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Home My WebLink About196-115CAUTION: 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. Some people who received this message don't often get email from michael.heinzbrown@hilcorp.com. Learn whythis is important From:Brooks, Phoebe L (OGC) To:Michael Heinz-Brown - (C) Cc:Regg, James B (OGC) Subject:RE: MPE-17 MIT-T_MIT-IA Date:Monday, January 22, 2024 5:00:41 PM Attachments:MIT MPU E-17 12-04-23 Revised.xlsx Attached is a revised report changing the interval to “O”, adding remarks, changing the Packer tvd to 6885’ and removing the inspector’s name from the AOGCC Rep field per the inspector. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Michael Heinz-Brown - (C) <Michael.HeinzBrown@hilcorp.com> Sent: Tuesday, December 5, 2023 6:50 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com>; Todd Sidoti <Todd.Sidoti@hilcorp.com>; Derek Weglin <Derek.Weglin@hilcorp.com> Subject: MPE-17 MIT-T_MIT-IA Please find attached for MIT-T and MIT-IA performed on MPE-17. Thank you, Mike Heinz-Brown | Milne Point | DSM | Hilcorp Alaska Rig Office: 907-685-1266 | Cell: 480-296-5214 Milne Pt Unit E-17 PTD 1961150 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1961150 Type Inj W Tubing 0 3550 3510 3510 Type Test P Packer TVD 6885 BBL Pump 2.5 IA 0 0 0 0 Interval O Test psi 3000 BBL Return 2.5 OA 40 40 40 40 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1961150 Type Inj W Tubing 0 0 0 0 Type Test P Packer TVD 6885 BBL Pump 3.8 IA 0 1900 1900 1900 Interval O Test psi 1800 BBL Return 3.8 OA 90 95 95 95 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: HILCORP ALASKA, LLC MILNE POINT UNIT / MPU E-17 A.HABERTHUR / M.HEINZ-BROWN 12/04/23 Notes:MIT-T. Tested to 3500psi due to Packer full set minimum. Notes: Notes: Notes: E-17 E-17 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MIT-IA after new tubing and packer were run during RWO. Notes: Notes: Form 10-426 (Revised 01/2017)2023-1204_MIT_MPU_E-17_2tests            J. Regg; 5/6/2024 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC E-17 MILNE PT UNIT E-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/25/2024 E-17 50-029-22687-00-00 196-115-0 W SPT 6885 1961150 1721 1675 1675 1692 1688 97 332 330 330 INITAL P Guy Cook 12/15/2023 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT E-17 Inspection Date: Tubing OA Packer Depth 168 2355 2305 2294IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC231214193959 BBL Pumped:4.8 BBL Returned:4.1 Thursday, January 25, 2024 Page 1 of 1           Test due 2/28/2022; well SI since 6/2020; put on injection 12/6/2023 (jbr) 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install 3-1/2" Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 16,565 feet N/A feet true vertical 7,207 feet N/A feet Effective Depth measured 16,433 feet feet true vertical feet feet 7,167 Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 / TSH-563 15,536' 6,870' SLB MRP Ret. Baker S-3 4.5" Baker HMC Packers and SSSV (type, measured and true vertical depth)4.5 Baker KB N.A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 20" 9-5/8" 112' 5,410psi 7,500psi N/A 5,750psi 7,240psi 8,430psi 9,185' 4,676' N/A 3,090psi 15,806' 16,565' 9,185'Surface Intermediate Length Liner 15,806' 16,565' Casing Conductor ADL0025518, ADL0028231 & ADL0028232 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT E-17 Plugs Junk measured measured TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-115 50-029-22687-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: 0 0 32450 1827 Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 112' 0 Size 112' 2545 920 Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical 6,963' 7,207' Burst Collapse 15,488, 15,582, 15,618 & 16,151 6,854, 6,885, 6,898 & 7,080 323-259 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:17 pm, Jan 17, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.01.17 12:00:40 - 09'00' Taylor Wellman (2143) RBDMS JSB 012324 WCB 2024-07-02 DSR-1/26/24 _____________________________________________________________________________________ Revised By: TDF 12/12/2023 SCHEMATIC Milne Point Unit Well: MP E-17 Last Completed: 12/03/2023 PTD: 196-115 TD = 1 6,656’ (MD) / TD = 7,207’(TVD) 20” Orig.KB Elev.: 53.6’/ GL Elev.: 24.10 Nabors 4ES RKB Elev. 20.40 7” 12 9-5/8” 6 9 PBTD =16,433’(MD) / PBTD =7,167’(TVD) 10 Howco ES Cementer @ 2,130’ (2) 7” x 20’ Marker Joints F/ 15,112’ to 15,153’ 4.5” 7 8 11 (2) 4.5” x 20’ Marker Joints F/ 16,436’ to 16,520’ Tubing Cut @ ±15,522’ 1 2 3 4 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80 / N/A N/A Surface 112’ 0.355 9-5/8" Surface 40 / L-80 / Btrc 8.835” Surface 9,158’ 0.0759 7" Intermediate 26 / L-80 / BTC Mod 6.276” Surface 15,806’ 0.0383 4.5” Liner 12.6/ L-80 / BTC Mod 3.958” 15,618’ 16,565’ 0.0152 TUBING DETAIL 3.5” Tubing 9.2 / L-80 / HYD562 2.992 Surface ±15,536’ 0.0087 4.5" Tubing 12.6 / L-80 / EUE 8rd 3.958”±15,552’15,562’ 0.0152 JEWELRY DETAIL No Depth Item 1 15,385’ Viking SSD 2.813''- 3 Covered Ports for TEC Bypass (Down to Open) 2 15,435’ 4-1/2” Baker Zenith Gauge Carrier 3 15,489’ 7” x 3-1/2” SLB MRP Retrievable Packer 4 15,508’ 3-1/2” XN Nipple with RHC Plug Installed – Min ID= 2.666” 5 15,526’ 3-1/2” x 4-1/2” Overshot with Dual Pins – Btm @ 15,536’ 6 15,582’ Baker S-3 Packer 7 15,610’ 4.5”HES XN Nipple,Min ID= 3.725” 8 15,618’ 7” x 5” Baker HMC Packer 9 15,624’ WLEG – Btm @ 15,625’ 10 16,151’ 4.5” Baker Model 45 KB Iso Packer 11 16,163’ 2-7/8” XN Nipple,Min ID= 2.205”w/ PXN Plug, FN on Prong is 1-3/8” 12 16,164 WLEG – Btm @ 16,165 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 15,973’ 16,093’ 7,021’ 7,061’ 120 2/7/1997 Open Kup. B Sands 16,187’ 16,287’ 7,091’ 7,123’ 100 2/5/1997 Open Ref Log: LWD 12/22/1996. 2-3/4” Alpha Jet, 15gm, Charges 6spf @ 60 Deg. Phasing OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 30” Hole 9-5/8" 2,405 sx PF “E”, 460 sx “G”, 100 sx PF ‘C’ in 12-1/4” Hole 7” 300 sx Class “G” in 8-1/2” Hole 4-1/2” 365 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 69 -72 deg. f/ 3,350’ to 16,433 Hole Angle through perforations = 71 deg. TREE & WELLHEAD Tree 4-1/8” 5M CIW Wellhead 11” x 11” 5M FMC Gen 5 11” x 4.5” NSCT Tubing Hanger and 4” CIW ‘H’ Profile profile. GENERAL WELL INFO API: 50-029-22687-00-00 Drilled and Cased by Nabors 22E - 1/1/1997 Completed & Perforated by Nabors 4ES – 2/7/1997 Isolation Packer Set w/ CTU – 2/21/2002 Install 3-1/2” Tubing w/ Overshot by ASR – 12/3/2024 Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 ASR #1 50-029-22687-00-00 196-115 11/27/2023 12/15/2023 11/24/2023 - Friday No operations to report. 11/22/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/23/2023 - Thursday No operations to report. WELLHEAD; M/U Tbar pullled CTS plug/BPV well was dead no pressure, M/U LJ into hanger BOLDS pulled hanger to floor using casing jacks. then layed down hanger and LJ.Continue troubleshooting Casing Jacks. Repair jacks to fully functional, Install landing joint. Jack the hanger to the rig floor, lay it down. Continue POOH, jacking 4-1/2'' tubing, filling with double displacement. POOH from ~15,550' to 14,552' MD. No operations to report. 11/25/2023 - Saturday Rig up on E-17. Rig Aaccepted at 0600 HRS. Rig up and test BOP's as per sundry 250 / 2500 PSI. No failures. Perform accumulator tests. Nipple down riser and spools. Rig up casing jacks utilizing the crane. Troubleshoot Casing Jack electrical issues. 11/28/2023 - Tuesday 11/26/2023 - Sunday No operations to report. 11/27/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 ASR #1 50-029-22687-00-00 196-115 11/27/2023 12/15/2023 12/1/2023 - Friday POOH w/ 373 joints and one 14.54' cut joint of 4-1/2 IBT-M. Pumping double displacement. Change handling equipment to 3- 1/2". Load Pipe on racks & Tally Pipe and Jewelry. PU & MU Overshot Assy., XN Nipple, SLB MRP Retrievable Packer, BOT Gauge Mandrel, SSD. RIH w/ 3-1/2",9.2#,L, TSH-563 completion to 1,409' MD while maintaining double displacement and clamping TEC every other joint. 11/29/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue POOH, jacking 4 1/2'' tubing, filling with double displacement F/ 13,907' T/ 12,266' MD. 11/30/2023 - Thursday Continue PU & MU - TIW, Landing Joint, Hanger. Land Hanger, RILDS. EOT @ ~ 12,266' MD. Secure well. RD Casing Jacks, RU Spacers & Spools. Lay Mast over, replace Load Cell in Mast. Troubleshoot Load Cell issues. BOLDS, pull Hanger and LD. Continue POOH w/ 4-1/2" completion on Elevators F/ 12,266' - T/ 8,901' while maintaining double displacement. WELLHEAD: Set 4" Bpv RIG ND and pull BOP. Clean void, new RX 54 gasket and term 1/4" tech line through adapter. Torque to spec and test 500/5000 (PASS). Bled off void and attempt to pull Bpv (unable to pull due to pressure. MPU Well Support tied well into process,PT'd all surface lines and serviced wellhead. Wellhead Crew pulled BPV. Turned well over to I&E Group. No issues. Cont. RIH w/ 3-1/2",9.2#,L, TSH-563 completion from 1,409' to 11,376' MD while maintaining double displacement and clamping TEC every other joint. 12/2/2023 - Saturday PT SL PCE to 3,600psi. Remove TWC. RIH w/ 3-1/2" GR, CAT Standing Valve. Set Packer, MIT-T to 3,500psi - Good Test, MIT-IA to 1,900psi - Good Test. Unable to shift SSD open to FP IA & TBG. RD Slickline. Set BPV & secure well. RDMO ASR-1. 12/5/2023 - Tuesday 12/3/2023 - Sunday Cont. RIH w/ 3-1/2",9.2#,L, TSH-563 completion from 11,376' to 15,536' MD while maintaining double displacement and clamping TEC every other joint. Space out and land Hanger w/ EOT at 15,535' MD. RILDS, install TWC. MIRU Slickline w/ full PCE. Test PCE 250 Low. MU 4 " tbg hgr and LJ to string, cut and term 1/4" tech line through hgr. Five ft into profile 17.61' RILDS and BOLJ. RIG to pump and Slick Line ops. Set 4" Bpv for RD. 12/4/2023 - Monday Set Packer, MIT-T to 3,500psi - Good Test, MIT-IA to 1,900psi - Good Test. Cont. RIH w/ 3-1/2",9.2#,L, TSH-563 completion from 11,376' to 15,536' MD while maintaining double displacement and clamping TEC every other joint. Space out and land Hanger w/ EOT at 15,535' MD. RILDS, install TWC POOH w/ 373 joints and one 14.54' cut joint of 4-1/2 IBT-M Change handling equipment to 3- 1/2". Load Pipe on racks & Tally Pipe and Jewelry. PU & MU Overshot Assy., XN Nipple, SLB MRP Retrievable Packer, BOT Gauge Mandrel, SSD. RIH w/ 3-1/2",9.2#,L, TSH-563 completion to 1,409' MD while maintaining double displacement and clamping TEC every other joint. Cont. RIH w/ 3-1/2",9.2#,L, TSH-563 completion from 1,409' to 11,376' MD Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 WS & Fullbore 50-029-22687-00-00 196-115 11/27/2023 12/15/2023 12/8/2023 - Friday RAN 2" PUMP BAILER. SAT DOWN SOLID @ 15,580' SLM. RDMO. WELL TURNED OVER TO DSO FOR INJECTION. 12/6/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MPU Well Support tied well into process,PT'd all surface lines and serviced wellhead. Wellhead Crew pulled BPV. Turned well over to I&E Group. No issues. T/I/O=0/37/0 Load & Freeze protect TBG for Slickline. Pumped 160 bbls of 110* 1% KCL with safe lube down TBG. Freeze protected with 30 bbls of 100* diesel. Final Whps=560/75/0. 12/7/2023 - Thursday OPEN SSD @ 15,389' MD. FREEZE PROTECT IA W/ 80 BBLS DIESEL. CLOSE SSD @ 15,389 MD. PT IA TO 1500 PSI. LOST 29 PSI IN 10 MIN. PASSED. T/I/O=1636/627/427 MIT-IA PASSED to 1688 psi. Pressured up IA to 1714 psi with 2 bbls diesel. 1st 15 min IA lost 24 psi. 2nd 15 min IA lost 2 psi for a total loss of 26 psi in 30 min. Bled back 2 bbls. Final Whps=1636/725/425. No operations to report. 12/9/2023 - Saturday No operations to report. 12/12/2023 - Tuesday 12/10/2023 - Sunday No operations to report. 12/11/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 WS & Fullbore 50-029-22687-00-00 196-115 11/27/2023 12/15/2023 12/15/2023 - Friday T/I/O = 1675/168/97 AOGCC MIT-IA 2200 psi Witnessed by Guy Cook **Passed**, 4.8 bbls Diesel to pressure up, 15 min IA lost 50 psi, 30 min IA lost 11 psi, FWP = 1687/163/100. 12/13/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/14/2023 - Thursday No operations to report. No operations to report. No operations to report. 12/16/2023 - Saturday No operations to report. 12/19/2023 - Tuesday 12/17/2023 - Sunday No operations to report. 12/18/2023 - Monday AOGCC MIT-IA 2200 psi Witnessed by Guy Cook **Passed**, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: MPE-17 (PTD #1961150) - RWO, passing MIT-IA Date:Wednesday, December 6, 2023 3:49:03 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, December 6, 2023 1:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPE-17 (PTD #1961150) - RWO, passing MIT-IA Mr. Wallace, WAG Injector MPE-17 (PTD #1961150) had a passing MIT-IA on 12/4/23 to 1900 psi after new tubing & packer were run during the RWO. The well is now classified as OPERABLE. An online MIT-IA will be performed once on stabilized injection per sundry 323-259. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Wyatt Rivard < wrivard@hilcorp.com> Sent: Friday, June 12, 2020 7:20 PM To: Wallace, Chris D ( CED) Cc: Schwartz, Guy L ( CED); Regg, James B ( CED); David Gorm; David Haakinson; Chad Helgeson; Darci Horner - (C); Alaska NS - Wells Foreman; Alaska NS - Milne - Wellsite Supervisors Subject: MPU Injector E- 17 (PTD # 1961150) Shut -In For TxIA Communication Attachments: E- 17 TIO.XLSX All, Milne point WAG injector E- 17 ( PTD # 1961150) was shut-in today for TxlA communication after the IA was observed at 2480 psi ( injection pressure). There were no previous indications of IA pressurization. A TIO plot is attached for reference. The well' s IA was bled to 80 psi but immediately began to repressure. T/ I/ O stabilized after shut- in at 1850/ 1850/ 300. A tubing hanger packoff test passed to 5000 psi indicating either a tubing or packer leak. The well will remain shut in until integrity can be restored. Please call with any questions. Thank You, Wyatt Rivard I Operations Engineer IHilcorp Alaska, LLC 0: (907) 777- 8547 1 C: ( 509) 670- 80011 wrivard@hilcorg.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. From:Alaska NS - ASR - Well Site Managers To:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: MPE-17 BOPE Test Report - Initial Date:Tuesday, November 28, 2023 5:42:09 PM Attachments:Copy of MPE-17 Initial BOPE Test_11-27-2023.xlsx Re-submit Thank you Scott Heim ASR Rig Supervisor 907-685-1266 Office 907-982-9226 Cell Scott.heim@hilcorp.com From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, November 28, 2023 1:10 PM To: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] RE: MPE-17 BOPE Test Report - Initial Report is incomplete – resubmit Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Sent: Monday, November 27, 2023 8:19 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Subject: MPE-17 BOPE Test Report - Initial Please find attached. 0LOQH3RLQW8QLW( 37' Thank you, Mike Heinz-Brown | Milne Point | DSM | Hilcorp Alaska Rig Office: 907-685-1266 | Cell: 480-296-5214 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 11/27/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11961150 Sundry #323-259 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1976 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11''P Pit Level Indicators PP #1 Rams 1 2 7/8'' x 5''P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16''P Time/Pressure Test Result HCR Valves 1 2 1/16''P System Pressure (psi)2980 P Kill Line Valves 3 2 1/16''P Pressure After Closure (psi)1750 P Check Valve 0NA200 psi Attained (sec)17 P BOP Misc 0NAFull Pressure Attained (sec)56 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2313 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 14 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/25/2023 06:51 Waived By Test Start Date/Time:11/27/2023 6:30 (date) (time)Witness Test Finish Date/Time:11/27/2023 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Hilcorp Tested w/ 3-1/2" & 4-1/2 Test Mandrels Bottle average pre-charge = 1,000psi C. Greub / M. Boord Hilcorp Alaska, LLC S. Heim / M. Heinz-Brown MPU E-17 Test Pressure (psi): skans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2023-1127_BOP_Hilcorp_ASR1_MPU_E-17 9 9 9 999 9 9 9 9 9 9 -5HJJ 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 16,565 feet N/A feet true vertical 7,207 feet N/A feet Effective Depth measured 16,433 feet feet true vertical 7,167 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / BTC Mod 15,625' 6,900' Baker S-3 7" x 4.5" Baker HMC Packers and SSSV (type, measured and true vertical depth) 4.5 Baker KB Iso N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 15,582, 15,618 & 16,151 6,885, 6,898 & 7,080 322-068 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 112' 20 Size 112' 4,676' 000 0 32050 3235 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-115 MILNE PT UNIT E-17 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0028232 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT E-17 Plugs Junk measured Length 16,565' Casing Conductor 7,207'16,565' 15,806' 9,185'Surface Intermediate Liner 20" 9-5/8" 7" 112' 9,185' 7,500psi 5,750psi 7,240psi 8,430psi 15,806' 6,963' Burst N/A Collapse N/A 3,090psi 5,410psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 9:07 am, Apr 27, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533) Date: 2023.04.26 10:42:33 - 08'00' David Haakinson (3533) WCB 1-2-2024 DSR-4/27/23 50029226870000 JSb RBDMS JSB 050223 _____________________________________________________________________________________ Revised By: TDF 4/26/2023 SCHEMATIC Milne Point Unit Well: MP E-17 Last Completed: 1/15/1997 PTD: 196-115 TD = 1 6,656’ (MD) / TD = 7,207’(TVD) 20” Orig.KB Elev.: 53.6’/ GL Elev.: 24.10 Nabors 4ES RKB Elev. 20.40 7” 8 9-5/8” 2 5 PBTD =16,433’(MD) / PBTD =7,167’(TVD) 6 Howco ES Cementer @ 2,130’ (2) 7” x 20’ Marker Joints F/ 15,112’ to 15,153’ 4.5” 3 4 7 (2) 4.5” x 20’ Marker Joints F/ 16,436’ to 16,520’ Tubing Leak @ 4,549 MD 1/17/2023 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80 / N/A N/A Surface 112’ 0.355 9-5/8" Surface 40 / L-80 / Btrc 8.835” Surface 9,158’ 0.0759 7" Intermediate 26 / L-80 / BTC Mod 6.276” Surface 15,806’ 0.0383 4.5” Liner 12.6/ L-80 / BTC Mod 3.958” 15,618’ 16,565’ 0.0152 TUBING DETAIL 4.5" Tubing 12.6 / L-80 / EUE 8rd 3.958” Surface 15,625’ 0.0152 JEWELRY DETAIL No Depth Item 1 4,540’ N.S. Patch from 4,540’-4,556’Min ID =2.38” 2 15,582’ Baker S-3 Packer 3 15,610’ 4.5”HES XN Nipple,Min ID= 3.725” 4 15,618’ 7” x 5” Baker HMC Packer 5 15,624’ WLEG – Btm @ 15,625’ 6 16,151’ 4.5” Baker Model 45 KB Iso Packer 7 16,163’ 2-7/8” XN Nipple,Min ID= 2.205”w/ PXN Plug, FN on Prong is 1-3/8” 8 16,164 WLEG – Btm @ 16,165 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 15,973’ 16,093’ 7,021’ 7,061’ 120 2/7/1997 Open Kup. B Sands 16,187’ 16,287’ 7,091’ 7,123’ 100 2/5/1997 Open Ref Log: LWD 12/22/1996. 2-3/4” Alpha Jet, 15gm, Charges 6spf @ 60 Deg. Phasing OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 30” Hole 9-5/8" 2,405 sx PF “E”, 460 sx “G”, 100 sx PF ‘C’ in 12-1/4” Hole 7” 300 sx Class “G” in 8-1/2” Hole 4-1/2” 365 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 69 -72 deg. f/ 3,350’ to 16,433 Hole Angle through perforations = 71 deg. TREE & WELLHEAD Tree 4-1/8” 5M CIW Wellhead 11” x 11” 5M FMC Gen 5 11” x 4.5” NSCT Tubing Hanger and 4” CIW ‘H’ Profile profile. GENERAL WELL INFO API: 50-029-22687-00-00 Drilled and Cased by Nabors 22E - 1/1/1997 Completed & Perforated by Nabors 4ES – 2/7/1997 Isolation Packer Set w/ CTU – 2/21/2002 Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 SL 50-029-22687-00-00 196-115 3/26/2023 4/20/2023 No operations to report. No operations to report. 3/25/2022 - Saturday No operations to report. 3/28/2023 - Tuesday 3/26/2023 - Sunday WELL SHUT-IN ON ARRIVAL. RAN 4-1/2" GR, 20' x 3.70" DUMMY WHIPSTOCK, 5' x 1-7/8" STEM, 3.70" CENT (oal - 30') SMOOTH SAILING DOWN TO 4,700' SLM(target depth). WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 3/27/2023 - Monday 3/24/2022 - Friday No operations to report. 3/22/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/23/2022 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 SL 50-029-22687-00-00 196-115 3/26/2023 4/20/2023 3/31/2022 - Friday No operations to report. 3/29/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/30/2022 - Thursday No operations to report. No operations to report. No operations to report. 4/1/2022 - Saturday WELL S/I UPON ARRIVAL (patch tubing / liner). DRIFTED TBG W/ 3.78" GAUGE RING, TAGGED XN-NIPPLE @ 15,610' MD. SET 4- 1/2" XN-LOCK W/ 4-1/2" x 2-7/8" NIPPLE REDUCER IN XN-NIPPLE @ 15,610' MD (2.31" x-nipple). WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS. 4/4/2023 - Tuesday 4/2/2023 - Sunday No operations to report. 4/3/2023 - Monday SET 4- 1/2" XN-LOCK W/ 4-1/2" x 2-7/8" NIPPLE REDUCER IN XN-NIPPLE @ 15,610' MD Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 SL 50-029-22687-00-00 196-115 3/26/2023 4/20/2023 Set NS 450-368 One Trip Straddle across leak @ 4,549'. Top element @ 4,540', bottome element @ 4,556'. For detailed log, see well file in O-Drive. Job Complete. No operations to report. 4/15/2022 - Saturday No operations to report. 4/18/2023 - Tuesday 4/16/2023 - Sunday No operations to report. 4/17/2023 - Monday 4/14/2022 - Friday No operations to report. 4/12/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/13/2022 - Thursday No operations to report. Set NS 450-368 One Trip Straddle across leak @ 4,549'. Top element @ 4,540', Well Name Rig API Number Well Permit Number Start Date End Date MP E-17 SL 50-029-22687-00-00 196-115 3/26/2023 4/20/2023 No operations to report. No operations to report. 4/22/2022 - Saturday No operations to report. 4/25/2023 - Tuesday 4/23/2023 - Sunday No operations to report. 4/24/2023 - Monday 4/21/2022 - Friday No operations to report. 4/19/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Attempted MIT-IA, Pumped 20 bbls Diesel down IA, No Pressure Increase. 