJ number: 5048'NSL, 3599'WEL, Sec22, T11N, R14E, UM. ~'eJrrF~'~ ~ ~ -' 00~.~-~ At effective depth: 10. APl number: 50-029-22676 At total depth: 11. Field/Pool: 3525' NSL, 2751' WEL, Sec 22, T11N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11043 feet Plugs (measured) CIBP @ 10675' MD (set 10/5/97). true vertical 8847 feet Effective Depth: measured 10675 feet Junk (measured) true vertical 8832 feet Casing Length Size Cemented Measured depth True vedlcal depth Conductor 110' 20" 260 Sx Arctic Set 110' 110' Surface 3519' 9-5/8" 1700 Sx CS 111, 3553' 3541' 336 Sx CIG Production 8574' 7" 215 Sx Class G 8605' 8299' Liner 2591' 4-1/2" 310 Sx Class G 11043' 8847' Perforation Depth measured 9672 - 9846'; 9878 - 9974'; 10003 - 10206'; 10296 - 10322'; 10422 - 10605'; (Isolated below CIBP: 10755- 10782'; 10862- 10940') true vertical 8851 - 8849'; 8848 - 8841'; 8840 - 8846'; 8845 - 8843'; 8837 - 8833'; (Isolated below CIBP: 8833 - 8833'; 8838- 8841') Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Tubing @ 8453' MD. Packers and SSSV (type and measured depth) Baker S-3 Packer @ 8418' MD; 4-1/2" HES HXO SVLN SSSV @ 2219' MD.- ~ ,, - .,.... 13. Stimulation or cement squeeze summary ., : intervals treated (measured) see attached ,~-, ,',:'i',':1~ ?. ;'-' 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2554 51868 0 - 1045 Subsequent to operation 3465 19248 0 - 393 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~~ %. ~ Title: Engineering Supervisor Date /~2-/~,- '~'7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~~' 15-43 DESCRIPTION OF WORK COMPLETED CAST IRON BRIDGE PLUG INSTALLATION FOR GAS SHUTOFF 10/5/97: MIRU CTU & PT equipment. Loaded the wellbore w/Crude, then RIH w/HES CIBP & set the CIBP at 10675' MD in the 4-1/2' liner, to isolate the two lower open perforation intervals located at: 10755- 10782' MD (Z1) 10862- 10940' MD (Z1) Tagged top of CIBP at 10672' MD. POOH. Rigged down. Returned the well to production & obtained a valid welltest. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10405 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 9/18/96 Field: Prudhoe Bay ,,,' o'L'~ ;. I~S' .5-2o'2 ;.oqt Anadrill Anadrill Anadrill Well Job # Log Description Date BL RF Sepia Survey Program Performance Calculation Letter Floppy Disk D.S. 15-26 TDTP BORAX 960804 I 1 D.S. 15-43 TDTP BORAX 960806 I 1 .......... D.S. 15-42 TDTP BORAX 9 6 0 51 2 I 1 ,,, D.S. 15-48 TDTP BORAX 960805 I 1 ,, D.S. 18-30 TDTP BORAX 960514 I 1 ........... SIGNED: ~__~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 9/13/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrie NO. 10392 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter D.S. 1-6A PRODUCTION PROFILE 96 0731 I 1 D.S. 3-28 CNTG 96081 9 1 1 _ .... D.S. 4-3 CNTG 960821 1 1 D.S. 5-01 B GR-CCL TIE IN LOG 9 6 0 81 1 I 1 ,, D.S. 7-7A PRODUCTION PROFILE 9 6 0 8 0 4 I 1 D.S. 7-7A CNTD 960804 1 1 ..... D.S. 9-2 PRODUCTION PROFILE 9 6 0 8 0 3 I 1 D.S. 09-07 PRODUCTION PROFILE 9 6 0 81 5 I 1 , , D.S. 9-13 PRODUCTION PROFILE 9 6 0 81 2 I 1 D.S. 9-29 PRODUCTION PROFILE 9 6 0 8 03 I 1 D.S. 15-43 GR/PDC LOG 960817 I 1 D.S. 15-45 GR/PDC LOG 9 6 0 81 8 I 1 ,. D.S. 15-46 iGPJPDC LOG 960818 1 I S '-" c.r 2 0 .oo~ -07~, -oocJ - t'3,O '- oo--~ ;- · o'~ .-o(,,9 ,.o1~1 SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10374 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 9/6/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter D.s''' 15-43 96226 TDTP BORAX '"7! S"c// 960806 I SIGNED:~~~_ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS ECC No. Run # 1 6642.00 Run # 1 6666.00 Run # i 6676.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Gas Cons. Comrni~smn A~orage D !:t I I--I--I I~ G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 15-43 September 10, 1996 AK-MM-960527 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.' Yum Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. RECEIVED SEP 10 199~ ,qlaska Oil & Gas Co~s. Commission An~orage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dra.q.qar Indu.~triR.~ Inn ~nmnmnv - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-83 3. Address 8. APl Number P.O. Box 196612. Anchorage. Alaska 99519-6612 50-029-22676 4. Location of well at surface 9. Unit or Lease Name --.~ .......... ~ ..... ~..~. i~,,,-~.~,~r~ ~ .-..~.~?~'.j~',%,i~.~: 10. PrudhOewell NumberBay Unit 4706' NSL, 5172' WEE, SEC. 22, T11N, R14E At top of productive interval Attotaldepth~tS i~ ~,~.~,,g ~~' ' 11 FieldandPool ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Le nat n and Serial No. Pool KBE = 67.80 I ADL 028306 12. Date Spudded05/05/96 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre 116' NO' Of COmpletiOns05/21/96 05/25/96 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 11043 8847 F'r] 10949 8841 F'r] []Yes []No I 2219' MD! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIFL, GR, Caliper, DIP, Db, DIL, LSS, FE 23. CASING, LINER AND CEMENTING RECORD CASING SE'Iq'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 47# N-80 34' 3553' 12-1/4" 1700 sx CS III, 336 sx 'G' 7" 26# L-80 31' 8605' 8-1/2" 215 sx Class 'G' 4-1/2" 12.6# L-80 8452' 11043' 6" 310 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8453' 8418' MD TVD MD TVD 9672' - 9846' 8851' - 8849' 9878' - 9974' 8848' - 8841' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 10003' - 10206' 8840' - 8846' 10296' - 10322' 8845' - 8843' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10422' - 10605' 8837' - 8833' Freeze Protect with 130 Bbls Diesel 10755' - 10782' 8833' - 8833' 10862' - 10940' 8838' - 8841' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 31, 1996 Gas Lift 'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Markers 30. r-urmation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 8543' 8241' Shublik 8587' 8282' Top of Sadlerochit 8657' 8348' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /"~~ ¢ (~~4~_ Terq/Jordan Title Senior Drilling Engineer Date Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL; This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Operations Summary for: 15-4,.. May 11 Drilled to Made up May 12 Drilled to Drilled to Drilled to May 13 1996 (7) 5601 ft. Circulated at 5601 ft. Pulled out of hole to 500 ft. BHA no. 6. R.I.H. to 5601 ft. Drilled to 6283 ft. 1996(8 ) 6654 7649 8145 Pulled BHA. ft. Circulated at 6654 ft. Pulled out of hole to 5585 ft. R.I.H. to 6654 ft. ft. Circulated at 7649 ft. Pulled out of hole to 5775 ft. R.I.H. to 7649 ft. ff. 1996(9 ) Drilled to 8613 ft. Circulated at 8613 ft. Pulled out of hole to 7600 ft. R.I.H. to 8613 ft. Circulated at 8613 ft. Laid down 1400 ft of 5 in OD drill pipe. Pulled out of hole to 1000 ft. Pulled BHA. Retrieved Wear bushing. Ran Casing to 3500 ft (7 in OD). Circulated at 3500 ft. Ran Casing to 4500 ft (7 in OD). May 14 1996 (10) Ran Casing to 8605 ft (7 in OD). Circulated at 8605 ft. Mixed and pumped slurry - 42 bbl. Displaced slurry - 321.5 bbl. Rigged down Handling equipment. Installed Seal assembly. Rigged up All rams. Tested Well control. Installed Wear bushing. Rigged up Kelly. Laid out.5 in drill pipe from derrick. Made up BHA no. 7. May 15 1996 (11 ) Made up BHA no. 7. Singled in drill pipe to 8473 ft. Serviced Block line. Repaired Survey wireline unit. Tested Kelly. Tested Casing - Via annulus and string. Held drill (Kick (well kill)). Drilled installed equipment - Float collar. Circulated at 8623 ft. Drilled to 8860 ft. May 16 1996 (12) Drilled to 8902 ft. Circulated at 8902 ft. Pulled out of hole to 45 ft. Made up BHA no. 8. R.I.H. to 8597 ft. Reamed to 8814 ft. Drilled to 9238 ft. May 17 1996 (13) Drilled to 9270 ft. Circulated at 9270 ft. Pulled out of hole to 0 ft. Made up BHA no. 9. R.I.H. to 9227 ft. Logged hole with LWD: DIR/DD from 9227 ft to 9270 ft. Drilled to 9492 ft. Circulated at 9492 ft. Pulled out of hole to 8597 ft. R.I.H. to 9492 ft. Circulated at 9492 ft. Pulled out of hole to 2935 ft. Page 2 Operations Summary for: 15-4~ May 18 1996 (14) Held safety meeting. Rigged up sub-surface equipment - Formation logs. Ran electric logs. Ran electric logs. Rigged down sub-surface equipment - Formation logs. Made up BHA no. 10. R.I.H. to 8597 ft. Serviced Block line. R.I.H. to 9285 ft. Logged hole with LWD: DIR/DD from 9285 ft to 9492 ft. Drilled to 9612 ft. May 19 1996 (15 ) Drilled to 9803 ft. Circulated at 9803 ft. Flow check. Pulled out of hole to 25 ft. Made up BHA no. 11 . R.I.H. to 9803 ft. Drilled to 9909 ft. Circulated at 9909 ft. Flow check. Pulled out of hole to 25 ft. Made up BHA no. 12. R.I.H. to 5500 ft. May 20 1996 (16 ) R.I.H. to 9470 ft. Logged hole with LWD: DIR/FE/DD from 9470 ft to 9909 ft. Drilled to 10725 ft. May 21 1996 (17 ) Drilled to 10860 ft. Circulated at 10860 ft. Flow check. Pulled out of hole to 25 ft. Pulled BHA. Made up BHA no. 13. R.I.H. to 8597 ft. Serviced Block line. R.I.H. to 10860 ft. Drilled to 11043 ft. Circulated at 11043 ft. Flow check. Pulled out of hole to 8597 ft. Logged hole with LWD: DIR/FE/DD from 9824 ft to 10500 ft. May 22 1996 (18) Logged hole with LWD: DIR/FE/DD from 10500 ft to 11043 ft. Circulated at 11043 ft. Flow check. Pulled out of hole to 2960 ft. Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 2600 ft (4.5 in OD). Circulated at 2600 ft. Ran Drillpipe on landing string to 8597 ft. Circulated at 8597 ft. Ran Drillpipe on landing string to 11043 ft. Circulated at 11043 ft. May 23 1996 (19) Circulated at 11043 ft. Held safety meeting. Pumped spacers - volume 70 bbl. Mixed and pumped slurry - 61 bbl. Displaced slurry - 96.5 bbl. Retrieved downhole equipment- Liner hanger. Reverse circulated at 8452 ft. Rigged down Casing handling equipment. Flow check. Retrieved downhole equipment- Liner hanger. Retrieved Wear bushing. Tested All functions. Installed Wear bushing. Made up BHA no. 14. R.I.H. to 10949 ft. Circulated at 10949 ft. Circulated at 10949 ft. Page SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: 1 5-43 Rig Name: Doyon 14 AFE: 4J0306 Accept Date: 05/05/96 Spud Date: 05/05/96 Release Date: 05/25/96 May 5 1996 (1) Rig moved 100 %. Rigged up Divertor. May 6 1996 (2) Rigged up Divertor. Made up BHA no. 1 . Tested Divertor. Held safety meeting. Circulated at 80 ft. Drilled to 499 ft. Pulled BHA. Made up BHA no. 2. R.I.H. to 445 ft. Took MWD survey at 445 ft. Pulled out of hole to 0 ft. Made up BHA no. 3. R.I.H. to 499 ft. Drilled to 732 ft. Pulled out of hole to 100 ft. Pulled BHA. May 7 1996 (3) Made up BHA no. 4. R.I.H. to 732 ft. Drilled to 1989 ft. Circulated at 1989 ft. Pulled out of hole to 400 ft. R.I.H. to 1989 ft. Circulated at 1989 ft. Drilled to 2765 ft. May 8 1996 (4) Drilled to 3565 ft. Circulated at 3565 ft. Pulled out of hole to 1075 ft. R.I.H. to 3565 ft. Circulated at 3565 ft. Pulled out of hole to 500 ft. Pulled BHA. Ran electric logs. Rigged up Casing handling equipment. Ran Casing to 2068 ft (9.625 in OD). Worked toolstring at 2213 ft. May 9 1996 (5) Worked toolstring at 2760 ft. Ran Casing to 3553 ft (9.625 in OD). Circulated at 3553 ft. Mixed and pumped slurry - 659 bbl. Displaced slurry - 254 bbl. Rigged down Divertor. Rigged up BOP stack. Tested Well control. Installed Wear bushing. Made up BHA no. 5. R.I.H. to 1180 ft. Serviced Block line. R.I.H. to 3466 ft. Tested Casing - Via annulus and string. May 10 1996 (6) Tested Casing - Via annulus and string. Held drill (Kick (well kill)). Tested Kelly cocks. Drilled installed equipment - Float collar. Circulated at 3575 ft. Performed formation integrity test. Drilled to 4607 ft. Circulated at 4607 ft. Pulled out of hole to 3550 ft. R.I.H. to 4607 ft. Drilled to 5012 ft. Operations Summary for: 15-4,., May 24 1996 (20) Circulated at 10949 ft. Tested Casing - Via annulus and string. Pulled out of hole to 1080 ft. Pulled BHA. Held safety meeting. Made up DST tools - TCP guns. Ran Drillpipe to 2575 ft (2.875 in OD). Made up DST tools - Packer assembly. Ran Drillpipe to 10949 ft (3.5 in OD). Set packer at 8373 ft with 0 psi. Held safety meeting. Perforated from 9672 ft to 10942 ft. Laid down 8365 ft of Drillpipe. Laid down 1275 ft of Drillpipe. Held safety meeting. Laid down 1276 ft of Tubing. May 25 1996 (21) Laid down 1000 ft of Tubing. Held safety meeting. Rigged up Completion string handling equipment. Ran Tubing to 6235 ft (4.5 in OD). Rigged up sub-surface equipment- Landing nipple assembly. Ran Tubing to 8453 ft (4.5 in OD). Space out tubulars. Circulated at 8453 ft. Set packer at 8418 ft with 4000 psi. Tested Tubing. Tested Permanent packer. Rigged down Completion string handling equipment. Held safety meeting. Rigged down All functions. Installed Xmas tree. Tested All tree valves. Retrieved Hanger plug. Freeze protect well - 74 bbl of Diesel. May 26 1996 (22) Freeze protect well - 56 bbl of Diesel. Held safety meeting. Rig moved 100 %. Page 4 SPB~:~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -67.80 208.69 208.69 140.89 297.84 .297.84 230.04 388.15 388.14 320.34 417.60 417.59 349.79 465.53 465.51 397.71 511.87 511.83 444.03 541.62 541.57 473.77 571.44 571.37 503.57 601.21 601.09 533.29 631.08 630.85 563.05 660.71 660.33 592.53 687.80 687.26 619.46 776.48 775.32 707.52 866.16 864.32 796.52 956.35 953.80 886.00 1047.76 1044.43 976.63 1141.08 1136.92 1069.12 1234.77 1229.77 1161.97 1327.17 1321.42 1253.62 1419.23 1412.81 1345.01 1512.39 1505.34 1437.54 1606.04 1598.46 1530.66 1700.53 1692.57 1624.77 1793.23 1785.02 1717.22 1885.98 1877.64 1809.84 1979.37 1970.97 1903.17 2072.79 2064.37 1996.57 2165.77 2157.33 2089.53 2259.72 2251.26 2183.46 2354.32 2345.83 2278.03 2447.36 2438.82 2371.02 2538.53 2529.87 2462.07 2631.98 2623.13 2555.33 2725.07 2715.99 2648.19 DATE OF SURVEY: 052196 MWD SURVEY JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = 67.80 OPERATOR: ARCO ALASKA INC. COURS INCLN DG MN 0 0 0 4 0 20 1 6 0 52 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00N .00E S 74.80 E .03 .03S .12E N 19.40 W .43 .20N .09E N 8.40 W .85 1.31N .13W N 15.70 W .86 1.81N .23W 1 27 1 20 1 30 2 27 4 8 FT. 5 31 5 56 6 35~ 6 57 7 8 VERT. SECT. 7 19 7 35 7 43 7 38 7 0 .0O .13 -.00 -.66 - .96 6 49 6 30 5 34 4 43 3 37 N 15.40 W 1.19 2.75N .49W -1.59 N 37.50 W 1.18 3.74N .98W -2.44 N 72.00 W 2.88 4.14N 1.56W -3.14 S 72.40 W 5.09 4.07N 2.54W -4.00 S 61.20 W 6.02 3.36N 4.09W -5.11 2 20 1 29 0 57 1 16 1 16 S 57.10 W 4.76 2.06N 6.24W S 60.10 W 1.74 .52N 8.77W S 58.80 W 2.49 .99S ll.31W S 54.40 W .71 6.76S 20.04W S 52.80 W .30 13.29S 28.90W 1 19 2 17 3 35 3 40 4 19 S 55.00 W .37 19.97S 38.07W S 52.10 W .51 27.02S 47.60W S 48.60 W .52 34.95S 57.17W S 49.00 W .10 43.20S 66.59W S 45.40 W .84 51.19S 75.24W S 41.00 W .61 59.26S 82.83W S 37.60 W .54 67.62S 89.68W S 34.00 W 1.07 75.60S 95.46W S 32.10 W .92 82.71S 100.10W S 28.00 W 1.24 88.53S 103.51W S 24.40 W 1.39 92.84S 105.66W S 7.10 E 1.42 95.78S 106.30W S 79.50 E 1.62 97.13S 105.38W N 78.80 E .57 97.07S 103.60W N 79.30 E .00 96.67S 101.54W N 82.80 E .10 96.34S 99.42W N 79.40 E 1.05 95.86S 96.52W N 80.80 E 1.43 95.06S 91.89W N 82.90 E .16 94.23S 86.03W N 72.90 E 1.02 92.83S 79.72W -6.53 -8.19 -9.89 -15.44 -20.79 -26.36 -32.11 -37.53 -42.68 -47.24 -50.79 -53.56 -55.52 -56.79 -57.48 -57.65 -57.01 -55.62 -54.02 -52.31 -50.52 -48.08 -44.20 -39.21 -34.05 SPEk~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 DATE OF SURVEY: 052196 MWD SURVEY JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = 67.80 FT. OPERATOR: ARCO ALASKA INC. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2818.63 2809.23 2741.43 5 11 2912.87 2903.07 2835.27 5 15 3005.24 2995.05 2927.25 5 20 3100.20 3089.60 3021.80 5 19 3192.83 3181.83 3114.03 5 16 N 71.30 E .94 90.43S 72.35W N 73.10 E .19 87.81S 64.18W N 74.20 E .15 85.41S 56.00W N 76.40 E .22 83.17S 47.47W N 77.20 E .10 81.22S 39.13W -28.33 -21.99 -15.54 -8.70 -1.92 3285.45 3274.06 3206.26 5 15 3378.17 3366.39 3298.59 5 19 3494.97 3482.68 3414.88 5 19 3601.31 3588.56 3520.76 5 24 3692.89 3679.74 3611.94 5 11 N 74.40 E .28 79.13S 30.89W N 67.30 E .71 76.33S 22.83W N 70.20 E .23 72.40S 12.72W N 70.00 E .07 69.02S 3.37W N 68.60 E .27 66.03S 4.53E 4.71 10.88 18.45 25.55 31.51 3786.02 3772.50 .3704.70 3880.37 3866.46 3798.66 3973.53 3959.25 3891.45 4066.88 4052.08 3984.28 4162.28 4146.60 4078.80 5 8 5 10 5 6 6 54 8 34 N 65.70 E .28 62.78S 12.26E N 70.70 E .48 59.63S 20.12E N 78.60 E .76 57.43S 28.15E N 82.30 E 1.96 55.85S 37.78E N 85.90 E 1.82 54.58S 50.55E 37.19 43.04 49.43 57.54 68.63 4254.21 4237.48 4169.68 8 43 4348.40 4330.40 4262.60 10 6 4443.30 4423.50 4355.70 12 6 4535.41 4513.26 4445.46 13 46 4625.97 4600.81 4533.01 15 48 N 85.90 E .17 53.59S 64.34E N 86.80 E 1.47 52.62S 79.72E N 85.50 E 2.12 51.37S 97.96E N 81.20 E 2.09 48.93S 118.44E N 78.20 E 2.40 44.76S 141.17E 80.77 94.36 110.45 128.06 147.02 4719.57 4690.38 4622.58 17 51 4814.70 4780.51 4712.71 19 26 4908.26 4868.69 4800.89 19 36 5002.55 4957.19 4889.39 20 45 5097.08 5045.33 4977.53 21 36 N 76.60 E 2.23 38.83S 167.61E N 71.50 E 2.39 30.43S 196.80E N 71.80 E .21 20.58S 226.48E N 74.20 E 1.50 11.09S 257.59E N 74.50 E .91 1.88S 290.49E 168.62 191.70 214.62 239.00 265.11 5191.86 5133.47 5065.67 5280.89 5216.26 5148.46 5373.03 5301.76 5233.96 5466.59 5388.15 5320.35 5555.69 5469.90 5402.10 21 31 21 36 22 10 22 57 23 53 N 74.20 E .14 7.52N 324.04E N 76.60 E .99 15.77N 355.71E N 75.20 E .84 24.14N 389.03E N 76.30 E .95 32.98N 423.83E N 75.20 E 1.15 41.70N 458.16E 291.74 317.14 343.99 371.99 399.61 5648.16 5554.71 5486.91 23 4 5743.00 5641.95 5574.15 23 7 5835.17 5727.16 5659.36 21 40 5928.44 5813.97 5746.17 21 14 6020.91 5900.10 5832.30 21 26 N 71.80 E 1.71 52.14N 493.47E N 71.60 E .10 63.83N 528.79E N 70.60 E 1.63 75.19N 562.01E N 69.70 E .58 86.77N 594.10E N 72.50 E 1.12 97.66N 625.93E 427.42 454.71 480.23 504.63 529.07 SPEk~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 6113.14 5986.00 5918.20 6205.95 6072.49 6004.69 6300.07 6160.12 6092.32 6393.32 6246.80 6179.00 6485.87 6332.74 6264.94 21 16 21 15 21 31 21 43 21 51 6578.70 6418.88 6351.08 6672.05 6505.48 6437.68 6763.47 6590.32 6522.52 6856.06 6676.28 6608.48 6948.03 6761.90 6694.10 21 53 21 56 21 49 21 47 21 2 7043.90 6851.50 6783.70 7136.17 6937.95 6870.15 7229.54 7025.25 6957.45 7323.99 7112.77 7044.97 7416.91 7198.15 7130.35 20 38 20 16 21 16 22 50 23 38 7510.86 7284.44 7216.64 7604.41 7370.79 7302.99 7697.09 7456.86 7389.06 7790.02 7543.73 7475.93 7884.14 7631.66 7563.86 22 57 22 16 21 16 20 17 21 30 7978.07 7718.08 7650.28 8068.25 7800.39 7732.59 8164.09 7888.58 7820.78 8255.92 7973.50 7905.70 8349.40 8060.03 7992.23 24 35 23 38 22 25 22 19 22 8 8442.35 8146.37 8078.57 8537.71 8235.66 8167.86 8650.49 8341.50 8273.70 8745.76 8430.00 8362.20 8840.23 8516.19 8448.39 21 18 19 46 20 37 22 48 25 30 8879.58 8551.64 8483.84 8897.89 8568.08 8500.28 8929.72 8596.49 8528.69 8961.53 8624.25 8556.46 8993.19 8650.82 8583.02 25 57 26 15 27 21 31 1 34 51 DATE OF SURVEY: 052196 MWD SURVEY JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA INC. PAGE 67.80 FT. COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N 73.90 E .58 107.37N 658.08E N 73.20 E .27 116.90N 690.36E N 74.40 E .55 126.48N 723.33E N 73.90 E .29 135.87N 756.40E N 73.50 E .21 145.51N 789.38E N 75.40 E .76 154.79N 822.70E N 75.70 E .13 163.48N 856.45E N 75.50 E .15 171.95N 889.44E N 74.90 E .24 180.74N 922.70E N 74.40 E .84 189.63N 955.08E N 74.60 E .42 198.74N 987.94E N 74.40 E .41 207.36N 1019.02E N 75.20 E 1.12 216.03N 1050.98E N 75.10 E 1.65 225.13N 1085.26E N 75.30 E .87 234.49N 1120.71E N 74.30 E .84 244.23N 1156.57E N 75.20 E .83 253.70N 1191.27E N 74.30 E 1.13 262.73N 1224.44E N 74.70 E 1.07 271.55N 1256.23E N 75.70 E 1.33 280.12N 1288.69E N 77.70 E 3.39 288.53N 1324.47E N 78.50 E 1.10 296.14N 1360.53E N 78.10 E 1.29 303.74N 1397.25E N 77.90 E .14 311.00N 1431.43E N 77.30 E .31 318.60N 1465.97E N 77.60 E .90 326.08N 1499.56E N 78.00 E 1.61 333.15N 1532.26E N 76.50 E .87 341.75N 1570.24E N 76.60 E 2.30 349.95N 1604.51E N 73.50 E 3.15 359.97N 1641.83E N 73.90 E 1.25 364.77N 1658.23E N 73.50 E 1.90 367.03N 1665.96E N 74.70 E 3.85 370.96N 1679.77E N 79.60 E 13.76 374.37N 1694.89E N 83.20 E 13.58 376.91N 1711.91E VERT. SECT. 554.30 579.72 605.75 631.95 657.96 684.44 711.54 738.05 764.67 790.45 816.57 841.28 866.76 894.19 922.56 951.15 978.81 1005.24 1030.51 1056.49 1085.56 1115.22 1145.48 1173.58 1201.86 1229.32 1256.14 1287.13 1314.92 1344.73 1357.66 1363.76 1374.69 1387.04 1401.47 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 DATE OF SURVEY: 052196 MWD SURVEY JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = 67.80 OPERATOR: ARCO ALASKA INC. FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL- DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9025.01 8676.46 8608.66 9056.95 8701.27 8633.47 9088.91 8725.02 8657.22 9119.00 8746.04 8678.24 9150.94 8767.00 8699.20 37 46 40 17 43 42 47 41 50 15 N 86.30 E 10.81 378.62N 1730.67E N 88.70 E 9.20 379.49N 1750.76E S 86.60 E 14.53 379.07N 1772.13E S 85.60 E 13.44 377.59N 1793.61E S 82.90 E 10.27 375.17N 1817.57E 1417.83 1435.75 1455.37 1475.53 1498.34 9182.84 8786.42 8718.62 9214.25 8803.77 8735.97 9247.19 8820.18 8752.38 9278.90 8833.90 8766.10 9310.74 8844.91 8777.11 54 43 58 12 62 3 66 39 72 52 S 81.90 E 14.20 371.82N 1842.65E S 80.40 E 11.77 367.78N 1868.51E S 77.40 E 14.13 362.27N 1896.53E S 74.10 E 17.25 355.22N 1924.22E S 71.60 E 20.88 346.41N 1952.74E 1522.55 1547.75 1575.54 1603.66 1633.27 9342.77 8852.52 8784.72 9374.63 8856.28 8788.48 9406.64 8856.86 8789.06 9438.40 8855.59 8787.79 9462.68 8853.97 8786.17 79 86 91 93 94 37 49 4 28 11 S 69.90 E 21.73 336.15N 1982.09E S 68.00 E 23.36 324.79N 2011.60E S 62.70 E 21.22 311.45N 2040.67E S 55.10 E 25.07 295.07N 2067.82E S 52.20 E 12.28 280.72N 2087.33E 1664.23 1695.79 1727.77 1759.27 1782.98 9494.81 8852.07 8784.27 9527.04 8851.56 8783.76 9558.66 8851.89 8784.09 9591.29 8852.07 8784.27 9622.35 8851.97 8784.17 92 35 89 11 89 35 89 46 90 36 S 51.50 E 5.46 260.90N 2112.55E S 51.90 E 10.59 240.93N 2137.84E S 52.70 E 2.83 221.60N 2162.85E S 52.90 E .82 201.87N 2188.84E S 53.20 E 2.84 183.20N 2213.67E 1814.14 1845.44 1876.22 1908.05 1938.38 9654.28 8851.49 8783.69 9685.07 8850.53 8782.73 9717.00 8849.01 8781.21 9749.12 8847.80 8780.00 9780.04 8847.69 8779.89 91 6 92 27 92 58 91 20 89 3 S 51.40 E 5.85 163.68N 2238.92E S 47.10 E 14.63 143.60N 2262.23E S 42.30 E 15.10 120.93N 2284.66E S 37.10 E 16.95 96.25N 2305.15E S 33.10 E 14.92 70.96N 2322.93E 1969.46 1998.99 2028.80 2057.69 2084.35 9812.00 8848.37 8780.57 9843.84 8848.81 8781.01 9853.96 8848.79 8780.99 9875.62 8848.33 8780.53 9907.26 8846.70 8778.90 88 31 89 52 90 24 92 0 93 54 S 26.80 E 19.78 43.29N 2338.87E S 18.00 E 27.96 13.88N 2350.99E S 15.70 E 23.30 4.20N 2353.92E S 8.90 E 32.24 16.95S 2358.54E S 3.00 E 19.57 48.36S 2361.81E 2110.33 2133.56 2140.24 2153.20 2169.21 9938.97 8844.19 8776.39 9971.16 8841.60 8773.80 10002.85 8840.36 8772.56 10034.80 8840.26 8772.46 10066.63 8840.79 8772.99 95 94 90 89 88 10 4 24 58 7 S 1.50 E 6.21 79.94S 2363.05E S 1.70 E 3.50 112.01S 2363.95E S 2.40 E 11.79 143.65S 2365.08E S 2.70 E 1.64 175.57S 2366.50E S 2.70 E 5.81 207.36S 2368.00E 2183.44 2197.55 2211.70 2226.23 2240.78 SPERRY-SUN DRILLING SERVICES SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 10098.91 8841.90 8774.10 10130.37 8842.94 8775.14 10162.30 8844.16 8776.36 10194.20 8845.70 877.7.90 10226.05 8846.91 8779.11 10258.00 8846.79 8778.99 10289.87 8845.27 8777.47 10321.81 8843.27 8775.47 10353.67 8841.26 8773.46 10385.60 8839.42 8771.62 10417.50 8837.67 8769.87 10449.34 8836.14 8768.34 10481.25 8835.18 8767.38 10512.06 8834.64 8766.84 10543.96 8834.12 8766.32 10575.91 8833.57 8765.77 10607.76 8832.97 8765.17 10639.73 8832.30 8764.50 10671.57 8832.00 8764.20 10703.75 8832.21 8764.41 10735.43 8832.42 8764.62 10767.28 8832.85 8765.05 10797.60 8834.08 8766.28 10828.62 8835.92 8768.12 10860.42 8837.51 8769.71 10892.42 8838.87 8771.07 10924.22 8840.25 8772.45 10956.32 8841.73 8773.93 10987.15 8843.43 8775.63 11043.00 8846.73 8778.93 ANCHORAGE ALASKA DATE OF SLrRVEY: 052196 MWD SURVEY JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA INC. COURS INCLN DG MN PAGE 5 67.80 FT. COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 87 56 S 3.60 E 2.84 239.57S 2369.77E 88 16 S 5.10 E 4.89 270.92S 2372.16E 87 19 S 5.10 E 3.01 302.70S 2374.99E 87 10 S 5.90 E 2.55 334.41S 2378.05E 88 27 S 5.30 E 4.47 366.08S 2381.15E 91 58 S 4.50 E 11.27 397.91S 2383.88E 93 28 S 3.20 E 6.25 429.67S 2386.02E 93 43 S 2.80 E 1.47 461.50S 2387.69E 93 28 S 3.10 E 1.22 493.26S 2389.32E 93 8 S 3.30 E 1.23 525.08S 2391.10E 93 8 S 2.60 E 2.19 556.89S 2392.74E 92 22 S 1.50 E 4.21 588.67S 2393.88E 91 4 S .60 E 4.93 620.56S 2394.47E 90 56 S 1.40 E 2.63 651.36S 2395.00E 90 55 S 1.40 E .09 683.25S 2395.78E 91 3 S 1.20 E .75 715.18S 2396.51E 91 6 S .10 E 3.46 747.02S 2396.87E 91 17 S .10 E .56 778.99S 2396.92E 89 46 S .50 E 4.91 810.82S 2397.09E 89 28 S 2.20 E 5.36 842.99S 2397.85E 89 45 S 1.80 E 1.52 874.65S 2398.95E 88 42 S 3.20 E 5.48 906.46S 2400.34E 86 38 S 3.10 E 6.84 936.71S 2402.01E 86 33 S 4.50 E 4.51 967.60S 2404.06E 87 43 S 4.10 E 3.89 999.27S 2406.44E 87 24 S 4.00 E 1.02 1031.16S 2408.70E 87 37 S 4.50 E 1.72 1062.84S 2411.05E 87 4 S 4.30 E 1.85 1094.82S 2413.51E 86 36 S 5.30 E 3.57 1125.49S 2416.09E 86 36 S 5.30 E .04 1181.00S 2421.24E THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2693.91 FEET AT SOUTH 63 DEG. 59 MIN. EAST AT MD = 11043 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 114.50 DEG. VERT. SECT. 2255.75 2270.92 2286.68 2302.61 2318.57 2334.25 2349.37 2364.09 2378.74 2393.56 2408.24 2422.46 2436.21 2449.47 2463.41 2477.31 2490.84 2504.15 2517.50 2531.53 2545.67 2560.12 2574.18 2588.86 2604.16 2619.44 2634.72 2650.22 2665.28 2692.99 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 DATE OF SURVEY: 052196 JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = 67.80 OPERATOR: ARCO ALASKA INC. FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAI~G~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -67.80 .00 N .00 E 1000.00 997.09 929.29 23.16 S 42.63 W 2000.00 1991.59 1923.79 96.31 S 106.23 W 3000.00 2989.83 2922.03 85.55 S 56.47 W 4000.00 3985.61 3917.81 56.96 S 30.46 E .00 2.91 2.91 8.41 5.50 10.17 1.76 14.39 4.22 5000.00 4954.80 4887.00 11.34 S 256.72 E 6000.00 5880.64 5812.84 95.37 N 618.64 E 7000.00 6810.42 6742.62 194.63 N 973.02 E 8000.00 7738.02 7670.22 290.48 N 1333.39 E 9000.00 8656.39 8588.59 377.35 N 1715.81 E 45.20 30.81 119.36 74.17 189.58 70.22 261.98 72.39 343.61 81.64 10000.00 8840.39 8772.59 140.81 S 2364.96 E 11000.00 8844.19 8776.39 1138.26 S 2417.27 E 11043.00 8846.73 8778.93 1181.00 S 2421.24 E 1159.61 816.00 2155.81 996.20 2196.27 40.46 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCt{ORAGE ALASKA PAGE SFIARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 DATE OF SURVEY: 052196 JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = 67.80 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -67.80 67.80 67.80 .00 167.80 167.80 100.00 267.80 267.80 200.00 367.81 367.80 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .02 S .07 E .00 .00 .03 N .15 E .00 .00 .93 N .07 W .01 .01 467.83 467.80 400.00 567.86 567.80 500.00 668.22 667.80 600.00 768.90 767.80 700.00 869.66 867.80 800.00 2.80 N .51 4.11 N 2.39 .11 N 9.46 6.22 S 19.30 13.55 S 29.25 W .03 .02 W .06 .04 W .42 .36 W 1.10 .68 W 1.86 .76 970.47 967.80 900.00 1071.33 1067.80 1000.00 1172.24 1167.80 1100.00 1273.14 1267.80 1200.00 1373.90 1367.80 1300.00 21.00 S 39.54 28.93 S 50.06 37.72 S 60.31 46.55 S 70.44 55.21 S 79.26 W W W W W 2.67 .81 3.53 .86 4.44 .91 5.34 .90 6.10 .76 1474.61 1467.80 1400.00 1575.23 1567.80 1500.00 1675.68 1667,80 1600.00 1775.98 1767.80 1700.00 1876.14 1867.80 1800.00 64.22 S 87.05 73.11 S 93.79 80.97 S 99.01 87.57 S 102.99 92.47 S 105.50 W 6.81 .71 W 7.43 .62 W 7.88 .45 W 8.18 .30 W 8.34 .16 1976.20 1967.80 1900.00 2076.22 2067.80 2000.00 2176.24 2167.80 2100.00 2276.27 2267.80 2200.00 2376.29 2367.80 2300.00 95.70 S 106.31 97.14 S 105.32 97.02 S 103.37 96.60 S 101.18 96.27 S 98.92 W 8.40 .06 W 8.42 .02 W 8.44 .02 W 8.47 .02 W 8.49 .03 2476.36 2467.80 2400.00 2576.54 2567.80 2500.00 2676.74 2667.80 2600.00 2777.04 2767.80 2700.00 2877.45 2867.80 2800.00 95.64 S 95.37 94.68 S 89.54 93.85 S 83.18 91.63 S 75.89 88.76 S 67.28 W W W W W 8.56 .07 8.74 .18 8.94 .21 9.24 .29 9.65 .41 2977.87 2967.80 2900.00 3078.31 3067.80 3000.00 3178.74 3167.80 3100.00 3279.16 3267.80 3200.00 3379.59 3367.80 3300.00 86.11 S 58.46 83.65 S 49.44 81.51 S 40.39 79.29 S 31.44 76.28 S 22.71 W W W W W 10.07 .42 10.51 .44 10.94 .43 11.36 .42 11.79 .43 SPEk~Y-SUN DRILLING SERVICES ANCI~ORAGE ALASKA PAGE 8 SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 DATE OF SURVEY: 052196 JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = 67.80 OPERATOR: ARCO ALASKA INC. FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3480.02 3467.80 3400.00 3580.46 3567.80 3500.00 3680.90 3667.80 3600.00 3781.31 3767.80 3700.00 3881.71 3867.80 3800.00 72.87 S 14.03 W 69.69 S 5.22 W 66.43 S 3.52 E 62.95 S 11.87 E 59.59 S 20.23 E 12.22 .43 12.66 .44 13.10 .43 13.51 .41 13.91 .41 3982.11 3967.80 3900.00 4082.72 4067.80 4000.00 4183.72 4167.80 4100.00 4284.88 4267.80 4200.00 4386.40 4367.80 4300.00 57.27 S 28.90 E 55.60 S 39.67 E 54.35 S 53.74 E 53.26 S 68.98 E 52.23 S 86.43 E 14.31 .40 14.92 .60 15.92 1.00 17.08 1.16 18.60 1.52 4488.64 4467.80 4400.00 4591.67 4567.80 4500.00 4695.84 4667.80 4600.00 4801.22 4767.80 4700.00 4907.31 4867.80 4800.00 50.53 S 107.57 E 46.67 S 132.03 E 40.51 S 160.53 E 31.85 S 192.55 E 20.68 S 226.18 E 20.83 2.23 23.87 3.03 28.04 4.18 33.42 5.38 39.51 6.09 5013.90 4967.80 4900.00 5121.25 5067.80 5000.00 5228.77 5167.80 5100.00 5336.37 5267.80 5200.00 5444.49 5367.80 5300.00 10.00 S 261.46 E .50 N 299.07 E 11.19 N 337.08 E 20.62 N 375.65 E 30.94 N 415.45 E 46.10 6.59 53.45 7.35 60.97 7.51 68.57 7.60 76.69 8.12 5553.39 5467.80 5400.00 5662.38 5567.80 5500.00 5771.10 5667.80 5600.00 5878.90 5767.80 5700.00 5986.21 5867.80 5800.00 41.46 N 457.26 E 53.88 N 498.77 E 67.31 N 539.26 E 80.55 N 577.24 E 93.85 N 613.83 E 85.59 8.90 94.58 8.99 103.31 8.72 111.10 7.79 118.41 7.31 6093.61 5967.80 5900.00 6200.92 6067.80 6000.00 6308.32 6167.80 6100.00 6415.92 6267.80 6200.00 6523.65 6367.80 6300.00 105.41 N 651.27 E 116.38 N 688.61 E 127.29 N 726.25 E 138.19 N 764.43 E 149.49 N 802.87 E 125.81 7.40 133.12 7.31 140.52 7.41 148.12 7.60 155.85 7.73 6631.42 6467.80 6400.00 6739.21 6567.80 6500.00 6846.92 6667.80 6600.00 6954.35 6767.80 6700.00 7061.32 6867.80 6800.00 159.73 N 841.74 E 169.70 N 880.72 E 179.86 N 919.42 E 190.24 N 957.26 E 200.37 N 993.86 E 163.62 7.78 171.41 7.79 179.12 7.71 186.55 7.43 193.52 6.97 SPER~f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/15-43 500292267600 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/31/96 DATE OF SURVEY: 052196 JOB NUMBER: AK-MW-60053 KELLY BUSHING ELEV. = 67.80 OPERATOR: ARCO ALASKA INC. FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7167.99 6967.80 6900.00 210.32 N 1029.63 E 200.19 6.67 7275.23 7067.80 7000.00 220.29 N 1067.07 E 207.43 7.25 7383.78 7167.80 7100.00 231.12 N 1107.86 E 215.98 8.54 7492.79 7267.80 7200.00 242.32 N 1149.78 E 224.99 9.01 7601.17 7367.80 7300.00 253.38 N 1190.09 E 233.37 8.39 7708.83 7467.80 7400.00 263.89 N 1228.54 E 241.03 7.66 7815.68 7567.80 7500.00 273.90 N 1264.81 E 247.88 6.85 7923.17 7667.80 7600.00 283.64 N 1302.98 E 255.37 7.49 8032.67 7767.80 7700.00 293.28 N 1346.52 E 264.87 9.50 8141.61 7867.80 7800.00 301.97 N 1388.86 E 273.81 8.94 8249.76 7967.80 7900.00 310.51 N 1429.15 E 281.96 8.15 8357.79 8067.80 8000.00 319.29 N 1469.06 E 289.99 8.03 8465.35 8167.80 8100.00 327.87 N 1507.72 E 297.55 7.56 8571.86 8267.80 8200.00 335.55 N 1543.57 E 304.06 6.52 8678.59 8367.80 8300.00 344.06 N 1579.86 E 310.79 6.72 8786.96 8467.80 8400.00 353.96 N 1620.39 E 319.16 8.37 8897.58 8567.80 8500.00 366.99 N 1665.84 E 329.78 10.62 9014.18 8667.80 8600.00 378.10 N 1724.18 E 346.38 16.60 9152.30 8767.80 8700.00 375.00 N 1818.67 E 384.50 38.13 11043.00 8846.73 8778.93 1181.00 S 2421.24 E 2196.27 1811.77 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY- PBU/i$-q3 500292267600 052196 NORTH SLOPE BOROUGH SUN DR T LL T NO VERTI~ClqL PROJECTION 1LifO- 2820 - I'~ L1280- .._J CE r,._) ~ 56Lt0- LLI LJ r-'r- 7050- p-- 8L~60 9870 SSDS 3.13 88L1:6. 