4/20/2022 - Thursday T/I/O=0/0/23 MIT-IA Failed (TBG Patch) Pumped 18 bbls diesel down IA and caught fluid. Unable to reach or maintain test pressure. Pumped an additional 17 bbls diesel down IA to get LLR of 1.6 bpm @ 2000 psi. Final Whp's=40/10/23 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Cut Tubing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install 3-1/2" Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16,565'N/A Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY todd.sidoti@hilcorp.com 777-8443 Todd Sidoti Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.6 / L-80 / BTC Mod 15,625' 5/15/2023 Baker S-3, 7" x 4.5" Baker HMC & 4.5 Baker KB Iso and N/A 15,582MD/ 6,885TVD, 15,618MD/ 6,898TVD & 16,151MD/ 7,080TVD and N/A See Schematic See Schematic 4.5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028232 196-115 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22687-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT E-17 Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,207' 16,433' 7,167' 1,976 N/A 112' 20" MILNE POINT MD N/A 8,430psi 5,750psi 7,240psi 4,676' 6,963' 7,207' 9,185' 15,806' 16,565' Perforation Depth MD (ft): 4-1/2"16,565' 9-5/8" 7" 9,185' 15,806' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-259 By Kayla Junke at 9:01 am, Apr 27, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533) Date: 2023.04.26 14:03:22 - 08'00' David Haakinson (3533) MDG 4/28/2023 MGR30APR2023 * BOPE test to 2500 psi. * State to witness MIT-IA to 1800 psi after setting packer before injection begins per 20 AAC 25.142 (c) and (d). * State to witness MIT-A to 1800 psi after 7 days of stabilized injection. * Variance to 20 AAC 25.412 (b) Approved for packer to be placed >200' MD above top of perforations. Packer to be placed ~500' above perforations but within the confining zones of the Kuparuk reservoir. 1,976 10-404 DSR-4/27/23 ADL0025518, ADL0028231 GCW 05/01/23JLC 5/1/2023 5/1/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.01 14:44:47 -08'00' RBDMS JSB 050223 RWO – Tubing Swap Well: MPU E-17 Date: 24 April 2023 Well Name: MPU E-17 API Number: 50-029-22687-00-00 Current Status: SI Injector [Tbg Leaks] Pad: E-Pad Estimated Start Date: May 15, 2023 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-115 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4223 (M) Second Call Engineer: Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Current Bottom Hole Pressure: 2619 psi @ 7021’ TVD 8/8/22 FL shot | 7.12 PPGE MPSP: 1917 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 73° @ 16,474’ MD Max Dogleg: 5.6°/100ft @ 1,200’ MD Brief Well Summary: MPU E-17 was drilled in December 1996 as a WAG injector. TXIA communication was verified in July 2020. A caliper was ran to assess the tubing condition and it was found to be poor, with 55 joints demonstrating 41- 85% penetration. A leak detection log was ran and a retrievable patch was installed from 4540-4556’ in an attempt to isolate the leak detected at 4549’. Notes Regarding Wellbore Condition x Combo MIT-IA Passed to 4,300 psig on 1/8/2023. x Tubing caliper ran to a depth of 5,440’ indicated poor tubing condition throughout the string. Objective: Pull tubing, install a 3-1/2” injection string and return well to injection. Pre-Rig Procedure (No sundry required): Eline & Fullbore 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU reverse out skid and 500 bbl returns tank. 4. MIRU slickline and pressure test PCE to 250 psi low / 2500 psi high. 5. Pull NS retrievable patch @ 4540’. RDMO slickline. 6. MIRU eline and fullbore, pressure test PCE to 250 psi low / 2500 psi high. 7. RIH with mechanical tubing cutter. 8. Pump down cutter assembly and correlate to tubing tally. 9. Cut tubing in middle of first full joint above packer ~15,552’. POOH and RDMO eline. 10. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 11. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. t full joint above packer ~15,552’. Variance required for packer placement greater than 200 fee measured depthy above the top of the perforations. - mgr RWO – Tubing Swap Well: MPU E-17 Date: 24 April 2023 12. RD fullbore pumpers and reverse out skid. 13. RU crane. Set BPV. ND tree and tubing head adapter. NU BOPE. 14. NU BOPE house. Spot mud boat. Brief RWO Procedure: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 5. MU landing joint or spear, PU and recover tubing hanger. 6. POOH and lay down the 4-1/2” tubing. 7. PU new 3-1/2” completion and run: A 3-1/2” x 4-1/2” Overshot with Dual Pins Pup Joint, 3-1/2" B Pup Joint, 3-1/2” 3-1/2” XN Nipple with Pump-out Standing Valve Installed Pup Joint, 3-1/2” C Pup Joint, 3-1/2" 7” x 3-1/2” Packer @ ~15,500’ Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" D Pup Joint, 3-1/2" Gauge Carrier, Baker, Zenith Gauge Installed Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" E Pup Joint, 3-1/2" Sliding Sleeve, 2.813" X profile, covered ports for I-wire bypass (closed) Pup Joint, 3-1/2" ~370 Joints Tubing, 3-1/2" RWO – Tubing Swap Well: MPU E-17 Date: 24 April 2023 8. Shear out on 4.5” tubing stub at ~15,550’. Space out and land tubing hanger. Note pickup and slack-off weights on tally. 9. Pump 400 bbls inhibited source water followed by 70 bbls FP down 3-1/2” x 7” IA. 10. Pump 30 bbls FP down tubing. 11. Pressure up on tubing to set packer as per manufacturer procedures. MIT-T to 3000 psi (charted). Perform MIT-IA to 1500 psi (charted). 12. Pressure up to 4200 psi to blow out standing valve. 13. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU 3-1/8” 5M tree. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Per 20 AAC 25.410 (c) and (d) 24 hour notice for state to witness. 6. Within 5 days of stabilized injection, state to witness MIT-IA to 1800 psi. - mgr 1800 psi - mgr _____________________________________________________________________________________ Revised By: TDF 1/26/2023 SCHEMATIC Milne Point Unit Well: MP E-17 Last Completed: 1/15/1997 PTD: 196-115 TD = 16,656’ (MD) / TD = 7,207’(TVD) 20” Orig.KB Elev.: 53.6’/ GL Elev.: 24.10 Nabors 4ES RKB Elev. 20.40 7” 7 9-5/8” 1 4 PBTD = 16,433’(MD) / PBTD =7,167’(TVD) 5 Howco ES Cementer @ 2,130’ (2) 7” x 20’ Marker Joints F/ 15,112’ to 15,153’ 4.5” 2 3 6 (2) 4.5” x 20’ Marker Joints F/ 16,436’ to 16,520’ Tubing Leak @ 4,549 MD 1/17/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80 / N/A N/A Surface 112’ 0.355 9-5/8" Surface 40 / L-80 / Btrc 8.835” Surface 9,158’ 0.0759 7" Intermediate 26 / L-80 / BTC Mod 6.276” Surface 15,806’ 0.0383 4.5” Liner 12.6/ L-80 / BTC Mod 3.958” 15,618’ 16,565’ 0.0152 TUBING DETAIL 4.5" Tubing 12.6 / L-80 / EUE 8rd 3.958” Surface 15,625’ 0.0152 JEWELRY DETAIL No Depth Item 1 15,582’ Baker S-3 Packer 2 15,610’ 4.5”HES XN Nipple,Min ID= 3.725” 3 15,618’ 7” x 5” Baker HMC Packer 4 15,624’ WLEG – Btm @ 15,625’ 5 16,151’ 4.5” Baker Model 45 KB Iso Packer 6 16,163’ 2-7/8” XN Nipple,Min ID= 2.205”w/ PXN Plug, FN on Prong is 1-3/8” 7 16,164 WLEG – Btm @ 16,165 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 15,973’ 16,093’ 7,021’ 7,061’ 120 2/7/1997 Open Kup. B Sands 16,187’ 16,287’ 7,091’ 7,123’ 100 2/5/1997 Open Ref Log: LWD 12/22/1996. 2-3/4” Alpha Jet, 15gm, Charges 6spf @ 60 Deg. Phasing OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 30” Hole 9-5/8" 2,405 sx PF “E”, 460 sx “G”, 100 sx PF ‘C’ in 12-1/4” Hole 7” 300 sx Class “G” in 8-1/2” Hole 4-1/2” 365 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 69 -72 deg. f/ 3,350’ to 16,433 Hole Angle through perforations = 71 deg. TREE & WELLHEAD Tree 4-1/8” 5M CIW Wellhead 11” x 11” 5M FMC Gen 5 11” x 4.5” NSCT Tubing Hanger and 4” CIW ‘H’ Profile profile. GENERAL WELL INFO API: 50-029-22687-00-00 Drilled and Cased by Nabors 22E - 1/1/1997 Completed & Perforated by Nabors 4ES – 2/7/1997 Isolation Packer Set w/ CTU – 2/21/2002 _____________________________________________________________________________________ Revised By: TDF 4/26/2023 PROPOSED Milne Point Unit Well: MP E-17 Last Completed: 1/15/1997 PTD: 196-115 TD = 1 6,656’ (MD) / TD = 7,207’(TVD) 20” Orig.KB Elev.: 53.6’/ GL Elev.: 24.10 Nabors 4ES RKB Elev. 20.40 7” 12 9-5/8” 6 9 PBTD =16,433’(MD) / PBTD =7,167’(TVD) 10 Howco ES Cementer @ 2,130’ (2) 7” x 20’ Marker Joints F/ 15,112’ to 15,153’ 4.5” 7 8 11 (2) 4.5” x 20’ Marker Joints F/ 16,436’ to 16,520’ Tubing Cut @ ±15,522’ 1 2 3 4 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80 / N/A N/A Surface 112’ 0.355 9-5/8" Surface 40 / L-80 / Btrc 8.835” Surface 9,158’ 0.0759 7" Intermediate 26 / L-80 / BTC Mod 6.276” Surface 15,806’ 0.0383 4.5” Liner 12.6/ L-80 / BTC Mod 3.958” 15,618’ 16,565’ 0.0152 TUBING DETAIL 3.5” Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface ±15,554’ 0.0087 4.5" Tubing 12.6 / L-80 / EUE 8rd 3.958”±15,552’15,562’ 0.0152 JEWELRY DETAIL No Depth Item 1 ±15,450’ Sliding Sleeve, 2.813" X profile, covered ports for I-wire bypass (closed) 2 ±15,475’ Gauge Carrier, Baker, Zenith Gauge Installed 3 ±15,500’ 7” x 3-1/2” Packer @ ~15,500’ 4 ±15,525’ 3-1/2” XN Nipple with RHC Plug Installed 5 ±15,548’ 3-1/2” x 4-1/2” Overshot with Dual Pins 6 15,582’ Baker S-3 Packer 7 15,610’ 4.5”HES XN Nipple,Min ID= 3.725” 8 15,618’ 7” x 5” Baker HMC Packer 9 15,624’ WLEG – Btm @ 15,625’ 10 16,151’ 4.5” Baker Model 45 KB Iso Packer 11 16,163’ 2-7/8” XN Nipple,Min ID= 2.205”w/ PXN Plug, FN on Prong is 1-3/8” 12 16,164 WLEG – Btm @ 16,165 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 15,973’ 16,093’ 7,021’ 7,061’ 120 2/7/1997 Open Kup. B Sands 16,187’ 16,287’ 7,091’ 7,123’ 100 2/5/1997 Open Ref Log: LWD 12/22/1996. 2-3/4” Alpha Jet, 15gm, Charges 6spf @ 60 Deg. Phasing OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 30” Hole 9-5/8" 2,405 sx PF “E”, 460 sx “G”, 100 sx PF ‘C’ in 12-1/4” Hole 7” 300 sx Class “G” in 8-1/2” Hole 4-1/2” 365 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 69 -72 deg. f/ 3,350’ to 16,433 Hole Angle through perforations = 71 deg. TREE & WELLHEAD Tree 4-1/8” 5M CIW Wellhead 11” x 11” 5M FMC Gen 5 11” x 4.5” NSCT Tubing Hanger and 4” CIW ‘H’ Profile profile. GENERAL WELL INFO API: 50-029-22687-00-00 Drilled and Cased by Nabors 22E - 1/1/1997 Completed & Perforated by Nabors 4ES – 2/7/1997 Isolation Packer Set w/ CTU – 2/21/2002 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: Revised: MP F-09 Sundry #"s 322-146 & 322-704 Withdrawal Request Date:Tuesday, April 18, 2023 11:28:27 AM Hi James, Hilcorp wants to withdraw these two sundries. They are older from 2022 and have already been processed. Kayla From: Tom Fouts <tfouts@hilcorp.com> Sent: Tuesday, April 18, 2023 10:24 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Subject: Revised: MP F-09 Sundry #'s 322-146 & 322-704 Withdrawal Request Hello, Hilcorp Alaska LLC requests the withdrawal of sundry numbers 322-146 & 322-704. We will submit a revised sundry for the proposed work on MPU F-09. Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: MP E-17 10-403 Withdrawal Request for Sundry # 322-492, PTD: 196-115 Date:Wednesday, April 26, 2023 8:55:28 AM Hi James, Hilcorp wants to withdraw this 403. Its older from August 2022 and was already processed. Thanks, Kayla From: Tom Fouts <tfouts@hilcorp.com> Sent: Wednesday, April 26, 2023 8:48 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Todd Sidoti <Todd.Sidoti@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: MP E-17 10-403 Withdrawal Request for Sundry # 322-492, PTD: 196-115 Hello, Hilcorp Alaska LLC requests the withdrawal of the 10-403 submittal for MP E-17 sent on 8/15/2022 Sundry # 322-492. We will not be installing the injection string. Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/07/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230207 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPE-17 50029226870000 196115 1/17/2023 YELLOW JACKET LDL CLU 10RD 50133205530100 222113 2/3/2023 YELLOW JACKET GPT-PERF BCU 04RD 50133202390100 219011 1/27/2023 YELLOW JACKET PERF BCU 04RD 50133202390100 219011 2/2/2023 YELLOW JACKET PERF BCU 05RD2 50133202620200 218068 1/26/2023 YELLOW JACKET PERF BCU 12A 50133205300100 214070 2/1/2023 YELLOW JACKET PLUG Please include current contact information if different from above. By Meredith Guhl at 9:51 am, Feb 07, 2023 T37492 T37492 T37493 T37494 T37495 T37496MPE-17 50029226870000 196115 1/17/2023 YELLOW JACKET LDL Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.07 10:08:10 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16,565'N/A Casing Collapse Conductor N/A Surface 3,090psi Intermediate 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9-5/8" 7" 9,185' 15,806' Perforation Depth MD (ft): 4-1/2"16,565' MD N/A 8,430psi 5,750psi 7,240psi 4,676' 6,963' 7,207' 9,185' 15,806' 16,565' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,207' 16,433' 7,167' 1,976 N/A 112' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028232 196-115 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22687-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT E-17 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.6 / L-80 / BTC Mod 15,625' 2/8/2023 7" x 4.5" Baker HMC, Baker 7"x5" HMC & 4.5 Baker KB Iso and N/A 15,618MD/ 6,898TVD, 15,618MD/ 6,898TVD & 16,151MD/ 7,080TVD and N/A See Schematic See Schematic 4.5" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 9:16 am, Feb 02, 2023 323-068 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.01.26 13:51:10 -09'00' David Haakinson (3533) DLB 02/02/2023 AOGCC to witness MIT-IA to 4300 psi after 5 days of stabilized injection. DSR-2/2/23 1,976 10-404x MGR13FEB23GCW 02/22/23 JLC 2/22/2023 2/22/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.22 15:27:05 -09'00' RBDMS JSB 022323 Well: MPE-17 PTD: 196-115 API: 50-029-22687-00-00 Well Name:MPU E-17 API Number:50-029-22687-00-00 Current Status: Shut-in Injector Pad:E-Pad Estimated Start Date:8 February 2023 Rig:E-Line Reg.Approval Req’std?Yes Date Reg. Approval Rec’vd: Regulatory Contact: Permit to Drill Number:196-115 First Call Engineer:Scott Pessetto (907) 564-4373 (801) 822-2203 (M) Second Call Engineer:Todd Sidoti (907) 777-8443 AFE Number:222-01094 Job Type:Tubing Patch Current Bottom Hole Pressure: 2679 psi @ 7021’ TVD 12/10/22 FL shot |7.33 PPGE MPSP:1976 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 73° @ 16,474’ MD Max Dogleg:5.6°/100ft @ 1,200’ MD Brief Well Summary: Milne injector MPE-17 is currently shut-in due to a TxIA leak. A spinner leak detect log was run on January 17th, 2023 and a single leak was detected at 4549’ MD. By running a 5,000psi rated patch, the well can be returned to service as an WAG injector. Notes Regarding Wellbore Condition x Combo MIT-IA Passed to 4300 psig on 1/8/2022. x E-line diagnosed leak at 4549’. See log dated 1/17/2023 x Leak was seen on spinner and CCL x Wireline loses slack-off around 7,000’ SLM. Objective: 1. Patch leak at 4,549’ MD. 2. Confirm tubing integrity. Procedure: Slickline 1. PT PCE to 3,000 psi. 2. Drift with dummy patch (~35 OAL) to 4570’ MD. 3. POOH. 4. Set 2-7/8” XN nipple reducer in 3.725” XN nipple at 15,610’ MD. 5. RDMO. E-Line 1. MIRU EL. 2. PT lines, PCE to 3,000 psi. 3. RIH with NSAK 450-368 single set straddle packer (5,000 psi rated). 4. Tie-in with leak detect log from 1/17/2023. 5. Set patch centered around leak at 4,549’. 6. Pressure IA to 2,500psi to confirm patch integrity. 7. RDMO Pumping 1. Once on stable water injection, MIT-IA to 4300 psig. Attacments: 1. Schematic 2. Proposed schematic 24 hour notice for AOGCC to witness. _____________________________________________________________________________________ Revised By: TDF 1/26/2023 SCHEMATIC Milne Point Unit Well: MP E-17 Last Completed: 1/15/1997 PTD: 196-115 TD = 16,656’ (MD) / TD = 7,207’(TVD) 20” Orig.KB Elev.: 53.6’/ GL Elev.: 24.10 Nabors 4ES RKB Elev. 20.40 7” 7 9-5/8” 1 4 PBTD = 16,433’(MD) / PBTD =7,167’(TVD) 5 Howco ES Cementer @ 2,130’ (2) 7” x 20’ Marker Joints F/ 15,112’ to 15,153’ 4.5” 2 3 6 (2) 4.5” x 20’ Marker Joints F/ 16,436’ to 16,520’ Tubing Leak @ 4,549 MD 1/17/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80 / N/A N/A Surface 112’ 0.355 9-5/8" Surface 40 / L-80 / Btrc 8.835” Surface 9,158’ 0.0759 7" Intermediate 26 / L-80 / BTC Mod 6.276” Surface 15,806’ 0.0383 4.5” Liner 12.6/ L-80 / BTC Mod 3.958” 15,618’ 16,565’ 0.0152 TUBING DETAIL 4.5" Tubing 12.6 / L-80 / EUE 8rd 3.958” Surface 15,625’ 0.0152 JEWELRY DETAIL No Depth Item 1 15,582’ Baker S-3 Packer 2 15,610’ 4.5”HES XN Nipple,Min ID= 3.725” 3 15,618’ 7” x 5” Baker HMC Packer 4 15,624’ WLEG – Btm @ 15,625’ 5 16,151’ 4.5” Baker Model 45 KB Iso Packer 6 16,163’ 2-7/8” XN Nipple,Min ID= 2.205”w/ PXN Plug, FN on Prong is 1-3/8” 7 16,164 WLEG – Btm @ 16,165 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 15,973’ 16,093’ 7,021’ 7,061’ 120 2/7/1997 Open Kup. B Sands 16,187’ 16,287’ 7,091’ 7,123’ 100 2/5/1997 Open Ref Log: LWD 12/22/1996. 2-3/4” Alpha Jet, 15gm, Charges 6spf @ 60 Deg. Phasing OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 30” Hole 9-5/8" 2,405 sx PF “E”, 460 sx “G”, 100 sx PF ‘C’ in 12-1/4” Hole 7” 300 sx Class “G” in 8-1/2” Hole 4-1/2” 365 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 69 -72 deg. f/ 3,350’ to 16,433 Hole Angle through perforations = 71 deg. TREE & WELLHEAD Tree 4-1/8” 5M CIW Wellhead 11” x 11” 5M FMC Gen 5 11” x 4.5” NSCT Tubing Hanger and 4” CIW ‘H’ Profile profile. GENERAL WELL INFO API: 50-029-22687-00-00 Drilled and Cased by Nabors 22E - 1/1/1997 Completed & Perforated by Nabors 4ES – 2/7/1997 Isolation Packer Set w/ CTU – 2/21/2002 _____________________________________________________________________________________ Revised By: STP 1/25/2023 PROPOSED Milne Point Unit Well: MP E-17 Last Completed: 1/15/1997 PTD: 196-115 TD = 16,656’ (MD) / TD = 7,207’(TVD) 20” Orig.KB Elev.: 53.6’/ GL Elev.: 24.10 Nabors 4ES RKB Elev. 20.40 7” 8 1 9-5/8” 2 5 PBTD = 16,433’(MD) / PBTD =7,167’(TVD) 6 Howco ES Cementer @ 2,130’ (2) 7” x 20’ Marker Joints F/ 15,112’ to 15,153’ 4.5” 3 4 7 (2) 4.5” x 20’ Marker Joints F/ 16,436’ to 16,520’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80 / N/A N/A Surface 112’ 0.355 9-5/8" Surface 40 / L-80 / Btrc 8.835” Surface 9,158’ 0.0759 7" Intermediate 26 / L-80 / BTC Mod 6.276” Surface 15,806’ 0.0383 4.5” Liner 12.6/ L-80 / BTC Mod 3.958” 15,618’ 16,565’ 0.0152 TUBING DETAIL 4.5" Tubing 12.6 / L-80 / EUE 8rd 3.958” Surface 15,625’ 0.0152 JEWELRY DETAIL No Depth Item 1 4,539’ Single trip 5,000psi rated, retrievable tubing patch. Min ID= 2.375” 2 15,582’ Baker S-3 Packer 3 15,610’4.5”HES XN Nipple,2-7/8” XN Nipple Reducer Min ID= 2.205” 4 15,618’ 7” x 5” Baker HMC Packer 5 15,624’ WLEG – Btm @ 15,625’ 6 16,151’ 4.5” Baker Model 45 KB Iso Packer 7 16,163’ 2-7/8” XN Nipple,Min ID= 2.205”w/ PXN Plug, FN on Prong is 1-3/8” 8 16,164 WLEG – Btm @ 16,165 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 15,973’ 16,093’ 7,021’ 7,061’ 120 2/7/1997 Open Kup. B Sands 16,187’ 16,287’ 7,091’ 7,123’ 100 2/5/1997 Open Ref Log: LWD 12/22/1996. 2-3/4” Alpha Jet, 15gm, Charges 6spf @ 60 Deg. Phasing OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 30” Hole 9-5/8" 2,405 sx PF “E”, 460 sx “G”, 100 sx PF ‘C’ in 12-1/4” Hole 7” 300 sx Class “G” in 8-1/2” Hole 4-1/2” 365 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 69 -72 deg. f/ 3,350’ to 16,433 Hole Angle through perforations = 71 deg. TREE & WELLHEAD Tree 4-1/8” 5M CIW Wellhead 11” x 11” 5M FMC Gen 5 11” x 4.5” NSCT Tubing Hanger and 4” CIW ‘H’ Profile profile. 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dƌĞĞϰͲϭͬϴ͟ϱD/t tĞůůŚĞĂĚϭϭ͟ǆϭϭ͟ϱD&D'ĞŶϱϭϭ͟ǆϰ͘ϱ͟E^ddƵďŝŶŐ,ĂŶŐĞƌĂŶĚ ϰ͟/t͚,͛WƌŽĨŝůĞƉƌŽĨŝůĞ͘ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϴϳͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϭͬϭͬϭϵϵϳ ŽŵƉůĞƚĞĚΘWĞƌĨŽƌĂƚĞĚďǇEĂďŽƌƐϰ^ʹϮͬϳͬϭϵϵϳ /ƐŽůĂƚŝŽŶWĂĐŬĞƌ^ĞƚǁͬdhʹϮͬϮϭͬϮϬϬϮ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-17 (PTD 196-115) Multi Finger Caliper Log 08/08/2020 Please include current contact information if different from above. Received by the AOGCC 11/13/2020 PTD: 1961150 E-Set: 34246 Abby Bell 11/13/2020 Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, June 12, 2020 7:20 PM To: Wallace, Chris D (CED) Cc: Schwartz, Guy L (CED); Regg, James B (CED); David Gorm; David Haakinson; Chad Helgeson; Darci Horner - (C); Alaska NS - Wells Foreman; Alaska NS - Milne - Wellsite Supervisors Subject: MPU Injector E-17 (PTD # 1961150) Shut -In For TxIA Communication Attachments: E-17 TIO.XLSX All, Milne point WAG injector E-17 (PTD # 1961150) was shut-in today forTxlA communication after the IA was observed at 2480 psi (injection pressure). There were no previous indications of IA pressurization. A TIO plot is attached for reference. The well's IA was bled to 80 psi but immediately began to repressure. T/I/O stabilized after shut-in at 1850/1850/300. A tubing hanger packoff test passed to 5000 psi indicating either a tubing or packer leak. The well will remain shut in until integrity can be restored. Please call with any questions. Thank You, Wyatt Rivard I Operations Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard@hilcorg.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 •S . 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 27,2018 TO: Jim Regg r--", / P.I.Supervisor l 0 PIiS SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC E-17 FROM: Jeff Jones MILNE PT UNIT E-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JL - NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT E-17 API Well Number 50-029-22687-00-00 Inspector Name: Jeff Jones Permit Number: 196-115-0 Inspection Date: 2/6/2018 Insp Num: mit3J180207193238 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-17 • Type Inj W TVD 6885 ' Tubing 2510 2510 2509 , j 2509 'j 2510 - 2509,, — I PTD j 1961150 Type Test SPT Test pSl 1721 IA 3197 3210 1 3183 _ 3190 32U - 3204- Interval li4YRTST BBL Returned: 3.8 - ; OA 174 183 211 250 296- 325 BBL Pumped: –L P/F P Notes: Extended test time another hour;test determined to be a pass per J.Regg. Te-St — Tuesday,February 27,2018 Page 1 of 1 • # MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: � DATE: Tuesday,February 27,2018 Jim Regg �l c Z1Z7Ci8 P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC E-17 FROM: Jeff Jones MILNE PT UNIT E-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry :1 i— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT E-17 API Well Number 50-029-22687-00-00 Inspector Name: Jeff Jones Permit Number: 196-115-0 Inspection Date: 2/6/2018 • Insp Num: mitJJl80207192634 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-17 - Type Inj W TTVD 6885 • Tubing 2510 2511 2509 2511 2510 I 2510 PTD 1961150 . IType Test SPT 1Test psi I 1721 - IA 471 3206 3207 3226 3234 3224 BBL Pumped: 13 6 , jBBL Returned I OA 157 158 159 , 160 � 162 167 Interval1 4YRTST P/F I Notes: IA pressure did not stabilize,extended test time another hour(see mitJJ 180207193238). ._TC"I Tuesday,February 27,2018 Page 1 of I . 