01-t3 6 l~io 28~o VEIST I EFIL SECT I ON 2693.05 FEET ItT S 65 BEG 30 M IN E SERVICES STRRT TVO = 0.00 FINISH TVO = 88q6.93 SCRLE IS lqlO FEET/IN C: \SURVE'r\ 15u, 3 SPERRY-SUN PBU/15-q3 500292267600 052196 NORTH SLOPE BOROUGH OR -LLTN. O HORIZONTFtL PROJECTION SERVICES STflRT TVD = 0.00 FINISH TVD = 88q6.93 SCRLE IS q70 FEET/IN HORIZONTAL DISPLACEMENT IS 2693.97 DEPFtRTURE -200 270 ?riO 1210 1680 2 i 50 I i i I i i ERST 2620 qO0 -7O -5qO- l-- -1010 -1~80. -1950 -2q20 llOq3 SSOS 3.13 C:\SURVET\ISq3 ri I~! I I__1__1 ~ G S I:=: !::! L~ I r' I~ S WELL LOG TRANSMITTAL To: State of Alaska June 19, 1996 Alaska Oil and Gas Conservation Comm. Atm.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 15-43, RE: AK-MM-960527 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 15-43: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22676-00 2" x 5" TVD Resistivity and Cramma Ray Logs: 50-029-22676-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia N~a Oi~ & G~s Co~s. Comm'~ssion 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company 0 I~! I I_1_ I I~J 13 S ~ FlVl r' ~=: S June 17, 1996 AOGCC Howard Oakland 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 15-43 Dear Mr. Oakland, Enclosed are two hard copies of the above mentioned file(s). Well 15-43 MWD survey, from surface to interpolated depth 11,043' Please call me at 563-3256 if you have any questions or concerns. 1 Relgar s,d~/~./'' '- L/:/~- 1/ ._ , X II Duane V~g~ ......... Operations Engineer Attachments. JU~'I ~ 7 ~99g 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 May 1996 RE: Transmittal of Data ECC #: 6676.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: 15-43 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: u./1 DIFL FINAL BL+RF Run # 1 ~ BH PRO FINAL BL+RF Run # 1 ~-~ SSVD FINAL BL+RF Run # 1 C.2f DLL FINAL BL+RF Run # 2 ~-~ CN FINAL BL+RF Run # 2 DAC FINAL BL+RF Run # 2 SSVD FINAL BL+RF Run # 2 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 MEMORANDUM TO: David Johnste~ Chairm ~af¢~ THRU: Blair Wondzell, ~- P. I. Super,'isor ~"/~/-;~' FROM: Lou Grimaldi, ~"- Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 8, 1996 FILE NO: AGGJEHDD.DOC SUBJECT: BOPE Test Doyon rig #9 Doyon rig #9 Arco well #15-43 Prudhoe Bay Field PTD #96-83 Wednesday, May 8, 1996: I witnessed the initial BOPE test on Doyon rig #9 which was drilling Arco well #15-43 in the Prudhoe Bay Field. The rig was ready to test when I arrived. I toured the area surrounding the rig and found it to be kept clean and orderly. The test once started went very well. The Kelly valves both had a small amount of leakage and will be repaired before the rig drills out. The rest of the BOPE tested out OK and as usual i found the upkeep of this rig to be good. SUMMARY:'. I witnessed the initial BOPE test on Doyon rig #9. There were two failures, the Kelly valves. Test time 3 hours. Two failures. Attachments: AGGJEHDD.XLS CC: Scott SigurdsenFFom Horten.(Prudhoe Bay drlg.) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8 Test: Initial X Workover: DATE: Doyon Rig No.- 14 PTD # 96-83 Rig Ph.# ARCO Alaska Inc. Rep.: Vance Hazard . 5-43 Rig Rep.: Mark Egholm Set @ 3,555 Location: Sec. 22 T. 11N R. 14E Meridian Umiat Weekly Other 5/8/96 659-4510 TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 250/3000 ~ 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P ~2,S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 F 500/5,000 F 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 500/5, 000 P 38 500/5,000 P I P Functioned Func~oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2500 Average 3,000 P 1,800 P minutes 45 minutes 27 P Remote: Psig. sec. sec. P TEST RESULTS Number of Failures: 2 ,Test Time: 2.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within N/A 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, Please give better notice on upcoming tests.(Initial BOP tests are required witness by permit) Upper and lower Kelly failed. Repair and retest. Notify inspector with results.," 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 NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) AGGJEHDD.XLS BP EXPLORATION To: B. Wondzell Oato: April 23, 1996 From: J. Smith Subject: Dispensation for 20 AAC 25.035 (7)(b) on DS 15 Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon historical drilling experience on Drill Site 15 in the Eastern Operating Area of the Prudhoe Bay Unit. To date, there have been 45 wells drilled on DS 15, none of these wells experienced any difficulty with shallow gas in the interval prior to placement of surface casing. The attached spider plot identifies each wellbore with a 200' radius circle at a depth of 3600' along the wellbore to highlight the extent to which the shallow subsurface interval has been explored. In light of the historical evidence indicating minimal risk due to shallow gas at this location, we conclude that furore wells on the pad can be safely drilled without the installation of the diverter system. Should any of the future wells require placement of surface casing at a depth deeper than that used historically (which is just above the SV3 sand at about 3600' TVD) the diverter system would be installed. Sincerely, SSD Engineer TONY KNOWLE$, GOVERNOR May 1, 1996 ALASKA OII, ~ GAS CONSERYATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Terry Jordan, Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 15-43 ARCO Alaska, Inc. 96-083 47062qSL, 5172'WEL, Sec 22, TllN, R14E. UM 1662'SNL, 2488'EWL, Sec 22, T1 IN, R14E, UM Dear Mr Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were nm. The documentation submitted should assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Your requested waiver of the diverter system described in 20 AAC 25.035 (7)(b) for this well is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission max, witness the test. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. - David W. Johnston [ -- oPera OF CO ssIo ljb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encI STATE OF ALASKA ALASKA rilL AND GAS CONSERVATION CO~vIMISSlON PERMIT TO DRILL 20 AAC 25.005 Jla. Typeofwork I~Drill I-IRedrill Ilb. Type ofwell I-IExploratory I-IStratigraphic Test I~Development Oil : [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 66.4' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028306 :~4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4706' NSL, 5172' WEL, SEC. 22, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 580' SNL, 2406' EWL, SEC. 22, T11 N, R14E 15-43 Attotal depth 9. Approximate spud date Amount $200,000.00 1662' SNL, 2488' EWL, SEC. 22, T11N, R14E 05/03/96 i12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028307 2792'I 15-33, 15' at surface 2560 10932' MD / 8866' TVD i16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 200' Maximum Hole Angle 90° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig i18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 47# N-80 BTC 3504' 30' 30' 3545' 3534' 1137 sx cs III, 305 sx'G', 250 sx CS II 8-1/2" 7" 26# L-80 BTCM 8568' 30' 30' 8598' 8296' 213 sx Class 'G' 6" 4-1/2" 12.6# L-80 NSCT 2484' 8448' 8157' 10932' 8866' 273 sx Class 'G' !19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface i'':~ i'i'; i: ..... :.i.i'J ~: '!', :::' 'i'; Intermediate Production Liner /".!':'!-~ ',~.:i ";.' :~!;'il :., ,..; --'-,~; ;-'.. ~':~::-. (';:.7:.;. Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared By Name/Number Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~.~...,~, Tern/Jordan "~¢'~¢ //''~ Title Senior Drilling Engineer Date ~t/7 ¢~, Commission Use Only :. ~"_,~-- ~',,~ 50- O~- ~-- '~' ~-- ~' 7~' f_~// / ~ (/ for other requirements Conditions of Approval: Samples Required [] Yes ]~] No Mud Log Required [] Yes ,1~ No Hydrogen Sulfide Measures ,]~]Yes [] No Directional Survey Required ,~] Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~ 5M; [] 10M; [] 15M Other: Original Signed By by order of Approved By David W .Inhn~,~m~ Commissioner the commission Date.~/'/ Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX - Shored Services Drilling Alaska State Plane: Zone4 PBU : EOA: DS15 15-Spider WEU. PLAN FEASIBILITY STUDY Thlm plan is for feasibility purposes only it has not yet been certifledl ~-_-_-_-_-_-_-_-_-_~% N TON PLOT INFORMATION DI::~WING NAME / FILE NAME DS l& ~(M,i'/ SURFACE LOCATION No~: ~ ~ ~ ~ 0.00 RTE FL: ~ ~ ~ Ver~ By : CeAEI~ ~ : I Well Name: 115-43 Well Plan Summary ]Type of Well (producer or injector): I Producer Surface Location: 4706' FSL, 5172' FEL, sec 22, T1 IN, R14E X=676024.40 Y=5960908.73 Target Location: 580' FNL, 2406'FWL, sec 22, TllN, R14E X=678320 Y=5960960 Bottom Hole Location: 1662' FNL, 2488'FWL, sec 22, T1 iN, R14E X=678430 Y=5959880 I AFE Number: 14J0306.0 I I Rig: I DOYON 14 Estimated Start Date: I May 03, 1996I Operating days to 125 complete: I Well Design (conventional, slimhole, etc.):I Ultra-Slimhole Horizontal Formation Markers: Formation Tops MD TVD Comments (BKB) Base of Permafrost 1973 1900 9-5/8" Casing 3545 3534 Set above the T5 TT4/T5/SV3 3555 3544 UGNU Sands 5422 5352 Ugnu S marker WEST SAK 6243 6113 SEABEE (K- 12) 6476 6329 K-5 7711 7474 PUT RIVER 8258 7981 BHRZ is 8252'MD, 7976'TVD LCU (KINGAK) 8288 8009 SAG RIVER 8544 8246 SHUBLIK 8587 8286 7" Casing 8598 8296 Sadlerochit (Z 4) 8662 8356 Zone 3 8824 8506 Zone 2 8889 8566 GOC 9167 8776 Zone 1 9167 8776 Kavik 9842 8866 Begin Lateral @ 9846'MD,8866'TVD End of Lateral 10932 8866 Lateral is 1086'MD in length Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 30" 20" 91.5# H40 WEIRD 80' 30'/30' 110'/110' 12-1/4" 9-5/8" 47# N-80 BTC 3504' 30'/30' 3545'/3534' 8-1/2" 7" 26# L-80 BTCM 8568' 30'/30' 8598¥8296' 6" 4 1/2" 12.6# L80 NSCT 2484' 8448'/8157' 10932'/8866' NA 4 1/2" 12.6# LB0 IBTMod 8418' surface 8448' Logging Program: I Open Hole Logs: I Cased Hole Logs: 12-1/4" MWD Dir 8-1/2" MWD Dir from surface shoe to intermediate casing point. Sample catcher from Zone 2 to TD. 6" MWD Dir/GR to TD GR-DEN-NPHI-RES-SONIC from+/-9950' (at horizontal) to Casing shoe GR w/PRIMARY DEPTH CONTROL-PDC (post rig work) Mud Program: Special design MI Flow Pro ® Polymer system in 6" horizontal hole section. considerations Higher mud weight in the surface hole possibly needed due to Cretaceous interval injection. Surface Mud Properties: I 12-1/4" hole section Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 300 60 60 80 8.5 25 to to to to to to to 9.8 100 20 15 20 10 20 Intermediate Mud Properties: [ 8-1/2" hole section Density Plastic Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.4 8 10 5 30 8.5 15 to to to to to to to 10.4 15 25 15 50 10.5 5 Production Mud Properties: I 6" hole section Density LSRV Yield 10 sec 10 min pH Fluid (PPG) (cps) Point gel gel Loss 8.5 50,000 40 18 24 8 <6 to to to to to to to 9.0 75,000 45 23 29 9 <6 Well Control: Well control equipment consisting of 5000 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. Directional: I KOP: 1 200' MD Maximum Hole Angle: Close Approach Well: 90degrees, start @9846'MD nearest wells 15-49 (30'south) & 15-33 (15' north) at surface. Both will be shut-in during rig up and rig down of the drilling operation.No downhole close approach. Cement Data: Casing/Liner Lead: Sxs/Wt/Yield 9-5/8" 1137/12.2/1.92 ** 110% excess lead Top Out Job 250/14.95/0.96 7" n one 4-1/2" none Tail: Sxs/Wt/Yield Comments 305/15.8/1.15 Cold Set III & Class "G" Top Out-~CSII 213/15.8/1.14 TOC-7258' +/- (1000' above Put R.) 273/15.7/1~.1~. Class "G"Acid resist. ** Lead cement volume has been increased to 110% excess ~nstead of the normal 100% excess based upon the indicator from the 15-45 well (dropping pH) which indicated that cement was very near to the surface on that well. Contacts Name Office Home Pacjer James E. Smith David Nims Drilling Eng. Drilling Supt. 564-5026 345-8660 275-4015 564-5219 346-2026 275-4539 Drilling Hazards Surface Hole Possible tight hole in both the permafrost and lower zone, hole enlargement and casing drag. Hole cleaning is critical, design flowrates high enough to clean the expected washed out hole, not gauge hole. It is recommended that there be a wiper trip made at midpoint of the interval, and another at TD. Drill, case and cement the surface hole as fast as possible. Faulting In many wells on Drill Site 15, drilling through faults has resulted in catastrophic lost returns. Be aware that faults are present on Drill Site 15 and are known to be conductive. The asset have listed as a major uncertainty the presence and location of smaller conductive faults. A fault with up to 40' of throw is possible within the Sadlerochit between 9000'MD and 9350'MD. No other faults have been prognosed within the target polygon. Close Approaches The nearest surface well, 15-33 is 15ft north from the 15-43 wellhead. The 15-49 well is located 30ft south of the 15-43. Both wells will be shut- in and secured during the move in and rigup/rig down. The wells can be returned to service after rig up and until just before rig release. There are no deep close approaches. Pore Pressure Expectations CRETACEOUS: (3555MD-6476MD) The Cretaceous interval on Drill Site 15 has possible overpressured sands in the T-5 to K12 intervals. The degree of overpressuring will depend at any given time on the daily injection volume at GC3-D. The 15-48, drilling on Jan 23, 1996, had flow between 4000-5675 MD, (4000-5630 TVD). Mud weight had to be raised from 9.3 ppg to 9.8 ppg. Close contact with the onsite pad supervisor on the injection status at GC3-D is necessary. It is recommended that a 9.8 ppg mud is in the hole prior to 4500 TVD. K-5 to BASE HRZ: (7711MD-8252MD) Pore pressures should be in the normal range considering shales (9.2-9.5 ppg) but 9.8 ppg should be maintained due to Cretaceous overpressure. PUT RIVER: (8258MD-8288MD) Some gas cut mud problems have been observed. It is recommended that mud weight be 10.4 ppg at the Put River. 