0 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday,January 28, 2016 3:40 PM To: 'Wyatt Rivard' Cc: Schwartz, Guy L (DOA); Regg, James B (DOA);Ted Kramer; Bo York;Alaska NS - Milne - Wellsite Supervisors Subject: RE:Injector MPE-17 (PTD # 1961150) Return to Injection Wyatt, Thank you for the meeting and discussion today. Permission to return MPE-17 to injection is GRANTED. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue cul 2 1 2°16Anchorage,AK 99501 S�414C® (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Thursday, January 28, 2016 3:30 PM To: Wallace, Chris D (DOA) Cc: Schwartz, Guy L(DOA); Regg, James B (DOA); Ted Kramer; Bo York; Alaska NS - Milne - Wellsite Supervisors Subject: RE: Injector MPE-17 (PTD # 1961150) Return to Injection Chris, Hilcorp would like to return injector MPE-17 (PTD# 1961150)to injection following the determination that cement observed in the 9-5/8" surface casing by 20" conductor annulus originated from the nearby MPE-21 P&A work.The cement is believed to have traveled from MPE-21 up the conductor annulus.The cement has now hardened and has effectively filled the void left by fallback from the original surface casing cement job. Hilcorp believes that there are no integrity concerns on this injector. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • Ilik.rp 1#. .ha. LI.c; From: Wyatt Rivard Sent: Wednesday, January 27, 2016 3:35 PM To: 'Wallace, Chris D (DOA)' Cc: 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)'; Ted Kramer; Bo York Subject: Injector MPE-17 (PTD # 1961150) Wet Cement In Conductor All, Milne Point water injector MPE-17 (PTD# 1961150)was observed with wet cement to surface in the surface casing by conductor annulus.The top of cement in the conductor was previously measured at 12.75' from surface on 8/21/2011. It is believed that the wet cement is associated with nearby P&A operations on MPE-21 (PTD# 1981150).The well has been SI until the source of the cement can be verified.A TIO plot is attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@ hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Hiiw.rp %k ka.l.UUt: 2 S Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, January 27, 2016 3:35 PM To: Wallace, Chris D (DOA) Cc: Schwartz, Guy L (DOA); Regg, James B (DOA); Ted Kramer; Bo York Subject: Injector MPE-17 (PTD# 1961150) Wet Cement In Conductor Attachments: MPE-17 TIO.xlsx All, Milne Point water injector MPE-17 (PTD# 1961150)was observed with wet cement to surface in the surface casing by conductor annulus. The top of cement in the conductor was previously measured at 12.75' from surface on 8/21/2011. It is believed that the wet cement is associated with nearby P&A operations on MPE-21 (PTD# 1981150).The well has been SI until the source of the cement can be verified.A TIO plot is attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 IIiM. rp 1h.ka. 11.ld, SCANNED 2 ,7 ; it; 1 Tree: 4 1/8" - 5M CIW gh Orig. DF elev. = 53.6' (N 22E) Wellhead: 11 x11" 5M FMC G 5 M P U E - 1 7 1 Orig. GL. elev. = 24.1' 11" x 4.5" NSCT tbg, hng. and 4" — 4-ES RKB elev. = 20.40' CIW "H" BPV profile 20" 91.1 ppf, H-40 113' I- O 9 5/8" Howco ES' Cementer 2130' KOP @ 300' Max. hole angle = 69° to 72° f/ 3350' to 16,433' (PBTD) Hole angle through perfs = 71° 9 5/8", 40 ppf, L-80 Btrc. 9185' 4.5" 12.6 ppf, L-80 BTC mod tubing (cap. = 0.0152 bpf, drift = 3.958") SCANNED MAY 2 5 2016 7" 26 ppf, L-80, Btrc Mod production csg. ( drift ID = 6.151", cap. = 0.0383 bpf ) Minimum tubing restriction = 3.725" "XN" profile @ 3.813" Two 7" x 20' marker jts. III=t 7" x 4.5" Baker S - 3 Pkr 15,582' f/ 15,112' - 15,153' md Note : 4.5" Tail pipe is 4' into the seal bore extention Stimulation Summary 4.5" HES XN-Nipple 15,610' none performed ( 3.725" id ) 7" x 5" Baker HMC Pkr. 15,618' Perforation Summary Ref log: LWD 12- 22- 96 , 4.5" WLEG 15,625' - - 7" Float Shoe (btm.) 15,806' Size SPF Interval (TVD) 4.5" 12.6 ppf, L-80 BTC Mod. liner KUP C-Sands — — (ID = 3.958", cap. = 0.01522 bpf) 2 3/4 6 15,973'-16,093' 6,965'-7,007' KUP B-Sands 4.5" Baker model 45 KB Iso pkr. 16,151' 2 3/4 6 16,187'-16,287' 7,034'-7,067' _ 2-7/8"XN-Nipple (2.313 pkg.)2.205" id. 16,163' ALPHA Jet , 15gm, Charges @ 60 — WLEG 16,165' deg. phasing Note: PXN plug installed in XN-Nipple W/CTU 7/21/02 two 4.5"x 21' marker jts. FN on prong is(1-3/8") f/ 16,436'to 16,520' and 4.5" Landing collar PBTD 16,432' ;•�•�•�•4 4.5" float collar 16,520' 4.5" guide shoe 16,563' DATE REV.BY COMMENTS MILNE POINT UNIT 01 / 02 / 97 JBF Drill and Case by Nabors 22E WELL E-17i 01 / 17 / 97 MDO Completion 4-ES API NO: 50-029-22687 02 / 08 / 97 Lee H Initial Perforations 02/21/02 MDO I Isolation packer set on with CTU BP EXPLORATION (AK) Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~_,/~~' 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; Beve~Vincent TO RE-SCAN Notes: Nathan Lowell Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • MEMORANDUM To: Jim Regg ~~{~ 4 ~ /~ Il p P.I. Supervisor FROM: Jeff Jones Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 09, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-17 MILNE PT iJNIT KR E-17 Src: Inspector NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR E-17 API Well Number: 50-029-22687-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ10022721153s Permit Number: 196-115-0 ~ Inspection Date: 2/8/2010 Rel Insp Num: MITOP000002953 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-17 ' Type Inj. ~ w TVD ~ 6sss ~ IA so zooo ~ 200o zooo P.T.D 196uso iTypeTest SPT Test pts 1721 OA o lI - 0 0 0 Interval FourYeazCycle p~F, Pass -Tubing 2400 2400 2400 2400 Notes: 2.s BBLS diesel pumped. 1 well inspected ; one exception noted: the surface casing flutes are outside the conductor pipe, allowing excessive ~ well head movement. Mr. Parks will initiate repair. p~ ~>~~y' tiE~~+ Friday, April 09, 2010 Page 1 of 1 • ~ Q ! I`a' `U ~~ /~ MPU E-17 (BPXA) Wellhead Stabilizing Clamp PTD 1961150 Photos by AOGCC Inspector J. Jones April 12, 2010 Inspector witnessed mechanical integrity test on February 7, 2010 and observed surface casing not landed properly in the conductor, allowing excessive wellhead movement. BPXA was instructed to make repairs. During follow-up after notification by BPXA of repairs, Inspector observed a sturdy steel clamp device installed to prevent movement as shown in these photographs. MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'Ref( ~¡f;J(D!( DATE: Tuesday, February 28, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-17 MILNE PT UN1T KR E-17 Src: Inspector V~Io" \ \ S Reviewed By: P.I. Suprv..íf5'l- Comm FROM: John Spaulding Petroleum Inspector NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR E- I 7 API Well Number 50-029-22687-00-00 Inspector Name: John Spaulding Insp Num: miùS060227120416 Permit Number: 196-115-0 Inspection Date: 2/15/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well! E-17 ¡Type Inj. i G TVD 6885 I IA 460 1980 1980 1980 I __I I i P.T. i 1961150 ITypeTest SPT Test psi 1721.25 ! OA 0 0 0 0 -L ' , Interval 4YRTST PIF P Tubing 3980 3980 3900 3950 I -- Notes I' Tuesday, February 28, 2006 Page 1 of 1 ""-~' STATE OF ALASKA -"'~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 56 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic._ Anchorage, AK 99519-6612 Service__X Milne Point Unit 4. Location of well at surface 8. Well number 1616' FNL, 1775' FEL, Sec. 25, T13N, R10E, UM (asp's569370, 6016203)~ MPE-17 At top of productive interval" 9. Permit number / approval number 155' FNL, 4503' FEL, Sec. 33, T13N, R11 E, UM (asp's 582294, 6012515) '~- 196-115 At effective depth 10. APl number 272' FNL, 4289' FEL, Sec. 33, T13N, R11E, UM (asp's582711, 6012403) 50-029-22687-00 At total depth 11. Field ! Pool 303' FNL, 4166' FEL, Sec. 33, T13N, R11 E, UM (asp's 582834, 6012373) Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 16565 feet Plugs (measured) true vertical 7207 feet Effective depth: measured 16433 feet Junk (measured) true vertical 7167 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 250 SX Arcticset I (Approx 147' 147' Surface 9163' 9-5/8" 2405 sx PF 'E', 460 sx 9185' 4676' 'G', 100 sx PF 'C' Intermediate 15777' 7" 300 sx Class 'G' 15806' 6963' Liner 947' 4-1/2" 365 sx Class 'G' 15618' - 16565' 6898' - 7207' (ECEIVE[.._ Perforation depth: measured Open Perfs 15973' - 16093', 16187' - 16247', 16247' - 16287' MAR 2 8 2003 true vertical Open Perfs 7021' - 7061', 7091' - 7110', 7110' - 7123' ;'-'~JaslmOl& Ga~ Cc,~. C~mm!c-,,:- Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tubing to 15582'. 4-1/2", 12.6#, L-80 Tubing Tal~.'~5'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 15,582'. No SSSV in well. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/20/2003 1340 3451 Subsequent to operation 02/28/2003 1807 2483 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended _ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant Date Mamh 07, 2003 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · RSDNS ltFL ORIGINAL SUBMIT IN DUPLICAT MPE-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/21/2003 WAG SWAP: GAS TO WATER IN]ECTION/ C/O LATERAL VALVES / VERFIY ORIFICE PLATE SIZE. EVENT SUMMARY 02/21103 WELL SUPPORT TECHS RIGGED UP AND CHANGED PUT THE LATERAL VALVE RIGHT BEHIND WELLHOUSE TO DOUBLE BLOCK AND BLEED VALVES. SWAPPED BLINDS FOR WELL TO TAKE WATER INJECTION AND CHECKED THE ORIFICE PLATE SIZE. ALL FLANGES WERE TORQUED TO SPEC. HB&R RIGGED UP AND PRESSURE TESTED TO WATER AND GAS LINES. HB&R RIGGED UP AND PUMPED 10 BBLS METHANOL AND FOLLOWED IT WITH 90 BBLS OF SOURCE WATER. PUMPED @ 1.5 TO 2.0 BPM FROM 4100 TO 4500 PSI. PUMPED 2 BBLS METHANOL TO FREEZE PROTECT UNIT. HB&R RIGGED UP AND PUMPED ANOTHER 90 BBLS SOURCE WATER AND 2 BBLS METHANOL. PUMPED FROM 4300 TO 3250 PSI. CONCLUSION: ALL TASKS WERE COMPLETED WITH NO PROBLEMS AND THE PRESSURE TESTS WERE GOOD. FLUIDS PUMPED BBLS 14 METHANOL 180 SOURCE WATER 194 TOTAL Page I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 56 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Milne Point Unit 4. Location of well at surface 8. Well number 1616' FNL, 1775' FEL, Sec. 25, T13N, R10E, UM (asp's569370, 6O162O3) MPE-17 At top of productive interval 9. Permit number / approval number 155' FNL, 4503' FEL, Sec. 33, T13N, R11 E, UM (asp's 582294, 6012515) 196-115 At effective depth 10. APl number 272' FNL, 4289' FEL, Sec. 33, T13N, R11E, UM (asp's582711, 6012403) 50-029-22687-00 At total depth 11. Field / Pool 303' FNL, 4166' FEL, Sec. 33, T13N, R11 E, UM (asp's 582834, 6012373) Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 16565 feet Plugs (measured) true vertical 7207 feet Effective depth: measured 16433 feet Junk (measured) true vertical 7167 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 250 sx Arcticset I (Approx 147' 147' Surface 9163' 9-5/8" 2405 sx PF 'E', 460 sx 9185' 4676' 'G', 100 sx PF 'C' Intermediate 15777' 7" 300 sx Class 'G' 15806' 6963' Liner 947' 4-1/2" 365 sx Class 'G' 15618' - 16565' 6898' - 7207' Perforation depth: measured Open Perfs 15973' - 16093', 16187' - 16247', 16247' - 16287' true vertical Open Perfs 7021' - 7061', 7091' - 7110', 7110' - 7123' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tubing to 15582'. 4-1/2", 12.6#, L-80 Tubing Tail @ 15625'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 15,582'. No SSSV in well. 13. Stimulation or cement squeeze summary ''' "" ; .. Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ~ .... -' 14. Representative Daily Avera.qe Production or Iniection Dat~: OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 03/12/2002 2985 2611 Subsequent to operation 03/23/2002 4604 1806 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended _ Service WAG INJECTOR 17. I h~er~t~o~ing~cor rect to the b est of my knowledge. Title: Technical Assistant Date May 09, 2002 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE v MPE-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/18/2002 WAG SWAP' GAS TO WATER ]:N.]ECTI'ON EVENT SUMMARY 03/18/O2 PJSM. SAFED OUT AND BLED DOWN SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUE TO SPEC. SERVICED TREE AND FLUSHED CENSING LINES. MIRU HB&R PT'd TO 4800 PSI. PUMPED 85 BBLS SOURCE WATER AND 18 BBLS METHANOL TO KNOCK DOWN PRESSURE AND ALLEVIATE HYDRATES, AT 2 BPM, 3250 TO 2200 PSI. RDMO. CONCLUSION: JOB WAS COMPLETED WITH NO PROBLEMS. PUT ON WATER INJECTION AT 2000 BPD. FLUIDS PUMPED BBLS 18 METHANOL 85 SOURCE WATER I O3 TOTAL Page 1 STATE OF ALASKA ALt \ OIL AND GAS CONSERVATION COMMI )N REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing Repair well Perforate X Other, 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 2602'NSL, 667' WEL, SEC. 8, T11N, R17E At top of productive interval 2933'NSL, 1221' WEL, SEC. 9, T11N, R17E At effective depth 2969' NSL, 1392' WEL, SEC g, T11N, R17E At total depth 3245' NSL, 3839' EWL, SEC. 9, T11N, R17E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 55.6 feet feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 4-34/0-38 9. Permit number/approval number 96-115 10. APl number 50- 029-22705-00 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical 12950' feet 10257' feet Plugs (measured) ORIGINAL Effective depth: measured true vertical 12835 feet 10204' feet Junk (measured) Baker inflatable pkr rubber element lost 12/13/97. 2 X-Keys 2 1/2"x2.00"x3/8". Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vedical depth BKB BKB 49" 20" Driven 90' 90' 4628' 9-5/8' 1312 sx PF 'E'. 300sx Class 'G' 4669' 4582' 12860 7" 575 sx Class 'G' 12901' 10183' measured 10425'-10555, 10575'-10760', 10844'-10950', 11100'-11190', 11410'-11440', 11580L11700', 12210'-12260', 12365'-12400', 12,562'-12582', 12681'-12686', 12727-12742' (all open) I0396'- I0400', 11120'- 11124", 11420'- 11424', 12246'- 12250', 12546'- 12550' (all squeezed) true vertical TVDSS 9916'-9925; 9926'-9929', 9928'-9950', 9926'-9929', 9937~.9939', 9942'-9944', 9961'-9966', 9983'-9991', I0037'-10043', 10081'- 10083', 12727-12742' all open) 9909'-9910', 9926'-9927, 9937'-9938', 9964'-9965', 10032'- 10033' (all squeezed) Tubing (size, grade, and measured depth) 4-1/2" 12.6# NSCT 13CR80 tubing Taiipipe to 10085' ¢~.~. !~' ¢aker ~S.-3" Packer Packers and SSSV (type and measured depth) SSSV Landing Nipple HES "HXO" 3.8113" I.D.~¢ set at 10028' 13. Stimulation or cement squeeze summary Addtional Perforations (9/13/99) Intervals treated (measured) 12,562'-12582', 12681'-12686; 12727-12742' Treatment description including volumes used and final pressure Anchorag~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 8.00 118 1511 0 2866 4773 13991 0 Tubing Pressure 1220 520 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 hereb~certify that the foregoing is true and correct to the best of my knowledge. r, /' r- 'q' rr) Form 10-404 Rev 06/15//~8 - ' ' Date 9/17/99 SUBMIT IN DUPLICAT~ To: Anchorage Production Engineering Location: Endicott From: Nordlander Date: 9/12/99 Operation: Endicott 4-34 CTE Add Peris Cost Code: N15434 - etc Detail Code: Cs - Add Peris - etc Est. Costs: $ 44,897 CTE-Line Summary .9/12/99 Rigged up E-line coil and dh w/20' guns with well flowing. Tied into Sperry LWD 10/20/96 and tagged up at 12,817 elmd. Confirmed with Tave that it was unfeasible and unnecessary to try and shoot lowest requested interval. Made jewelry log from td up to 9900'. Rih and tied in, painted flag for next run, picked up and perforated 12,562-12,582, logged off and pooh while pumping slack management. Layed down for night. 9/13-14/99 Rih w/15' gun and 5' gun on selective switch with well flowing. Tried getting whp down so it would be easier and safer to snub, then tded slight kill with seawater, but eventually snubbed slowly in hole. Tied into flag (4' shorter toolstring) and to collar log made on day prior, parked and perforated at respective shooting depths, and fired guns, although there were no indications that guns fired. Pooh pumping slack management; at surface guns not fired. After checking tools, replaced switch and dh with same guns. Tied into flag and collar log. Perforated 12,681-12,686, logged up, dh and tied in again. Perforated 12,727-12,742, logged up and pooh pumping slack management. Freeze protected coil and rigged down. Left well to be brought on by operator. Interval 12,562 - 12,582 20' 12,681 - 12,686 5' 12,727 - 12,742 15' All shots were 2-7/8" SWS Powerjets, 6 spf, 60 deg phasing, non-oriented. 9/12/99 Initial Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Shutin 2000 600 0 n/a 200 50 Time Operation 7:10 Miru DS E-line-Coil-lnteriace (E-coil-i) #1, 14,300' of 1-3/4" (crv 28.0 bbls). 8:09 Hold safety meeting. 8:40 Start making head. 9:15 Start making up tools, GR/CCI & Safe system. 9:48 Pick up guns. 10:40 Pressure test. 10:50 Open well to flow and decrease pressure. Time Depth Rate Ctp Whp Stage Remarks ft bpm psi psi bbls 11:45 surf - 1000 1000 Rih. 12:57 8000 1300 1270 Weight check 15.0k up, 10.5k down. Well is opened 176 beans, flowing 135°F--gas lift not needed. 13:52 12797 1210 1210 Tag td (~12,797 ctmd, pu logging for tie-in, weight 22.2k up. 14:00 12500 Park. Correct to bottom of bha 12,532.8 elmd. ~ 14:04 1150 1200 Rih. 14:10 12817 1210 1210 Tag td, pu logging jewelry pass, td is 12,817 elmd. Fit is 152°F. Operation: Endicott 3-43 CTE Add Perfs Page: 2 14:49 10449 710 1160 CCI kicked out for noise, dh to relog and "splice". 14:52 10540 650 1140 Log up. 14:54 10400 Not a good oveday in same area, dh to repeat pass. 14:57 10560 650 1200 Log up. 15:07 9935 590 1200 Rib. 15:35 12813 1250 1330 Log up. Four feet shallow to previous tag, but cci is about the same +/- 2'. 15:37 12741 1230 1330 Park. Paint flag at 12,720 elmd (corrected to cci). 15:46 1210 1270 Rih. 15:49 12811 1220 1300 Log up tie in pass. 15:55 12470 Rih. 15:58 12811 1180 1320 Log up. 16:01 12660 1190 1330 Rih. ..1.6:03 12811 1140 1320 Log up. 16:06 1160 1350 Park, dh. 16:09 12710 1100 1320 Log up. ;16:12 1090 1300 Park, perf 12,562-12,582. Log off. 16:16 12490 1090 1270 Pooh pumping slack management. 17:48 surf 0.75 3320 1690 66/s At surface bleed down, break down, all shots fired. 18:45 Off location for night. 9/13/99 7:00 Start today's dg up. 7:20 1800 Start flowing well. 7:40 Hold safety meeting. 8:00 Call for radio silence. Start picking up and arming guns. Shutin well while rigging over. Pressure test, good. Flow well again. Cannot get whp down. Try killing well with 75 bbls seawater. Ineffective. Close wing and open choke more and ease into well with 1500 psi. "10:40 200 1500 1500 75/s Release radio silence. 13:02 12716 1300 1350 Tie into flag, log up. 13:05 12610 1310 1340 Rih. 13:09 12750 1280 1350 Log up. 13:13 12515 1240 1350 Rih. 13:17 12763 1260 1350 Log up. 13:25 12473 1220 1340 Rih. 13:40 12730 1290 1350 Log up. 13:43 12460 1270 1340 Rih. 13:49 12767 1260 1340 Log up. 13:51 1260 1350 Shoot 12,681-12,686, log up. Although no indication. 13:57 12470 1250 1330 Rih. 14:00 12792 1250 1340 Log up. 14:03 12596 1290 1340 Rih. 14:06 12790 1240 1350 LOg up. 14:07 Shoot--t2,727-12,742, log up. Although no indication. Pooh puming slack management. "16:00 surf 73/s Atsurface. Bleed down. 18:10 Finally bled off, guns not fired. Check all points, change out switch. 21:30 Rib. 23:42 12716 1310 1340 Tie in to flag. Log up. ~ 23:47 12519 I Rih. Operation: Endicott 3-43 CTE Ad~! ~erfs 123:581 127861 I 300 I 350 I 9/14/99 Page: 3 I Log up. 0:02 12453 1270 1340 Rih. 0:12 12786 1290 1350 Log up. 0:16 1300 1350 Shoot 12,681-12,686, log up. 0:21 12473 1280 1350 Rih. 0:24 12787 1300 1350 Log up. 0:29 12639 1300 1350 Rih. -0:30 12786 1280 1350 Log up. 0:32 1280 1350 Shoot 12,727-12,742, log up. Pump slack management. 1:20 4000 1300 67/s Freeze protect coil w/meoh. 2:00 surf 30/m Shut down, bleed down. 3:20 All shots fired. Start dg down. 6:30 Off location, left well shutin for operator to bdng on. Final Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Shutin 1800 600 0 0 200 70 Fluid Summary II Seawater. - I Meoh. Total SWS CTE Perforating String Bottom Hole Assembly #1 Tool String Descriptions O.D. I.D. Length Comments DS slim ct connector 2-1/8 - DS check valve & cable clamp. 2-1/8 - DS short adapter 2-1/8 DS rope socket 1-3/8 - SWS PEH tool w/support sleeve 1-11/16 5.4 7.5-8.5k weak point SWS PGGT-CC 1-11/16 6.4 5.4' CCI to top shot. SWS AH-SAFE 1-11/16 2.8 SWS 2-7/8 guns 2-7/8" 20.0 6 spf, 60° phasing, Power Jets SWS bottom nose 2.00 1.5 Total Length 36.1 AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS Page: 1 Date: 01/21/99 RUN RECVD / 96-115 PERF/GR/CCL ~'15870-16310 FINAL 96-115 COMP ROD ~973-16287 FINAL . 96-115 7618 ~F~CHLUM CDR/ADN 1-3 96-115 ~D SR~ ~~RILL 0-16565.2 10-407 ~0MPLETION DATE DALLY WELL CPS R )~../ / /{~/ TO ~/*~/?// Are dry ditch samples required? yes ~ And received? Was the well cored? yes ~ ..Analys~s & description received? Are well tests required? yes ~Q~,~ Received? y~e~s~ .... Well is in compliance Ini6ial COMMENTS 02/19/97 02/21/97 02/21/97 02/21/97 02/21/97 02/21/97 02/21/97 02/21/97 06/30/97 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto ,r¢,~'-' DATE: Chairman January 15, 1998 THRU: Blair Wondzell, -~~ FILE NO: P. I. Supervisor akqgaofe.doc Confidential· Yes Attachment Only _, NoX, · FROM: Larry Wade, SUBJECT: BOP test .~m Inspector January 15 ! traveled to Milne Point and witnessed a BOP test on Nabors 27E. The rig was clean and orderly and the test supervised by Richard Larkin ex drilling supt. The test went smooth and the crew performed in a professional manner. SUMMARY: Witnessed a BOP test on Nabors 27E with 0 failures. Attachment: akqgaofe.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover:~ ~ Drlg Contractor: Nabors Rig No. 27E PTD # ~{~-/l~- Operator: BPX Rep.: Well Name: MPUF-17 Rig Rep.: Casing Size: 9 5/8" Set @ 9544' Test: Initial Weekly Other DATE: January 15,1998 Rig Ph.# Jimmy Pyrone Richard Larkin Location: Sec. 6 T. 13N R. fOE Meridian Umiat Test Pressu res Test MISC. INSPECTIONS: Location Gen.' ~i~ Housekeeping: [~' (Gen) PTD On Location ~' Standing Order Posted .~ FLOOR SAFETY VALVES: Quan. Well Sign '~ Upper Kelly / IBOP 1 Drl. Rig ~' Lower Kelly / IBOP 1 Hazard Sec. ,~' Ball Type 1 Inside BOP Pressure P/F 5,000 P 5,000 P 5,000 P 5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 25O/35OO P I 250/5000 P I 250/5000 P I 250/5000 P I 250/5000 P I 250/5000 P I 250/5000 P N/A 0 CHOKE MANIFOLD: No. Valves 15 J No. Flanges 39 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 250/5000 P 5,000 P Functioned Functioned P P ACCUMULATOR SYSTEM: System Pressure 3,100 I P Pressure After Closure 1,825 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 25 Trip Tank Yes Yes System Pressure Attained 1 minutes 48 Pit Level Indicators Yes Yes Blind Switch Covers: Master: Yes Remote: Flow Indicator Yes Yes Nitgn. Btl's: 2000 2150 2100 2150 Meth Gas Detector Yes Yes 2190 2200 2250 2250 Psig. H2S Gas Detector Yes Yes sec. sec. Yes Number of Failures: 0 ,TestTime: 3.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade F1-021 L (Rev. 12/94) akqgaofe.xls STATE OF ALASKA ALASK~--~'. AND GAS CONSERVATION COMMISSION - REPORT Oi ..4UNDRY WELL OPER.-,rlONS Operations performed: Operation shutdown.__ Stimulate X Plugging__ Perforate Pull tubing__ Alter casing __ Repair well_ Other__ 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development X Exploratory __ 3. Address Stratigraphic __ 7. P. O. Box 196612, Anchora_cle, Alaska 99519-6612 Service __ 4. Location of well at surface 8. 2602'NSL, 667' WEL, SEC. 8, T11N, R17E At top of productive interval 9. 2933'NSL, 1221' WEL, SEC. 9, T11N, R17E At effective depth 10. 2969' NSL, 1392' WEL, SEC 9, T11N, R17E At total depth 11. 3245' NSL, 3839' EWL, SEC. 9, T11N, R17E Datum elevatr~r~-%r K~}chorage KBE = 55.6 feet feet Unit or Property name Duck Island Unit/Endicott Well number 4-34/0-38 Permit numbedapproval number 96-115 APl number 50- 029-22705-00 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12950' feet 10257' feet Plugs (measured) 12835 feet Junk (measured) 10204' feet Field/Pool Endicott Field/Endicott Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Baker inflatable pkr rubber element lost 12/13/97. 2 X-Keys 2 1/2"x2.00"x3/8". Length Size Cemented Measured depth True vertical depth BKB BKB 49' 20" Driven 90' 90' 4628' 9-5/8" 1312 sx PF 'E; 300sx Class 'G' 4669' 4582' 12860 7" 575 sx Class 'G' 12901' 10183' measured 10425'-10555, 10575'-10760', 10844'-10950', 11100'-11190', 11410;11440', 11580'-11700', 12210'-12260', 12365'-12400' (afl open) 10396;10400', 11120'~11124', 11420;11424', 12246'-12250', 12546;12550' (afl squeezed) true vertical TVDSS 9916'-9925', 9926'-9929', 9928'-9950', 9926'-9929', 9937'-9939', 9942'-9944', 9961'-9966', 9983'-9991' (afl open) 9909'-9910', 9926'-9927', 9937'-9938', 9964'-9965', 10032'-10033' (all squeezed) Tubing (size, grade, and measured depth) 4-1/2" 12.6# NSCT 13CR80 tubing Tailpipe to 10085' Packers and SSSV (type and measured depth) SSSV Landing Nipple HES "HXO" 3.8113" I.D. @ 1557'. 7" Baker "S-3" Packer set at 10028' 13. Stimulation or cement squeeze summary WSO/Gel Squeeze 12/11-15/1997 Intervals treated (measured) 10425'-10555, 10575'-10760', 10844'-10950', 11100'-11190', 11410'-11440', 11580'-11700', 12210'-12260', 12365'-12400' Treatment description including volumes used and final pressure (see attached for fluid summary), fsiwhp=1130osu Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 450 0 25 1728 5039 0 Tubing Pressure 1103 1096 14. 16. Status of well classification as: Oil X Gas__ Suspended Service 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I here/~ce .rtify that~,~fo~re,going is true and correct to the best of my knowledge. Signed L/~k~F'/~~ ~ Title.~enior Technical 4.~.~i.~t~,,t IV Date 1/7/98 Form 10-4~/Re~/06/1~/8-8 ' --- J SUBMIT IN DUPLICATE ORIGINAL jmmissi0~ ,aration: 4-34 Marcit CTU WSO ' Page: 5 3:151 11240 0 1150 0.50 1280 210 Weight check - 18,200#. Mini Injectivitytest. 3:20 11240 0 1140 0.30 1160 211 Min. pumprate. POH. 3:40 10080 0 1140 0.30 1120 218 At tailpipe. Pull slightly into tail. Stop and relax. 3:50 10080 0 1140 0.30 1120 220 Continue POH. Looking good. No hang ups. 4:23 8000 0 1150 0.35 1110 255/s Switch to Meoh. 4:25 8000 0 1145 0.35 1100 0 Pumping Meoh down coil at min. rate. 6:45 3850 0 1140 0.35 1100 34/m Shut down. Coil is freeze protected. Continue to POH. 7:52 surf 1135 270 Freeze protect well down backside. 8:31 0.75 1230 24/m Shut down. Start dg down. 9:03 1130 Packer in good condition & with element. 11:00 Off location. Final Well Status Siwhp lap 0ap GIp FIp Fit I psi psi psi psi psi °F I 1130 250 0 n/a 320 90 I Fluid Summary 7 Seawater. 14 464 327 55 220 294 9 24 255 1669 Total 408 0.5% Marcit. 77 1.0% Marcit. 10 Meoh. 33 34 24 101 Total 2255 Total Baker Inflatable Packer Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Length Comments Baker Coil Connector & Fishing Neck. 2-3/4 1-1/4 0.88 Baker Check Valves. 3 1 1.50 Baker Hydraulic Disconnect. 3-3/8 1-3/16 1.45 7/8" ball. Baker Tubing End Locator. _ 3-3/8 1-1/4 3.10 8.03' to mid element. Baker Circulation Sub. 2-3/4 9/16 1.00 5/8" ball. Baker Retrievable Packer. 3-3/8 0.68 10.24 1/2" ball. Total Length 18.17 Wire Grab Tool String Descriptions Baker Coil Connector & Fishing Neck. Bottom Hole Assembly # 2 O.D. I.D. I Length 3-1/16 15/16I 0.92 Comments ~ALASKA~ eared rvices tilling BP Exploration / Arco Alaska Date: To: From: Subject: June 24, 1997 Alaska Oil & Gas Conservation Commission Tim Schofleld Senior Drilling Engineer , 10-407 for Permit #96-115, MPE-17i An error has been discovered on the Permit To Drill (10-401) for MPE-17i, approved on July 23, 1996, and drilled in December 1996. The locations of the target and well TD were incorrectly converted from the directional plan which was attached to the permit. Originally Permitted (Incorrectly) At top of productive interval 5168' NSL, 3682' WEL, SEC. 33, T13N, R11E At total depth 4948' NSL, 2946' WEL, SEC. 33, T13N, R11E Should Have Been Permitted 5097' NSL, 4673' WEL, SEC. 33, T13N, R11E 4877' NSL, 3937' WEL, SEC. 33, T13N, R11E I apologize for any inconvenience this may have caused. Please let Kathy Campoamor (phone# 564-5122) know if there is any further action required. Thank you for your assistance and patience in this matter. /klc ALASKA OIL AND GAS CONSERVATION I WELL COMPLETION OR RECOMPLETION REPORT ...... ,~, 1. Status of Well Classification of Service Wel~i'l¢&~.0_J'~g¢~.~ E~ Oil F-ICes [] Suspended F-IAbandoned [~ Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-115 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22687 4. Location of well at surface ~.--~ ~ 9. Unit or Lease Name 3664' NSL, 1775' WEb, SEC. 25, T13N, R10E, UM '"~~ ;! Milne Point Unit At top of productive interval ~,.~ 10. Well Number 155' SNL, 575' EWL, SEC. 33, T13N, R11E, UM,... ¢-',~z~ ~ · MPE-17i At total depth .~ 11. Field and Pool 291' SNL, 1114' EWL, SEC. 33, T13N, R11E, UM Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 56'I ADb 028232 12. Date Spudded12/2/96 I 13' Date T'D' Reached ! 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °fish°re 116' N°' °f c°mpleti°nsl 2/21/96 2/7/97 N/A MSL One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 16565 7207 FTI 16433 7167 FTI [~Yes F-INo N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/RES/DEN, EMS, CBTE/GR/CCL, CRD, SlBHP, CDR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # NTSOLHE 35' 112' 30" 250 SX Arcticset I (Approx.) 9-5/8" 40# L-80 32' 9185' 12-1/4" 2405 sx PF 'E', 460 sx 'G', 100 sx PF 'C' 7" 26# L-80 29' 15806' 8-1/2" 300 sx Class 'G' 4-1/2" 12.6# L-80 15618' 16565' 8-1/2" 365 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 6 spf 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 15625' 15582' MD TVD MD 'I-VD 15973'-16093' 7021'-7061' 16247'-16287' 7110'-7123' 16187'-16247' 7091'-7110' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 68 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) February 22, 1997i WAG Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb 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. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. (subsea) Top KC1 15979' 6970' Top Kuparuk 'B' 16102' 7011' Top Kuparuk B7 16189' 7038' 31. List of Attachments Summary of Daily Drilling Reports, Surveys certify that th~foregoing i~ true a.nd~correct to the best of my knowledge Signed Tim Sohofield' (' ~f~ Title Senior Drilling Engineer Date - 15MPE-17i Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No, / Approval No. INSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24-' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27'.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 01 Dec 96 02 Dec 96 03 Dec 96 04 Dec 96 05 Dec 96 M Pt E Pad Progress Report Well MPE- 17 Rig Nabors 22E Page Date Duration Activity 09:01-11:00 11:00-18:00 18:00-18:30 18:30-22:30 22:30-00:01 00:01-06:00 06:00-06:30 06:30-06:45 06:45-09:00 09:00-09:30 09:30-12:30 12:30-14:00 14:00-14:30 14:30-16:30 16:30-16:45 16:45-18:00 18:00-18:30 18:30-20:30 20:30-20:45 20:45-00:00 00:00-06:00 06:00-06:30 06:30-06:45 06:45-18:00 18:00-18:30 18:30-19:45 19:45-20:15 20:15-22:15 22:15-22:30 22:30-23:15 23:15-00:00 00:00-06:00 06:00-06:30 06:30-06:45 06:45-11:30 11:30-13:00 13:00-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-05:45 05:45-06:00 06:00-06:30 06:30-06:45 06:45-09:30 09:30-11:30 11:30-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-20:15 20:15-21:15 1-3/4 hr 7hr 1/2 hr 4hr 1-1/2 hr 5-3/4 hr 1/2 hr 1/4 hr 2-1/4 hr 1/2 hr 3hr 1-1/2 hr 1/2 hr 2hr 1/4 hr 1-1/4 hr 1/2 hr 2hr 1/4 hr 3-1/4 hr 6hr 1/2 hr 1/4 hr 11-1/4 hr 1/2 hr 1-1/4 hr 1/2 hr 2hr 1/4 hr 3/4 hr 3/4 hr 6hr 1/2 hr 1/4 hr 4-3/4 hr 1-1/2 hr 3hr lhr lhr 1/2 hr 1/2hr 10-3/4 hr 1/4 hr 1/2 hr 1/4 hr 2-3/4 hr 2hr 5hr 1-1/2 hr 1/2 hr 1/2 hr 1/4 hr lhr lhr Rigged down Drillfloor / Derrick Rig moved 60.00 % Held safety meeting Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up Divertor Held safety meeting Held drill (Fire) Rigged up Divertor Tested Divertor Racked back drill pipe Made up BHA no. 1 Held safety meeting Drilled cement to 112.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 1 Held safety meeting Drilled to 301.0 ft Held drill (Spill) Took MWD survey at 210.0 ft Drilled to 693.0 ft Held safety meeting Held drill (Kick while drilling) Drilled to 1852.0 ft Held safety meeting Drilled to 2138.0 ft Circulated at 2138.0 ft Pulled out of hole to 0.0 ft Held drill (H2S) Serviced Top drive R.I.H. to 2138.0 ft Drilled to 2900.0 ft Held safety meeting Held drill (Spill) Drilled to 3568.0 ft Circulated at 3568.0 ft Pulled out of hole to 0.0 ft Serviced Top drive R.I.H. to 2000.0 ft Held safety meeting R.I.H. to 3568.0 ft Drilled to 4712.0 ft Held drill (Fire) Held safety meeting Held drill (Spill) Drilled to 4993.0 ft Circulated at 4993.0 ft Pulled BHA Made up BHA no. 2 Held safety meeting R.I.H. to 1115.0 ft Took MWD survey at 1115.0 ft Serviced Top drive Serviced Block line 1 16 May 97 Facility Date/Time 06 Dec 96 07 Dec 96 08 Dec 96 M Pt E Pad Progress Report Well MPE- 17 Rig Nabors 22E Page Date Duration Activity 21:15-22:00 22:00-23:30 23:30-01:30 01:30-06:00 06:00-06:30 06:30-06:45 06:45-10:00 10:00-10:30 10:30-14:30 14:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-22:15 22:15-23:00 23:00-23:15 23:15-00:30 00:30-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-06:30 3/4 hr 1-1/2 hr 2hr 4-1/2 hr 1/2 hr 1/4 hr 3-1/4 hr 1/2 hr 4hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 1-3/4 hr 3/4 hr 1/4 hr 1-1/4 hr 1-1/2 hr lhr 1-1/2 hr 1-1/2 hr 1/2 hr Singled in drill pipe to 1790.0 ft Reamed to 1890.0 ft Pulled BHA Fished at 1890.0 ft Held safety meeting Held drill (Fire) Made up BHA no. 3 R.I.H. to 1909.0 ft Pulled BHA R.I.H. to 1909.0 ft Washed over string at 1909.0 ft Pulled BHA Held safety meeting Pulled BHA Made up BHA no. 4 R.I.H. to 1800.0 ft Reamed to 1910.0 ft Circulated at 1910.0 ft Pulled BHA Serviced Top drive Made up BHA no. 5 R.I.H. to 1850.0 ft Held safety meeting 06:30-08:00 08:00-09:00 09:00-11:00 11:00-12:00 12:00-13:30 13:30-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-18:45 18:45-19:15 19:15-20:00 20:00-20:45 20:45-21:45 21:45-23:00 23:00-23:45 23:45-00:30 00:30-01:00 01:00-02:30 02:30-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-12:30 12:30-13:30 13:30-17:00 17:00-18:00 18:00-18:30 18:30-18:45 18:45-19:30 19:30-21:00 1-1/2 hr lhr 2hr lhr 1-1/2 hr lhr 1/2 hr 3hr 1/2 hr 1/4 hr 1/2 hr 3/4 hr 3/4 hr lhr 1-1/4 hr 3/4 hr 3/4 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr lhr 2-1/2 hr lhr 3-1/2 hr lhr 1/2 hr 1/4 hr 3/4 hr 1-1/2 hr Washed over string at 1916.0 ft Circulated at 1916.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 1916.0 ft Fished at 1916.0 ft Circulated at 1916.0 ft Pulled BHA Held safety meeting Held drill (H2S) Made up BHA no. 7 R.I.H. to 1916.0 ft Washed to 1916.0 ft Circulated at 1916.0 ft Pulled BHA Made up BHA no. 8 R.I.H. to 1916.0 fl Fished at 1916.0 ft Circulated at 1916.0 ft Pulled BHA Held safety meeting Pulled BHA Serviced Top drive Made up BHA no. 9 R.I.H. to 1400.0 ft Reamed to 3020.0 ft Circulated at 3020.0 ft Held safety meeting Held drill (Kick while tripping) Pulled out of hole to 1595.0 ft R.I.H. to 4400.0 ft 2 16 May 97 Facility Date/Time 09 Dec 96 10 Dec 96 11 Dec 96 12 Dec 96 13 Dec 96 14 Dec 96 M Pt E Pad Progress Report Well MPE- 17 Rig Nabors 22E Page Date Duration Activity 21:00-22:00 22:00-23:30 23:30-00:00 00:00-06:00 06:00-06:30 06:30-10:00 10:00-11:30 11:30-12:30 12:30-13:15 13:15-13:30 13:30-18:00 18:00-18:30 18:30-18:45 18:45-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-09:00 09:00-11:00 11:00-11:15 11:15-18:00 18:00-18:30 18:30-18:45 18:45-05:30 05:30-06:00 06:00-08:30 08:30-15:00 15:00-16:00 16:00-17:00 lhr 1-1/2 hr 1/2hr 6hr 1/2 hr 3-1/2 hr 1-1/2 hr lhr 3/4 hr 1/4 hr 4-1/2 hr 1/2 hr 1/4hr 9-3/4 hr 1-1/2 hr 1/2 hr 1/2 hr lhr lhr 2hr 1/4 hr 6-3/4 hr 1/2 hr 1/4 hr 10-3/4 hr 1/2 hr 2-1/2 hr 6-1/2 hr lhr lhr Circulated at 4400.0 ft R.I.H. to 4926.0 ft Reamed to 4994.0 ft Drilled to 5877.0 ft Held safety meeting Drilled to 6067.0 ft Circulated at 6067.0 ft Pulled out of hole to 4927.0 ft Singled in drill pipe to 5974.0 ft Washed to 6067.0 ft Drilled to 6454.0 ft Held safety meeting Held drill (Kick while drilling) Drilled to 7504.0 ft Circulated at 7504.0 ft Held safety meeting Circulated at 7504.0 ft Pulled out of hole to 4927.0 ft Serviced Top drive Singled in drill pipe to 7414.0 ft Held drill (Spill) Drilled to 7791.0 ft Held safety meeting Held drill (Abandonment) Drilled to 8150.0 ft Circulated at 8150.0 ft Circulated at 8150.0 ft Pulled out of hole to 300.0 ft Pulled BHA Serviced Top drive 17:00-18:30 18:30-18:45 18:45-22:00 22:00-23:00 23:00-06:00 06:00-10:30 10:30-13:00 13:00-14:30 14:30-15:30 15:30-18:30 18:30-22:30 22:30-01:00 01:00-02:00 02:00-05:30 05:30-06:00 06:00-10:00 10:00-11:00 11:00-12:00 12:00-16:00 16:00-18:00 18:00-19:00 19:00-23:00 23:00-00:00 00:00-04:00 1-1/2 hr Made up BHA no. 10 1/4 hr Held drill (Abandonment) 3-1/4 hr R.I.H. to 8020.0 ft 1 hr Washed to 8150.0 ft 7 hr Drilled to 8838.0 ft 4-1/2 hr Drilled to 9195.0 ft 2-1/2 hr Circulated at 9195.0 ft 1-1/2 hr Pulled out of hole to 6261.0 ft 1 hr R.I.H. to 9195.0 ft 3 hr Circulated at 9195.0 ft 4 hr Pulled out of hole to 1100.0 ft 2-1/2 hr Pulled BHA 1 hr Serviced Top drive 3-1/2 hr Made up BHA no. 11 1/2 hr R.I.H. to 1000.0 ft 4 hr R.I.H. to 9088.0 ft (cont...) 1 hr Washed to 9094.0 ft 1 hr Circulated at 9094.0 ft 4 hr Pulled out of hole to 567.0 ft 2 hr Pulled BHA 1 hr Made up BHA no. 12 4 hr R.I.H. to 9094.0 ft 1 hr Fished at 9094.0 ft 4 hr Pulled out of hole to 577.0 ft 3 16 May 97 Facility Date/Time 15 Dec 96 16 Dec 96 17 Dec 96 18 Dec 96 19 Dec 96 20 Dec 96 21 Dec 96 M Pt E Pad Progress Report Well MPE- 17 Rig Nabors 22E Duration Activity 04:00-06:00 06:00-08:00 08:00-11:30 11:30-12:30 12:30-16:30 16:30-18:30 18:30-22:00 22:00-23:30 23:30-00:30 00:30-01:00 01:00-06:00 06:00-12:00 12:00-14:30 14:30-16:30 16:30-17:30 17:30-20:00 20:00-21:00 21:00-22:30 22:30-23:30 23:30-00:30 00:30-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-08:30 08:30-11:30 11:30-12:00 12:00-15:30 15:30-17:00 17:00-21:30 21:30-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-13:30 13:30-16:00 16:00-03:00 03:00-03:30 03:30-06:00 06:00-06:00 06:00-06:15 06:15-08:30 08:30-12:00 12:00-14:00 14:00-06:00 06:00-13:30 2hr 2hr 3-1/2 hr lhr 4hr 2hr 3-1/2 hr 1-1/2 hr lhr 1/2 hr 5hr 6hr 2-1/2 hr 2hr lhr 2-1/2 hr lhr 1-1/2 hr lhr lhr lhr 2hr lhr 1-1/2 hr 2-1/2 hr 3hr 1/2 hr 3-1/2 hr 1-1/2 hr 4-1/2 hr 5hr 1/2 hr lhr 2hr 1/2hr 1/2 hr 1/2 hr 21-1/2 hr lhr 1/2hr 1-1/2 hr lhr 4-1/2 hr 2-1/2 hr llhr 1/2 hr 2-1/2 hr 24 hr 1/4 hr 2-1/4 hr 3-1/2 hr 2hr 16hr 7-1/2 hr Laid down fish Laid down fish (cont...) Serviced Block line Made up BHA no. 13 R.I.H. to 9195.0 ft Circulated at 9195.0 ft Pulled out of hole to 600.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 9-5/8in (4100.0 ft OD) Ran Casing to 9185.0 ft (9-5/8in OD) (cont...) Circulated at 9185.0 ft Mixed and pumped slurry - 514.000 bbl Displaced slurry - 660.000 bbl Circulated at 2130.0 ft Circulated at 2130.0 ft Mixed and pumped slurry - 526.000 bbl Displaced slurry - 130.000 bbl Cleared Flowline Rigged down Casing handling equipment Rigged down Divertor Installed Casing spool Rigged up BOP stack Rigged up BOP stack (cont...) Tested BOP stack Installed Wear bushing Made up BHA no. 14 R.I.H. to 2128.0 ft Drilled installed equipment - DV collar R.I.H. to 9098.0 ft Circulated at 9098.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Landing collar Drilled installed equipment - Float shoe Circulated at 9215.0 ft Performed formation integrity test, i~.3~ [.S~/~ Drilled to 11558.0 ft Circulated at 11558.0 ft Circulated at 11558.0 ft Pulled out of hole to 9150.0 ft Serviced Top drive Tested Drilling tool / logs - Via string R.I.H. to 11558.0 ft Drilled to 12416.0 ft Serviced Top drive Drilled to 12607.0 ft Drilled to 14990.0 ft (cont...) Drilled to 14990.0 ft (cont...) Circulated at 14990.0 ft Pulled out of hole to 11200.0 ft R.I.H. to 14990.0 ft Drilled to 15880.0 ft Drilled to 16137.0 ft (cont...) Page Date 4 16 May 97 Facility Date/Time 22 Dec 96 23 Dec 96 24 Dec 96 25 Dec 96 26 Dec 96 27 Dec 96 M Pt E Pad Progress Report Well MPE- 17 Rig Nabors 22E Page Date Duration Activity 13:30-14:00 14:00-20:00 20:00-22:00 22:00-22:30 22:30-01:30 01:30-04:00 04:00-05:00 05:00-06:00 06:00-09:00 09:00-13:00 13:00-15:30 15:30-16:30 16:30-19:00 19:00-20:00 20:00-04:00 04:00-06:00 06:00-08:00 08:00-10:00 10:00-12:00 12:00-12:30 12:30-21:30 21:30-22:30 22:30-06:00 06:00-09:00 09:00-10:00 10:00-14:00 14:00-14:30 14:30-15:00 15:00-16:00 16:00-17:00 17:00-19:00 19:00-19:30 19:30-19:45 19:45-21:30 21:30-22:30 22:30-23:30 23:30-03:00 03:00-06:00 06:00-07:30 07:30-10:00 10:00-10:30 10:30-15:00 15:00-16:00 16:00-17:00 17:00-06:00 06:00-07:00 07:00-08:30 08:30-09:30 09:30-10:00 10:00-13:00 13:00-16:00 16:00-19:00 19:00-00:00 00:00-05:00 1/2 hr 6hr 2hr 1/2 hr 3hr 2-1/2 hr lhr lhr 3hr 4hr 2-1/2 hr lhr 2-1/2 hr lhr 8hr 2hr 2hr 2hr 2hr 1/2 hr 9hr lhr 7-1/2 hr 3hr lhr 4hr 1/2 hr 1/2 hr lhr lhr 2hr 1/2 hr 1/4 hr 1-3/4 hr lhr lhr 3-1/2 hr 3hr 1-1/2 hr 2-1/2 hr 1/2 hr 4-1/2 hr lhr lhr 13hr lhr 1-1/2 hr lhr 1/2 hr 3hr 3hr 3hr 5hr 5hr Circulated at 16137.0 ft Drilled to 16565.0 ft Circulated at 16565.0 ft Pulled out of hole to 15250.0 ft Backreamed to 14430.0 ft Pulled out of hole to 9150.0 ft Serviced Block line Serviced Top drive R.I.H. to 16565.0 ft Circulated at 16565.0 ft Pulled out of hole to 12767.0 ft R.I.H. to 16565.0 ft Circulated at 16565.0 ft Took EMS survey at 16565.0 ft Laid down 15980.0 ft of 5in OD drill pipe Pulled BHA Pulled BHA (cont...) Laid down 2511.0 ft of Drillpipe Rigged up Casing handling equipment Held safety meeting Ran Casing to 9100.0 ft (7in OD) Circulated at 9100.0 ft Ran Casing to 7in (16320.0 ft OD) Ran Casing to 16180.0 ft (7in OD) (cont...) Laid down 410.0 ft of Casing Circulated at 15856.0 ft Washed to 15876.0 ft Laid down 82.0 ft of Casing Circulated at 15815.0 ft Rigged up Cement head Circulated at 15805.0 ft Pumped 75.000 bbl spacers - volume (null) Mixed and pumped slurry - 61.000 bbl Displaced slurry - 572.000 bbl Rigged down Casing handling equipment Installed Seal assembly Rigged down BOP stack Rigged up BOP stack Serviced Top drive Tested BOP stack Installed Wear bushing Made up BHA no. 15 Serviced Block line Serviced Top drive R.I.H. to 15567.0 ft Drilled cement to 15720.0 ft Circulated at 15720.0 ft Tested Casing Repaired Mud pumps Drilled installed equipment - Float collar Washed to 15890.0 ft Circulated at 15890.0 ft Pulled out of hole to 0.0 ft R.I.H. to 15890.0 ft 5 16 May 97 Facility Date/Time 28 Dec 96 29 Dec 96 30 Dec 96 31 Dec 96 01 Jan 97 M Pt E Pad Progress Report Well MPE- 17 Rig Nabors 22E Page Date Duration Activity 05:00-06:00 06:00-07:30 07:30-13:30 13:30-14:30 14:30-16:00 16:00-23:00 23:00-00:00 00:00-01:30 01:30-05:00 05:00-05:15 05:15-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-10:00 10:00-12:30 12:30-18:00 18:00-19:30 19:30-20:00 20:00-06:00 06:00-09:00 09:00-13:00 13:00-14:30 14:30-15:00 15:00-16:00 16:00-21:30 21:30-22:30 22:30-23:30 23:30-00:30 00:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-13:30 13:30-22:00 22:00-23:00 23:00-01:00 01:00-06:00 06:00-15:00 15:00-00:00 00:00-01:00 01:00-01:30 01:30-02:30 02:30-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-09:00 09:00-10:30 10:30-11:00 lhr 1-1/2 hr 6hr lhr 1-1/2 hr 7hr lhr 1-1/2 hr 3-1/2 hr 1/4 hr 1/4hr 1/2 hr 1/2 hr 2hr 1-1/2 hr 2-1/2 hr 5-1/2 hr 1-1/2 hr 1/2 hr 10hr 3hr 4hr 1-1/2 hr 1/2 hr lhr 5-1/2 hr lhr lhr lhr 4-1/2 hr 1/2 hr 1/2hr 1/2 hr lhr 6hr 8-1/2 hr lhr 2hr 5hr 9hr 9hr lhr 1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr lhr lhr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/2hr Circulated at 15890.0 ft Circulated at 15890.0 ft Pulled out of hole to 0.0 ft Serviced Top drive Made up BHA no. 17 R.I.H. to 15806.0 ft Serviced Block line Washed to 16565.0 ft Circulated at 16565.0 ft Pulled out of hole to 15806.0 ft R.I.H. to 16565.0 ft Circulated at 16565.0 ft Circulated at 16565.0 ft Reamed to 15806.0 ft Reamed to 16565.0 ft Circulated at 16565.0 ft Pulled out of hole to 920.