15-48 drilled into the Put River with 10.0 ppg mud, the mud was gas cut and the weight was raised in steps to 10.4 ppg before drilling ahead while prior wells this year and late last year on DS 15 drilled the Put River with 10.0-10.1 ppg. The 10.4 ppg weight should produce sufficient overbalance for the Put River. High levels of cuttings gas should be expected from this interval. If gas-cut mud becomes a problem, pick up off bottom and circulate the gas cut mud out of the system. If after circulating bottoms up the gas still appears in the mud, raise the mud weight by 0.1-0.2 ppg and circulate the gas out. Continue drilling if the well appears stable. SAG RIVER: (8544MD-8587MD) No DS 15 well drilled during the 1995-96 season has seen problems with the Sag while drilling with 9.0-10.4 ppg fluid. SADLEROCHIT (8662MD'-TD)' Current pore pressure in the Sadelrochit is 3550 psi @ 8800' TVDss (7.7 ppg EMW). Mud weights used on DS 15 previously were 8.8 - 9.3 ppg. Lost Circulation Lost circulation has been a serious problem on Drill Site 15, but catastrophic losses have been primarily associated with crossing faults. Be prepared to handle massive lost circulation associated with faults following M-I's recommendations, a prototype (Damaging) massive loss circulation prevention fluid has been developed but not tested, use is decided on a case by case condition. Check with D. Nims before use. Lost circulation from seepage has been most common at mud weights greater than 10.2 ppg, with loss rates of 20 - 50 bph. Be prepared to handle lost circulation while drilling below the Put River, If lost circulation due to seepage occurs and is at a Iow rate, OM Seal and Liquid Casing have shown to be effective. In cases of catastrophic losses, pre-treatment with calcium carbonate followed by Maraseal has been effective in controlling losses. · Stuck Pipe There has been several cases of stuck pipe, 15-6 Cretaceous, 15-24 Ivishak and 15-4 Ivishak zone 2. There were also some cases of tire hole. Stuck pipe potential for this well is highest in the Sag River and Shublik due to the decrease in pore pressure, and in the Kingak due to mud weights too Iow for the stabilization of the shales. ° Surface Casing Shoe Kick Tolerance The smallest kick tolerance for the casing shoes is calculated as 26 bbls of influx assuming a swabbed gas influx at the top of the Put River along the planned directional path. Based on 10.2 ppg MW (8258'MD & 7981'TVD, 10.2 ppg reservoir pore pressure, and a 12.5 ppg shoe test. 15-43 DRILLING AND COMPLETION PROGRAM , MIRU drilling rig. N/U diverter and function test same. Ensure diverter setup conforms to diagram posted with AOGCC, and that the flowlines to the production skid are protected. Note that we are requesting a variance for the diverter installation , Drill 121/4" hole to surface casing point (10' TVD above the T5) as per Recommended Practices for Surface Hole, V I.0. Hole cleaning is critical, design for flowrates on washed out hole, not gauge. Drill, case and cement the surface hole as fast as possible. Run and cement 9-5/8" surface casing. Monitor displacement from pit volume. NU BOPE, function test and pressure test to 5000 psi. . PU 8-1/2" BHA and RIH. Test casing to 3000 psi for 30 minutes. Perform a well kill drill. Drill 10' of new hole and perform leak off test. Expected LOT is at least 13.1ppg EMW based on the 15-49 (3/96) and 15-45 (4/96). , RIH and drill 81/2" hole as per directional program to 10'TVD into the Shublik formation, ensure rat hole to provide casing shoe into the Shublik. Follow the Recommended Practices for Intermediate Hole VI.0. , MU and RIH with 7" casing string with RA tag (from Atlas) 5 joints above the shoe and cement as per well plan to put cement 1000' above the Put River. Monitor displacement volume from pit strap to doublecheck accuracy. , MU 6" MWD BHA and PU 3-1/2" DP. Clean out to 7" float collar and test casing to 3500 psi for 30 min. Perform a well kill drill. Drill 10' of new hole and run a formation integrity test at 0.5 ppg or more than the expected mud weight to be used to drill the section. Displace to 9.0 ppg used FIo Pro mud system. Drill ahead following the directional plan, picking up the build BHA and completing that section to horizontal Follow the Recommended Practices for Production Hole, VI.0. , Drill the horizontal section, limit tricone bit runs on the medium speed motor to about 20 hr. The 6 inch BHA will have MWD/GR tools, a recorded resistivity tool is planned following after the build into the horizontal section is done. , Full suite open hole logging is requested for this section from reaching horizontal at approx. 9950'MD to 7 inch shoe. , If required, run solid (Baker) hole opener to TD of 6" hole. Circulate hole clean. If the hole opener run is required the BHA should be: Hole Opener, NB stab, HWDP, Jars, HWDP, DP. 10. Run 41/2", L-80 solid liner assembly to bottom. Space the liner hanger and packer 150' above the 7" casing shoe. 11. 12. 13. 14. 15. 16. 17. 18. Cement the liner in place with the total cement volume based on 30% excess in the openhole, 150' liner lap, top of cement 200' above the liner with drillpipe in the hole, and 80' shoe volume. Set liner hanger and packer. Unsting running tool and reverse circulate excess cement from the wellbore. POOH. RIH with clean-out mill. Olean out to landing collar. Pre-test liner and liner lap to 3500 psi for 5 minutes to verify integrity. Displace well to clean, filtered, seawater. Perform required test of liner and liner lap to 3500 psi for 30 minutes. RIH with 2 3/4" drillpipe conveyed perforating guns and perforate the 41/2" liner. POOH and lay down guns. RIH with 41/2'' L-80 completion with SSSV, 3-GLMs (4-1/2" KBG-2-LS(mod)), and 7" x 41/2" packer. Packer should be set with the wireline reentry guide spaced out to set in the liner tieback stem. Circulate filtered treated seawater. Set packer and test tubing to 4000 psi. Refer to the Recommended Practices for Running Tubing, V$.2. Set 2-way check valve. Test to 1000 psi. ND BOPs. NU tubing head adapter and tree. Test same to 5000 psi. Pull 2-way check valve. Test 41/2" x 7" annulus to 3500 psi with 2000 psi on tubing. Shear RP valve. Freeze protect well through shear valve in top GLM station. Set BPV, Release rig. Disposal Cuttings Handling: Fluid Handling: Cuttings should be hauled to the ball mill at CC-2A. All drilling and completion fluids can be annular injected. Well DS 15-43 is being permitted for annular injection. Request to AOGCC for Annular Pumping Approval For DS 15-43 1. Approval is requested for Annular Pumping for well DS 15-43 and any well on the pad/drillsite previously permitted for disposal activities by AGOCC. 2. The Base of the Permafrost for all wells located in the PBU Unit is 1900 feet. Aquifers in the PBU Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #1 as referenced in Area Injection Order #4 (PBU-EOA). 3. The receiving zone to which the fluids will migrate is identified as the Sagavanirtok (Tertiary/Cretaceous Sands) geological formation at 3544'TVD. The confining layer is the overlying shales above the SV3, defined by the base of the permafrost and 3544 'TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7/25/95. 4. There are 55 wells on Pad/Drillsite 15. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5- 6. The drilling wastes to be disposed of during this operations can be defined as drilling muds and cuttings, rig wash up and waste water, cement wash up water, brine, and formation fluids. The maximum volume to be disposed of in the annulus is 35,000 bbls. The maximum density is 17 ppg. 7. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 1525 psi for a 17 ppg fluid in this well. MASP - 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 8. The 9-5/8" casing shoe will be set at 3545'md (3534' tvd) and cemented with 1442 sacks of cement. This depth is below the base of the permafrost (1900'TVD) and into the SV3 formation which has a long established history of annular pumping at PBU. 9. The burst rating (80%) for the 9-5/8" casing is 5496 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Ugnu formation is 13.5 ppg equivalent mud weight. 10. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (aBE) VOL (SaL) PBU DS 15-43 0 35000 submitted NOTE: SSD Annular Injection Checklist will be completed and evaluated before commencement of annular injection on this well (15-43). 95/8" Surface Casing-Cementing Program Casing Size: 95/8'', 47#, N-80, BTC @ 3545'MD Circ. Temperature: 40°F Spacer: 75 bbls fresh water ahead of lead slurry. Cement Volume Basis 1. Lead slurry to surface w/l10% excess. 2. Tail slurry volume 500' fill w/100% excess 3. Top job volume 250 sx if no cement returns to surface Lead Cement Type: BJ Coldset 1II + 1 ghs FP-6L 12.2 ppg 1.92 ft3/sx 10.53 gps 1137 389 Thickening Time 4.00 hrs + Tail Cement Type: Class G + 2% A-7 CaC1 + 1 ghs FP-6L (all volumes to be recalculated at location prior to job.) 15.8 ppg 1.15 ft3/sx 4.95 gps 305 62 Thickening Time I 3.5 hrs +/- Top Job Cement Type: Cold Set II 14.95 ppg 0.96 ft3/sx 4.95 gps 250 43 Thickening Time Centralizer Placement: 1. Run one(l) bow type centralizer per joint for the first 15 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Do not run cement baskets. Other Cement Considerations: 1. Mix all slurries "on the fly." Other Information See Recommended Practices for Surface Hole, Version 1.0 for more details 7" Intermediate Casing-Cementing Program Casing Type: 7", 26#, L-80, Mod BTC @ 8598'MD Circ Temperature: 130° F Preflush/Spacer: 20 bbls of H20,50 bbls BJ MCA-4 spacer at 1.0 ppg over mud weight. Cement Volume Basis 1. fill with 30% excess (on 8 1/2" hole) designing for 1000 ft above the PUT. Tail Cement Type: Class G + 0.35% FL-33 + 0.3% CD-32+ 0.1%R-1 + 1 ghs FP-6L as required (all volumes to be recalculated at location prior to job.) Calculated fill is to the 1000' above the top of the Put River sands 15.8 ppg 1.14 ft3/sx 4.95 gps 213 Barrels I Thickening TimeI 42 3.5- 4.5 hrs Centralizer Placement: 1. 1 turbulator centralizer (1/4" under hole size) per joint, in the middle of the joint for the first 10 joints. Other Cement Considerations: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. 2. Ensure thickening times are adequate relative to pumping job requirement. 3. Displace at as per Recommended Practices for given hole section. 41/2" Liner-Cementing Program Job Type: 6" hole and 4-1/2", 12.6#, L-80, production liner @ 10932'MD Circ. Temperature: 140° F. Bottom Hole Static Temp = 220° F at 8800' SS. Preflush/Spacer: 20 bbls of H20 (with 2%KC1), 50 bbls MCS-4 w/2% KCL at 1.0 ppg over mud weight. Cement Volume Basis 1. Open hole + 30% excess 2. 41/2'' casing capacity below landing collar 3. 150' of liner lap (TOL at 9103'MD) 4. 200' of cement above the liner top without DP in hole Cement Type: Class G + 175 ghs BA-86L + 2% A-9 + 0.3% FL-33 + 0.6% CD-32 + 0.2% A-2 + 0.5% gel + 1 ghs FP-6L (all volumes to be recalculated at location prior to job.) Weight Yield Mix Water Sacks Barrels Thickening Time 15.7 ppg 1.19 ft3/sx 3.43 gps 273 58 3-4 hr @ 140° includes .75hr @sfc Centralizer Placement: 1. Run 2 turbolators per joint over the entire length of the liner except for the joint that will be reciprocating in and out of the 7" intermediate shoe. (1/8" under hole size) 2. Turbulator placement may be revised based on hole condition after the hole opener run is completed. It is very important that a good cement job is achieved. Note: well designed for 15 deg/100 ft build. Other Cement Considerations: 1. Ensure that a thickening time test is performed that simulates the shut down time inculTed while rotating off the liner. Note gellation tendencies of slurry when consistometer is re-started after shutdown period. If additional retarder is required, consult with cementer. 2 Batch mix the cement slUlTy. 3. Fluid loss should be 50cc or less. 4. Displace @ 5-7 bpm. T...:.~" ~W 1 5-43 PROPOSED .~,....V -xx' WELLHEAD: FMC BF. ELEV--xx' ACTUATOR: (]]) ...---~v ~,~ ~'~""" 12200' I 95,8", 47,,,t, N- 13545r 80, BTC ' GAS LI~ MANDRELS N~ MD(BKB~ TVDss ~' 3 XXX XXX 4-1/2", 12.6fi/fi, L-80, 2 XXX XXX IBT MOD TUBING 1 XXX XXX GASLIFT ~ ~ ~ 7"x 4.5" PACKER ] 8378' I 4-1/2 .... X" NIPPLE J (OTIS) (3.813" ID) 8408' 4.s" 8448' ~ LINER i ~", ~6~/ft, .-~o, [ 8598' ~ BTC-MoO . I , .;".;~;.; :-;: ..T~ [10312'1 ~ IBTMod 11 392' DATE REV. BY COMMENTS PRUDHOE BAY UNIT 4/22/96 J.E. Smith PROPOSED ORIGINAL COMPLETION WELL; DS 1 A~I ~O' SEC 22~ T~ 16 · 6~ 26 · 5~ 19 ~' [] 45 3~ · · . - · 49 18 I NOTES 1. Dote oflSurvey February 20, 1996. 2. Reference Field Book: PB96-01 (pgs. 29-31). 3. Horiz..o.n. tol ond:"'ivO'tic, ol control is based on monui~'ents Mon-~15C and Mon-15D. 4. Alaska State Plane Co~)rdinotes ore Zone 4, Alaska, NAD 27. 5. Drill...s.i:tel 15 a_verage scale; factor is 0.999355. 6. Elevati.o'~s are:bas, ed on'ARCO Datum M.L.L.W. . VICINITY MAP N.T.S. 2 · 1 32 · As-Built Well Conductor Existing Well SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 20,1996. LOCATED WITHIN PROTRACTED SECTION 22, T. 11 N'., R. 14 E., UMIAT MERIDIAN, ALASKA V~TE-L[' ..... ~.'~;~] .......... PLANT GEODETIC GEODETIc CELLAR SECTION NO.COORDINATESCOORDINATES POSITI.ON(DMS)- POSiTION(.D.DD) BOX ELEV. OFFSETS Y:5,960,908.73 N. 2079.72 · 70'1 ?'55.667" 70.298~'964' 4,706' FSL 4.3X= 676,024.40 E. 200.35' '.1-.48'34'27,742.".' 14'8.57'4~728' 32.6' 5,172' FEL · . . 4,735' ESL iY=5,960,937.68 N 2109.62'.,70'17'55.95-3" 70.2988758' 52.5' 44 X= 676,016.93 E. 199.5~148'34'27.940" 148.5744278' 5,178"EEL SCALE; 1 "=400' ARCO Alaska, Inc. DRILL SITE 15 CONDUCTOR AS-BUILT WELLS 45 AND 44 Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 1 Proposal No: 95-152 Date: 4/23196 Tune: 11:54 am Welipath ID: 15-43 Wp6 Last Revision: 4/22/96 Survey Reference: WELLHEAD Refer~nce. W~ld Coordinate,s: Lat. 70.17.56 N - Long. 148.34.28 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coo~finat~: (ft): 5960908.73 N 676024.40 E No~'th Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD BPX-Shared Se. rvic~ Drilling Alaska State Plane: Zone~4 PB U: EOA: DS 15 Slot: 15-43 Wellpath: 15-43 Wp6 AWD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.1 Vertical Section Plane: 114.50 deg. Measured Ira:! Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (fl) (deg.) (deg.) (ft) (fi) (ft) (ft) (fl) GRID Coordinates Northing Easting (f0 (fi) TIE IN 0.00 0.00 0.00 -66.40 0.00 0.00 0.00N KOP ! START OF BUILD @ 1.00 deg/100 fi 200.00 0.00 0.00 133.60 200.00 200.00 0.OON 300.00 1.00 230.00 233.59 299.99 100.00 0.56 S 0.00 E 5960908.73 676024.40 0.00 E 5960908.73 676024.40 0.67W 5960908.15 676023.75 Closure Vertical Build Walk DLS Cum. Expected Total Max Ho~ Min Ho~ Dir. Vett Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Far(~ Max Ear Exror (fi) (deg.) (ft) (dg/lOOft) (dg/10Oft) (dg/lOOft) (deg) (fi) (ft) (ft) (ft) (deg.) (ft) Survey Tool 0.~@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00E 0.00 0.00 0.00 0.00 MWD 0.~@ 0.00 0.00 0.00 0.00 0.87@230.00 -0.38 1.00 0.00 0.00 0.0 0.00N 1.00 1.0 0.56 S 0.00 E 2.03 2.03 0.00 0.20 BPHM-PBD 0.67W 2.09 2.09 320.00 0.35 BPHM-PBD 4000.00 2.00 230.00 333.56 399.96 100.00 2.24 S 2.6t'W 5960906.43 676021.78 3.49@230.00 -1.50 1.00 500.00 3.00 230.00 433.46 499.86 100.00 5.05 S 6.0k'3tV 5960903.54 676018.51 7.85@230.00 -3.38 1.00 600.00 4.00 230.00 533.28 599.68 100.00 8.97 S 10.6,oW 5960899.51 676013.92 13.9~@230.00 -6.01 1.00 0.00 0.00 0.00 1.00 2.0 2.25 S 2.6'/W 2.19 2.18 320.00 0.50 BPHM-PBD 1.00 3.0 5.06 S 6.0CN 2.33 2.30 320.00 0.65 BPHM-PBD 1.00 4.0 9.00S 10.6C'W 2.51 2.44 320.00 0.81 BPHM-PBD 700.00 5.00 230.00 632.97 699.37 100.00 14.01 S 16.70,V 5960894.33 676008.03 21.8C@230.00 -9.38 1.00 800.00 6.00 230.00 732.50 798.90 100.00 20.18 S 24.0~V 5960888.00 676000.84 31.39@230.00 -13.51 1.00 900.00 7.00 230.00 831.86 898.26 100.00 27.45 S 32.7~'3~r 5960880.52 675992.34 42.71@230.00 -18.38 1.00 0.00 0.00 0.00 1.00 5.0 14.07 S 16.65W 2.76 2.61 320.00 0.96 BPHM-PBD 1.00 6.0 20.27 S 23.9c'W 3.06 2.79 320.00 1.12 BPHM-PBD 1.00 7.0 27.60 S 32.5gW 3.42 2.99 320.00 1.28 BPHM-PBD 1000.00 8.00 230.00 931.00 997.40 100.00 35.84 S 42.71W 5960871.90 675982.54 55.7(~@230.00 -24.00 1.00 START OF CURVE @ 1.25 deg/100 ft 1 100.00 9.00 230.00 1029.90 1096.30 100.00 45.34 S 54.04W 5960862.14 675971.44 70.54@230.00 -30.36 1.00 1200.00 7.75 230.00 1128.84 1195.24 100.00 54.70 S 65.1,cw 5960852.52 675960.51 85.11@230.00 -36.63 -1.25 1300.00 6.50 230.00 1228.06 1294.46 100.00 62.68 S 74.713hr 5960844.33 675951.20 97.51@230.00 -41.97 -1.25 1400.00 5.25 230.00 1327.53 1393.93 100.00 69.26 S 82.5,6V 5960837.57 675943.51 107.74@230.00 -46.38 -1.25 1500.00 4.00 230.00 1427.21 1493.61 100.00 74.44 S 88.71W 5960832.24 675937.46 115.81@230.00 -49.85 -1.25 1600.00 2.75 230.00 1527.03 1593.43 100.00 78.22 S 93.2k'W 5960828.35 675933.04 121.69@230.00 -52.38 -1.25 1700.00 1.50 230.00 1626.96 1693.36 100.00 80.61S 96.06V 5960825.90 675930.26 125.4£@230.00 -53.98 -1.25 1800.00 0.25 230.00 1726.95 1793.35 100.00 81.59 S 97.2.W~r 5960824.89 675929.11 126.93@230.00 -54.64 -1.25 END OF CURVE 1820.00 0.00 0.00 1746.95 1813.35 20.00 81.62 S 97.2t'W' 5960824.86 675929.08 126.97@ 230.00 -54.65 - 1.25 tL~t. B. Perm 1973.05 0.00 0.00 1900.00 1966.40 153.05 81.62S 97.2t~tW 5960824.86 675929.08 126.97@230.00 -54.65 0.00 2~20,00 0,00 0,00 2246,95 2313,35 346,95 81,62 S ~;7.2~W .'i';60824,86 675929.08 12t,.970~2'10.00 -54.65 0.