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 12000.0 ft (4-1/2in OD) Ran Casing in stands to 16565.0 ft Circulated at 16565.0 ft Mixed and pumped slurry - 75.000 bbl Set Liner hanger at 15620.0 ft with 4500.0 psi Reverse circulated at 15620.0 ft Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 18 Serviced Top drive Serviced Block line R.I.H. to 15620.0 ft Drilled installed equipment - Liner hanger Circulated at 15620.0 ft Circulated at 15620.0 ft Repaired Iron roughneck Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe in stands to 16432.0 ft Tested Casing Circulated at 16432.0 ft Circulated at 16432.0 ft Filter Brine Laid down 14032.0 ft of 3-1/2in OD drill pipe Serviced Block line Freeze protect well - 85.000 bbl of Diesel Laid down 1550.0 ft of 3-1/2in OD drill pipe Pulled BHA Rigged down Drillstring handling equipment Removed Wear bushing Serviced Top drive Serviced Top drive (cont...) Held safety meeting Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested All tree valves 6 16 May 97 Facility Date/Time Progress Report M Pt E Pad Well MPE- 17 Rig Nabors 22E Page Date 11:00-11:30 11:30-12:00 12:00-13:00 Duration 1/2 hr 1/2 hr lhr Activity Removed Hanger plug Installed Hanger plug Freeze protect well - 70.000 bbl of Diesel 7 16 May 97 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPE-171 Rig Name: N-4ES AFE: 347034 Accept Date: 01/14/97 Spud Date: - Release Date: 01/16/97 Jan 15 1997 MIRU. Rig accepted 01/14/97 @ 1500 hrs. Check wellhead pressure, ND tree. Pull hanger, set test plug. NU BOP, install 4-1/2" rams. Test BOP, shear rams failed. Install new set shear rams. Test BOP, TP SSD specs 250#-5000#. Load pipe shed with 4-1/2" tubing, pull thrd protc, install seal rings. Shed full. MU pkr & tailpipe assy. Jan 16 1997 PU run 4-1/2" tubing. Slip/cut drill line. Load pipe shed with 4-1/2" tubing. Remove protctr, install seals. PU RIH with 4-1/2" tubing, circ tag pkr @ 15635' - 4ES RKB. Space out MU hanger, LD tubing, RILDS. 50# press increase when sting in. ND BOP/NU tree. Test adapter flange, comp tree, surface lines-5000#. Pull TWC. Rev circ inhibt seawater 3 BPM @ 400#. Jan 17 1997 Rev circ, inhibt source water. Pump 68 bbls diesel protect, U tube. Drop ball set pkr, test tubing to 5000#. Test annul 4000#. Set BPV, secure tree cellar. AC)GCC rep witness pkr, tubing, casing test. Rig released 01/16/97 @ 1300 hrs. Page MILNE POINT, ALASKA TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Rossberg L. M. Hinkel IMPE-17i Completion E-Line 2/4/97 Date' 12/7/97 Objective- Operations 08:30 10:00 12:00 12'10 14:10 14:25 14:50 16:30 17:15 18:40 18:55 19:05 20:15 2/5/97 07:00 08:00 08:45 08:55 Continue with the initial perforations in the Kuparuk "B" and "C" formation. MIRU Atlas Wireline Unit # 6555. Wellhead pressure 140 psi. Hold safety and pre-job meeting. Pick-up lubricator, grease head, BOPs and 2~/±" Alpha Jet Gun. Wait on triplex pump to pressure test lubricator. Pressure test lubricator and wellhead connection to 2500 psi. Good test. Open swab valve (23 turns). Start RIH with Gun #3 (20 ft). Logging tools through XN at 15610 ft. Pull back through. Drop back through and continue RIH. Stop at 16320 ft. Log up for tie-in pass. Make a (-) 2 ft correction. Make repeat pass with no further corrections. Log Gun #3 into place with TS at 16,227 ft. and BS at 16,247 ft. Fire Gun and Icg off. Start CCH. Finish CCH. Close in well. LD gun. All shots fired. Pick-up Gun #4 (20 ft) and start in hole. Log tie-in pass. Make a (+) 11 ft correction. Make a repeat pass with no further corrections. Log Gun #4 into place with TS at 16,207 ft and the BS at 16,227 ft. Fire gun and Icg off. Start CCH. Finish CCH. Close in well. LD gun. All shots fired. LD lubricator and BOPs. Secure well for night. Operations to resume in morning. Resume operations. Pick-up lubricator and Gun #5 (20 ft). Pressure test lubricator to 2500 psi. Found small leak. Lay down lubricator and make repairs ("O" ring). Pick-up lubricator and gun again. Pressure test to 2500 psi. Good test. Open well (23 turns) and start RIH. · 10:45 11:30 13:30 15:15 15:40 17:00 18:35 20:00 21:40 02:30 2/6/97 17:00 17:45 20:00 20:40 21:35 22:30 Stop at 16,320 ft. Log up. Make a (+)7 ft correction. Drop back down. Make a repeat pass with no further corrections. Log gun into place. Attempt to fire gun, but it appears to have an "open circuit" POOH. Trouble shoot system. Found EBW package problems in gun. Make repairs. Start RIH with Gun #5. Stop at 16,320 ft. Log up. Make a (+)9 ft correction. Drop back down. Make a repeat pass with no further corrections. Log Gun into place with the TS at 16,187 ft and the BS at 16,207 ft. Fire gun. Log off. POOH. Lay down Gun #5. All shots fired. Note: Skipped Gun #6 - Select Fire - for the time being. Start RIH with Gun #7 (20 ft). Stop at 16,230 ft. Log up. Made no correction. Log gun into place with TS at 16,073 ft. and BS at 16,093 ft. Fire gun and log off. POOH. Lay down gun #7. All shots fired. Start RIH with Gun #8 (20 ft). Stop at 16,230 ft. Log up. Made a (+) 2 ft correction. Log gun into place with TS at 16,053 ft and BS at 16073 ft. Fire gun. Log off. POOH. Lay down Gun #8. All shots fired. Noticed a "broken strand" in line nearI the cable head. Lay down lubricator. Secure well for night. Spool off approx. 1000 ft of line and inspect. Good. Cut off 250 ft of line "just in case". Re-head line. SD for night. Atlas crew change-out. Resume operations. Pick-up lubricator and Gun #9 (20 ft). Hold safety and pre-job meeting for new crew. Pressure test lubricator to 2500 psi. Good test. Start RIH with Gun #9. Stop at 16,250 ft. Log up. Make a (+)3 ft. correction. Drop back down and log gun into place with the TS at 16,033 ft and the BS at 16,053 ft ..... Fire gun and log off. Start POOH. Finish OOH. Lay down gun #9. All shots fired. Start RIH with Gun #10 (20 ft). 2/7/97 00:30 00:50 02:00 02:45 04:30 05:15 06:30 08:00 10:30 11'15 13:15 13:30 Stop at 16,225 ff. Log up. Make a (+) 2 fl correction. Drop back,////','., ~. ,./ . down. Log gun into place with the TS at 16,013 ff and t~~.~ & L;as 16,033 ff. "" ' .... Fire Gun. Log off. Sta~ POOH. ~icl~or~ Finish OOH. Lay down Gun ~10. All shots fired. Stad RIH with Gun ¢11 (20 ~). Stop at 16,175 ff. (Starling to lose hole - possibly peal debris). Log up. Make a (-) 2 ff correction. Drop back down hole. Log Gun into place with the TS at 15,993 ff and BS at 16,013 ~. Fire Gun. Log off. Sta~ POOH. Finished OOH. Lay down Gun ~11. All shots fired. Sta~ RIH with Gun ¢12 (20 fi). Stop at 16,100 ff (having trouble getting any deeper). Log up. Make a (-) 4 ff correction. Drop back down hole. Log Gun into place with the TS at 15,973 ff and the BS at 15,993 ff. Fire Gun. Log off. Sta~ POOH. Talk to Anch. Eng. about running last Gun (Gun ¢6 - Select fire). See notice after Perf, data, Finished OOH. Lay down Gun ~12. All shots fired. Lay down lubricator. Secure well. RDMO Atlas Wireline. Tie in log/date: CBL/GR/CCL 1/7/97 (SWS) and the Lithology from the CRD (Schlumberger) LWD 12/22/96 TD Tag: None Schlumberger Charge Type: CCL to Top Shot: Gun #1, Gun #2 = 5 ft. .......... Interval Measured Depth Top Ft. Base Ft. Gun Dia. Shot Density Orientation Kurparuk "B" [ 16,287 J l 16,247 ii2 7/8" J l 6 SPF J l Random Charge Type: CCL to Top Shot: DS 2 7/8" Deep Penetrating EHD= 0.29" TTP= 20.5" Atlas Alpha Jet, 15 gm. EHD=0.28" TTP= 23.2" Phasing Gun #3, Gun #4, Gun #5, Gun #7, Gun #8, Gun #9 = 3 ft. Gun #10, Gun #11, Gun #12 = 7 ft. Kurparuk "B" Interval Measured Depth ......... Top Ft. Base Ft. Gun Dia Shot Density Orientation I16,247 I[ 16,187 II It 6SPF J[ Random Kuparuk "C" Interval Measured Depth ......... Top Ft. Base Ft. Gun Dia 6,093 Notice: Phasing Shot Density Orientation Phasing It 15,973 il !! 6SPF !1 Random I[ 60° ] Unable to perforate the top 3 ft of the Kuparuk "B" sands or the bottom 5 ft. of the Kuparuk "C" sands, with the Select Fire Gun. This Gun was planned to be run last, but hole conditions prevented getting gun to proper depth. S-'~'RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 BP EXPLORATION (ALAS~) MILNE POINT / MPE-17i 500292268700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 122396 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60202 KELLY BUSHING ELEV. = 53.60 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9022.60 4616.87 4563.27 9308.80 4720.23 4666.63 9403.30 4754.38 4700.78 9499.80 4790.00 4736.40 9593.80 4823.76 4770.16 68 53 68 46 68 51 67 48 7O 5 S 72.20 E .00 1977.30S 6628.83E S 74.48 E .74 2053.80S 6884.46E S 76.39 E 1.89 2075.96S 6969.73E S 78.13 E 2.00 2095.74S 7057.19E S 78.07 E 2.43 2113.82S 7143.02E 6917.44 7184.28 7272.32 7361.80 7449.22 9689.10 4856.06 4802.46 9784.60 4888.78 4835.18 9880.20 4921.96 4868.36 9975.80 4955.01 4901.41 10071.40 4988.09 4934.49 70 16 69 39 69 43 69 49 69 41 S 78.25 E .27 2132.22S 7230.77E S 78.52 E .71 2150.28S 7318.65E S 79.81 E 1.27 2167.13S 7406.70E S 78.87 E .93 2183.73S 7494.85E S 77.70 E 1.16 2201.94S 7582.68E 7538.57 7627.96 7717.17 7806.40 7895.77 10167.00 5021.51 4967.91 10262.80 5055.10 5001.50 10358.40 5088.76 5035.16 10454.10 5123.30 5069.70 10549.50 5156.68 5103.08 69 23 69 33 69 12 68 28 70 33 S 78.64 E .97 2220.30S 7670.34E S 76.44 E 2.16 2239.65S 7757.93E S 77.44 E 1.05 2259.87S 7845.09E S 77.03 E .86 2279.59S 7932.13E S 77.69 E 2.26 2299.14S 8019.32E 7985.04 8074.51 8163.82 8252.87 8342.02 10645.00 5188.63 5135.03 10740.90 5220.84 5167.24 10836.20 5253.07 5199.47 10931.90 5285.14 5231.54 11027.50 5316.87 5263.27 70 20 70 24 70 3 70 47 70 26 S 78.21 E .55 2317.93S 8107.33E S 78.57 E .36 2336.11S 8195.81E S 78.80 E .44 2353.70S 8283.75E S 77.92 E 1.16 2371.90S 8372.06E S 77.87 E .37 2390.81S 8460.23E 8431.74 8521.73 8611.04 8700.88 8790.79 11122.50 5348.84 5295.24 11218.20 5382.00 5328.40 11314.00 5415.78 5362.18 11409.40 5448.89 5395.29 11505.20 5482.59 5428.99 70 13 69 13 69 29 69 53 68 55 S 78.38 E .55 2409.22S 8547.78E S 79.15 E 1.30 2426.71S 8635.82E S 78.49 E .70 2444.09S 8723.77E S 78.38 E .43 2462.03S 8811.42E S 78-.57 E 1.03 2479.94S 8899.28E 8879.95 8969.33 9058.58 9147.71 9237.04 11600.50 5516.20 5462.60 11696.00 5548.58 5494.98 11791.50 5580.48 5526.88 11887.00 5612.35 5558.75 11982.20 5644.03 5590.43 69 46 70 34 70 23 70 37 70 30 S 77.26 E 1.57 2498.62S 8986.48E S 77.64 E .92 2518.14S 9074.17E S 77.29 E .40 2537.67S 9162.04E S 75.49 E 1.79 2558.85S 9249.52E S 76.41 E .92 2580.65S 9336.61E 9325.94 9415.57 9505.36 9595.26 9684.94 12077.70 5675.51 5621.91 12173.60 5706.42 5652.82 12269.10 5737.15 5683.55 12364.90 5768.15 5714.55 12460.70 5798.84 5745.24 71 71 71 71 71 0 23 3 11 28 S 76.26 E .55 2601.95S 9424.22E S 76.21 E .40 2623.55S 9512.39E S 76.38 E .38 2644.97S 9600.24E S 76.30 E .16 2666.38S 9688.32E S 70.20 E 6.04 2692.52S 9775.18E 9774.99 9865.67 9955.97 10046.51 10137.22 ORIGINAL £'~-~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION (ALASKA) MILNE POINT / MPE-17i 500292268700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 122396 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60202 KELLY BUSHING ELEV. = 53.60 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. 12556.30 5829.45 5775.85 12652.10 5860.43 5806.83 12747.20 5891.06 5837.46 12843.30 5922.05 5868.45 12938.90 5953.14 5899.54 71 11 71 5 71 18 71 4 70 58 S 74.33 E 4.10 2720.11S 9861.42E S 78.41 E 4.03 2741.47S 9949.50E S 76.96 E 1.46 2760.67S 10037.46E S 75.44 E 1.52 2782.36S 10125.79E S 73.93 E 1.50 2806.24S 10212.98E 10227.74 10318.26 10408.04 10498.89 10589.27 13034.60 5984.45 5930.85 13127.10 6015.04 5961.44 13225.60 6047.88 5994.28 13320.90 6080.03 6026.43 13416.80 6113.19 6059.59 70 49 70 33 70 3O 7O 4 69 26 S 74.86 E .93 2830.57S 10300.07E S 72.36 E 2.57 2855.19S 10383.80E S 72.93 E .55 2882.89S 10472.43E S 73.33 E .59 2908.93S 10558.29E S 73.95 E .89 2934.27S 10644.62E 10679.69 10766.96 10859.81 10949.53 11039.50 13512.40 6146.71 6093.10 13607.60 6179.97 6126.37 13703.20 6213.60 6160.00 13798.90 6247.49 6193.89 13894.50 6281.46 6227.86 69 30 69 34 69 14 69 16 69 7 S 72.40 E 1.52 2960.19S 10730.32E S 72.14 E .27 2987.35S 10815.28E S 73.76 E 1.63 3013.59S 10900.83E S 73.75 E .04 3038.62S 10986.75E S 70.38 E 3.30 3066.14S 11071.76E 11129.03 11218.21 11307.69 11397.18 11486.51 13990.20 6316.31 6262.71 14084.30 6351.21 6297.61 14179.70 6386.35 6332.75 14275.30 6420.86 6367.26 14370.40 6454.68 6401.08 68 10 68 17 68 30 69 10 69 10 S 73.73 E 3.41 3093.60S 11156.54E S 73.49 E .27 3118.26S 11240.37E S 70.53 E 2.89 3145.65S 11324.72E S 70.89 E .78 3175.10S 11408.87E S 70.56 E .32 3204.44S 11492.77E 11575.59 11662.98 11751.64 11840.68 11929.47 14465.90 6489.19 6435.59 14561.50 6523.47 6469.87 14657.10 6556.78 6503.18 14752.70 6590.23 6536.63 14846.70 6622.73 6569.13 68 27 69 30 69 43 69 19 70 13 S 70.69 E .75 3233.98S 11576.77E S 70.85 E 1.11 3263.37S 11661.03E S 73.77 E 2.87 3290.60S 11746.39E S 73.36 E .58 3315.94S 11832.29E S 72.30 E 1.43 3341.98S 11916.55E 12018.40 12107.54 12197.12 12286.68 12374.87 14942.40 6654.66 6601.06 15037.80 6686.48 6632.88 15133.40 6717.67 6664.07 15228.90 6747.07 6693.47 · 15324.40 6776.45 6722.85 70 46 70 15 71 40 72 28 71 41 S 74.22 E 1.98 3367.95S 12002.93E S 73.86 E .66 3392.68S 12089.40E S 74.38 E 1.57 3417.41S 12176.31E S 75.68 E 1.54 3440.87S 12264.08E S 77.23 E 1.75 3462.15S 12352.41E 12465.07 12555.00 12645.36 12736.18 12826.91 15420.00 6806.82 6753.22 15515.70 6838.11 6784.51 15611.30 6870.13 6816.53 15703.90 6901.73 6848.13 15798.60 6934.99 6881.39 71 16 70 33 70 18 69 48 69 4 S 77.74 E .67 3481.80S 12440.91E S 77.31 E .85 3501.33S 12529.21E S 77.89 E .63 3520.67S 12617.18E S 78.29 E .68 3538.64S 12702.35E S 78.00 E .82 3556.85S 12789.13E 12917.33 13007.54 13097.38 13184.14 13272.51 St RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION (ALASKA) MILNE POINT / MPE-17i 500292268700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 122396 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60202 KELLY BUSHING ELEV. = 53.60 FT. OPEP~ATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 15894.30 6968.53 6914.93 69 53 S 77.01 E 1.29 15989.90 7001.40 6947.80 69 54 S 77.20 E .19 16565.00 7199.04 7145.44 69 54 S 77.20 E .00 3576.24S 12876.62E 13361.91 3596.28S 12964.13E 13451.50 3715.93S 13490.79E 13990.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 13993.19 FEET AT SOUTH 74 DEG. 36 MIN. EAST AT MD = 16565 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 106.54 DEG. TIE-IN SURVEY AT 9022.60' MD PROJECTED SURVEY AT 16565.00' MD S~RRY-SI/N DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 BP EXPLORATION (ALASKA) MILNE POINT / MPE-17i 500292268700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 122396 JOB NUMBER: AK-EI-60202 KELLY BUSHING ELEV. = 53.60 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9022.60 4616.87 4563.27 1977.30 S 6628.83 E 10022.60 4971.16 4917.56 2192.21 S 7537.96 E 11022.60 5315.23 5261.63 2389.84 S 8455.72 E 12022.60 5657.52 5603.92 2589.60 S 9373.62 E 13022.60 5980.51 5926.91 2827.61 S 10289.13 E 4405.73 5051.44 645.71 5707.37 655.93 6365.08 657.71 7042.09 677.01 14022.60 6328.36 6274.76 3102.03 S 11185.41 E 15022.60 6681.35 6627.75 3388.70 S 12075.66 E 16022.60 7012.63 6959.03 3603.08 S 12994.08 E 16565.00 7199.04 7145.44 3715.93 S 13490.79 E ' 7694.24 652.15 8341.25 647.02 9009.97 668.71 9365.96 356.00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP-qRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) MILNE POINT / MPE-17i 500292268700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 122396 JOB NIIMBER: AK-EI-60202 KELLY BUSHING ELEV. = 53.60 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9022.60 4616.87 4563.27 1977.30 S 6628.83 E 4405.73 9124.58 4653.60 4600.00 2006.38 S 6719.41 E 4470.98 65.25 9401.14 4753.60 4700.00 2075.48 S 6967.78 E 4647.54 176.56 9681.80 4853.60 4800.00 2130.82 S 7224.03 E 4828.20 180.65 9971.70 4953.60 4900.00 2182.98 S 7491.08 E 5018.10 189.91 10258.50 5053.60 5000.00 2238.71 S 7754.01 E 5204.90 186.80 10540.26 5153.60 5100.00 2297.28'S 8010.80 E 5386.66 181.76 10837.75 5253.60 5200.00 2353.99 S 8285.18 E 5584.15 197.49 11136.57 5353.60 5300.00 2411.88 S 8560.74 E 5782.97 198.81 11423.09 5453.60 5400.00 2464.62 S 8824.01 E 5969.49 186.52 11711.11 5553.60 5500.00 2521.19 S 9088.09 E 6157.51 188.01 12010.86 5653.60 5600.00 2586.99 S 9362.86 E 6357.25 199.75 12319.80 5753.60 5700.00 2656.27 S 9646.85 E 6566.20 208.95 12631.02 5853.60 5800.00 2737.27 S 9930.01 E 6777.42 211.22 12940.33 5953.60 5900.00 2806.61 S 10214.27 E 6986.73 209.31 13242.72 6053.60 6000.00 2887.63 S 10487.86 E 7189.12 202.40 13532.10 6153.60 6100.00 2965.77 S 10747.90 E 7378.50 189.38 13816.13 6253.60 6200.00 3043.24 S 11002.19 E 7562.54 184.04 14090.76 6353.60 6300.00 3120.00 S 11246.12 E 7737.16 174.62 14367.36 6453.60 6400.00 3203.50 S 11490.08 E 7913.76 176.60 14647.93 6553.60 6500.00 3288.16 S 11738.15 E 8094.33 180.57 14939.17 6653.60 6600.00 3367.12 S 12000.00 E 8285.57 191.24 15250.59 6753.60 6700.00 3445.99 S 12284.12 E 8496.99 211.42 15562.25 6853.60 6800.00 3510.97 S 12572.04 E 8708.65 211.66 15850.95 6953.60 6900.00 3567.13 S 12836.96 E 8897.35 188.70 16141.81 7053.60 7000.00 3627.88 S 13103.24 E 9088.21 190.85 16432.79 7153.60 7100.00 3688.42 S 13369.71 E 9279.19 190.98 16462.60 7163.84 7110.24 3694.63 S 13397.01 E 9298.76 19.57 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TIE-IN SURVEY AT 9022.60' MD PROJECTED SURVEY TO TD AT 16565.00' MD Shared Sevices Drilling Milne Point / MPE-17i 50-029-22687-00 North Slope Borough Computation Date: 12/22/96 Anadrill / Schlumberger Anchorage, Alaska MEASURED VERTICAL SUB-SEA COURSE COURSE DEPTH DEPTH VERTICAL INCLN. DIRECTION FT FT DEPTH DEG DEG 0.00 0.00 -57.10 0.00 0.00 112.00 112.00 54.90 0.00 0.00 197.70 197.70 140.60 0.26 91.40 288.50 288.50 231.40 0.83 86.60 379.00 378.96 321.86 2.23 97.50 3.43 4.11 5.36 7.18 8.60 469.10 468.95 411.85 560.20 559.85 502.75 648.00 647.35 590.25 735.30 734.13 677.03 826.10 824.06 766.96 Date of Survey: 12/21/96 MWD Survey Job Number: 39090 Kelly Bushing Elevation: 57.10ft Operator: BP Exploration DLS TOTAL RECTANGULAR COORDINATES D/H F NORTH/SOUTH EAST/WEST 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.19 0.63 0.03 1.06 1.57 -0.16 3.46 93.40 1.35 -0.55 7.89 90.80 0.77 -0.76 13.87 96.70 1.53 -1.28 21.09 101.60 2.17 -2.85 30.48 100.80 1.57 -5.27 42.71 917.80 914.48 857.38 10.53 99.80 1008.30 1003.31 946.21 11.53 101.50 1103.20 1095.78 1038.68 14.44 103.10 1200.00 1188.23 1131.13 19.90 103.40 1293.80 1275.76 1218.66 22.20 104.20 1390.30 1364.56 1307.46 23.87 104.40 1484.30 1449.74 1392.64 26.15 105.20 1579.90 1534.30 1477.20 29.46 105.50 1675.90 1616.54 1559.44 32.62 107.50 1774.00 1697.66 1640.56 35.79 107.70 1867.20 1773.29 1716.19 35.74 1962.30 1849.60 1792.50 37.53 2057.50 1923.78 1866.68 40.07 2153.00 1995.64 1938.54 42.32 2249.10 2065.59 2008.49 44.26 2344.10 2132.81 2075.71 45.66 2439.00 2197.95 2140.85 47.64 2534.20 2261.30 2204.20 48.94 2630.10 2322.84 2265.74 51.22 2725.80 2381.10 2324.00 53.77 107.10 107.80 106.80 108.80 108.30 2.11 -7.98 57.71 1.16 -11.19 74.72 3.09 -15.76 95.54 5.64 -22.32 123.34 2.47 -30.37 156.06 1.73 -39.70 192.64 2.45 -49.86 231.06 3.47 -61.67 274.06 3.46 -75.76 321.49 3.23 -92.44 374.05 108.00 108.10 105.80 105.30 104.80 0.38 -108.73 426.03 1.93 -125.75 480.16 2.75 -143.47 537.11 2.73 -162.72 596.98 2.05 -183.68 659.45 2820.70 2435.52 2378.42 56.24 105.90 2914.80 2486.14 2429.04 58.67 105.80 3010.60 2534.36 2477.26 60.88 105.50 3107.50 2579.88 2522.78 63.08 105.90 3202.30 2620.73 2563.63 65.87 106.70 1.49 -204.59 723.24 2.09 -225.97 788.85 2.26 -246.67 856.83 2.41 -266.38 927.68 2.70 -286.09 1000.99 2.77 -306.68 1075.95 2.58 -328.34 1152.25 2.32 -350.66 1231.95 2.30 -373.81 1314.30 3.04 -397.83 1396.39 VERTICAL SECTION FT 0.00 0.00 0.19 1.00 3.36 7.72 13.51 20.58 30.04 42.44 57.59 74.81 96.07 124.59 158.24 195.97 235.69 280.27 329.76 384.89 439.36 496.09 555.73 618.61 684.46 751.56 820.54 891.59 965.13 1041.01 1118.73 1198.04 1280.81 1366.33 1451.87 Schlumberger ANADRILL Survey Report MEASURED VERTICAL SUB-SEA COURSE DEPTH DEPTH VERTICAL INCLN. FT FT DEPTH DEG 3297.30 2658.33 2601.23 67.49 3392.90 2693.36 2636.26 69.52 3482.70 2724.79 2667.69 69.51 3582.80 2760.63 2703.53 68.53 3679.80 2796.12 2739.02 68.54 3777.70 2831.99 2774.89 68.48 COURSE DIRECTION DEG 106.20 106.80 106.00 106.30 106.60 106.90 3871.60 2866.35 2809.25 68.59 107.60 3967.50 2900.03 2842.93 70.28 108.40 4062.00 2932.47 2875.37 69.57 108.10 4157.80 2966.67 2909.57 68.60 108.70 4253.20 3000.84 2943.74 69.42 108.90 4348.40 3033.17 2976.07 70.88 108.80 4444.90 3065.02 3007.92 70.57 109.10 4538.60 3095.81 3038.71 71.06 108.10 4632.70 3126.50 3069.40 70.88 107.00 4728.00 3158.83 3101.73 69.46 107.60 4820.70 3191.08 3133.98 69.82 107.00 4915.70 3223.33 3166.23 70.49 107.30 5016.00 3257.99 3200.89 69.08 106.20 5110.70 3292.27 3235.17 68.47 106.40 5206.80 3327.11 3270.01 69.02 106.70 5300.80 3360.01 3302.91 70.00 106.30 5395.80 3392.91 3335.81 69.48 106.10 5491.80 3426.82 3369.72 69.15 106.40 5584.10 3459.28 3402.18 69.67 106.20 5678.80 3491.05 3433.95 71.12 106.00 5774.90 3522.67 3465.57 70.47 106.40 5870.00 3555.11 3498.01 69.63 106.10 5965.30 3587.87 3530.77 70.16 107.30 6064.80 3621.04 3563.94 70.90 106.90 6162.70 3653.47 3596.37 70.41 107.30 6257.40 3685.47 3628.37 70.09 107.10 6352.10 3718.38 3661.28 69.24 107.20 6447.40 3752.01 3694.91 69.43 106.70 6543.00 3785.47 3728.37 69.60 105.90 6635.30 3817.61 3760.51 69.64 106.20 6733.90 3851.94 3794.84 69.61 106.50 6828.70 3885.21 3828.11 69.30 107.40 6924.20 3917.26 3860.16 71.47 107.40 7020.30 3947.75 3890.65 71.54 106.40 7114.60 3977.42 3920.32 71.79 105.20 23-Dec-96 Page 002 DLS TOTAL VERTICAL RECTANGULAR COORDINATES SECTION D/HF NORTH/SOUTH EASTNVEST FT 1.77 -422.53 1480.06 1539.11 2.20 -447.79 1565.34 1628.05 0.83 -471.55 1646.04 1712.17 1.02 -497.54 1735.82 1805.63 0.29 -523.10 1822.39 1895.90 0.29 -549.36 1909.62 1987.00 0.70 1.93 0.81 1.17 0.88 1.54 0.44 1.14 1.12 1.60 0.72 0.77 1.74 0.67 0.64 1.12 0.58 0.45 0.60 1.54 0.78 0.93 1.31 0.83 0.63 0.39 0.90 0.53 0.80 0.31 0.29 0.95 2.27 0.99 1.24 -575.27 1993.08 -603.02 2078.47 -630.82 2162.76 -659.06 2247.67 -687.76 2331.99 -716.69 2416.73 -746.28 2502.88 -774.50 2586.75 -801.32 2671.57 -827.98 2757.16 -853.82 2840.14 -880.17 2925.52 -907.30 3015.64 -932.08 3100.37 -957.59 3186.22 -982.60 3270.65 -1007.46 3356.23 -1032.59 3442.46 -1056.84 3525.39 -1081.58 3611.09 -1106.90 3698.24 -1131.92 3784.06 -1157.63 3869.78 -1185.22 3959.44 -1212.38 4047.73 -1238.73 4132.87 -1264.92 4217.72 -1290.91 4303.02 -1316.05 4388.97 -1339.97 4472.12 -1365.99 4560.81 -1391.87 4645,73 -1418.77 4731,56 -1445.26 4818,76 -1469.63 4904.89 2074.38 2164.13 2252.85 2342.29 2431,29 2520.76 2611.77 2700.20 2789.15 2878.78 2965.69 3055.04 3149.15 3237.43 3326.99 3415,04 3504.16 3593.97 3680.38 3769.58 3860.33 3949.72 4039.21 4133.02 4225.39 4314.51 4403.30 4492.47 4582.02 4668.54 4760,97 4849.74 4939.68 5030.81 5120.31 Schlumberger ANADRILL Survey Report 23-Dec-96 Page 003 MEASURED VERTICAL SUB-SEA COURSE DEPTH DEPTH VERTICAL INCLN. FT FT DEPTH DEG 7211.50 4008.13 3951.03 71.25 7314.50 4041.00 3983.90 71.53 7401.20 4068.75 4011.65 71.13 7500.10 4100.18 4043.08 71.82 7593.90 4129.75 4072.65 71.42 COURSE DIRECTION DEG 105.60 105.70 105.70 106.00 105.40 7689.60 4160.41 4103.31 71.21 105.40 7785.30 4191.06 4133.96 71.43 105.60 7880.90 4222.11 4165.01 70.67 105.80 7976.00 4253.47 4196.37 70.82 105.40 8070.00 4284.07 4226.97 