¢)¢) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 8.0 36.06 S 42.5.~V 3.85 3.21 320.00 1.44 BPHM-PBD 1.00 9.0 45.65 S 53.7fiv 4.36 3.44 320.00 1.60 BPHM-PBD 1.25 10.3 55.08 S 64.8fW 4.83 3.68 320.00 1.74 BPHM-PBD 1.25 11.5 63.10S 74.34W 5.26 3.93 320.00 1.88 BPtLM-PBD 1.25 12.8 69.71 S 82.1C'W 5.65 4.18 320.00 2.02 BPHM-PBD 1.25 14.0 74.91 S 88.32W 5.98 4.43 320.00 2.16 BPHM-PBD 1.25 15.3 78.70S 92.82W 6.27 4.67 320.00 2.30 BPHM-PBD 1.25 16.5 81.09 S 95.6C'W 6.50 4.90 320.00 2.45 BPHM-PBD 1.25 17.8 82.07 S 96.82fi~r 6.68 5.14 320.00 2.59 BPHM-PBD 1.25 18.0 82.10S 96.St'W 6.72 5.18 320.00 2.62 BPHM-PBD 0.00 18.0 82.10S 96.8'/W 7.00 5.54 320.00 2.85 BPHM-PBD 0.00 18.0 g2.10S 96.87W 7.67 6,37 320,t~ 'L17 BI'IIM Piti) Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 4/23/96 Wellpath ID: 15-43 Wp6 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectaagular Offsets (ft) (deg.) (deg.) (ft) (fl) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Erro~ Max Err Error (ft) (deg.) (ft) (dg/lOOft) (dg/lOOft) (dg/lOOft) (deg) (fl) (ft) (fl) (fi) (deg.) (ft) Survey Tool 2370.00 0.00 0.00 2296.95 2363.35 50.00 81.62 S 97.2~'W 5960824.86 675929.08 126.97@230.00 -54.65 START OF BUILD @ 1.50 deg/100 ft 2371.00 0.00 0.00 2297.95 2364.35 1.00 81.62 S 97.2~'W 5960824.86 675929.08 126.97@ 230.00 -54.65 2471.00 1.50 80.00 2397.93 2464.33 100.00 81.39 S 95.9L~¥ 5960825.12 675930.36 125.84@229.70 -53.58 0.00 0.00 0.00 0.00 1.50 0.00 0.00 18.0 82.10 $ 96.89W 7.78 6.49 320.00 3.45 BPHM-PBD 0.00 18.0 82.10 $ 96.87W 7.78 6.50 320.00 3,45 BPHM-PBD 1.50 19.5 81.87 $ 95.58W 8.03 6.74 320.61 3,60 BPHM-PBD 2571.00 3.00 80.00 2497.85 2564.25 100.00 80.71 S 92.11W 5960825.89 675934.21 122.47@228.78 -50.34 2671.00 4.50 80.00 2597.64 2664.04 100.00 79.57 $ 85.6~'W 5960827.18 675940.62 116.92@227.11 -44.95 END OF BUILD 2704.33 5.00 80.00 2630.86 2697.26 33.33 79.09 S 82.9_'W 5960827.72 675943.33 114.62@226.36 -42.68 1.50 1.50 1.50 0.00 0.00 1.50 21.0 81,21S 91.71W 8.32 6.99 321.80 3,77 BPHM-PBD 1.50 22.5 80.11 S 85.26V 8.67 7.24 323.47 3.94 BPHM-PBD 1.50 23.0 79.64 S 82.54W 8.79 ' 7.33 324.05 3.99 BPHM-PBD 3204.33 5.00 80.00 3128.95 3195.35 500.00 71.53 $ 40.04W 5960836.29 675986.05 81.97@209.24 -6.76 CASING POINT OD = 9 5/8 in, ID = 8.68 in, Weight = 47.00 lb/ft. 3544.67 5.00 80.00 3468.00 3534.40 340.34 66.37 S 10.82W 5960842.13 676015.13 67.25@ 189.26 17.68 T5 3554.71 5.00 80.00 3478.00 3544.40 10.04 66.22 S 9.907q 5960842.30 676015.99 66,97@ 188.56 18.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 23.0 72,30 $ 39.5/JW 10.65 8.65 329.99 4,75 BPHM-PBD 0.00 23.0 66.37 S 10.82~r 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 23.0 67,16S 9.4~ 11.98 9.58 332.80 5.28 BPHM-PBD 3704.33 5.00 80.00 3627.05 3693.45 149.62 63.96 S 2.88 E 5960844.86 676028.78 64.02@ 177.42 29.15 START OF CURVE @ 1.50 deg/100 fl 3977.92 5.00 80.00 3899.60 3966.00 273.59 59.82 S 26.36 E 5960849.55 676052.16 65.37@ 156.22 48.80 4077.92 6.49 78.52 3999.09 4065.49 100.00 57.94 $ 36.19 E 5960851.66 676061.94 68.31@ 148.01 56.96 0.00 0.00 0.00 0.00 1.49 -1.48 0.00 23.0 64.96S 3.37 E 12.55 9.98 333.78 5.51 BPHM-PBD 0.00 23.0 60.94S 26.88E 13.61 10.72 335.31 5.92 BPHM-PBD 1.50 24.5 59.13 $ 36.73 E 14.06 10.97 335.96 6.12 BPHM-PBD T-3 4137.26 7.38 77.93 4058.00 4124.40 59.34 56.47 $ 43.21E 5960853.29 676068.92 71.116}142.58 62.74 4177.92 7.99 77.59 4098.29 4164.69 40.66 55.32 S 48.52 E 5960854.57 676074.20 73.58@ 138.74 67.10 4277.92 9.49 76.96 4197.13 4263.53 100.00 51.96S 63.34E 5960858.27 676088.93 81.93@129.37 79.18 1.50 - 1.00 1.50 -0.82 1.50 -0.64 1.50 25.4 57.73 S 43.75 E 14.35 11.12 336.35 6.24 BPHM-PBD 1.50 26.0 56.62 S 49.08 E 14.56 11.22 336.61 6.33 BPHM-PBD 1.50 27.5 53.42 S 63.93 E 15.14 11.47 337.27 6.56 BPHM-PBD 4377.92 10.98 76.49 4295.54 4361.94 100,00 47.88 S 80.63 E 5960862.76 676106.12 93.77@120.70 93.22 4477.92 12.48 76.14 4393.45 4459.85 100.00 43.07 S 100.38 E 5960868.03 676125.76 109.23@ 113.22 109.20 4577.92 13.98 75.86 4490.79 4557.19 100.00 37.53 S 122.59 E 5960874.09 676147.83 128.2C@ 107.02 127.11 1.50 -0.46 1.50 -0.35 1.50 -0.28 1.50 29.0 49.55 $ 81.27 E 15.79 11.72 337.91 6.80 BPHM-PBD 1.50 30.5 45.00 S 101.09 E 16.52 11.97 338.52 7.06 BPHM-PBD 1.50 32.0 39.80S 123.38E 17.33 12.21 339.08 7.33 BPHM-PBD K-15 4672.22 15.39 75.64 4582.00 4648.40 94.29 31.64 S 145.76 E 5960880.52 676170.85 149.15@ 102.25 145.75 4677.92 15.48 75.63 4587.50 4653.90 5.71 31.26S 147.23E 5960880.93 676172.31 150.51@101.99 146.93 4777.92 16.98 75.45 4683.51 4749.91 100.00 24.28 S 174.29 E 5960888.54 676199.20 175.97@ 97.93 168.66 1.50 -0.23 1.50 -0.21 1.50 -0.19 1.50 33.4 34.29S 146.65 E 18.18 12.44 339.56 7.60 BPHM-PBD 1.50 33.5 33.94S 148.12E 18.23 12.46 339.59 7.61 BPHM-PBD 1.50 35.0 27.45 S 175.31 E 19.23 12,71 340.06 7.92 BPHM-PBD 4877.92 18.48 75.29 4778.76 4845.16 100.00 16.59 S 203.75 E 5960896.92 676228.47 204.42@ 94.65 192.28 4977.92 19.98 75.15 4873.18 4939.58 I00.00 8.19S 235.59E 5960906.07 676260.10 235.73@ 91.99 217.76 5077.92 21.48 75.04 4966.71 5033.11 100.00 0.92N 269.79 E 5960915.97 676294.07 269.79@ 89.81 245.11 END OF CURVE 5112.88 22.00 75.00 4999.18 5065.58 34.96 4.26N 282.29E 5960919.61 676306.50 282.32@ 89.13 255.10 iIgnu 5422.23 22.00 75.00 5286.00 5352.40 309.35 34.26N 394.23 E 5960952.22 676417.69 395.71@ 85.03 344.51 5612.88 22.00 75.00 5462.77 5529.17 190.65 52.74N 463.21 E 5960972.32 676486.22 466.21@ 83.50 399.62 6112,88 22,00 75.00 5926,36 5992,76 500.00 101.22N 644.13E 5961025.03 676665.94 652.04@ 81.07 544.13 \V Sak 6242.99 22.00 75.00 6047.00 6113.40 130.12 113.83N 691,22 E 5961038.75 676712.71 700.53@ 80.65 581.74 K-12 6475.96 22.00 75.00 6263.00 6329.40 232.96 136.42N 775,51E 5961063.31 676796.45 787.42@ 80.02 649.08 6612.88 22.00 75.00 6389.95 6456.35 136.92 149.70N 825,06E 5961077.75 676845.66 838.53@ 79.72 688.65 1.50 -0.16 1.50 -0.13 1.50 -0.12 1.50 -0.11 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.50 36.5 20.33 S 204.92 E 20.32 12.95 340.48 8.23 BPHM-PBD 1.50 38.0 12.597 236.94E 21.53 13.20 340.86 8.57 BPHM-PBD 1.50 39.5 4.25 S 271.34E 22.84 13.45 341.20 8.92 BPHM-PBD 1.50 40.0 1.197 283.92E 23.32 13.54 341.31 9.04 BPHM-PBD 0.00 40.0 26.33 N 396.52 E 27.66 14.69 342.02 9.62 BPHM-PBD 0.00 40.0 43.29N 465.91 E 30.42 15.42 342.34 9.99 BPHM-PBD 0.00 40.0 87.77N 647.90E 37.81 17.38 342.94 10.97 BPHM-PBD 0.00 40.0 99.35N 695.26 E 39.76 17.90 343.05 11.23 BPHM-PBD 0.00 40.0 120.07N 780.06E 43.28 18.83 343.23 11.70 BPHM-PBD 0.00 40.0 132.25N 829.90E 45.36 19.39 343.32 11.98 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 3 Date: 4/23/96 Wellpath ID: 15-43 Wp6 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (fi) (deg.) (deg.) (fl) (ft) (fl) (fl) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/10Ofl) (dg/10Ofl) (ag/10Oft) (deg) (f-t) (ft) (fl) (ft) (deg.) (fl) Survey Tool K-lO 6938.65 22.00 75.00 6692.00 6758.40 325.77 181.28N 942.93E 5961112.10 676962.76 960.2¢@ 79.12 782.81 7112.88 22.00 75.00 6853.54 6919.94 174.23 198.17N 1005.98E 5961130.47 677025.38 1025.31@ 78.86 833.17 7612.88 22.00 75.00 7317.14 7383.54 500.00 246.65N 1186.90E 5961183.19 677205.10 1212.2~@ 78.26 977.69 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.0 161.23 N 948.47 E 50.32 20.72 343.50 12.65 BPHM-PBD 0.00 40.0 176.73N 1011.89E 52.99 21.43 343.59 13.01 BPHM-PBD 0.00 40.0 221.21N 1193.88 E 60.68 23.51 343.78 14.05 BPHM-PBD, K-5 7710.88 22.00 75.00 7408.00 7474.40 98.00 256.15N 1222.36E 5961193.53 677240.32 1248.91@ 78.16 1006.01 K-2 8034.44 22.00 75.00 7708.00 7774.40 323.56 287.52N 1339.44E 5961227.65 677356.62 1369.95@ 77.88 1099.53 8112.88 22.00 75.00 7780.73 7847.13 78.44 295.13N 1367.82E 5961235.92 677384.81 1399.3£@ 77.82 1122.21 K-I 8239.36 22.00 75.00 7898.00 7964.40 126.48 307.39N 1413.59 E 5961249.26 677430.28 1446.62@ 77.73 1158.76 BHRZ 8252.30 22.00 75.00 7910.00 7976.40 12.94 308.65N 1418.27 E 5961250.63 677434.93 1451.47@ 77.72 1162.50 Put 8257.70 22.00 75.00 7915.00 7981.40 5.39 309.17N 1420.22E 5961251.19 677436.87 1453.48@ 77.72 1164.06 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.0 229.93N 1229.55 E 62.19 23.92 343.81 14.26 BPHM-PBD 0.00 40.0 258.71N 1347.33 E 67.19 25.28 343.91 14.94 BPHM-PBD 0.00 40.0 265.69N 1375.88 E 68.41 25.61 343.93 15.10 BPHM-PBD 0.00 40.0 276.94N 1421.91 E 70.37 26.14 343.96 15.37 BPHM-PBD 0.00 40.0 278.09N 1426.62 E 70.57 26.20 343.96 15.40 BPHM-PBD 0.00 40.0 278.57N 1428.59 E 70.65 26.22 343.96 15.41 BPHM-PBD B Put / LCU / T Kingak 8287.90 22.00 75.00 7943.00 8009.40 30.20 312.10N 1431.15E 5961254.38 677447.72 1464.78@ 77.70 1172.79 Jur B 8320.25 22.00 75.00 7973.00 8039.40 32.36 315.23N 1442.86E 5961257.79 677459.35 1476.89@ 77.68 1182.14 JurA 8444.28 22.00 75.00 8088.00 8154.40 124.03 327.26N 1487.74E 5961270.87 677503.93 1523.3C@ 77.59 1217.99 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.0 281.25N 1439.58 E 71.12 26.35 343.97 15.47 BPHM-PBD 0.00 40.0 284.13N 1451.36E 71.62 26.48 343.98 15.54 BPHM-PBD 0.00 40.0 295.17N 1496.50E 73.54 27.01 344.01 15.81 BPHM-PBD Sag 8543.51 22.00 75.00 8180.00 8246.40 99.22 336.88N 1523.64E 5961281.34 677539.60 1560.44@ 77.53 1246.67 Shub A 8586.65 22.00 75.00 8220.00 8286.40 43.14 341.06N 1539.25E 5961285.89 677555.10 1576.58@ 77.51 1259.14 CASING POINT OD = 7 ia, ID = 6.28 in, Weight = 26.00 lb/ft. 8597.43 22.00 75.00 8230.00 8296.40 10.79 342.11N 1543.15E 5961287.03 677558.98 1580.62@ 77.50 1262.26 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.0 303.99N 1532.62 E 75.08 27.43 344.03 16.02 BPHM-PBD 0.00 40.0 307.83N 1548.32E 75.75 27.61 344.04 16.11 BPHM-PBD 0.00 40.0 342.11N 1543.15 E 0.00 0.00 0.00 0.00 BPHM-PBD 8612.88 22.00 75.00 8244.32 8310.72 15.44 343.61N 1548.74E 5961288.66 677564.53 1586.4C@ 77.49 1266.72 Shub B 8616.85 22.00 75.00 8248.00 8314.40 3.97 343.99N 1550.18E 5961289.07 677565.96 1587.89@ 77.49 1267.87 Shub C 8630.87 22.00 75.00 8261.00 8327.40 14.02 345.35N 1555.25E 5961290.55 677571.00 1593.13@ 77.48 1271.92 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.0 310.16N 1557.87 E 76.16 27.72 344.04 16.17 BPHM-PBD 0.00 40.0 310.52N 1559.31 E 76.22 27.74 344.04 16.17 BPHM-PBD 0.00 40.0 311.76N 1564.42 E 76.44 27.80 344.05 16.20 BPHM-PBD Z4 8662.15 22.00 75.00 8290.00 8356.40 31.28 348.38N 1566.57E 5961293.85 677582.24 1604.84@ 77.46 1280.96 8823.93 22.00 75.00 8440.00 8506.40 161.78 364.07N 1625.11 E 5961310.92 677640.39 1665.39@ 77.37 1327.72 8888.64 22.00 75.00 8500.00 8566.40 64.71 370.34N 1648.52E 5961317.74 677663.65 1689.61@ 77.34 1346.43 8897.91 22~00 75.00 8508.60 8575.00 9.27 371.24N 1651.88E 5961318.72 677666.98 1693.08@ 77.33 1349.11 8898.91 22.00 75.00 8509.53 8575.93 1.00 371.34N 1652.24E 5961318.82 677667.34 1693.45@ 77.33 1349.40 5TART OF CURVE @ 14.82 deg/100 ft 8899.91 22.00 75.00 8510.45 8576.85 1.00 371.44N 1652.60E 5961318.93 677667.70 1693.83@ 77.33 1349.69 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.0 314.55N 1575.80 E 76.92 27.93 344.05 16.27 BPHM-PBD 0.00 40.0 328.94N 1634.69 E 79.44 28.62 344.08 16.62 BPHM-PBD 0.00 40.0 334.70N 1658.24 E 80.44 28.89 344.10 16.76 BPI-LM-PBD 0.00 40.0 335.52N 1661.62 E 80.58 28.93 344.10 16.78 BPHM-PBD 0.00 40.0 335.61N 1661.98 E 80.60 28.94 344.10 16.78 BPHM-PBD 0.00 40.0 335.70N 1662.34 E 80.62 28.94 344.10 16.78 BPHM-PBD I'ango 8939.02 27.21 81.15 8546.00 8612.40 39.10 374.71N 1668.52E 5961322.58 677683.54 1710.08@ 77.34 1362.82 13.31 15.73 14.82 45.8 338.48N 1678.34 E 81.38 28.51 344.29 17.94 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 4 Date: 4/23/96 Wellpath ID: 15-43 Wp6 Measur~ lncl Drift Subsea TVD Course T O T A L ~ Dh'. Depth Length Rectangular Offsets (tO (deg.)(deg.) (fO (fO (fO (fO (fO GRID Coordinates Northing Fasting (ft) (fi) Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hot' Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/lOOfi) (dg/lOOfi) (dg/lOOft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 8999.91 35.65 87.29 8597.93 8664.33 60.90 377.70N 1700.07 E 5961326.31 677715.00 1741.52@ 77.47 1390.28 13.87 10.09 14.82 54.8 340.21N 1709.95 E 82.97 27.68 344.82 19.99 BPHM-PBD Romeo 9095.04 49.22 93.05 8668.00 8734.40 95.13 377.09N 1764.05 E 5961327.21 677778.98 1803.91@ 77.93 1448.76 14.26 6.05 14.82 68.9 336.28N 1773.76 E 86.42 26.13 346.11 23.34 BPHM-PBD 9099.91 49.92 93.28 8671.16 8737.56 4.87 376.88N 1767.75 E 5961327.10 677782.68 1807.48@ 77.96 1452.21 14.39 4.65 14.82 69.7 335.90N 1777.45 E 86.60 26.05 346.17 23.51 BPHM-PBD ZI/GOC 9167.36 59.66 96.01 8710.00 8776.40 67.44 372.35N 1822.60E 5961323.86 677837.61 1860.24@ 78.45 1503.99 14.45 9199.91 64.38 97.14 8725.27 8791.67 32.56 369.05N 1851.15E 5961321.24 677866.23 1887.58@ 78.73 1531.34 14.50 9299.91 78.93 100.15 8756.67 8823.07 100.00 354.72N 1944.71 E 5961309.13 677960.09 1976.79@ 79.66 1622.42 14.54 4.06 14.82 79.7 328.33N 1831.97 E 89.55 24.94 347.23 25.64 BPHM-PBD 3.46 14.82 84.5 323.44N 1860.32 E 91.08 24.45 347.74 26.54 BPHM-PBD 3.01 14.82 99.3 303.40N 1952.86 E 96.42 23.38 349.47 28.65 BPHM-PBD END OF CURVE 9326.29 82.77 100.88 8760.86 8827.26 26.38 349.96N 1970.31E 5961304.98 677985.80 2001.15@ 79.93 1647.69 14.57 2.76 14.82 103.2 297.12N 1978.17E 97.87 23.28 349.88 29.01 BPHM-PBD START OF CURVE @ 14.82 deg/100 ft 9341.84 82.77 100.88 8762.82 8829.22 15.54 347.05N 1985.46E 5961302.43 678001.00 2015.5~@ 80.09 1662.67 0.00 -0.00 0.00 103.2 293.31N 1993.14E 98.75 23.29 350.09 29.10 BPHM-PBD 9441.84 83.52-115.79' 8774,82 .... 8841~22 ..... 100.00 315.90N 2079.42E 5961273.52 678095.67 2103.28@ 81.36 1761.10 0.75 14.91 14.82 118.0 257.27N 2084.75 E 102.99 25.77 352.60 29.72 BPHM-PBD 9541.84 84.70 130,64 8785,14 8851.54 100.00 261.56N 2162.40E 5961221.16 678179.89 2178.1~@ 83.10 1859.14 9641.84 86.22 145.43 8793.10 8859.50 100.00 187.64N 2228.85E 5961148.84 678248.07 2236.74@ 85.19 1950.27 9741.84 88.00 160.16 8798.17 8864.57 100.00 99.05N 2274.38E 5961061.37 678295.66 2276.53@ 87.51 2028.43 1.18 14.85 14.82 132.9 199.44N 2164.73 E 106.01 28.45 355.09 30.37 BPHM-PBD 1.53 14.79 14.82 147.7 123.56N 2228.34E 107.76 30.83 357.28 31.05 BPHM-PBD 1.78 14.73 14.82 162.5 34.28N 2271.92E 108.42 32.52 358.94 31.74 BPHM-PBD BSad / Kavik 9841.84 89.91 174.86 8800.00 8866.40 100.00 1.7IN 2295.93E 5960964.57 678319.51 2295.93@ 89.96 2088.42 1.91 14.70 14.82 177.3 63.12S 2292.93E 108.36 33.23 359.95 32.43 BPHM-PBD END OF CURVE 9846.43 90.O0 175.54 8800.00 8866.40 4.59 2.87 S 2296.32 E 5960960.00 678320.00 2296.32@ 90.07 2090.67 1.93 14.69 14.82 178.0 67.69 S 2293.29 E 108.37 33.24 359.99 32.46 BPHM-PBD CASING POINT OD = 4 1/2 in, ID = 3.95 in, Weight = 12.60 lbfft. 10932.00 90.00 175.54 ' 8800.00 8866.40 1085.57 1085.14 S 2380.82 E 5959880.10 678429.99 2616.45@ 114.50 2616.45 -0.00 0.00 0.00 178.0 1085.14 S 2380.82 E 0.00 O.00 0.00 0.00 BPHM-PBD 10932.10 90.00 175.54 8800.00 8866.40 0.10 1085.24S 2380.82E 5959880.00 678430.00 2616.5C@ 114.50 2616.50 -0.01 -0.02 0.02 178.0 1150.47 $ 2372.65 E 116.44 34.60 18.47 40.96 BPHM-PBD WELL PERMIT CHECKLIST comPlY GEOL AREA PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg [] _ _ ON/O~ s~o~ ~ / UN I T8 ADMINI ~TRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. N 10. Operator has appropriate bond in force ........ N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. N 13. Can permit be approved before 15-day wait ...... ' N ENGINEERING REMARKS DATE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 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 .......... 23. If diverter required, is it adequate ......... ~Y 24. Drilling fluid program schematic&equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~(i~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: HOW/ljb- A:%FORMS%cheklist rev 11195 ENGINEERING: BEW COMMISSION: ^ Comments/Instructions: ' ., ~ .,~ .'~ ~ m 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. RECEIVED SEP 1 1 199~ Oil & Gas Corm, C. ommi.~ion .Anchorage . * · ALASKA COMPUTING CENTER * . * ****************************** . ............................ * · ....... SCHLUMBERGER ....... * . ............................ * ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME '. DS 15-43 FIELD NAM~ : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292267600 REFERENCE NO : 96226 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12: 05 PAGE: **** REEL HEADER **** SERVICE NAi~E : EDIT DATE : 96/09/ 5 ORIGIN : FLIC REEL NAME : 96226 CONTINUATION # : PREVIOUS REEL : CORk4ENT : ARCO ALASKA INC, D.S. 15-43, PRUDHOE BAY, 50-029-22676-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 96/09/ 5 ORIGIN : FLIC TAPE NAME : 96226 CONTINUATION # : 1 PREVIOUS TAPE : COf~4E~Ff : ARCO ALASKA INC, D.S. 15-43, PRUDHOE BAY, 50-029-22676-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 15-43 API 1VUMBER: 500292267600 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 4-SEP-96 JOB NU~iBER .. 96226 LOGGING ENGINEER: G. SCHWARTZ OPERATOR WITNESS: BILL MOXLOW SURFACE LOCATION SECTION: 22 TOWNSHIP: 1 iN RANGE: 14E FNL: FSL: 4706 FEL: 5172 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 66.30 GROUND LEVEL: 32.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 3553.0 47. O0 2ND STRING 7. 000 8605.0 26. O0 3RD STRING 4. 500 11043.0 12.60 PRODUCTION STRING 4. 500 8453.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: PDC LDWG CURVE CODE: GRCH RUN ~ER : 1 PASS NUMBER: 1 DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH TDTP ..................... 88888.0 88887.0 9341.0 9340.0 9308.0 9307.5 9290.5 9289.5 9269.0 9268.5 9262.5 9262.0 9255.5 9254.0 9253.0 9252.0 9183.5 9183.0 9129.5 9129.5 9099.0 9098.5 9085.5 9084.5 9074.5 9072.5 9035.0 9033.5 9007.0 9005.5 100.0 98.5 $ REMARKS: THIS LIBRARY TAPE CONTAINS THE LDWG FORMATTED EDIT ON ARCO ALASKA'S D.S. 15-43. THE TAPE CONTAINS 3 BASELINE PASSES, 3 BORAX PASSES, AN AVERAGE PASS, AND 3 FLOWING PASSES. TWO OF THE FLOWING PASSES WERE OBTAINED WITH THE MINITRON TtHANED OFF AND ARE CONSIDERED BACKGROUN PASSES. THE BACKGROUND PASSES WILL BE INCLUDED IN THE EDITED FILES AND NUMB~ SEQUENTIALLY AS PER DISCUSSION 8/29/96 WITH D. DOUGLAS (BP) .THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT SIGM BASELINE PASS #1 TO PRIMARY DEPTH CONTROL GAFk4A RAY CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 3 FILE NVJMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~Jh~Y LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10919.0 9004.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... TDTP ....... REMARKS: THIS FILE CONTAINS TDTP PASS #1 (BASELINE PASS #1). NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDA T EPD FT LMF APD FT EDF FT EGL FT TDD FT BLI FT TLI FT ARCO ALASKA INC. PRUDHOE BAY DS 15-43 500292267600 4706' FSL & 5172'FEL 22 liN 14E NORTH SLOPE ALASKA USA BILL MOXLOW 500488 MSL O. RT 66.3 66.3 32.6 10949. 10920. 9000. Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Wi tness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 4 TUNI VALU DEFI DFT BORAX/PRODUCED FLUIDS Drilling Fluid Type BHT DEGF 194. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBPZN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension CCL CCL Amplitude GR API-Corrected Gamma Ray ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 .............................. ** SET TYPE - CHAN ** N~ME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~4~ SAMP ELE~ CODE (HEX) DEPT FT 500488 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 500488 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 500488 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 500488 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 500488 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 500488 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 500488 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 500488 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 500488 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 500488 O0 000 O0 0 1 1 1 4 68 0000000000 GR PDC GAPI 500488 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10918.000 SIGM. TDTP 14.178 TPHI.TDTP 27.868 SBHF. TDTP SBHN. TDTP 39.495 SIGC. TDTP 0.907 SIBH. TDTP 44.222 TRAT. TDTP SDSI.TDTP 0.250 BACK. TDTP 124.964 FBAC. TDTP 31.275 TCAN. TDTP TCAF. TDTP 20180.027 TCND. TDTP 31553.609 TCFD. TDTP 10031.363 TSCN. TDTP TSCF. TDTP 4337.552 INND. TDTP 1781.120 INFD. TDTP 370.106 TENS.TDTP CCL.TDTP 0.000 GR.PDC -999.250 DEPT. 9000.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP SBHiN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND.TDTP -999.250 INFD. TDTP -999.250 TENS.TDTP CCL.TDTP -999.250 GR.PDC 24.641 30.960 1.997 52025.273 11182.459 -4830.000 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE . FLIC VERSION . O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NXIM~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCRE~iENT : 0. 5000 FILE SU~9~ARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10919.0 10070.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: SIGM PASS--ER: 1 BASELINE DEPTH .............. 88888 0 10877 0 10862 0 10802 0 10754 5 10721 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... TDTP ....... 88887.0 10876.0 10861.0 10800.5 10753.0 10720.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 7 10690.0 10675.0 10660.0 10650.0 10646.0 10636.0 10627.0 10610.0 10605.0 10581.0 10412.0 10385.0 10367.0 10365.0 10348.0 10336.0 10327.5 10306.5 10283.5 10270.5 10213.0 10113.0 10090.5 100.0 $ 10689.5 10673.5 10658.0 10649.0 10645.0 10634.0 10626.5 10609.5 10605.0 10581.5 10411.0 10384.0 10367 0 10364 0 10347 0 10334 5 10326 0 10305 0 10283 0 10270 5 10212 0 10112 5 10090 0 99 5 REMARKS: THIS FILE CONTAINS TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT SIGM BORAX PASS #1 TO SIGM BASELINE PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD FT LMF ARCO ALASKA INC. PRUDHOE BAY DS 15-43 500292267600 4706' FSL & 5172'FEL 22 liN 14E NORTH SLOPE ALASKA USA BILL MOXLOW 500488 MSL O. RT Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 8 TUNI VALU DEFI APD FT 66.3 EDF FT 66.3 EGL FT 32.6 TDD FT 10949. BLI FT 10920. TLI FT 9000. DFT BORAX/PRODUCED FLUIDS BHT DEGF 194. Above Permanent Datum Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling Fluid Type Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 9 TYPE REPR CODE VALUE .............................. 7 65 8 68 0.5 9 65 FT 11 66 12 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500488 O0 000 O0 0 2 1 1 4 SIGM TDTP CU 500488 O0 000 O0 0 2 1 1 4 TPHI TDTP PU-S 500488 O0 000 O0 0 2 1 1 4 SBHF TDTP CU 500488 O0 000 O0 0 2 1 1 4 SBHN TDTP CU 500488 O0 000 O0 0 2 1 1 4 SIGC TDTP CU 500488 O0 000 O0 0 2 1 1 4 SIBH TDTP CU 500488 O0 000 O0 0 2 1 1 4 TRAT TDTP 500488 O0 000 O0 0 2 1 1 4 SDSI TDTP CU 500488 O0 000 O0 0 2 1 1 4 BACK TDTP CPS 500488 O0 000 O0 0 2 1 1 4 FBAC TDTP CPS 500488 O0 000 O0 0 2 1 1 4 TCANTDTP CPS 500488 O0 000 O0 0 2 1 1 4 TCAF TDTP CPS 500488 O0 000 O0 0 2 1 1 4 TCND TDTP CPS 500488 O0 000 O0 0 2 1 1 4 TCFD TDTP CPS 500488 O0 000 O0 0 2 1 1 4 TSCN TDTP CPS 500488 O0 000 O0 0 2 1 1 4 TSCF TDTP CPS 500488 O0 000 O0 0 2 1 1 4 INND TDTP CPS 500488 O0 000 O0 0 2 1 1 4 INFD TDTP CPS 500488 O0 000 O0 0 2 1 1 4 TENS TDTP LB 500488 O0 000 O0 0 2 1 1 4 CCL TDTP V 500488 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 10918.000 SIGM. TDTP 22.293 TPHI.TDTP 25.342 SBHF. TDTP 59.569 SBHN. TDTP 76.227 SIGC. TDTP 0.660 SIBH. TDTP 150.213 TRAT. TDTP 1.520 SDSI. TDTP 0.964 BACK. TDTP 228.258 FBAC. TDTP 38.776 TCAN. TDTP 8209.570 TCAF. TDTP 3769.728 TCND. TDTP 11998.371 TCFD.TDTP 3918.452 TSCN. TDTP 2499.044 TSCF. TDTP 1147.528 INND. TDTP 1596.482 INFD. TDTP 336.133 TENS.TDTP -4775.000 CCL. TDTP 0.000 LI~ Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 10 DEPT. 10069.500 SIGM. TDTP 15.952 TPHI.TDTP 26.857 SBHF. TDTP 62.923 SBHN. TDTP 71.725 SIGC. TDTP 0.307 SIBH. TDTP 137.876 TRAT. TDTP 1.816 SDSI.TDTP 0.400 BACK. TDTP 233.422 FBAC. TDTP 41.127 TCAN. TDTP 19693.184 TCAF. TDTP 8311.840 TCND.TDTP 17808.766 TCFD. TDTP 6026.457 TSCN. TDTP 6000.586 TSCF. TDTP 2532.648 INND.TDTP 1633.695 INFD.TDTP 379.309 TENS. TDTP -4780.000 CCL. TDTP 0.020 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAIVIE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~iARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10919.0 9515.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: SIGM PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH TDTP L~S Tape Verification Listing Schlumberger Alaska Computing Center 88888.0 10912.5 10899.5 10886.0 10879.5 10863.0 10851.0 10817.0 10811.5 10802.0 10797.5 10771.0 10763.0 10758.5 10753.5 10745.5 10729.5 10720.5 10690.5 10677.0 10672.5 10659.0 10656.5 10627.0 10623.0 10604.5 10602.0 10592.0 10567.0 10563.0 10558.5 10554.5 10551.5 10547.5 10537.5 10528.5 10517.5 10498.0 10473.5 10455.0 10449.0 10441.5 10431.5 10428.5 10426.5 10415.5 10396.5 10386.0 10381.0 10374.5 10367.0 10364.5 10346.5 10335.5 10324.0 88887.0 10911.5 10899 0 10885 5 10879 0 10861 0 10849 0 10816 0 10811 0 10801 0 10796 5 10769 5 10762 0 10758.0 10752.5 10745.0 10729.0 10720.0 10689.5 10676.0 10671.5 10658.0 10655.5 10626.5 10621.5 10605.0 10602.0 10592.0 10567.0 10563.0 10560.0 10555.0 10551.5 10547.0 10538.0 10529.5 10517.5 10498.0 10473.5 10455.0 10449.0 10440.5 10430.5 10428.5 10426.0 10415.0 10397.5 10386.5 10380.0 10373.0 10366.5 10364.0 10346.5 10334.5 10323.0 5-SEP-1996 12:05 PAGE: 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10320.0 10311.0 10301.5 10297.0 10289.0 10208.5 10202.0 10198.5 10189.5 10186.0 10183.5 10179.5 10176.5 10170.5 10167.0 10158.5 10142.5 10141.0 10131.0 10129.0 10120.0 10116.5 10113.0 10110.0 10106.5 10090.0 10088.5 10077.5 10069.0 10048.5 10037.0 10029.5 10025.5 10011.5 10008.0 10005.0 9977.0 9966.0 9963.0 9959.0 9950.0 9943.5 9936.5 9934.0 9928.0 9919 5 9895 5 9887 5 9873 0 9869 5 9843 5 9826.5 9814.5 9796.0 9793.0 10319.0 10311.0 10301.0 10296.0 10288.0 10208.5 10201.0 10198.0 10189.5 10186.0 10183.5 10178 5 10175 5 10170 5 10167 0 10159 0 10143 5 10141 0 10131 5 10129 0 10121.0 10117.0 10112.0 10110.0 10107.0 10090.5 10088.0 10077.0 10068.0 10049.5 10036.5 10029.0 10024.5 10011.5 10007.5 10005.0 9976.0 9964 5 9961 5 9957 5 9948 5 9942 0 9936 0 9933 5 9928.5 9919.0 9895.5 9887.5 9873.0 9869.0 9843.5 9826.0 9814.0 9795.5 9792.5 5-SEP-1996 12~05 PAGE: 12 LI~ Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 13 9791.0 9783.0 9769.5 9761.0 9756.0 9721.5 9714.0 9669.5 9661.0 9644.0 9641.0 9636.0 9632.5 9605.5 9590.5 9568.0 9561.0 9556.0 9543.0 9540.0 9538.0 9534.5 9530.5 9524.5 100.0 $ 9791.0 9782.0 9770.5 9762.0 9757.0 9721.5 9714.0 9670.0 9661.0 9644.0 9641.0 9636.0 9633.0 9605.0 9590 5 9567 5 9561 0 9556 0 9543 0 9540 5 9538 5 9534 5 9530 5 9524 5 100.0 ~KS: THIS FILE CONTAINS TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT SIGM BORAX PASS #2 TO SIGM BASELINE PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD FT ARCO ALASKA INC. PRUDHOE BAY DS 15-43 500292267600 4706' FSL & 5172'FEL 22 lin 14E NORTH SLOPE ALASKA USA BILL MOXLOW 500488 MSL O. Company Name Field Name Well Name API Serial Number Field Location Section Township Range Court ty State or Province Nation Wi tness Name Service Order Number Permanent datum Elevation of Permanent Datum LI~ Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 14 TUNI VAL U DEFI LMF RT APD FT 66.3 EDF FT 66.3 EGL FT 32.6 TDD FT 10949. BLI FT 1092 O. TLI FT 9000. DFT BORAX/PRODUCED FLUIDS BHT DEGF 194. Log Measured From Above Permanent Datum Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling Fluid Type Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts ~ Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension CCL CCLAmplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12: 05 PAGE: 15 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500488 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 500488 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 500488 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 500488 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 500488 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 500488 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 500488 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TCAFTDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 500488 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 500488 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 500488 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP CCL. TDTP 10918 000 81 411 1 566 1924 325 599 413 0 000 SIGM. TDTP 27.591 TPHI. TDTP 35.828 SBHF. TDTP 62.125 SIGC. TDTP 0.389 SIBH. TDTP 181.994 TRAT. TDTP 1.639 BACK. TDTP 194.126 FBAC. TDTP 54.520 TCAN. TDTP 5039.069 TCND. TDTP 10119.549 TCFD. TDTP 2930.883 TSCN. TDTP 1569.634 INND.TDTP 1680.714 INFD. TDTP 360.728 TENS.TDTP -4770.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 16 DEPT. 9515.000 SIGM. TDTP 17.650 TPHI.TDTP 24.714 SBHF. TDTP 54.269 SBHN. TDTP 73.211 SIGC. TDTP 0.134 SIBH. TDTP 136.968 TRAT. TDTP 1.668 SDSI.TDTP 0.437 BACK. TDTP 215.985 FBAC. TDTP 39.481 TCAN. TDTP 17338.152 TCAF. TDTP 7874.605 TCND. TDTP 16227.830 TCFD. TDTP 5887.478 TSCN. TDTP 5068.648 TSCF. TDTP 2302.068 INND. TDTP 1676.802 INFD.TDTP 379.352 TENS.TDTP -4780.000 CCL. TDTP -0.005 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10919.0 9112.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: SIGM PASS N73FiBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 88888.0 88886.0 10913.5 10911.5 10899.0 10899.0 10885.5 10885.5 10877.0 10877.5 10862.5 10861.0 10837.0 10836.5 10813.5 10813.0 10801.5 10801.0 10797.5 10796.5 10770.5 10770.0 10761.5 10761.0 10753.0 10752.5 10745.5 10744.5 10720.0 10719.5 10689.0 10689.0 10676.0 10675.5 10664.5 10664.0 10659.0 10658.0 10651.5 10651 . 0 10647.5 10647.0 10626.0 10626.0 10602.0 10602.5 10566.0 10566.5 10558.5 10559.5 10551.0 10551.5 10539.5 10540.5 10536.5 10537.5 10529.5 10529.5 10526.0 10526.5 10497.5 10498.5 10486.5 10486.5 10474.0 10474.0 10453.0 10454.0 10442.0 10441.0 10436.5 10437.0 10431.5 10431.0 10415.0 10415.0 10406.0 10406.5 10383.0 10384.0 10374.0 10373.5 10367.5 10367.5 10347.5 10347.0 10335.0 10334.5 10313.0 10312.5 10311.0 10310.5 10288.5 10287.5 10212.5 10212.5 10201.0 10201.0 10189.0 10189.5 10186.5 10186.0 10184.0 10183.5 10179.0 10178.5 10170.5 10170.5 5-SEP-1996 12: 05 PAGE: 17 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10158.5 10130.0 10123.5 10117.0 10113.0 10106.0 10100.0 10091.0 10086.0 10068.0 10051.0 10041.0 10029.0 10025.0 10004.5 10001.5 9989.0 9968.0 9949.5 9944.5 9934.0 9927.0 9919.5 9908.5 9906.5 9887.5 9873.0 9869.0 9857.5 9827.0 9786.0 9776.0 9768.0 9749.5 9730.5 9726.5 9722.0 9670.0 9661.5 9657.5 9655.0 9651.5 9648.5 9644.0 9641.5 9632.5 9610.0 9608.0 9605.0 9597.0 9584.5 9568.0 9561.5 9556.5 9551.5 10159.0 10131.0 10123.5 10117.0 10112.5 10107.0 10100.0 10090.0 10085.5 10068 0 10051 5 10041 0 10028 5 10025 0 10004 5 10001 0 9988 0 9967 0 9948.0 9942.0 9933.5 9926.0 9919.0 9908.0 9906.0 9887.5 9872.5 9869.0 9857.5 9826.0 9785.0 9775.0 9768.0 9750.5 9730.5 9725.5 9721.5 9670.0 9661.0 9657.0 9654.0 9651.0 9648.5 9643 5 9641 0 9632 5 9610 5 9608 0 9604 5 9596 0 9584 0 9567 5 9561.0 9556.0 9551.5 5-SEP-1996 12:05 PAGE: 18 LI~S Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 19 9543 5 9540 5 9538 0 9535 0 9528 5 9525 0 9517 5 9502 0 9498 0 9479 5 9476 5 9462 5 9437 5 9410 5 9383 0 9342 5 9338 5 9310 0 9299 0 9283 0 9270 5 92 64 0 9261 5 9255 5 9231 5 9225 0 9222 0 9193 0 9183 0 9161 5 9158 0 9152 5 9136.5 9126.5 9123.0 9117.0 100.0 $ 9543. 0 9540.5 9538.5 9535. 0 9528.0 9524.5 9516. 0 9502.5 9498.0 9480.0 9476.5 9463.0 9438.0 9411.0 9382.5 9342.0 9338.0 9311.0 9300.5 9283. 0 9270.5 9264.5 9262. 