71.19 105.80 8165.10 4314.73 4257.63 71.19 106.80 8261.80 4347.01 4289.91 69.76 107.30 8356.90 4380.28 4323.18 69.34 107.70 8452.80 4414.09 4356.99 69.37 107.20 8547.80 4447.47 4390.37 69.49 107.20 8643.30 4480.93 4423.83 69.49 107.40 8738.90 4514.87 4457.77 68.92 107.20 8834.60 4549.15 4492.05 69.10 107.80 8928.00 4582.71 4525.61 68.78 106.80 9022.60 4616.87 4559.77 68.89 107.80 68.81 68.73 68.28 67.49 68.07 9096.10 4643.39 4586.29 9267.20 4705.35 4648.25 9359.90 4739.32 4682.22 9457.60 4776.10 4719.00 9549.30 4810.78 4753.68 9644.50 4844.99 4787.89 69.81 9741.70 4878.72 4821.62 69.58 9838.60 4912.51 4855.41 69.60 9933.90 4945.78 4888.68 69.54 10029.10 4979.25 4922.15 69.29 107.70 109.50 109.20 106.90 106.60 105.70 105.10 104.60 104.20 104.30 10125.70 5013.41 4956.31 69.29 104.50 10221.20 5047.51 4990.41 68.87 105.10 10316.10 5081.56 5024.46 69.08 106.20 10411.40 5115.98 5058.88 68.57 105.60 10508.40 5151.17 5094.07 68.89 106.00 10603.10 5184.34 5127.24 70.10 10698.70 5216.91 5159.81 70.06 10794.60 5249.75 5192.65 69.89 10889.70 5282.28 5225.18 70.11 10986.30 5315.07 5257.97 70.20 105.70 105.20 104.90 105.10 106.20 DLS D/HF 0.68 0.29 0.46 0.75 0.74 0.22 0.30 0.82 0.43 0.56 1.00 1.56 0.59 0.49 0.13 0.20 0.63 0.61 1.06 0.99 0.17 0.98 0.57 2.33 0.70 2.03 0.63 0.48 0.40 0.28 0.19 0.73 1.10 0.79 0.51 1.31 0.49 0.34 0.30 1.08 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EASTNVEST -1494.04 4993.50 -1520.37 5087.49 -1542.59 5166.56 -1568.21 5256.77 -1592.29 5342.47 -1616.37 5429.87 -1640.60 5517.23 -1665.06 5604.27 -1689.21 5690.75 -1713.11 5776.35 -1738.37 5862.75 -1765.07 5949.80 -1791.89 6034.87 -1818.80 6120.48 -1845.10 6205.44 -1871.70 6290.84 -1898.28 6376.17 -1925.15 6461.39 -1951.07 6544.60 -1977.30 6628.83 -1998.20 6694,11 -2049.06 6845.27 -2077.64 6926.65 -2105.69 7012.69 -2130.15 7093.98 -2154.86 7179,31 -2179.07 7267,20 -2202.34 7354.98 -2224.55 7441.48 -2246.49 7527.86 -2268.96 7615.38 -2291.75 7701.63 -2315.64 7786.92 -2339.99 7872.39 -2364.60 7959.36 -2388.83 8044.69 -2412.77 8131.32 -2436.17 8218.33 -2459.30 8304.65 -2483.81 8392,15 VERTICAL SECTION FT 5212.20 5309.80 5391.93 5485.70 5574.70 5665.34 5755.98 5846.39 5936.16 6025.03 6115,05 6206,09 6295.28 6385.00 6473.94 6563.38 6652.75 6742.08 6829.23 6917.44 6985.98 7145.35 7231.50 7321.97 7406.86 7495.70 7586,84 7677,62 7766.86 7855.91 7946.20 8035.37 8123.94 8212.80 8303,18 8391,87 8481.74 8571.81 8661.14 8751.99 Schlumberger ANADRILL Survey Report MEASURED VERTICAL SUB-SEA COURSE COURSE DEPTH DEPTH VERTICAL INCLN. DIRECTION FT FT DEPTH DEG DEG 11077.30 5346.12 5289.02 69.90 105.60 11176.70 5380.92 5323.82 69.12 105.70 11272.50 5415.21 5358.11 68.93 105.90 11368.10 5449.21 5392.11 69.41 105.60 11463.40 5483.18 5426.08 68.82 105.60 11558.20 5517.28 5460.18 69.02 106.40 11652.80 5550.05 5492.95 70.44 106.60 11748.10 5582.36 5525.26 69.92 106.50 11844.00 5615.29 5558.19 69.92 106.90 11939.90 5647.77 5590.67 70.48 107.40 12034.50 5679.14 5622.04 70.79 107.40 12129.60 5710.24 5653.14 71.03 107.50 12226.60 5741.66 5684.56 71.17 106.90 12320.00 5771.90 5714.80 71.06 107.10 12417.70 5803.38 5746.28 71.34 106.70 12514.00 5834.37 5777.27 71.11 12609.20 5865.31 5808.21 70.96 12703.90 5896.01 5838.91 71.21 12800.30 5927.24 5870.14 70.99 12895.50 5958.21 5901.11 71.04 106.80 106.30 105.80 106.60 107.60 12987.40 5988.28 5931.18 70.76 106.90 13086.80 6021.27 5964.17 70.47 107.20 13182.30 6053.05 5995.95 70.66 107.00 13278.00 6085.20 6028.10 70.08 106.70 13373.30 6118.19 6061.09 69.42 106.30 13469.10 6152.03 6094.93 69.20 13565.00 6185.98 6128.88 -69.34 13659.30 6219.41 6162.31 69.13 13755.40 6253.57 6196.47 69.23 13851.20 6287.69 6230.59 69.04 107.20 108.20 107.10 107.00 106.80 13948.50 6323.18 6266.08 68.18 106.50 14043.50 6358.70 6301.60 67.91 107.60 14137.20 6393.56 6336.46 68.40 107.50 14232.20 6428.51 6371.41 68.43 108.30 14329.10 6463.65 6406.55 69.05 108.20 14424.10 6498,07 6440.97 68.46 108.20 14519.20 6532.82 6475.72 68.68 108.70 14614.50 6566.68 6509.58 69.70 107.20 14710.30 6600.23 6543.13 69.30 107.30 14806.30 6633.96 6576.86 69.56 107.60 23-Dec-96 DLS D/HF 0.70 0.79 0.28 0.58 0.62 0.82 1.51 0.55 0.39 0.76 0.33 0.27 0.60 0.23 0.48 0.26 0.52 0.56 0.82 0.99 0.78 0.41 0.28 0.67 0.80 0.91 0.99 1.11 0.14 0.28 0.93 1.11 0.53 0.78 0.65 0.62 0.54 1.82 0.43 0.40 Page 004 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST -2507.24 8474.41 -2532.36 8564.07 -2556.72 8650.14 -2580.97 8736.14 -2604.91 8821.90 -2629.29 8906.93 -2654.50 8992.01 -2680.04 9077.95 -2705,92 9164.22 -2732.53 9250.44 -2759.22 9335.60 -2786.16 9421.34 -2813.30 9509.00 -2839.14 9593.51 -2866.03 9682.01 -2892.30 9769.31 -2917.95 9855.61 -2942.72 9941.71 -2968.16 10029.29 -2994.63 10115.33 -3020.38 10198.26 -3047.87 10287.91 -3074.35 10373.98 -3100.48 10460.25 -3125.88 10545.98 -3151.70 10631.80 -3178.97 10717.24 -3205.71 10801.26 -3232.05 10887.14 -3258.07 10972.79 -3284.03 11059.59 -3309.86 11143.82 -3336.09 11226.75 -3363.24 11310.81 -3391.52 11396.57 -3419.17 11480.68 -3447.19 11564.66 -3474.64 11649.40 -3501.25 11735.10 -3528.20 11820.84 VERTICAL SECTION FT 8837.52 8930.62 9020.07 9109.41 9198.44 9286.89 9375.63 9465.28 9555.35 9645.58 9734.81 9824.67 9916.44 10004.80 10097.29 10188.46 10278.50 10368.08 10459.28 10549.29 10636.13 10729.89 10819.94 10910.08 10999.49 11089.11 11178.78 11266.93 11356.76 11446.27 11536.87 11624.97 11711.93 11800.24 11890.51 11979.01 12067.49 12156.54 12246.27 12336.13 Schlumberger ANADRILL Survey Report 23-Dec-96 Page 005 MEASURED VERTICAL SUB-SEA COURSE COURSE DEPTH DEPTH VERTICAL INCLN. DIRECTION FT FT DEPTH DEG DEG 14899.60 6665.71 6608.61 70.64 107.00 14994.10 6697.16 6640.06 70.48 107.40 15089.80 6728.49 6671.39 71.30 107.30 15185.80 6758.38 6701.28 72.43 106.20 15282.30 6787.72 6730.62 72.17 105.00 15377.00 6817.44 6760.34 71.24 104.30 15472.00 6848.51 6791.41 70.58 104.60 15568.70 6880.89 6823.79 70.30 103.80 15664.50 6913.52 6856.42 69.87 103.80 15757.00 6945.91 6888.81 69.14 103.60 15851.00 6979.15 6922.05 69.44 104.40 15946.50 7012.30 6955.20 69.93 104.00 16043.10 7044.88 6987.78 70.65 104.60 16138.30 7075.91 7018.81 71.31 104.10 16233.40 7106.19 7049.09 71.55 104.20 16329.60 7136.12 7079.02 72.20 103.80 16425.70 7165.28 7108.18 72.47 104.00 16473.60 7179.64 7122.54 72.66 104.10 Su~ey Pr~e~edto TD 16565.20 7206.94 7149.84 72.66 104.10 DLS TOTAL VERTICAL RECTANGULAR CO0~DINATES SECTION D/HF NORTH/SOUTH EAST/WEST FT 1.31 -3554.29 11904.60 12423.85 0.43 -3580.64 11989.73 12512.96 0.86 -3607.60 12076.04 12603.38 1.60 -3633.89 12163.40 12694.60 1.21 -3658.61 12251.94 12786.52 1.21 0.76 0.83 0.45 0.81 0.86 0.65 0.95 0.85 0.27 0.78 0.34 0.44 0.00 -3681.35 12338.93 -3703.76 12425.86 -3726.11 12514.20 -3747.59 12601.67 -3768.11 12685.85 -3789.39 12771.16 -3811.36 12857.99 -3833.82 12946.11 -3856.12 13033.30 -3878.16 13120.71 -3900.28 13209.42 -3922.28 13298.31 -3933.37 13342.64 -3954.67 13427.45 12876.38 12966.10 13057.14 13147.11 13233.65 13321.49 1341O.97 13501.84 13591.78 13681.85 13773.18 13864.66 13910.31 13997.67 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 1O814 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 2/21/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPF-21 ULTRASONIC IMAGER 9 701 04 I 1 M P F-21 GR-CCL CORRELATION 9 701 05 I 1 MPF-21 CEMENT BOND LOG 9701 04 1 1 MPF-21 TDT GRAVEL PACK LOG 9701 08 I 1 MPF-21 i9 5/8" PACKER RECORD 9701 05 I 1 MPU K-33 'STATIC TEMPERATURE PRESSURE 9 701 2 9 I 1 MPU K-33 BRIDGE PLUG SET 970207 I 1 MPU K-33 GR/CCL DEPTH LOG 9701 29 I 1 MPU F-54 GR/CCL DEPTH LOG 9701 31 I 1 M P H-07 GR/CCL CORRELATION LOG 9701 21 I 1 -- MPK-06 PERFORATION RECORD 9 7011 2 I 1 MPK-06 GR-CCL PRIMARY DEPTH LOG 97011 2 I 1 MPE-17 CEMENT BOND LOG 9701 07 I 1 M PE-17 COMPLETION RECORD 9701 2 7 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562:7669 (Bus.) (907) 563-3309 (Fax) February 19, 1997 . TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD Depth Corrected CDR/ADN, CDR/ADN TVD'S for well MPE-17, Job Cf 97067 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1 Depth Shift Display State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape 1 Blueline each 1 RF Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail: Z 777 937 529 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska!-~ .995i ~-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 State daska Alaska Oil & Gas Conservation Comm. Atten' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 - Transmittal of Final Prints. Please sign and return copy to' Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 14-Feb-97 "Well Name Services Bluelines R/F Sepia Film MPE-171 GR/CCL PERF 1 1 0 il I I! ' Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. ALAS~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 22, 1996 Tim Schofield, Sr Drilling.Engineer .. BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit MPE-17 BP Exploration (Alaska) Inc. Permit No. 96-115 Sur. Loc 3664'NSL, 1775'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc. 4948'NSL, 2946'WEL, Sec. 33, T13N, R11E, UM Dear Mr. Scofield: 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 mn. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity. (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting =lni~ion petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosure CCi Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REVISED 07/15/96 PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 57.1' Milne Point Unit / Kuparuk River 3. Address i6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028232 4. Location of well at surface i7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3664' NSL, 1775' WEL, SEC. 25, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 5168' NSL, 3682' WEL, SEC. 33, T13N, R11E MPE-17 At total depth 9. Approximate spud date Amount $200,000.00 4948' NSL, 2946' WEL, SEC. 33, T13N, R11E 08/20/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028231, 2334'I MPE-23, 88' @ 400' TVD 2560 16875' MD / 7337' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' Maximum Hole Angle 69.97° Maximum surface 3005 psig, Attotal depth (TVD) 7529' / 3758 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT80LHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 9486' 31' 31' 9517' 4817' 114645x PF'E', 1153sx'G' 8-1/2" 7" 26# L-80 Mod B 16845' 30' 30' 16875' 7337' 321 sx Class 'G' i19. 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 SurfaceR[CEIVED Intermediate Production Liner JUL 1 g 1996 Alaska 0;I & Qas tens. C~mmi$$ion Anchorage, Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number Kathy Campoamor, 564-5122 21. I hereby certify that the f~..,~oing is truce and c~[n act to the best of my knowledge , Signed '//'- (""~'-~ ~-~] Tim Schofield / [~3'"). ~ ,'"~'~.¢¢_.4Z4X:' Title Senior Drilling Engineer Date ° . ~ f ' Commission Use Only Permit Number [ APINum e I ApprovalDate [ Seecoverletter ~>~/"-////'.j~" 50- ~.2---~ ---' ~ ~ ~" ~:: ~ .,.-) ...-~j _ c)/,~ for other requirements Conditions of Approval: Samples Required [] Yes /~A~'No Mud Log Required [] Yes /~" No Hydrogen Sulfide Measures []Yes ,}~No Directional Survey Required ~'Yes [] No Required Working Pressure for DOPE [] 2M; []3M; .~ 5M; [] 10M; [] 15M Other: d,qglrla! Signed By by order of ,- Approved By I~wid W lnhqqtnrl Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I MPE-17i Well Plan Summary I Type of Well (producer or injector)' I KuparukWAG InjectorI Surface Location: 3664' FSL t775' FEL Sec 25 T13N R10E UM., AK. Target Location: 5168' FSL 3682' FEL Sec 33 T13N R11E UM., AK. Bottom Hole Location: 4948' FSL 2946' FEL Sec 33 T13N R11E UM., AK. Note: Target & BHL footages are based on assumed true and square sections and are not surveyed le~lal locations. I AFE Number: 1337034 I I Ri~l: J Nabors 27E I Estimated Start Date: I August 20, 1996 IOperating days t° drill and 121Icase: I MD' 116875' I I TVD: 17337' BKB I I KBE' J57.' J IWell Design (conventional, slimhole, etc.): Ultra Slimhole, 7" Longstring Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1 956 1857 n/a NA (Top Schrader) 8173 4300 1905 psig / 8.0 ppg OA 1955 psig / 8.0 ppg Base Schrader Bluff 8889 4602 1995 psig / 8.0 ppg Top HRZ 14510 6527 n/a Base HRZ n/a Kupark D Shale n/a Kuparuk C 16057 7057 3650 psig / 10 ppg TKA 3669 psig / 10 ppg Total Depth 16875 7337 n/a Casing/Tu bin~l Pro~lram' Hole ~:sg/ ' Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVD MD/TVD 30" 20" 91.1# NT80LHE weld 80 32' 112/112 12 1/4" 9 5/8" 40# L-80 BTRC 9486 31' 9517/4817 8 1/2" 7" 26# L-80 Mod B 16845 30' 16875/7337 N/A (tbg) 4.5" 12.75# L-80 IBTM 16029 29' 16058/7057 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. The Modified Buttress 7" 26# will be run for WAG injection. Logging Program' I Open Hole Logs: Surface Schrader Bluff Final IMud Logs' MWD with DWOB/DTOR MWD with DWOB/DTOR with LWD GR/Resistivity/SFC CSG to TD Neutron/Density over Kuparuk intervals. None required , , ~ StOR 'j~!ask~ Oil 8,, OraS Gens. 6o.'~ APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 Mud Program: Special design considerations Hydrates LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per the updated pad data sheet are encouraged. This well will be an ERD well with 14247' stepout. We will use a mixture of lubricants deveoped at Milne Point. We may have hydrates on E Pad. We will have our mud weight to 10. PPG by 2000 feet. We will weight up in 0.5 ppg increments if necessary. We will use the coldest mix water available to minimize warming in the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to 450 to 600 GPM when hydrates are present to keep mud temperatures to a minimum. We will control drilling rate and keep mud viscosity at 100 sec/qt to keep the hole clean. Surface Mud Properties: 0 - 9517' MD I Spud Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~]el ~lel Loss 8.6 80 15 8 10 9 8 to to to to to to to 11.0 - 11.2 100 35 15 30 10 15 Production Mud Properties:9517' - 16875' MD I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~el ~lel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.5 50 20 10 20 9.5 4-6 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: 1400' Maximum Hole Angle: Maximum Doll Les: Inclination in tar~let: Close Approach Well: 69.97 degrees < 4 degrees 69.97 Degrees MPE-23 will be 88' at 400' TVD when it is drilled This wellplan will allow MPE-17i to be drilled as per SSD close approach guidelines. well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. The Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing, APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 DRILLING HAZARDS AND RISKS: See both the Milne Point E-Pad Data Sheet prepared by Pete Van Dusen for information on the Cascade wells, and review recent wells drilled on E Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. Hydrates We may have hydrates on E Pad. We will have our mud weight to 10. PPG by 2000 feet. We will weight up in 0.5 ppg increments if necessary. We will use the coldest mix water available to minimize warming in the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to 450 to 600 GPM when hydrates are present to keep mud temperatures to a minimum. We will control drilling rate and keep mud viscosity at 100 sec/qt to keep the hole clean. The MPU PE group will be perforating, and cleaning out wells shortly after the dg drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells on F Pad have lost varying amounts of mud (from 70 to 1000 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 and MPK- 17 were stuck coming out on the short trip at surface casing point. In the MPK-17 well, proir to the stuck pipe incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we.lost the ability to circulate when the hole collapsed around the BHA at 2300 feet. Subsequent fishing operations were successful and a very expensive BHA was recovered. The interval was the first report of hydrates being present in the well so we had a 11.3 ppg mud weight, but our vis was only 66 sec/qt (26 cp). The Sand/Coal that hydrates were present in probably provided a ledge for the gravel to accumulate in, and fell into the hole when we were tripping out for casing. Future wells should have higher viscosity ( 150 sec/qt )for hole cleaning Most stuck pipe problems occur when we do not listen to the hole. Regular stuck pipe meeting to identify sticking trends and intervals will be held at the rig.. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 171 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3761 psig (10 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 10 ppg EMW (3646 psi @ 7011' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. We will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. WATER USAGE Have the water truck drivers track the water usage on'a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 DRILLING CONTINGENCIES Hydrate Issues 1. Hydrates have been encountered on several E-Pad wells in the past. They have not been as severe as those found on K-Pad, but still may pose a hazard to safe drilling operations. 2. The planned surface casing point of 9517' MD (4817' TVD) assumes that there will be no hydrates present or that they will be able to be controlled with a mud weight of 10.0ppg or less. Most wells on E- Pad have used mud weights below 10.0 ppg to drill surface hole. 3. The risk of losses to the Schrader Bluff formation dictates that surface casing will have to be set shallow at 3500' TVD / 5669 MD, if high mud weights are needed to control hydrates. In this case, "high" weights are considered to be anything over 10.0ppg. Losses to the Schrader Bluff have not occurred with mud weights below 11.0ppg, so there is a significant safety factor built into this limit. 4. All good practices on hydrate control developed on K-Pad operations should be transferred to E-Pad. 5. A new product "Lecithin" will be tested on this well. It has been proven to inhibit the sublimation of hydrates in laboratory trials. ERD Issues 1. E-17i will have one of the longest surface casing strings run at Milne Point. Provided that good practices are followed, there is considered to be little dsk involved in getting the casing to bottom. Conditions were much more challenging on F-38, where the hole inclination was 10° higher than will be seen on this well. 2. If the surface casing is set shallow, there is a potential to drill the longest production section in the field. If hole conditions are poor and/or mud weights reach 10.5 ppg, the casing may have to be set above the Kuparuk reservoir. 3. If 7" casing has to be set above the reservoir, 6" hole will be drilled through the Kuparuk. This will be the highest stepout 6" hole drilled on the N Slope. Nabors have 5000' of 3 1/2" hi-torque ddll pipe, which should be picked up if this contingency is required. APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 MP E-17i Proposed Summary of Operations . , , , , 10. 11. 12. 13. 14. 15. 16. 17. 18. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5A Wellhead on the conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. Prior to spud, discuss hydrates drilling with Nabors 22E toolpushers and company representatives J. C. Pyron and D. Montjoy. NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. Drill 12-1/4" surface hole to 9517' md (4817' tvd). Use extreme caution while drilling through the known hydrate interval down to 3100 feet. Run and cement 9-5/8" casing with 2 stage cememting procedure. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9:..5/8~asing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and (L~'ffeet of new formation, Perform a LOT t~ o ,'~'~'d,m,~m cf !2.-5-ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. Follow Pad Data Sheet short trip guidelines. Drill 8-1/2" hole to TD at 16875' MD (7337' TVD). (Note: This hole section will be logged with a LWD Triple Combo (GR/Res/Neu/Dens). Use due caution while for both stuck pipe and well control issues. We will gather torque data for this well for planning future wells. A schedule for data points will be sent out with the drilling program. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing with 1 stage cement program. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. Make sure there is a circulating head for the topdrive before starting to run casing. ND BOPE and NU dry hole tree. Release rig to MPE-19. Note: This well will be perforated, and cleaned out with a completion rig and prior to running the ESP completion. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 3.5" DP and 6" bit, clean out to PBTD. TOOH. PU and RIH with ROPE perforating string (procedure to be distributed later with perforation intervals). PU and RIH with 3-1/2" NSCT tubing with Dual injection packer completion. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. POST RIG WORK , Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. . A SBT/GR/CCL is required on this well to evaluate the long string cementing for injection. This will be done 2 weeks after cementing to develop the minimum compressive strength. , An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morninq report. 