0 9255. 0 9231.5 9225. 0 9221.5 9193.5 9183. 0 9162. 0 9158.5 9153. 0 9137.5 9127.0 9124.0 9118.5 101.5 REMARKS: THIS FILE CONTAINS TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT SIGM BORAX PASS #3 TO SIGM BASELINE PASS #1 CARRYING ALL TDTP CURVES WITH THE SIGM SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. PRUDHOE BAY DS 15-43 Company Name Field Name Wel 1 Name LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 20 TUNI VALU DEFI APIN 500292267600 API Serial Number FL 4706' FSL & 5172'FEL Field Location SECT 22 Section TOWN 1 iN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN BILL MOXLOW Wi tness Name SON 500488 Service Order Number PDAT MSL Permanent da turn EPD FT O. Elevation of Permanent Datum LMF RT Log Measured From APD FT 66.3 Above Permanent Datum EDF FT 66.3 Elevation of Derrick Floor EGL FT 32.6 Elevation of Ground Level TDD FT 10949. Total Depth - Driller BLI FT 10920. Bottom Log Interval TLI FT 9000. Top Log Interval DFT BORAX/PRODUCED FLUIDS Drilling Fluid Type BHT DEGF 194. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector T$CF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension CCL CCLAmplitude LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~q CODE (HEX) DEPT FT 500488 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 500488 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 500488 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNTDTP CU 500488 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 500488 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 500488 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 500488 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 500488 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 500488 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 500488 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 22 ** DATA ** DEPT. 10917. 000 SIGM. TDTP 32. 007 TPHI. TDTP 40. 821 SBHF. TDTP SBHN. TDTP 78. 038 SIGC. TDTP O. 171 SIBH. TDTP 170. 983 TRAT. TDTP SDSI. TDTP O. 947 BACK. TDTP 226. 411 FBAC. TDTP 62. 984 TCAN. TDTP TCAF. TDTP 3337. 706 TCArD. TDTP 9709. 012 TCFD. TDTP 2695. 693 TSCN. TDTP TSCF. TDTP 481 . 384 IArArD. TDTP 1706. 045 INFD. TDTP 345. 823 TENS. TDTP CCL. TDTP O. 000 DEPT. 9113.500 SIGM. TDTP 12.233 TPHI. TDTP 21 . 674 SBHF. TDTP SBHN. TDTP 68. 589 SIGC. TDTP O. 081 SIBH. TDTP 118. 875 TRAT. TDTP SDSI. TDTP O. 182 BACK. TDTP 208. 995 FBAC. TDTP 40. 891 TCAN. TDTP TCAF. TDTP 22845. 430 TCArD. TDTP 25124. 699 TCF~. TDTP 9936. 625 TSCN. TDTP TSCF. TDTP 5065. 329 INArD. TDTP 1874. 139 INFD. TDTP 392. 677 TENS. TDTP CCL. TDTP 0. O18 66.957 1.609 9591.660 1340.073 -4790.000 45.297 1.763 49529.422 10981.752 -4815.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMFJ~f 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... TDTP 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 23 REMARKS: THE ARI~TIC AVERAGE OF BASELINE PASSES 1, 2 & 3 WAS COMPUTED AFTER ALL DEPTH SHIFTS AND CLIPPING WAS APPLIED. $ LIS FORMAT DATA TABLE TYPE : CONS TONI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 15-43 Well Name APIN 500292267600 API Serial Number FL 4706' FSL & 5172'FEL Field Location SECT 22 Section TOWN liN Township RANG 14E Range COON NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN BILL MOXLOW Witness Name SON 500488 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RT Log Measured From APD FT 66.3 Above Permanent Datum EDF FT 66.3 Elevation of Derrick Floor EGL FT 32.6 Elevation of Ground Level TDD FT 10949. Total Depth - Driller BLI FT 10920. Bottom Log Interval TLI FT 9000. Top Log Interval DFT BORAX/PRODUCED FLUIDS Drilling Fluid Type BHT DEGF 194. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT SIGM TPHI SBHF SBt~N SIGC SIBH TRAT SDSI BACK FBAC TCAN Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Total counts analyzed - near detector (TDTP) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 24 DEFI TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 500488 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PNAV CU 500488 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PNAV PU-S 500488 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PNAV CU 500488 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPNAV CU 500488 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PNAV CU 500488 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PNAV CU 500488 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PNAV 500488 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PNAV CU 500488 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCAFPNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 TCNDPNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 INND PNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PNAV CPS 500488 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10918.000 SIGM. PNAV 14.430 TPHI.PNAV 29.506 SBHF. PNAV 28.943 SBHN. PNAV 40.209 SIGC.PNAV 0.904 SIBH. PNAV 46.709 TRAT. PNAV 2.048 SDSI.PNAV 0.281 BACK. TDTP 124.964 FBAC. TDTP 31.275 TCAN. PNAV 48643.172 TCAF. PNAV 18442.293 TCND.PNAV 30552.855 TCFD.PNAV 9504.840 TSCN. PNAV 10775.352 TSCF. PNAV 4083.675 INND.PNAV 1559.405 INFD.PNAV 357.144 DEPT. 9002.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBPIN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 195.982 FBAC. TDTP 38.307 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/09/ 5 ORIGIN : FLIC TAPE NA~E : 96226 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA INC, D.S. 15-43, PRUDHOE BAY, 50-029-22676-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1996 12:05 PAGE: 26 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/09/ 5 ORIGIN : FLIC REEL NA~E : 96226 CONTINUATION # : PREVIOUS REEL COf4~ENT : ARCO ALASKA INC, D.S. 15-43, PRUDHOE BAY, 50-029-22676-00 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD / MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MM-960527 G. GRIFFIN V. HAZHARD D.S. 15-43 500292267600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 09-SEP-96 MWD RUN 8 T. MCGUIRE N. SCALES MWD RUN 9 T. MCGUIRE N. SCALES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 10 T. MCGUIRE N. SCALES MWD RUN 11 S. BURKHARDT N. SCALES MWD RUN 12 T. MCGUIRE N. SCALES MWD RUN 13 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD S. B~T N. SCALES 22 liN 14E 4706 5172 67.80 66.30 32.60 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) lST STRING 30.000 20.000 2ND STRING 12.250 9.625 3RD STRING 8.500 7.000 PRODUCTION STRING 6.000 REMARKS: R CEiVED Alaska Oil & Ga~ Con~, ¢ommis,~ An~or~ DRILLERS DEPTH (FT) ~o.o 3555.0 8597.0 11043.0 MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. WELL 15-43 IS REPRESENTED BY RUNS 1-13. RUNS 1-6 ARE DIRECTIONAL ONLY AND NO DATA IS PRESENTED. RUNS 7-9 ARE DIRECTIONAL WITH GAMMA RAY (NGP/SGRD). RUNS 10-13 ARE GAMMA RAY (DGR/SGRC) WITH ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4). GAMMA RAY DATA FROM 8487' TO 9431' IS ACQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTOR, AND IS NOTED AS NGP/SGRD TYPE DATA. GAMMA RAY FROM 9431' TO 10950' IS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS, AND IS NOTED AS DGR/SGRC TYPE DATA. GAMMA RAY FROM 10950' TO 10980' IS SCINTILLATION TYPE (NGP/SGRD) DATA. A 3.5 AAPI SHIFT IN GAMMA RAY READINGS WAS NOTICED AFTER CHANGING OUT MUD SYSTEM TO FLO-PRO AT 8583'. THERE ARE THREE SEPARATE MEASURED AFTER DRILLING (MAD) PASSES WHICH COVER THE INTERVAL OF 9193' TO 11043'. WELL 15-43 IS DRILLED TO TD AT 11043'. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8491.0 RP 9397.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) all bit runs merged. BASELINE DEPTH GR 8490.5 8487.5 8530.5 8527.5 8540.0 8538.0 8548.0 8547.5 8555.0 8554.5 8592.5 8592.5 8597.0 8597.0 8602.5 8601.0 8612.5 8612.0 8618.5 8617.5 8626.5 8625.5 8629.0 8628.0 8631.0 8630.0 8635.5 8634.5 8636.5 8636.0 8642.0 8641.5 8649.5 8650.0 8659.5 8659.5 8661.0 8661.5 8668.0 8668.0 8680.5 8680.5 8706.5 8706.0 8714.0 8714.0 8735.0 8734.5 8744.5 8744.5 8747.0 8746.5 8752.5 8752.5 8758.0 8757.5 8763.0 8762.0 8791.0 8788.0 8811.5 8808.0 8948.5 8947.0 8953.5 8949.5 8957.0 8952.5 8961.0 8956.5 8965.5 8964.5 8969.0 8967.0 9002.0 8999.0 9005.5 9004.5 9012.5 9010.5 9033.5 9032.5 9069.0 9066.5 9082.5 9081.0 STOP DEPTH 10982.0 10959.0 (WALS, open hole, 17-MAY-96) EQUIVALENT UNSHIFTED DEPTH 9098 .'0 9124.0 9129.5 9133.5 9140.0 9163.0 9182.0 9191.5 9198.5 9226.0 9236.5 9253.0 9260.0 9268.5 9287.5 9302.0 9316.5 9321.5 9327.5 11043.5 $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: 9095.5 9122.0 9127.0 9131.0 9137.5 9161.5 9179.0 9188.5 9195.5 9224.0 9234.5 9250.5 9259.0 9266.5 9285.5 9300.0 9315.0 9320.0 9326.5 11042.5 BIT RUN NO 7 8 9 10 11 12 13 MERGED MAIN PASS. MERGE TOP 8613.0 8902.0 9269.0 9492.0 9803.0 9908.0 10860.0 MERGE BASE 8902.0 9269.0 9492.0 9803.0 9908.0 10860.0 11043.0 / ??SHIFT. OUT $ CN : ARCO ALASKA, WN : D.S. 15-43 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: INC. Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 'RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) Total Data Records: 165 998 BYTES * 4 4 4 28 90 120 46 90 120 46 90 180 01 90 810 01 Tape File Start Depth = 11044.000000 Tape File End Depth = 8487.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40921 datums Tape Subfile: 2 337 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR $ MERGED DATA SOURCE PBU TOOL CODE MAD MAD MAD $ REMARKS: CN WN FN COUN STAT .5000 START DEPTH STOP DEPTH 9197.0 10953.0 9203.0 10960.0 MAD RUN NO. MAD PASS NO. MERGE TOP 10 1 9193.0 11 2 9480.0 13 3 9889.0 MERGE BASE 9480.0 9889.0 11043.0 MERGED MAD PASS. ABOVE SPLICE DEPTHS ARE FOR GR CURVE. $ : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 ROP MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 121 Tape File Start Depth = 11044.000000 Tape' File End Depth = 9180.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29833 datums Tape Subfile: 3 148 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8487.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8777.0 15-MAY-96 MSC 1.32 DEP 2.041 MEMORY 8902.0 8613.0 8902.0 0 20.6 25.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 10.20 73.0 9.3 37800 19.6 .000 .000 .000 .000 .0 112.1 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 7. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 I AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 Tape File Start Depth = 8910.000000 Tape File End Depth = 8487.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 43463 datums Tape Subfile: 4 74 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8777.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : 'BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ STOP DEPTH 9207.0 NATURAL GAMMA PROBE 16 -MAY- 96 MSC 1.32 DEP 2.041 MEMORY 9269.0 8902.0 9269.0 0 26.0 58.2 TOOL NUMBER NGP 38 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 66.0 7.7 33500 4.4 .000 .000 .000 .000 .0 116.6 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 8. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 13 Tape File Start Depth = 9280.000000 Tape File End Depth = 8765.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 32927 datums Tape Subfile: 5 76 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9165.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG)~ MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ STOP DEPTH 9431.0 NATURAL GAMMA PROBE 17-MAY-96 MSC 1.32 DEP 2.041 MEMORY 9492.0 9269.0 9492.0 0 62.1 93.5 TOOL NUMBER NGP 188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 66.0 7.7 33500 4.4 .000 .000 .000 .000 .0 113.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN); EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 9. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 9 Tape File Start Depth = 9500.000000 Tape File End Depth = 9150.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45567 datums Tape Subfile: 6 72 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 0' : 000' 00' : (MI) NOI£D.~%IHOD .~qoM : X,I, ISNHG XIH,~,~54 e · X IH.l.k~4 qOO.~. NOHA~HN O. O' E'~LI O' 000 ' 000 ' 000 ' 000 ' 0'9 O0~J[:E 0'8 0 'OL 00'6 OHcI-OqzI 0't698 000'9 :(~) H~6HG ONISVD S,HHqqIHG :(NI) HZIS ~I8 HTOH NH~O V~G DNIS~D GN~f HTOHHH0~ 9~SE0~0~ ~SE0g0~ HHS~nN TOOA ~ ' SISHH ' Dk540H.I. DHTH ~HMH AYH ~A54~D T~fflO HOG H~A.~. TO0.1. HOOD TO0.~, HOGNHA (HO.~J. Oa 0.~. aOZ) DNIH.~.S qO0.~. 0'E6 '68 0 0'E086 0'E6~6 0'£086 I~0'E 6HG 9 6-A~- 8I 0'61L6 0 ' EIL6 H.~.~HG ~03.S 'saI!] aSw~edas u! un~ $!q qsea ~o] wSwp ~apeaq BoI puw OMI{ Mtqt 9 : H.~HflN H.~O~H SIT :adX$ s! L eI!~qns edwA CN WN FN COUN STAT MWD RUN 10. $ : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 FET MWD 68 1 HR 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 180 01 1 4 4 90 810 01 1 _____~_ 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 29 Tape File Start Depth = 9815.000000 Tape File End Depth = 9375.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 39976 datums Tape Subfile: 7 94 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9701.0 EWR4 9708.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9817.0 9824.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 19-MAY-96 MSC 1.32 DEP 2.041 MEMORY 9908.0 9803.0 9908.0 0 88.5 90.4 TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 62.0 8.9 35800 4.0 .000 .000 .000 .000 .0 116.6 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 CN WN FN COUN STAT MWD RUN 11. $ : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 FET MWD 68 1 HR 7 ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) Total Data Records: 15 998 BYTES * Tape File Start Depth = 9915.000000 Tape File End Depth = 9695.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49096 datums Tape Subfile: 8 80 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9796.0 EWR4 9803.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10769.0 10776.0 20-MAY- 96 MSC 1.32 DEP 2.041 MEMORY 10860.0 9908.0 10860.0 0 86.6 95.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 55.0 8.5 32100 4.0 .000 .000 .000 .000 .0 167.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 12. $ : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE~ 0) 998 BYTES * Total Data Records: 71 Tape File Start Depth = 10875.000000 Tape File End Depth = 9785.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57425 datums Tape Subfile: 9 136 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10749.0 EWR4 10756.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10951.0 10958.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 21-MAY- 96 MSC 1.32 DEP 2.041 MEMORY 11043.0 10860.0 11043.0 0 86.6 87.7 TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 65.0 8.5 36800 4.0 .000 .000 .000 .000 .0 168.8 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 13. $ : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 20 Tape File Start Depth = 11043.000000 Tape File End Depth = 10740.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53953 datums Tape Subfile: 10 85 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 10 MAD PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9193.0 EWR4 9200.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9388.0 9395.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 17-MAY-96 MSC 1.32 DEP 2.041 MEMORY 9492.0 9193.0 9395.0 0 62.1 93.5 TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 66.0 7.7 33500 4.4 .000 .000 .000 .000 .0 113.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: MAD PASS WAS RUN WHILE TRIPPING IN THE HOLE TO START MWD RUN 10. $ CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 2 RPX MAD 68 1 OHMM 3 RPS MAD 68 1 OHMM 4 RPM MAD 68 1 OHMM 5 RPD MAD 68 1 OHMM 6 FET MAD 68 1 HR 7 ROP MAD 68 1 FPHR 4 4 95 995 99 1 4 4 95 995 99 1 4 4 95 995 99 1 4 4 95 995 99 1 4 4 95 995 99 1 4 4 95 995 99 1 4 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 21 Tape File Start Depth = 9490.000000 Tape File End Depth = 9180.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 62394 datums Tape Subfile: 11 88 records... Minimum record length: 38 bytes Maximum record length: 998 bytes Tape Subfile 12 is type: LIS FILE HEADER FILE NUMBER: 11 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 11 MAD PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9381.0 EWR4 9388.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUMANGLE: STOP DEPTH 9794.0 9804.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 19-MAY-96 MSC 1.32 DEP 2.041 MEMORY 9908.0 9381.0 9804.0 0 88.5 90.4 TOOL NUMBER P0502SP4 P0502SP4 6.000 8597.0 FLO-PRO 9.00 62.0 8.9 35800 4.0 .000 .000 .000 .000 .0 116.6 .0 .0 .00 .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): REMARKS: MAD PASS WAS RUN WHILE TRIPPING IN THE HOLE TO START MWD RUN 12. $ CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4' RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 ROP MAD 68 I FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 34 Tape File Start Depth = 9900.000000 Tape File End Depth = '9375.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 62362 datums Tape Subfile: 12 101 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 13 is type: LIS FILE HEADER FILE NUMBER: 12 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 13 MAD PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9734.0 EWR4 9742.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10952.0 10959.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 21-MAY-96 MSC 1.32 DEP 2.041 MEMORY 11043.0 9734.0 10959.0 0 86.6 87.7 TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 8597.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 65.0 8.5 36800 4.0 .000 .000 .000 .000 .0 168.8 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): .0 EWR FR~.QUE~CY (HZ): REMARKS: MAD PASS RUN AFTER MWD RUN 13. $ CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 ROP MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 86 Tape File Start Depth = 11043.000000 Tape File End Depth = 9725.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 83491 datums Tape Subfile: 13 152 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 14 is type: LIS 96/ 9/ 7 01 **** REEL TRAILER **** 96/ 9/ 9 01 Tape Subfile: 14 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 9 SEP 96 9:35a Elapsed execution time = 12.03 seconds. SYSTEM RETURN CODE = 0 Ill Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE 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: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6676.00 B. ESARY V. HAZ ZARD D. S. 15 - 43 500292267600 ARCO ALASKA, INC. WESTERN ATLAS LOGGING SERVICES 03-SEP-96 RUN 2 J. DAHL SEE REMARKS 22 liN 14E 4706 5172 66.30 32.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 2ND STRING 3RD STRING 12.25 PRODUCTION STRING 6.000 REMARKS: RUN 1: DIFL/GR/4CAL 20.000 110.0 7.000 8597.0 9492.0 CIRCULATION STOPPED AT 17:30 07-MAY-96. NO REPEAT MADE AT COMPANY REPRESENTATIVE'S REQUEST. RUN 2: DLL/GR/CN/DAC TD NOT TAGGED. CIRCULATION STOPPED AT 03:00 17-MAY-96. REPEAT SECTION RECORDED OVER INTERVALS SELECTED BY CUSTOMER. PIPE CONVEYED LOGGING OPERATION. WITNESSES: H. HAYWOOD, N. SCALES. NEUTRON LOG PARAMETERS: OPEN HOLE SECTION SANDSTONE MATRIX, BOREHOLE CORRECTION = 6.000", CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. NEUTRON L~G PARAMETERS: CASED HOLE ,CTION SANDSTONE MATRIX, CASING CORRECTIONS ON, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 110.0 9398.0 DIL 110.0 3564.0 DLL '8595.0 9456.0 2446 8595.0 9404.0 BCS 8595.0 9424.0 $ BASELINE CURVE FOR SHIFTS: GRCH, SWS; 17-AUG-96 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 149.5 207.0 286.0 388.5 658.0 675.5 686.5 785.0 821.0 898.5 983.5 993.5 1105.0 1139.5 1215.0 1251.0 1443.0 1594.0 1680.5 1828.0 1908.0 1987.0 2542.0 3063.0 3512.0 3550.0 3550.0 8603.5 8604.0 8598.5 8618.5 8613.0 8635.0 8629.5 8643.5 8663.0 8665.5 8660.5 8677.5 8714.0 8734.5 8729.0 8740'0 8792.0 8786.5 8811.5 8805.5 EQUIVALENT UNSHIFTED DEPTH LL8 ILD 149.5 149.5 207.0 207.0 286.0 388.5 658.0 658.0 673.5 686.0 686.0 785.0 785.0 821.0 821.0 898.5 898.5 983.5 993.5 993.5 1105.0 1105.0 1139.5 1215.0 1215.0 1251.0 1443.0 1443.0 1594.0 1594.0 1680.5 1680.5 1828.0 1907.5 1907.5 1987.0 1987.0 2541.5 2541.5 3063.0 3063.0 3512.0 3512.0 LLD 8638.0 8672.0 8735.0 all runs merged; DT 8598.5 8658.5 8709.5 8735.0 no case 88'12.0 8947.0 8948.0 8949.0 8974.0 8977.5 8978.5 8979.0 8979.5 8982.0 8995.0 8996.0 8999.5 9005.5 9006.0 9008.0 9009.0 9024.0 9034.0 9071.5 9082.0 9083.0 9093.0 9093.5 9095.5 9098.5 9100.0 9105.5 9107.5 9122.0 9123.5 9125.5 9128.0 9129.0 9131.0 9133.0 9141.5 9143.0 9143.5 9144.0 9144.5 9156.5 9157.5 9158.5 9159.0 9159.5 9160.0 9160.5 9164.0 9166.0 9166.5 9167.5 9169.0 9179.5 9182.0 9183.0 9183.5 9184.0 9184.5 9188.5 8941.5 8971.0 8972.0 8973.0 8975.0 8977.5 8989.0 8989.5 8999.0 9000.0 9002.0 9002.5 9017.5 9075.0 9086.0 9087.0 9089.0 9100.0 9102.0 9117.0 9137.0 9138.0 9138.5 9153.0 9153.5 9154.5 9160.5 9161.0 9172.5 8806.0 8940.5 8967.5 9000.0 9028.0 9065.0 9076.0 9092.0 9119.0 9121.5 9122.0 9124.0 9134.0 9135.5 9136.5 9137.0 9138.0 9150.0 9150.5 9151.0 9151.5 9152.5 9153.0 9154.0 9159.5 9160.5 9163.0 9174.5 9175.5 9176.5 9177.0 9178.0 9182.0 8942.0 8994.0 9028.5 9094.0 9115.0 9126.0 9159.0 9'189.0 9189.5 9190.0 9192.0 9193.0 9194.0 9197.0 9198.5 9204.0 9204.5 9208.5 9210.5 9219.0 9219.5 9220.5 9222.5 9223.0 9224.0 9226.5 9228.0 9228.5 9230.0 9230.5 9231.0 9231.5 9235.0 9241.0 9255.5 9256.0 9260.0 9271.5 9272.0 9272.5 9273.0 9273.5 9274.5 9275.5 9277.0 9291.0 9292.5 9322.5 9323.0 9329.5 9335.0 9335.5 9348.0 9360.5 9374.5 9375.0 9375.5 9400.5 BASELINE DEPTH 8604.0 8618.5 8635.0 8665.5 8734.5 8792.0 8811.5 9182.5 9183.5 9186.5 9187.0 9212.5 9213.0 9222.5 9223.5 9224.0 9227.5 9315.0 9315.5 9352.0 NPHI 8598.5 8613.0 8629.5 8660.5 8729.0 8786.5 8806.5 9183.0 9183.5 9184.5 9187.5 9190.5 9192.0 9196.5 9197.0 9201.5 9203.5 9211.5 9215.0 9216.0 9217.0 9220.0 9221.5 9224.5 9234.0 9252.5 9265.0 9266.0 9267.0 9268.0 9268.5 9269.0 9270.0 9285.0 9286.5 9323.0 9330.5 9331.0 9370.5 9371.0 9371.5 9185.0 9221.0 9248.0 9249.0 9265.5 9266.0 9270.0 9341.0 9394.0 8832.0 8948.0 8966.5 8977.5 8978.5 8979.0 8979.5 8982.0 8995.0 8996.0 9005.5 9006.0 9008.0 9009.0 9024.0 9082.0 9093.0 9093.5 9095.5 9105.5 9107.5 9123.5 9143.5 9144.0 9144.5 9163.5 9179.5 9189.5 9190.0 9193.0 9194.0 9219.5 9220.5 9230.0 9230.5 9231.0 9235.0 9322.5 9323.0 9360.5 $ MERGED DATA SOURCE PBU TOOL CODE GR GR DIL DLL 2446 BCS $ REMARKS: ~o27.0 8941.5 8960.0 8971.0 8972.0 8973.0 8975.0 8977.5 8989.0 8989.5 8999.0 9000.0 9002.0 9002.5 9017.5 9075.0 9086.0 9087.0 9089.0 9100.0 9102.0 9117.0 9137.0 9138.0 9138.5 9157.0 9172.5 9182.5 9183.5 9186.5 9187.0 9212.5 9213.0 9222.5 9223.5 9224.0 9227.5 9315.0 9315.5 9352.0 RUN NO. 1 2 1 2 2 2 PASS NO. 1 5 1 5 5 5 MERGE TOP 110.0 8595.0 110.0 8595.0 8595.0 8595.0 OPEN HOLE PORTION OF THE MAIN PASS. MERGE BASE 3519.0 9398.0 3564.0 9456.0 9404.0 9424.0 C13, C24, DI, ILM, RT, & SP WERE SHIFTED WITH ILD. LLD, MTEM, TEND, & TENS WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI THERE IS A GAP IN THE DATA BETWEEN RUN 1 & RUN 2 DUE TO NOT BEING LOGGED. CN WN FN COUN STAT /??MATCHi.OUT /??MATCH2.0UT /??MATCH3.0UT /??MATCH4.0UT /??MATCH5.0UT /??MATCH6.0UT $ : ARCO Alaska Inc. : D.S. 15-43 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units 1 DTS BCS 68 1 US/F 2 GRS BCS 68 I GAPI 3 MTEM BCS 68 1 DEG 4 TEND BCS 68 1 LB 5 TENS BCS 68 1 LB 6 C13 DIL 68 1 IN 7 C24 DIL 68 1 IN 8 DI DIL 68 1 IN 9 LL8 DIL 68 1 OHMM 10 ILD DIL 68 1 OHMM 11' ILM DIL 68 1 OHMM 12 RT DIL 68 1 OHMM 13 SP DIL 68 1 MV 14 LL3 DLL 68 1 OHMM 15 LLDS DLL 68 1 OHMM 16 FUCT 2446 68 1 CPS 17 NPHI 2446 68 1 PU-S 18 NUCT 2446 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 57 530 16 1 4 4 57 995 99 1 4 4 57 995 99 1 4 4 57 995 99 1 4 4 57 995 99 1 4 4 12 995 99 1 4 4 12 995 99 1 4 4 12 995 99 1 4 4 12 995 99 1 4 4 12 995 99 1 4 4 12 995 99 1 4 4 12 220 06 1 '4 4 12 995 99 1 4 4 17 995 99 1 4 4 17 995 99 1 4 4 47 995 99 1 4 4 47 995 99 1 4 4 47 995 99 1 72 * DATA RECORD (TYPE# 0) Total Data Records: 1441 994 BYTES * Tape File Start Depth = 9475.000000 Tape File End Depth = 110.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 355890 datums Tape Subfile: 2 1759 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 8095.0 2446 8095.0 $ BASELINE CURVE FOR SHIFTS: GRCH, CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GRCH 8107.0 8102.0 8113.5 8108.5 8117.0 8112.5 8119.0 8114.5 8125.0 8120.0 8125.5 8120.5 8133.5 8128.0 8134.0 8128.5 8134.5 8129.5 8149.0 8162.5 8157.5 8163.5 8158.0 8166.0 8160.5 8171.0 8166.0 8171.5 8166.5 8172.5 8167.0 8212.0 8206.5 8213.0 8207.0 8214.0 8208.0 8214.5 8209.0 8217.5 8212.0 8219.0 8214.0 8242.0 8237.0 8248.0 8242.5 8257.0 8282.0 8276.5 8282.5 8277.5 8283.0 8278.0 8310.0 8304.5 8315.0 8309.5 8317.5 8312.5 8342.0 8337.0 8343.0 8337.5 8347.5 8342.0 8350.5 8344.5 8353.0 8347.0 8393.5 8388.0 8404.5 8399.0 8432.5 8426.5 8545.5 8540.5 STOP DEPTH 8595.0 8595.0 SWS; 17-AUG-96 EQUIVALENT UNSHIFTED DEPTH NPHI 8102.0 8108.5 8112.5 8114.5 8120.0 8120.5 8128.0 8128.5 8129.5 8143.5 8157.5 8158.0 8160.5 8166.0 8166.5 8167.0 8206.5 8207,0 8208.0 8209.0 8212.0 8214.0 8237.0 8242.5 8252.5 8276.5 8277.5 8278.0 8304.5 8309.5 8312.5 8337.0 8337.5 8342.0 8344.5 8347.0 8388.0 8399.0 8426.5 8540.5 8560.0 8560.5 8586.0 8586.5 $ REMARKS: 55.0 8556.0 8580.5 8581.0 8555.0 8556.0 8580.5 8581.0 CASED HOLE SECTION. / ? ?MATCH7. OUT /??MATCHS. OUT $ CN : WN : FN : COUN : STAT : * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2446 68 1 GAPI 4 2 FUCT 2446 68 1 CPS 4 3 NPHI 2446 68 1 PU-S 4 4 NUCT 2446 68 1 CPS 4 5 TEND 2446 68 1 LB 4 6 TENS 2446 68 1 LB 4 4 47 995 99 1 4 47 995 99 1 4 47 995 99 1 4 47 995 99 1 4 47 995 99 1 4 47 995 99 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 29 Tape File Start Depth = 8600.000000 Tape File End Depth = 8090.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7148 datums Tape Subfile: 3 103 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 101.0 3522.0 DIFL 101.0 3567.0 4CAL 101.0 3567.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 07-MAY-96 FSYS REV. J001 VER. 1.1 1730 07-MAY-96 2141 07-MAY-96 3565.0 3567.0 110.0 3564.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR 4CAL DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMARAY 4-ARM CALIPER DUAL INDUCTION TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 4203XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 12.250 110.0 0.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (MT) MUD FILTRATE AT MT: SPUD MUD 9.20 0.0 7.8 15.6 70.0 3.700 3.700 2.950 70.0 70.0 70.0 MUD FILTRATE ~.~ BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: RUN 1 MAIN PASS. 0000 3.260 0.000 0.00 0.000 1.5 0.0 70.0 0.0 THERE WAS NO REPEAT PASS MADE FOR RUN 1 PER BP REQUEST. CN : ARCO ALASKA INC. WN : D.S. 15-43 FN : COUN : STAT : * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 C13 DIFL 68 1 IN 4 2 C24 DIFL 68 1 IN 4 3 CAL DIFL 68 1 IN 4 4 CHT DIFL 68 1 LB 4 5 GR DIFL 68 1 GAPI 4 6 TEMP DIFL 68 1 DEGF 4 7 TTEN DIFL 68 1 LB 4 8 DI DIFL 68 1 IN 4 9 RFOC DIFL 68 1 OHMM 4 10 RILD DIFL 68 1 OHMM 4 11 RILM DIFL 68 1 OHMM 4 12 RT DIFL 68 1 OHMM 4 13 SP DIFL 68 1 MV 4 4 11 280 13 1 4 11 280 24 1 4 11 280 99 1 4 11 635 99 1 4 11 310 01 1 4 11 660 99 1 4 11 635 99 1 4 11 120 44 1 4 11 220 06 1 4 11 120 46 1 4 11 120 44 1 4 11 120 46 1 4 07 010 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 772 Tape File Start Depth = Tape File End Depth = 3570.000000 98.000000 Tape File Level S~=cing = Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 550337 datums Tape Subfile: 4 852 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0.250000 Tape Subfile 5 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String ~1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 2 1 5 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8095.0 9400.0 DLL 8550.0 9458.0 2446 8595.0 9406.0 AC 8520.0 9426.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : 17-MAY-96 ECLIPS 2.2 0300 17-MAY-96 1434 17-MAY-96 9492.0 9470.0 8595.0 9424.0 0.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV MIS MIS TTRM COMR KNJT DGR CN KNJT KNJT DAC SLAM KNJT MSUB DLL TGRD $ SWIVEL MASS ISOLATION MASS ISOLATION TEMPERATURE COMMON REMOTE KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT DIGITAL ACOUSTILOG SLAM ADAPTER KNUCKLE JOINT MASS ISLOLATION DUAL LATEROLOG TOOL GUARD TOOL NUMBER 3944XA 3997XA 3997XA 3981XA 3510XA 3923XA 1329XA 2446XA 3923XA 3923XA 1667EA/1680MA 3516XA 3923XA 3967XB 1229EB/1229MA 1313ZZ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.000 8597.0 8595.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD~ AT BOTTOM HOLE TEMPERATURE (MT) MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: RUN 2 MAIN PASS. $ CN : WN : FN : COUN : · STAT : O-PRO 9.00 64.0 8.0 4.4 172.0 0.095 0.044 0.081 0.000 0.121 0.000 THERMAL SANDSTONE 0.00 6.000 0.0 78.0 172.0 75.0 0.0 70.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 CHT DAC 68 1 LB 2 AC DAC 68 1 US/F 3 GR DAC 68 1 GAPI 4 TEN DAC 68 1 LB 5 TTEN DAC 68 1 LB 6 TEMP DAC 68 1 DEGF 7 CN 2446 68 1 PU-L 8 CNC 2446 68 1 PU-S 9 CNCF 2446 68 1 PU-S 10 LSN 2446 68 1 CPS 11 SSN 2446 68 1 CPS 12 RD DLL 68 1 OHMM 13 RS DLL 68 1 OHMM 4 4 56 635 99 1 4 4 56 995 99 1 4 4 56 310 01 1 4 4 56 635 99 1 4 4 56 635 99 1 4 4 56 995 99 1 4 4 47 890 01 1 4 4 47 995 99 1 4 4 47 995 99 1 4 4 47 334 31 1 4 4 47 334 30 1 4 4 17 220 10 1 4 4 17 220 09 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 340 Tape File Start Depth = 9476.000000 Tape File End Depth = 7950.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 92619 datums Tape Subfile: 5 426 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 2 1 4 0.2500 VENDOR TOOL CODE START DEPTH GR 8095.0 DLL 8550.0 2446 8595.0 AC 8520.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9400.0 9458.0 9406.0 9426.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV MIS MIS TTRM COMR KNJT DGR CN KNJT KNJT DAC SLAM KNJT MSUB DLL TGRD $ SWIVEL MASS ISOLATION MASS ISOLATION TEMPERATURE COMMON REMOTE KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT DIGITAL ACOUSTILOG SLAM ADAPTER KNUCKLE JOINT MASS ISLOLATION DUAL LATEROLOG TOOL GUARD BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): IX)GGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 17-MAY-96 ECLIPS 2.2 0300 17-MAY-96 1356 17-MAY-96 9492.0 9470.0 8595.0 9424.0 0.0 TOOL NUMBER 3944XA 3997XA 3997XA 3981XA 3510XA 3923XA 1329XA 2446XA 3923XA 3923XA 1667EA/1680MA 3516XA 3923XA 3967XB 1229EB/1229MA 1313ZZ 6.000 8597.0 8595.0 FLO-PRO 9'.00 MUD VISCOSITY ($,o MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (MT) MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: RUN 2 REPEAT PASS. $ CN ' WN : FN : COUN : STAT : ~.0 8.0 4.4 172.0 0.095 0.044 0.081 0.000 0.121 0.000 THERMAL SANDSTONE 0.00 6.000 0.0 78.0 172.0 75.0 0.0 70.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 CHT DAC 68 1 LB 4 2 AC DAC 68 1 US/F 4 3 GR DAC 68 1 GAPI 4 4 TEN DAC 68 1 LB 4 5 TTEN DAC 68 1 LB 4 6 TEMP DAC 68 1 DEGF 4 7 CN 2446 68 1 PU-L 4 8 CNC 2446 68 1 PU-S 4 9 CNCF 2446 68 1 PU-S 4 10 LSN 2446 68 1 CPS 4 11 SSN 2446 68 1 CPS 4 12 RD DLL 68 1 OHMM 4 13 RS DLL 68 1 OHMM 4 4 56 635 99 1 4 56 995 99 1 4 56 310 01 1 4 56 635 99 1 4 56 635 99 1 4 56 995 99 1 4 47 890 01 1 4 47 995 99 1 4 47 995 99 1 4 47 334 31 1 4 47 334 30 1 4 17 220 10 1 4 17 220 09 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 101 Tape File Start Depth = 9422.000000 Tape File End Depth = 8972.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 575552 datums Tape Subfile: 6 185 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS 96/ 9/ 4 01 **** REEL TRAILER **** 96/ 9/10 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 10 SEP 96 10:48a Elapsed execution time = 52.68 seconds. SYSTEM RETURN CODE = 0