4. The rig will not complete this well. PEs will perforate and clean out this well with a pulling unit. APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 RECOMMENDED PRACTICES FOR CEMENTING 2 STAGE SURFACE I , . , . , Minimun recommended rathole below float shoe for calculatinq pipe talle¥ is 20' for production hole. Circulate and condition the mud for running casing (See Mud Program for YP and Gel Strength recommendations -- Recommended YP @ 8 to 10 and Gels 2- 4, and 5-7). POOH and rack 5" DP and 12.25" BHA. Spot a Barafibre and Baracarb pill (as per Mud Pro~lram) across the Schrader Bluff sands while POOH -- this pill is intended to prevent losses into the U~lnu/West Sak sands while runnin~l casin~l. Lay down LWD equipment if still part of the BHA. Review pre-job checklist. CASING RUN NING PRE-JOB CHECKLIST Tally all pipe as it is loaded on the pipe racks. Remove all thread protectors, visually inspect threads for cleanliness and damage. Measure pipe from end of box to first full thread on pin end. Threadlock up to and including box end of float collar. Visually inspect float equipment to ensure floats are clear of debris. Drift casing while on rack (Drift is 8.835".) The centralizers and turbulators should be installed while pipe is on rack if possible. Have emergency slips and packoff available if casing sticks off bottom. Have a mix water sample taken to test with cement blend. Verify mix water temperature with cementers; make arrangements to have water of correct temperature on location. Have a safety valve (i.e. full opening ball valve) made up to cementing swedge on the floor for circulation and/or well control. Have a 20' pup joint available for space out purposes if it happens that the casing shoe is too far off bottom. Rig up casing running equipment. Check calibration papers of casing tongs. Make sure the tie-back line of power tongs is level and secured at a right angle to ensure accurate torque is being applied. Have at least one backup for power tongs, hydraulic unit, and spider/elevator on location. Run surface casing as follows: (Dope Pin Ends only on Production Casing!!!!!!!) a. Halliburton Super Seal Float shoe (with Auto Fill Tab in place -- Do not pump higher than 2 bpm at the shoe or tabs will pump out) -- Baker Lock b. One (1) joints of protection casing 9.625" 40# Btm -- Baker Lock c. Halliburton Super Seal Float collar (with Auto Fill Tab in place) -- Baker Lock d. One (1) joint of protection casing 9.625" 40# Btm -- Baker Lock e. Landing Collar-- Baker Lock f. 9.625" Halliburton ES 2 Stage Cementer (approximately 4000' MD to be below the hydrates and above the Ugnu) Pin the ES Cementer to shear open at +/-3000 psig. Bakerlock ES Cementer. h. 9.625" 40# L80 Btrc Modified Casing to surface. i. FMC 9.625" Casing Hanger with BTRC Pin TURBULATOR PLACEMENT & CASING RUNNING NOTES · Run 1 Straight Blade Rigid Centralizer per joint from the Base of the O Sands to the Top of the NA Sand (appx 9517 - 9117). · Run 1 straight blade rigid centralizer inside the 9-5/8" casing. · Use Mercasol Multi-make White compound on all premium connections. · Lay down all joints that do not make up within the specified torque ranges. 9.625" Modified Buttress (See make up guidelines) · Fill float joints immediately after running in hole to establish circulation through floats -- do not exceed 2 bpm or auto fill tabs will pump out. · Ensure Driller knows the proper displacement volumes for the casing being run. · Test fillup system prior to running in the hole with casing. · Fill every joint with mud while going in hole. · Line up on the trip tank or equalize a pit to serve as trip tank -- fill and take returns into this pit/trip tank and adjust pipe running speed based on returns. APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 . . 11. Note: 12. 13. 14. 15. Bring casing to a complete stop before setting slips. If casing needs to be pushed in the hole, install chain and cap assembly and chain to elevators. Do not set block down on top of casing and allow elevators to slide down casing. Monitor Pick-up and Slack-off weights while running hole. Record Hanging weight, PU weight, and SO weights with casing on bottom. Witness loading of the plugs in the cementing head. Closely monitor displacement while running in the hole, especially around the Ugnu Sands. If returns stop, consider engaging the circulating packer to circulate and reciproacate to remove packed off mud around casing shoe. MU the 9.625" casing hanger, and 9.625" landing joint. string, unset the slips, and RD the 9.625" casing spider. hanger and install cementing head. PU on the casing Land the casing Clear all personnel from the rig floor and all high pressure lines. Test rig manifold and cement hose to the cementing head to 3500 psi. Bring Pumps on slowly to establish circulation and avoid packing off around the centralizers, slowly increase pump rate up to the anticipated displacement rate (10-12 bpm) while circulating the equivalent of at least 2 annular volumes and/or until mud has been thinned back and hole has been adequately cleaned. Install pressure chart recorder and record standpipe pressures during displacement. Once circulation is established, reciprocate casing with 30' strokes while circulating and cementing. MAXIMUM PICK UP WEIGHT WHILE RECIPROCATING IS 730KIb. THIS IS 80% OF THE TUBE BODY STRENGTH WHICH IS LESS THAN THE CONNECTION IS THIS CASE. Perform Stage 1 of the Production Cement Job as follows: a. c. g. Load Bottom Plug #1 into the Cement Head. Safety Note: Have all personnel vacate the Rig Floor and all areas of High Pressure Lines when pressure testing. Test Cement Lines to 3500 psig. Pump Bottom Plug #1 out of Head with minimal volume of fresh water. Shut down and Icad Bottom Plug #2 and Top Plug. Pump 20 bbl freshwater followed by 70 bbls Alpha Spacer weighted spacer weighted 1 ppg above the mud weight as listed on the cement page of the Well Plan. Drop 2nd bottom plug immediately after spacer. Pump Cement as per Cementing Page. Drop top plug- verify that the positive indicator shows plug leaving the cement head. Switch to rig pumps and Displace cement with drillincj mud at 10-12 bpm once plug catches cement. As in past jobs, we may be experincing losses - if necessary use lake water to bump the plug. As the plug approaches the float collar (within 5 bbls), slow down to 3 bpm. Pump until the plucj is bumped- adjust rate to not exceed 2500 psig. Release pressure slowly and check floats-- If the floats do not hold, hold 1500 psig on casing for minimum of 4 hours and recheck floats. If the formation breaks down, wait at least 4 hours from the time cement was mixed to pump second stage. After successfully checking floats, bleed off all pressure and Icad the closing plug for the ES Cementer. Pressure up and shear the ES Cementer open with +/-3000 psig pressure. If the ES Cementer does not hydraulically open, there is a opening bomb available with the tool - at high hole angles, it may be necessary to push the bomb down with drill pipe. Circulate a minimum of two annular volumes. Perform Stage 2 of the production cement job as per the cementing program. Drop the ES Cementer closing plug and displace the plug to the ES Cementer with sea water and diesel for freeze protection. Pressure up and shear the ES Cementer closed. Bleed off the pressure and confirm that the ES Cementer closed. Immediately after checking floats, drain and flush the stack with water via annulus valve. Back out the 9.625" landing joint and rig down the cementers and casing crew equipment. Position' packoff and lower until contact with production casing hanger. Run in Iockdown screws to energize packoff. Test packoff to 5,000 psi if a casing mandrel hanger is used. If emergency slips are needed, test the packoff to 3,800 psi (Ensure that 3,800 psi does not exceed 80% of the collapse rating of the casing). APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 Make sure to fill the casing every joint to avoid having to shut down to fill the casing. Casing has been stuck while the rig was shut down filling only 5 joints. THE RIG SHOULD BE PREPARED TO HANDLE CEMENT RETURNS AT THE SURFACE. CEMENT VOLUME: 1. The Tail Slurry volume is increased to cover the 9-5/8" to 500 feet above the Schrader Bluff with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry surface with 30% excess to 1800 feet, and then 150% excess over the permafrost. 3. 80'md 9-5/8", 40# capacity for float joints is 6 BBL. APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 MPE-17i WELL 9-5/8" 2 STAGE SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 70 bbls NSCI Spacer weighted to 12 ppg WITH 3/4 PPB FLOCELE STAGE 1 LEAD CEMENT TYPE: annular hole volume) Type E Permafrost (30 % excess over ADDITIVES: Retarder ADD 1/4 PPSx FLOCELE. WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 815 THICKENING TIME: Greater than 4 hrs at 50° F. STAGE I'TAIL CEMENT TYPE: Premium G (30% excess over annular hole volume) ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg YIELD:I.15 ft3/sx MIX WATER: 5.0 gal/sk APPROX #SACKS: 374 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 SPACER: 70 bbls NSCI Spacer weighted to 12 ppg WITH 3/4 PPB FLOCELE STAGE 2 LEAD CEMENT TYPE: Type E Permafrost (150 % excess over annular hole volume) ADDITIVES: Retarder ADD 1/4 PPSx FLOCELE. WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 649 THICKENING TIME: Greater than 4 hrs at 50° F. STAGE 2 TAIL CEMENT TYPE: hole volume) Premium G (30% excess over annular ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 779 FLUID LOSS: 100-150 cc YIELD:i.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 CENTRALIZER PLACEMENT: 1. 1 Straight Blade centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. 1 TURBULATOR centralizer per joint of 9-5/8" casing from 2000 to 2500 feet. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 MPE-17i 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK SANDS: CIRC. TEMP: 115° F BHST 120 deg F at 7040' TVDSS. SPACER: 50 bbls fresh water . 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.4% Halad 344, 0.1% HR-5 WEIGHT: 15.8 ppg YIELD: 1.15 cu ft/sk MIX WATER: 5 gal/sk APPROX # SACKS' 321 THICKENING TIME: 4 1/2 hrs @ 140° F FLUID LOSS: < 45cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7"x 8-1/4" Straight Blade Rigid Centralizers-- two per joint across the Kuparuk Sands from 16875 - 16058 (58 total). This will cover 200' above the C Sand. 2. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 3. Total 7" x 8-1/4" Straight Blade Rigid Centralizers needed is 59. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. Make sure the float collar, float shoe, landing collar, and baffle plate are run in the proper sequence. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the Kuparuk Top with 30% excess. APl # 50-029-22XXX MPE-17 WAG Injector July 15, 1996 MPE-17 Cement Calculator Milne Point Cement and Centralizer Calculations Well MPE-17i Surface (1 Stage) Cement Job cement Type E G Hole Size 12.25 Yeild (cfs) 2.17 1.15 Casing Size 9.625 Weight (ppg) 1 2 15.8 BPF 0.0558 BPF + 30% 0.0725 BPF + 150% 0.1395 STAGE 1 Depth BBLS w/XSF Cu. Ft. Sacks 'Top of Cemenl =~.~ ....... ,. · ,, ..... ',~ Shoe Depth ~,.,,.. Calculated G Tail Volume 972 76.5 430 374 8545 E Lead Volume 4345 315.1 1769 81 5 4200 ES Cementer 4000 MD STAGE 1 G Tail Volume 2200 159.5 896 779 1800 E Lead Volume 1800 251.0 1409 649 0 STAGE 1 STAGE 2 Total E 81 5 649 Total G 374 779 9-5/8" St Blades I 0 from 9517 to 9117 9-5/8" Turbulator I 0 from 2400 to 2000 Production 1-Stage Cement Job Cement Yield Hole Size 8.5 Premium G 1.15 Casing Size 7 BPF 0.0226 BPF + 30% 0.0294 Top of Cement Stage 1 MD BBLS Cu. Ft. Sacks Calculated Kuparuk Top ~ 6 6 369 321 14740 Kuparuk C1 Target Total G ST1 321 7" St Blades 58 From 16875 to 16058 One in 9.625" shoe 1 Total ST Blades 5 9 Page 1 BPX - Shared Services Dr'illina Alaska State Plane' Zone4 Xilne Pt ' MPE MPE- 17 As-Built Milne Pt, E Pad MPE- 17 Wp3 VERTICAL VIEW SCALE 1000 It, / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 0 -~ o. oo' E o MD TIE IN 400~ 0.00' ~ 400 MD KOP ! START DF BUILD ~ 1.50'/100 ?~ ~00 3.00' e Goo MD ~TART DF BUILD e 2,50'/100 ~ B. O0' R BOO MD 1000 ~ ~ t~.oo' e ~ooo ~ 18.00' ~ 1800 M~ 23,00' e ~400 MD . ~28.00' e 1600 HD ~ 45,00' E ~DBO MD ~ 50.00' ~ 25~0 MD ~ 55, 00' ~ ~780 MD CORVE 68.50' ~ 3080 ~.~ ~ EN~ OF 2715 ~sss 3000 -- 4000 -- 4357 4602 5000 -- 6000 -- 6527 6777 7337 8000 6071 6743 CRITICAL PDINT DATA MD Inc Azi TIE IN 0 0.00' 106.59' KDP / START 400 0.00° 106.59' DF BUILD 8 1.50'/100 Ft START DF BUILD 600 3.00' 106.59' 8 2,50'/100 END DF BUILD 1880 35.00' 106.59' B~$e 1956 35.00' 106.59' PermaFrost START DF 1980 35.00' 106.59' CURVE 8 2.50'/100 Ft END DF CURVE 3379 69.97' 106,59' NA S~nd$ 8174 69.97' 106.59' Bose Schrader 8889 69.97' 106.59' THRZ 1451069.97' 106.59' TKLB 1584069.97' 106.59' T~pge~ / TKUCl16058 69.97' 106.59' TVD 0 400 13479 12024 12710 600 1795 1857 1876 8715 4357 4602 6527 6777 7057 N/S 0 N 0 N I S E/W 0 E 0 E 5E 119 S 399 E 131S 441E 135 S 454 E 447 S 1501E 1733 S 5818 E 1925 S 6463 E 3433 ~1524 E 3689 ~2181E 3848 ~2918 E 0oo 0 o0o 000 :ooo ooo 5000 6000 HORIZONTAL VIEW (TRUE NORTH) SCALE 1000 ft. / DIVISION [ I I I 14247 SURVE~ aR~EF: WELLHEAD ,o ,o ,o ,~a a · 0 1000 2000 3000 4000 VERTICAL SECTION [PLANE: 106.59° 7112196 1000 0 1000 2000 3000 4000 5000 6000 7000'8000 9000100001100012000130001400015000 HALLIBURTON 12000 13000 14000 15000 16000 5000 6000 7000 8000 9000 10000 11000 ~ 69.97' ~ 1451D MD ~ 69.97' ~ 16058 MB T~B PROPOSED BHL TVD 7337.10 MD 16875.29 VS 14246.69 N/S 4067.16 S E/W 13653.81 E CASING PDINT DATA OD MD Inc Azi TVD N/S E/W 9 5/8 in 9517 69,97' 106,59° 4817 2093 S 7028 E 7 in 16875 69.97' 106,59' 7337 4067 S13654 E Tcrget Nome TVD NS EW Grid X Grid Y Tar9et 7057 3848 S 12918 E 582325 6012488 Halliburton Energy Services - Drilling Systems PSL Proposal Report Page I Date: 7/12/96 Time: 10:49 am Wellpath ID: MPE-17 Wp3 Last Revision: 7/11/96 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.27.17 N - Long. 149.26.02 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6016203.86 N 569370.12 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.2 Vertical Section Plane: 106.59 deg. BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPE MPE-17 As-Built Milne Pt E Pad MPE-17 Wp3 Measured Incl Drift Depth Dir. (ft) (deg.) '(deg.) Subsea TVD Course Depth Length (ft) (ft) (ft) TIE IN 0.00 0.00 0.00 -57.10 0.00 0.00, KOP/'START OF BUILD @ 1.50 deg/100 ft 400.00 0.00 0.00 342.90 400.00 400.00 500.00 1.50 106.59 442.89 499.99 100.00 TOTAL Rectangular Offsets (ft) (ft) 0.00N 0.00 E 0.00N 0.00 E 0.37 S 1.25 E GRiD Coordinates Northing Easting (ft) (ft) 6016203.86 569370.12 6016203.86 569370.12 6016203.50 569371.38 Closure Vertical Build Walk DLS Cum. Dist. Dir. Section Rate Rate Dogleg (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) Expected Total Rectangular Coords (ft) (ft) 0.0C@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.0£@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 1.31@106.59 1.31 1.50 0.00 1.50 1.5 0.38 S 1.25E Max Hor Min Hor Dir. Vert Error Error Max Err Error (ft) (ft) (deg.) (ft) 0.00 0.00 0.00 0.00 2.00 2.00 0.00 0.51 2.01 2.00 16.59 0.66 Survey Tool BPHM-PBD BPHM-PBD BPHM-PBD START OF BUILD @ 2.50 deg/100R 600.00 3.00 106.59 542.81 599.91 100.00 700.00 5.50 106.59 642.53 699.63 100.00 800.00 8.00 106.59 741.82 798.92 100.00 1.49 S 5.02 E 3.61 S 12.12E 6.97 S 23.38 E 6016202.41 569375.15 6016200.36 569382.27 6016197.11 569393.56 5.23@ 106.59 5.23 1.50 0.00 1.50 3.0 1.51 S 5.01 E 12.65@106.59 12.65 2.50 0.00 2.50 5.5 3.68 S 12.10E 24.4C@ 106.59 24.40 2.50 0.00 2.50 8.0 7.15 S 23.33 E 2.02 2.01 16.59 0.81 2.10 2.02 16.59 0.96 2.30 2.04 16.59 1.11 BPHM-PBD BPHM-PBD BPHM-PBD 900.00 10.50 106.59 840.52 897.62 100.00 11.56 S 38.79E 1000.00 13.00 106.59 938.41 995.51 I00.00 17.37 S. 58.30E 1100.00 15.50 106.59 1035.33 1092.43 100.00 24.40 S 81.89E 6016192.67 569409.01 6016187.04 569428.58 6016180.23 569452.23 40.47@ 106.59 40.47 2.50 0.00 2.50 10.5 60.83@ 106.59 60.83 2.50 0.00 2.50 13.0 85.45@ 106.59 85.45 2.50 0.00 2.50 15.5 11.92 S 38.68 E 18.02 S 58.11E 25.45 S 81.58 E 2.68 2.08 16.59 1.26 3.29 2.15 16.59 1.41 4.14 2.26 16.59 1.56 BPHM-PBD BPHM-PBD BPHM-PBD 1200.00 18.00 106.59 1131.08 1188.18 I00.00 32.62 S 109.51E 1300.00 20.50 106.59 1225.48 1282.58 100.00 42.04S 141.10E 1400.00 23.00 106.59 1318.35 1375.45 100.00 52.62 S 176.61E 6016172.26 569479.92 6016163.14 569511.59 6016152.90 569547.20 114.2fi@I06.59 114.26 2.50 0.00 2.50 18.0 147.23@106.59 147.23 2.50 0.00 2.50 20.5 184.28@106.59 184.28 2.50 0.00 2.50 23.0 34.21S 109.04E 44.31S 140.42E 55.75 S 175.68 E 5.23 2.42 16.59 1.72 6.54 2.63 16.59 1.89 8.09 2.89 16.59 2.06 BPHM-PBD BPHM-PBD BPHM-PBD 1500.00 25.50 106.59 1409.52 1466.62 100.00 64.34 S 215.97 E 1600.00 28.00 106.59 1498.81 1555.91 100.00 77.19 S 259.10E 1700.00 30.50 106.59 1586.06 1643.16 100.00 91.14 S 305.93 E 6016141.54 569586.66 6016129.09 569629.91 6016115.58 569676.86 225.35@106.59 225.35 2.50 0.00 2.50 25.5 270.3fi@ 106.59 270.36 2.50 0.00 2.50 28.0 319.22@106.59 319.22 2.50 0.00 2.50 30.5 68.51S 214.73 E 82.60 S 257.49 E 98.00S 303.89 E 9.87 3.20 16.59 2.25 11.88 3.55 16.59 2.46 14.14 3.94 16.59 2.70 BPHM-PBD BPHM-PBD BPHM-PBD 1800.00 33.00 106.59 1671.08 END OF BUILD 1880.00 35.00 106.59 1737.40 Base Perma~ost 1956.42 35.00 106.59 1800.00 START OF CURVE @ 2.50 deg/100 1980.00 35.00 106.59 1819.32 2080.00 37.50 106.59 1899.96 1728.18 100.00 1794.50 80.00 1857.10 76.42 1876.42 23.58 1957.06 100.00 106.17 S 356.36 E 118.94 S 399.23 E 131.45 S 441.23 E 135.32 S 454.20 E 152.20 S 510.86 E 6016101.03 569727.42 6016088.66 569770.40 6016076.55 569812.52 6016072.80 569825.52 6016056.46 569882.33 371.83@106.59 371.83 2.50 0.00 2.50 33.0 416.57@106.59 416.57 2.50 0.00 2.50 35.0 460.4C@106.59 460.40 0.00 0.00 0.00 35.0 473.92@106.59 473.92 0.00 0.00 0.00 35.0 533.05@106.59 53~.o5 ? ~ -o oo ? co q? ~ 114.68 S 353.82 E 128.93 S 396.25 E 142.86 S 437.83 E 147.15 S 450.67 E 16.65 4.37 16.59 2.97 18.82 4.73 16.59 3.21 20.90 5.07 16.59 3.44 21.55 5.18 16.59 3.51 BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 7/12/96 Wellpath ID: MPE-17 Wp3 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (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 Error Max Err Error (ft) (deg.) (ft) (dgtl00ft) (dgtl00ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 2180.00 40.00 106.59 1977.94. 2035.04 100.00 170.07 S 570.84E 6016039.15 569942.48 595.64@106.59 595.64 2280.00 42.50 106.59 2053.12 2110.22 100.00 188.89 S 634.03E 6016020.93 570005.83 661.57@106.59 661.57 2380.00 45.00 106.59 2125.35 2182.45 100.00 208.63S 700.30E 6016001.81 570072.27 730.71@106.59 730.71 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 40.0 186.30 S 566.01 E 27.77 6.15 16.59 4.24 BPHM-PBD 2.50 42.5 207.69 S 628.43E 31.27 6.66 16.59 4.67' BPHM-PBD 2.50 45.0 230.23 S 693.86E 35.03 7.17 16.59 5.14 BPHM-PBD 2480.00 47.50 106.59 2194.49 2251.59 100.00 229.25 S 769.52E 6015981.84 570141.68 802.94@106.59 802.94 2580.00 50.00 106.59 2260.42 2317.52 100.00 250.72 S 841.57E 6015961.06 570213.92 878.12@106.59 878.12 2680.00 52.50 106.59 2323.01 2380.11 100.00 272.98 S 916.31E 6015939.50 570288.86 956.1C@106.59 956.10 2.50 -0.00 2.50 ~0.00 2.50 -0.00 2.50 47.5 253.91 S 762.18E 39.05 7.68 16.59 5.66 BPHM-PBD 2.50 50.0 278.66 S 833.24 E 43.33 8.19 16.59 6.23 BPHM-PBD 2.50 52.5 304.46 S 906.93E 47.86 8.69 16.59 6.84 BPHM-PBD 2780.00 55.00 106.59 2382.14 2439.24 100.00 296.00 S 993.59E 6015917.21 570366.35 1036.74@106.59 1036.74 2880.00 57.50 106.59 2437.69 2494.79 100.00 319.74 S 1073.27E 6015894.23 570446.24 1119.88@106.59 1119.88 2980.00 60.00 106.59 2489.56 2546.66 100.00 344.14 S 1155.20E 6015870.61 570528.39 1205.37@106.59 1205.37 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 55.0 331.24 S 983.09E 52.64 9.18 16.59 7.49 BPHM-PBD 2.50 57.5 358.97 S 1061.58E 57.66 9.66 16.59 8.19 BPHM-PBD 2.50 60.0 387.58 S 1142.25E 62.91 10.12 16.59 8.94 BPHM-PBD 3080.00 62.50 106.59 2537.66 2594.76 100.00 369.17 S 1239.21E 6015846.38 570612.63 1293.03@106.59 1293.03 3180.00 65.00 106.59 2581.88 2638.98 100.00 394.77 S 1325.16E 6015821.60 570698.81 1382.71@106.59 1382.71 3280.00 67.50 106.59 2622.15 2679.25 100.00 420.90 S 1412.88E 6015796.30 570786.76 1474.24@106.59 1474.24 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 62.5 417.03 S 1224.96E 68.38 10.56 16.59 9.72 BPHM-PBD 2.50 65.0 447.24 S 1309.53 E 74.06 10.97 16.59 10.54 BPHM-PBD 2.50 67.5 478.15 S 1395.82 E 79.93 11.35 16.59 11.40 BPHM-PBD END OF CURVE 3378.93 69.97 106.59 2658.03 2715.13 98.93 447.22 S 1501.22E 6015770.83 570875.34 1566.42@106.59 1566.42 NA Sands 8173.56 69.97 106.59 4300.00 4357.10 4794.63 1733.22 S 5818.47E 6014527.33 575204.59 6071.13@106.59 6071.13 Base Schrader 8888.97 69.97 106.59 4545.00 4602.10 715.41 1925.10 S 6462.65E 6014342.00 575850.62 6743.25@106.59 6743.29 2.50 -0.00 0.00 0.00 0.00 0.00 2.50 70.0 509.37 S 1482.71 E 85.91 11.70 16.59 12.28 BPHM-PBD 0.00 70.0 2032.84 S 5729.22E 378.61 29.00 16.59 56.32 BPHM-PBD 0.00 70.0 2260.15 S 6362.85E 422.38 31.60 16.59 62.94 BPHM-PBD CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 9516.78 69.97 106.59 4760.00 4817.10 627.81 2093.49 S 7027.95E 6014179.41 576417.55 7333.13@106.59 7333.13 THRZ 14510.06 69.97 106.59 6470.00 6527.10 4993.28 3432.77 S 11524.07E 6012887.78 580927.14 12024.48@106.59 12024.48 TKLB 15240.07 69.97 106.59 6720.00 6777.10 730.01 3628.57S 12181.40E 6012699.17 581586.50 12710.35@106.59 12710.35 0.00 0.00 0.00 0.00 0.00 0.00 0.00 70.0 2093.49 S 7027.95 E 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 70.0 4046.22 S 11341.34E 766.34 52.08 16.59 114.96 BPHM-PBD 0.00 70.0 4278.18 S 11987.89 E 811.01 54.74 16.59 121.71 BPHM-PBD Target/TKUC1 16057.68 69.97 106.59 7000.00 7057.10 817.61 3847.87 S 12917.60E 6012488.00 582325.00 13478.52@106.59 13478.52 CASING POINT OD = 7in, ID = 6.28in, Weight= 26.001b/~. 16875.29 69.97 106.59 7280.00 7337.10 817.61 4067.16 S 13653.81E 6012276.91 583063.53 14246.6~@106.59 14246.69 0.00 70.0 4537.97 S 12712.04E 861.05 57.73 16.59 129.28 BPHM-PBD 0.00 70.0 4797.76 S 13436.18E 911.09 60.71 16.59 136.85 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page I Date: 7/12/96 Time: 10:58 am Wellpath ID: MPE-17 Wp3 Last Revision: 7/12/96 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.27.17 N - Long. 149.26.02 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6016203.86 N 569370.12 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.2 Vertical Section Plane: 106.59 deg. BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPE MPE-17 As-Built Milne Pt E Pad MPE-17 Wp3 Measured Incl Drift Subsea TVD Course Depth Dir. Depth Length (ft) (deg.) (deg.) (ft) (ft) (ft) TIE IN 0.00 0.00 0.00 -57.10 0.00 0.00 KOP / START OF BUILD @ 1.50 deg/100 ft 400.00 0.00 0.00 342.90 400.00 400.00 500.00 1.50 106.59 442.89 499.99 100.00 TOTAL Rectangular Offsets fit) (ft) 0.37S 1.25E GRID Coordinates Northing Easting (ft) (ft) 6016203.86 569370.12 6016203.86 569370.12 6016203.50 569371.38 Closure Vertical Build Walk DLS Cum. Dist. Dir. Section Rate Rate Dogleg (ft) (deg.) (ft) (dgJl00ft) (dgJl00ft) (dg/100ft) (deg) Expected Total Rectangular Coords (ft) (ft) 0.0C@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.0C@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 1.31@ 106.59 1.31 1.50 0.00 1.50 1.5 0.37 S 1.25 E Max Hor Min Hor Dir. Vert Error Error Max Err Error (ft) (ft) (deg.) (ft) 0.00 0.00 0.00 0.00 2.50 2.50 0.00 0.86 2.78 2.78 16.59 1.11 Survey Tool BPHG-PBD BPHG-PBD BPHG-PBD START OF BUILD @ 2.50 deg/100~ 600.00 3.00 106.59 542.81 599.91 100.00 700.00 5.50 106.59 642.53 699.63 100.00 800.00 8.00 106.59 741.82 798.92 100.00 1.49 S 5.02 E 3.61 S 12.12E 6.97 S 23.38 E 6016202.41 569375.15 6016200.36 569382.27 6016197.11 569393.56 5.23@ 106.59 5.23 1.50 0.00 1.50 3.0 1.49 S 5.02 E 12.65@106.59 12.65 2.50 0.00 2.50 5.5 3.61 S 12.12E 24.4C@ 106.59 24.40 2.50 0.00 2.50 8.0 6.97 S 23.38 E 3.10 3.10 16.59 1.36 3.46 3.44 16.59 1.63 3.84 3.78 16.59 1.91 BPHG-PBD BPHG-PBD BPHG-PBD 900.00 10.50 106.59 840.52 897.62 100.00 1000.00 13.00 106.59 938.41 995.51 100.00 1100.00 15.50 106.59 1035.33 1092.43 100.00 11.56 S 38.79 E 17.37 S 58.30 E 24.40 S 81.89 E 6016192.67 569409.01 6016187.04 569428.58 6016180.23 569452.23 40.47@ 106.59 40.47 2.50 0.00 2.50 10.5 60.83@ 106.59 60.83 2.50 0.00 2.50 13.0 85.45@ 106.59 ' 85.45 2.50 0.00 2.50 15.5 11.56 S 38.79 E 17.37 S 58.30 E 24.40 S 81.89 E 4.26 4.14 16.59 2.20 4.71 4.49 16.59 2.52 5.20 4.83 16.59 2.86 BPHG-PBD BPHG-PBD BPHG-PBD 1200.00 18.00 106.59 1131.08 1188.18 100.00 32.62 S 109.51E 1300.00 20.50 106.59 1225.48 1282.58 100.00 42.04S 141.10E 1400.00 23.00 106.59 1318.35 1375.45 100.00 52.62 S 176.61E 6016172.26 569479.92 6016163.14 569511.59 6016152.90 569547.20 114.2fi@ 106.59 114.26 2.50 0.00 2.50 18.0 147.23@106.59 147.23 2.50 0.00 2.50 20.5 184.28@106.59 184.28 2.50 0.00 2.50 23.0 32.62 S 109.51E 42.04S 141.10 E 52.62 S 176.61E 5.74 5.17 16.59 3.22 6.33 5.49 16.59 3.60 6.98 5.80 16.59 4.01 BPHG-PBD BPHG-PBD BPHG-PBD 1500.00 25.50 106.59 1409.52 1466.62 100.00 64.34 S 215.97 E 1600.00 28.00 106.59 1498.81 1555.91 100.00 77.19 S 259.10E 1700.00 30.50 106.59 1586.06 1643.16 100.00 91.14 S 305.93 E 6016141.54 569586.66 6016129.09 569629.91 6016115.58 569676.86 225.35@106.59 225.35 2.50 0.00 2.50 25.5 270.3fi@ 106.59 270.36 2.50 0.00 2.50 28.0 319.22@106.59 319.22 2.50 0.00 2.50 30.5 64.34 S 215.97 E 77.19 S 259.10E 91.14 S 305.93 E 7.69 6.09 16.59 4.44 8.46 6.36 16.59 4.90 9.30 6.60 16.59 5.38 BPHG-PBD BPHG-PBD BPHG-PBD 1800.00 33.00 106.59 1671.08 1728.18 100.00 106.17 S 356.36E END OF BUILD 1880.00 35.00 106.59 1737.40 1794.50 80.00 118.94 S 399.23 E Base Permafrost 1956.42 35.00 106.59 1800.00 1857.10 76.42 131.45 S 441.23 E 6016101.03 569727.42 6016088.66 569770.40 6016076.55 569812.52 371.83@106.59 371.83 2.50 0.00 2.50 33.0 416.57@106.59 416.57 2.50 0.00 2.50 35.0 460.4C@106.59 460.40 0.00 0.00 0.00 35.0 106.17 S 356.36 E 118.94 S 399.23 E 131.45 S 441.23 E 10.22 6.83 16.59 5.88 I1.01 6.99 16.59 6.30 11.78 7.27 16.59 6.55 BPHG-PBD BPHG-PBD BPHG-PBD START OF CURVE @ 2.50 deg/100 fl 1980.00 35.00 106.59 1819.32 1876.42 23.58 2080.00 37.50 106.59 1899.96 1957.06 100.00 135.32 S 454.20 E 152.20 S 510.86 E 6016072.80 569825.52 6016056.46 569882.33 473.92@ 106.59 473.92 0.00 0.00 0.00 35.0 533.05@106.59 533.05 2.50 -0.00 ?co aT q 135.32 S 454.20E 12.02 7.36 16.59 6.63 BPHG-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 7/12/96 Wellpath ID: MPE-17 Wp3 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) ~ (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting fit) (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/lOOft) (dg/lOOft) (dg/lOOft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 2180.00 40.00 106.59 1977.94 2035.04 100.00 170.07S 570.84E 6016039.15 569942.48 595.64@106.59 595.64 2280.00 42.50 106.59 2053.12 2110.22 100.00 188.89 S 634.03 E 6016020.93 570005.83 661.57@106.59 661.57 2380.00 45.00 106.59 2125.35 2182.45 100.00 208.63S 700.30E 6016001.81 570072.27. 730.71@106.59 730.71 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 40.0 170.07 S 570.84E 14.28 7.67 16.59 7.76 BPHG-PBD 2.50 42.5 188.89 S 634.03E 15.56 7.78 16.59 8.35 BPHG-PBD 2.50 45.0 208.63 S 700.30E 16.93 7.87 16.59 8.96 BPHG-PBD 2480.00 47.50 106.59 2194.49 2251.59 100.00 229.25 S 769.52E 6015981.84, 570141.68 802.94@106.59 802.94 2580.00 50.00 106.59 2260.42 2317.52 100.00 250.72 S 841.57E 6015961.06 570213.92 878.12@106.59 878.12 2680.00 52.50 106.59 2323.01 2380.11 I00.00 272.98 S 916.31E 6015939.50 570288.86 956.1¢@106.59 956.10 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 47.5 229.25 S 769.52 E 18.42 7.92 16.59 9.58 BPHG-PBD 2.50 50.0 250.72 S 841.57E 20.04 7.95 16.59 10.21 BPHG-PBD 2.50 52.5 272.98 S 916.31 E 21.78 7.94 16.59 10.85 BPHG-PBD 2780.00 55.00 106.59 2382.14 2439.24 100.00 296.00 S 993.59E 6015917.21 570366.35 1036.74@106.59 1036.74 2880.'00 57.50 106.59 '2437.69 2494.79 100.00 319.74 S 1073.27E 6015894.23 570446.24 1119.88@106.59 1119.88 2980.00 60.00 106.59 2489.56 2546.66 100.00 344.14 S 1155.20E 6015870.61 570528.39 1205.37@106.59 1205.37 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 55.0 296.00 S 993.59E 23.69 7.91 16.59 11.50 BPHG-PBD 2.50 57.5 319.74 S 1073.27E 25.76 7.85 16.59 12.15 BPHG-PBD 2.50 60.0 344.14 S 1155.20E 28.04 7.77 16.59 12.81 BPHG-PBD 3080.00 62.50 .106.59 2537.66 2594.76 100.00 369.17 S 1239.21E 6015846.38 570612.63 1293.03@106.59 1293.03 3180.00 65.00 106.59 2581.88 2638.98 100.00 394.77 S 1325.16E 6015821.60 570698.81 1382.71@106.59 1382.71 3280.00 67.50 106.59 2622.15 2679.25 100.00 420.90 S 1412.88E 6015796.30 570786.76 1474.24@106.59 1474.24 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 62.5 369.17 S 1239.21 E 30.55 7.66 16.59 13.46 BPHG-PBD 2.50 65.0 394.77 S 1325.16E 33.33 7.54 16.59 14.12 BPHG-PBD 2.50 67.5 420.90 S 1412.88E 36.44 7.41 16.59 14.76 BPHG-PBD END OF CURVE 3378.93 69.97 106.59. 2658.03 2715.13 98.93 447.22 S 1501.22E 6015770.83 570875.3/; 1566.42@106.59 1566.42 NA Sands 8173.56 69.97 106.59 4300.00 4357.10 4794.63 1733.22 S 5818.47E 6014527.33 575204.59 6071.13@106.59 6071.13 Base Schrader 8888.97 69.97 106'59 4545.00 4602.10 715.41 1925.10 S 6462.65E 6014342.00 575850.62 6743.29@106.59 6743.29 2.50 -0.00 0.00 0.00 0.00 0.00 2.50 70.0 447.22 S 1501.22E 39.92 7.27 I6.59 15.39 BPHG-PBD 0.00 70.0 1733.22 S 5818.47E 215.54 20.78 16.59 37.63 BPHG-PBD 0.00 70.0 1925.10 S 6462.65E 241.92 22.85 16.59 41.02 BPHG-PBD CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 9516.78 69.97 106.59 4760.00 4817.10 627.81 2093.49 S 7027.95 E 6014179.41 576417.55 7333.13@106.59 7333.13 0.00 70.0 2093.49 S 7027.95 E 0.00 0.00' 0.00 0.00 BPHG-PBD 11016.75 69.97 106.59 5273.68 5330.78 1499.97 2495.81S 8378.58E 6013791.12 577772.14 8742.4¢@106.59 8742.40 GIHR 11017.00 69.97 106.59 5273.77 5330.87 0.25 2495.87 S 8378.80E 6013791.06 577772.37 8742.64@106.59 8742.64 0.00 70.0 2495.81 S 8378.58E 320.41 28.99 16.59 51.11 BPHG-PBD 0.00 70.0 2495.87 S 8378.80 E 320.42 28.99 16.59 51.11 BPHG-PBD THRZ 14510.06 69.97 106.59 6470.00 6527.10 3493.06 3432.77 S 11524.07E 6012887.78 580927.14 12024.48@106.59 12024.48 TKLB 15240.07 69.97 106.59 6720.00 6777.10 730.01 3628.57 S 12181.40E 6012699.17 581586.50 12710.35@106.59 12710.35 GIHR 16000.00 69.97 106.59 6980.25 7037.35 759.93 3832.40 S 12865.66E 6012502.90 582272.90 13424.33@106.59 13424.33 0.00 0.00 0.00 0.00 0.00 0.00 0.00 70.0 3432.77 S 11524.07 E 449.33 39.11 16.59 67.74 BPHG-PBD 0.00 70.0 3628.57 S 12181.40E 476.27 41.23 16.59 71.22 BPHG-PBD 0.00 70.0 3832.40 S 12865.66E 504.32 43.43 16.59 74.84 BPHG-PBD 16001.00 69.97 106.59 6980.59 7037.69 1.00 3832.66 S 12866.56E 6012502.64 582273.80 13425.27@106.59 13425.27 Target / TKUC 1 16057.68 69.97 106.59 7000.00 7057.10 56.68 3847.87 S 12917.60E 6{~.2488.00 582325.00 13478.52@106.59 13478.52 CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/ft. 16875.29 69.97 106.59 7280.00 7337.10 817.61 4067.16 S 13653.81 E 61~:2276~ 583Q~-'~J~3 14246.69@106.59 14246.69 0.00 0.00 0.00 0.00 0.00 0.00 0.00 70.0 3832.66 S 12866.56E 504.33 43.44 16.59 74.85 BPIHRMWD-PBD 0.00 70.0 3847.87 S 12917.60E 504.74 43.59 16.59 75.20 BPIHRMWD-PBD 0.00 70.0 4067.16 S 13653.81 E 511.43 45.79 16.59 80.55 BPIHRMWD-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 1 Date: 7/12/96 Time: 10:56 am Wellpath ID: MPE-17 Wp3 Last Revision: 7/1 2/96 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.27.17 N - Long. 149.26.02 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6016203.86 N 569370.12 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.2 Vertical Section Plane: 106.59 deg. BPX - Shared Services Drilling Alaska State Plane: Zone4 Miln'e Pt: MPE ,MPE-17 As-Built Milne Pt E Pad MPE-17 Wp3 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) TIE IN 0.00 0.00 0.00 -57.10 0.00 0.00 0.00 N KOP / START OF BUILD @ 1.50 deg/100 ft 400.00 0.00 0.00 342.90 400.00 400.00 0.00N 500.00 1.50 106.59 442.89 499.99 100.00 0.37 S 0.00E 6016203.86 569370.12 0.00E 6016203.86 569370.12 1.25E 6016203.50 569371.38 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/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg0 (ft) Survey Tool 0.0~@ 0.00 0.00 0.00 0.00 0.0~@ 0.00 0.00 0.00 0.00 1.31@ 106.59 1.31 1.50 0.00 0.00 0.0 0.00N 0.00 0.0 0.00N 1.50 1.5 0.37 S 0.00 E 0.00 0.00 0.00 0.00 BPHG-PBD 0.00 E 2.50 2.50 0.00 0.86 BPHG-PBD 1.25 E 2.78 2.78 16.59 1.11 BPHG-PBD START OF BUILD @ 2.50 deg/100~ 600.00 3.00 106.59 542.81 599.91 100.00 1.49 S 5.02E 6016202.41 569375.15 5.23@106.59 5.23 700.00 5.50 106.59 642.53 699.63 100.00 3.61S 12.12E 6016200.36 569382.27 12.65@106.59 12.65 800.00 8.00 106.59 741.82 798.92 100.00 6.97 S 23.38E 6016197.11 569393.56 24.4C@106.59 24.40 1.50 0.00 2.50 0.00 2.50 0.00 1.50 3.0 1.49 S 5.02E 3.10 3.10 16.59 1.36 BPHG-PBD 2.50 5.5 3.61 S 12.12E 3.46 3.44 16.59 1.63 BPHG~PBD 2.50 8.0 6.97 S 23.38E 3.84 3.78 16.59 1.91 BPHG-PBD 900.00 10.50 106.59 840.52 897.62 100.00 11.56 S 38.79E 6016192.67 569409.01 40.47@106.59 40.47 1000.00 13.00 106.59 938.41 995.51 100.00 17.37 S 58.30E 6016187.00 569428.58 60.83@106.59 60.83 1100.00 15.50 106.59 1035.33 1092.43 I00.00 24.40 S 81.89E 6016180.23 569452.23 85.45@106.59 85.45 2.50 2.50 2.50 0.00 0.00 0.00 2.50 10.5 11.56 S 38.79E 4.26 4.14 16.59 2.20 BPHG-PBD 2.50 13.0 17.37 S 58.30E 4.71 4.49 16.59 2.52 BPHG-PBD 2.50 15.5 24.40 S 81.89E 5.20 4.83 16.59 2.86 BPHG-PBD 1200.00 18.00 106.59 1131.08 1188.18 100.00 32.62 S 109.51E 6016172.26 569479.92 114.2~@106.59 114.26 1300.00 20.50 106.59 1225.48 1282.58 100.00 42.04S 141.10E 6016163.14 569511.59 147.23@106.59 147.23 1400.00 23.00 106.59 1318.35 1375.45 100.00 52.62 S 176.61E 6016152.90 569547.20 184.28@106.59 184.28 2.50 2.50 2.50 0.00 0.00 0.00 2.50 18.0 32.62 S 109.51E 5.74 5.17 16.59 3.22 BPHG-PBD 2.50 20.5 42.00 S 141.10E 6.33 5.49 16.59 3.60 BPHG-PBD 2.50 23.0 52.62 S 176.61 E 6.98 5.80 16.59 4.01 BPHG-PBD 1500.00 25.50 106.59 1409.52 1466.62 100.00 64.34 S 215.97 E 6016141.54 569586.66 225.35@106.59 225.35 1600.00 28.00 106.59 1498.81 1555.91 100.00 77.19 S 259.10E 6016129.09 569629.91 270.3~@106.59 270.36 1700.00 30.50 106.59 1586.06 1643.16 100.00 91.14 S 305.93E 6016115.58 569676.86 319.22@106.59 319.22 2.50 2.50 2.50 0.00 0.00 0.00 2.50 25.5 64.34 S 215.97 E 7.69 6.09 16.59 4.44 BPHG-PBD 2.50 28.0 77.19 S 259.10 E 8.46 6.36 16.59 4.90 BPHG-PBD 2.50 30.5 91.14 S 305.93 E 9.30 6.60 16.59 5.38 BPHG-PBD 1800.00 33.00 106.59 1671.08 1728.18 100.00 106.17 S 356.36E 6016101.03 569727.42 371.83@106.59 371.83 END OF BUILD 1880.00 35.00 106.59 1737.40 1794.50 80.00 118.94 S 399.23E 6016088.66 569770.40 416.57@106.59 416.57 Base Permaffost 1956.42 35.00 106.59 1800.00 1857.10 76.42 131.45 S 441.23 E 6016076.55 569812.52 460.4C@106.59 460.40 2.50 2.50 0.00 0.00 0.00 0.00 2.50 33.0 106.17 S 356.36E 10.22 6.83 16.59 5.88 BPHG-PBD 2.50 35.0 118.94 S 399.23 E 11.01 6.99 16.59 6.30 BPHG-PBD 0.00 35.0 131.45 S 441.23E 11.78 7.27 16.59 6.55 BPHG-PBD START OF CURVE @ 2.50 de~100 fi 1980.00 35.00 106.59 1819.32 1876.42 23.58 135.32 S 454.20E 6016072.80 569825.52 473.92@106.59 473.92 2080.00 37.50 106.59 IR00 q6 105706 100.00 152.20 R qlo ~ ~ 6~l~nq~ a~ q~o~R9 ~ qqq 05~106.59 533.05 0.00 0.00 2.50 -O ~ 0.00 35.0 135.32 S 454.20 E 12.02 7.36 16.59 6.63 BPHG-PBD ~)~ '1'7 ~: !<o ot~ c' ~lt~ ~t;T:: I~ 11 '7 ~".l 1~ ~:c~ "7 ~o r)r,~r~ r)Dr~ Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 7/12/96 Wellpath ID: MPE-17 Wp3 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (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 Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 2180.00 40.00 106.59 1977.94 2035.04 100.00 170.07 S 570.84E 6016039.15 569942.48 595.64@106.59 595.64 2280.00 42.50 106.59 2053.12 2110.22 100.00 188.89 S 634.03E 6016020.93 570005.83 661.57@106.59 661.57 2380.00 45.00 106.59 2125.35 2182.45 100.00 208.63 S 700.30E 6016001.81 570072.27 730.71@106.59 730.71 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 40.0 170.07 S 570.84E 14.28 7.67 16.59 7.76 BPHG-PBD 2.50 42.5 188.89 S 634.03E 15.56 7.78 16.59 8.35 BPHG-PBD 2.50 45.0 208.63 S 700.30E 16.93 7.87 16.59 8.96 BPHG-PBD 2480.00 47.50 106.59 2194.49 2251.59 100.00 229.25 S 769.52E 6015981.84 570141.68 802.94@106.59 802.94 2580.00 50.00 106.59 2260.42 2317.52 100.00 250.72 S 841.57E 6015961.06 570213.92 878.12@106.59 878.12 2680.00 52.50 106.59 2323.01 2380.11 100.00 272.98 S 916.31E 6015939.50 570288.86 956.1¢@106.59 956.10 2780.00 55.00 106.59 2382.14 2439.24 100.00 296.00 S 993.59E 6015917.21 570366.35 1036.74@106.59 1036.74 2880.00 57.50 106.59 2437.69 2494.79 100.00 319.74 S 1073.27E 6015894.23 570446.24 1119.88@106.59 1119.88 2980.00 60.00 106.59 2489.56 2546.66 100.00 344.14 S 1155.20E 6015870.61 570528.39 1205.37@106.59 1205.37 3080.00 62.50 106.59 2537.66 2594.76 100.00 369.17 S 1239.21E 6015846.38 570612.63 1293.03@106.59 1293.03 3180.00 65.00 106.59 2581.88 2638.98 100.00 394.77 S 1325.16E 6015821.60 570698.81 1382.71@106.59 1382.71 3280.00 67.50 106.59 2622.15 2679.25 I00.00 420.90 S 1412.88E 6015796.30 570786.76 1474.24@106.59 1474.24 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 47.5 229.25 S 769.52E 18.42 7.92 16.59 9.58 BPHG-PBD 2.50 50.0 250.72 S 841.57E 20.04 7.95 16.59 10.21 BPHG-PBD 2.50 52.5 272.98 S 916.31E 21.78 7.94 16.59 10.85 BPHG-PBD 2.50 55.0 296.00 S 993.59E 23.69 7.91 16.59 11.50 BPHG-PBD 2.50 57.5 319.74 S 1073.27E 25.76 7.85 16.59 12.15 BPHG-PBD 2.50 60.0 344.14 S 1155.20E 28.04 7.77 16.59 12.81 BPHG-PBD 2.50 62.5 369.17 S 1239.21E 30.55 7.66 16.59 13.46 BPHG-PBD 2.50 65.0 394.77 S 1325.16E 33.33 7.54 16.59 14.12 BPHG-PBD 2.50 67.5 420.90 S 1412.88E 36.44 7.41 16.59 14.76 BPHG-PBD END OF CURVE 3378.93 69.97 106.59 2658.03 2715.13 98.93 447.22 S 1501.22E 6015770.83 570875.34 1566.42@106.59 1566.42 NA Sands 8173.56 69.97 106.59 4300.00 4357.10 4794.63 1733.22 S 5818.47E 6014527.33 575204.59 6071.13@106.59 6071.13 Base Schrader 8888.97 69.97 106.59 4545.00 4602.10 715.41 1925.10 S 6462.65E 6014342.00 575850.62 6743.2¢@106.59 6743.29 2.50 -0.00 0.00 0.00 0.00 0.00 2.50 70.0 447.22 S 1501.22E 39.92 7.27 16.59 15.39 BPHG-PBD 0.00 70.0 1733.22 S 5818.47E 215.54 20.78 16.59 37.63 BPHG-PBD 0.00 70.0 1925.10 S 6462.65E 241.92 22.85 16.59 41.02 BPHG-PBD CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 9516.78 69.97 106.59 4760.00 4817.10 627.81 2093.49 S 7027.95E 6014179.41 576417.55 7333.13@106.59 7333.13 0.00 0.00 0.00 70.0 2093.49 S 7027.95E 0.00 0.00 0.00 0.00 BPHG-PBD 11016.75 69.97 106.59 5273.68 5330.78 1499.97 2495.81S 8378.58E 6013791.12 577772.14 8742.4¢@106.59 8742.40 GIHR 11017.00 69.97 106.59 5273.77 5330.87 0.25 2495.87 S 8378.80E 6013791.06 577772.37 8742.64@106.59 8742.64 0.00 0.00 0.00 0.00 0.00 70.0 2495.81 S 8378.58E 320.41 28.99 16.59 51.11 BPHG-PBD 0.00 70.0 2495.87 S 8378.80E 320.41 28.99 16.59 51.12 BPIHRMWD-PBD THRZ 14510.06 69.97 106.59 6470.00 6527.10 3493.06 3432.77S 11524.07E 6012887.78 580927.14 12024.48@106.59 12024.48 TKLB 15240.07 69.97 106.59 6720.00 6777.10 730.01 3628.57S 12181.40E 6012699.17 581586.50 12710.35@106.59 12710.35 Target / TKUC 1 16057.68 69.97 106.59 7000.00 7057.10 817.61 3847.87S 12917.60E 6012488.00 582325.00 13478.52@106.59 13478.52 0.00 0.00 0.00 0.00 0.00 0.00 0.00 70.0 3432.77 S 11524.07E 364.09 39.37 16.59 76.67 BPIHRMWD-PBD 0.00 70.0 3628.57 S 12181.40E 377.03 41.73 16.59 82.73 BPIHRMWD-PBD 0.00 70.0 3847.87 S 12917.60E 392.75 44.43 16.59 89.68 BPIHRMWD-PBD CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/ft. ~ 16875.29._~>9-97 106.59 7280.00 7337.10 817.61 4067.16 S 13653.81E 6012276.90 583063.53 C~t246.6~@106.59 14246.69 0.00 0.00 0.00 70.0 4067.16 S 13653.81E 409.64 47.18 16.59 96.76 BPIHRMWD-PBD BPX ~e~vic~ ]]lpiLLin~Q / ;'// f' i ItALLIBURFEJN AL~sk~ PLane: Zoned , , , Mi(n e P~ ' MPE i/ // ~ / MPE-17 As ~uiLt x. ................... / Mi Ln~ P~ E Pad ivipE- ~ 7 Wp3 T~aveLling CyLindep - Norms[ Plane Reference WeLL - ~PE-i7 MD: 0 - i6875 Ft, l ALl Bit ection s usin ~ BP Ne~hod Lines ape %he EXPECTEJ ;~nce CircLes ape ~he B.P, ?112196 10:43 am 3O 6O 9O 120 ~epth(Ct) TooL PE-23 0-13038 20,03 9,99 ~ ~ 0-8555 M~ 4333 0-! 2'0,01 6007-6007 6i00-1293; 20,01 6007-13565 20,05 MPE-!3 ST~2 0-59i0 20,01 5913-12795 20.05 !2845-16267 20,03 16350-16350 lO.O0 MPE-13 ST 0-5910 20,01 59!3-12795 20.05 i2845-13575 20,03 ~PE-l~ GiHR 0-4800 20,01 4895-12750 20,05 !2830-!~830 10,00 NPE-10 0-5520 20,01 5565-14145 20,05 ~4225-~4225 10,00 MPE-OgST 0-4880 20,01 4907-10505 20.05 1060B-~4492 20,03 I4570-i4570 iO.O0 MPE-OgOH 0-4880 20,01 4907-i3808 20,05 13938-~3938 t0.00 MPE-08 0-10382 20,01 MPE-07 0-8650 20,02 MPE-06 0-8347 20,02 MPE-05 0-9432 9.99 MPE-04 0-9900 20.02 MPE-03 0-!15~0 20,08 i1650-i~650 20.03 MPE-O8 0-9635 20.0B MPE-15 0-5285 20,03 5375-5375 lO,O0 10500 BPIPRMWD-PBD BPHG-PBD BPI~MWD-PBD WeL[path BPHG-PBD MPE-23 BPIHRMWD-PBD MPE-20 BPHM-PBD MPE-Oi PROJECTED BPHG-PBD BPIHRMWD-PBD BPHM-PBD BPHG-PBD BPIHRMWD-PBD PROJECTED BPHG-PBD BPIHRMWD-PBD PROJECTED BPHG-PBD BPIHRMWD-PBD BPHM-PBD PROJECTED BPHG-PBD BPIPRMWD-PBD PROJECTED BPHG-PBD BPCG-PBD BPCG-PBD UNKN3WN BPCG-PBD BPCG-PBD BPHM-PBD BPCG-PBD BPHM-PBD PROJECTED MPE-16 W 2 MPE-22 NED MPE-13 ~2 MPE-13 MPE-i3 ST~2 MPE-13 ST MPE-~I OlHR MPE-iO MPE-O9ST MPE-OgE]H MPE-08 MPE-07 ~PE-06 MPE-05 MPE-04 MPE-03 MPE-02 MPE-15 150 180 CLOSEST POINTS SLot MPE-23 MPE-20 As-BuLL MPE-O1 MPE-i6 As-BuiLt MPE-22 As-BuiL~ MPE-13 MPE-13 MPE-13 MPE-13 MPE-i~ MPE-iO MPE-OgOH MPE-OgOH MPE-08 MPE-07 MPE-06 MPE-05 MPE-04 MPE-03 MPE-02 MPE-15i As-BuiLt Distance 88,39 181,48 329,79 119,20 365.55 313.28 313,28 313,28 3~3.28 217.58 420,83 26i,62 26i.68 535.25 149,07 208.48 B52,42 348,71 541,91 448,55 158,43 Direction 321,64 ~61,14 320,9i 321,85 296.07 291.32 291,32 29i,32 291,32 275,19 299,7~ 284,74 B84,72 321,82 321,53 321.46 884,60 320.93 31~.31 321,74 831.88 ReC MD 400,00 250,00 50,00 300.00 50,00 50,00 50.00 50,00 50.00 50,00 50.00 450,00 450.00 0,00 0,00 400.00 2050,00 0.00 400.00 400,00 50,00 ReC TVD 400,00 250,00 50.00 300,00 50,00 50.00 50,00 50,00 50,00 50,00 50.00 450,00 450,00 0,00 0,00 400.00 i933, i4 0,00 400,00 400,00 50,00 Sep,Factor 22,10 55,80 719,50 34,00 336,60 263,40 263,40 263,40 263.40 182,90 350,40 56.20 56,20 535,30 8239,70 40,70 3,60 19272,10 105,70 87.60 20i.20 Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.2 Page 1 Date: 7/12/96 Time: 10:43 am Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPE MPE-17 As-Built Milne Pt E Pad MPE-17 Wp3 N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 16875.29 ff.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Well Safety Min. Clear Spread MD TVD Flowing Shut-in Enter Enter Exit Exit Close Safety Safety Shut-in Danger Danger Shut-in Approach Dist Dist Zone Zone Zone Zone Status MD MD MD MD MPE-23 77.7 83.3 450 450 6.7 1.1 M P E-20 171.6 176.6 400 400 6.0 1.0 MPE-01 318.3 323.9 450 450 6.7 1.1 MPE-16 Wp2 109.6 114.6 400 400 6.0 1.0 MPE-22 MWD 355.8 360.8 400 400 6.0 1.0 MPE-13 #2 307.8 310.9 250 250 3.7 0.6 MPE-13 307.8 310.9 250 250 3.7 0.6 MPE-13 ST# 307.8 310.9 250 250 3.7 0.6 MPE-13 ST 307.8 310.9 250 250 3.7 0.6 MPE-11 GIH 208.3 213.3 400 400 6.0 1.0 MPE-10 295.3 327.8 3000 2557 40.0 7.5 M PE-09ST 86.8 132.4 4750 3185 57.5 11.9 MPE-09OH 87.2 132.9 4750 3185 57.5 11.9 MPE-08 525.8 530.8 400 400 6.0 1.0 MPE-07 137.2 142.8 450 450 6.7 1.1 MPE-06 196.4 202.0 450 450 6.7 1.1 M P E-05 139.5 166.4 2250 2088 32.5 5.6 MPE-04 277.8 304.6 2250 2088 32.5 5.6 MPE-03 529.8 535.5 450 450 6.7 1.1 MPE-02 436.5 442.1 450 450 6.7 1.1 MPE-15 153.7 156.2 200 200 3.0 0.5 OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK OK Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.2 Page 1 Date: 7/12/96 Time: 10:44 am Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPE MPE-17 As-Built Milne Pt E Pad MPE-17 Wp3 N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ff.(MD) From 0.00 To 16875.29 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Closest Points Slot Wellpath Distance Direction MPE-23 MPE-23 88.39 321.64 1726.61 303.13 MPE-20 As-Built MPE-20 181.48 261.14 1098.90 284.56 MPE-01 MPE-01 329.79 320.91 1002.70 298.09 MPE-16 As-Built MPE-16 Wp2 119.20 321.85 704.04 345.88 MPE-22 As-Built MPE-22 MWD 365.55 296.07 3876.16 217.98 MPE-13 MPE-13 #2 313.28 291.32 651.95 290.75 MPE-13 MPE-13 313.28 291.32 651.95 290.75 MPE-13 MPE-13 ST#2 313.28 291.32 651.95 290.75 MPE-13 MPE-13 ST 313.28 291.32 651.95 290.75 MPE-11 MPE-11 GIHR 217.58 275.19 3592.60 226.50 MPE-10 MPE-10 420.83 299.71 2127.64 348.81 MPE-09OH MPE-09ST 261.62 284.74 948.71 245.18 MPE-09OH MPE-09OH 261.68 284.72 1279.34 241.76 MPE-08 MPE-08 535.25 321.82 4728.09 334.59 MPE-07 MPE-07 149.07 321.53 3888.62 266.17 MPE-06 MPE-06 208.48 321.46 695.99 329.92 MPE-05 MPE-05 252.42 284.60 334.98 255.84 MPE-04 MPE-04 348.71 320.93 636.21 342.88 M PE-03 MP E-03 541.91 312.31 9389.85 316.09 MPE-02 MPE-02 448.55 321.74 4703.66 335.37 MPE-15i As-Built MPE-15 158.43 231.82 2363.26 264.40 Ref MD 400.00 12250.00 250.00 2000.00 50.00 2050.00 300.00 1750.00 50.00 13150.00 50.00 1450.00 50.00 1450.00 50,00 1450,00 50.00 1450.00 50.00 10750.00 50,00 12750.00 450.00 10150.00 450.00 13150.00 0.00 8700.00 0.00 6500.00 400.00 2850.00 2050.00 2600.00 0.00 3250.00 400.00 2000.00 400.00 2700.00 50.00 2000.00 RefTVD 400.00 5753.12 250.00 1892.75 50.00 1933.14 300.00 1685.96 50.00 6061.33 50.00 1421.26 50,00 1421.26 50.00 1421.26 50.00 1421.26 50.00 5239.43 50.00 5924.35 450.00 5033.95 450.00 6061.33 0.00 4537.39 0.00 3783.97 400.00 2478.51 1933.14 2330.31 0.00 2667.59 400.00 1892.75 400.00 2392.22 50.00 1892.75 Sep Factor 22.1 1.4 55.8 34.8 719.5 24.4 34.0 19,2 336.6 2.9 263.4 39.5 263.4 39.5 263.4 39.5 263.4 39.5 182.9 4.6 350.4 2.2 56,2 1.3 56.2 1.3 535.3 8.5 8239.7 6.8 40.7 5.4 3.6 2.5 19272.1 3.2 105.7 12.8 87.6 15.3 201.2 24.7 · FIELD & POOL ._-~'" ADMINISTRATION WELL PERMIT CHECKLIST INIT CLASS 7'- d~ ~;q WELL NAME ,,,~/~r"-.// GEOL AREA ENGINEERING 1. Permit fee attached ....................... Y I ,N 2. Lease number appropriate ................... N 3. Unique well name and number ................ N 4. Well located in a defined 1:.3ol ................ N 5. Well located proper distance from drlg unit boundary .... '1 N 6. Well located proper distance from other wells ........ 7. Sufficient acreage available in ddlling unit. ......... 8. If deviated, is wellbore plat included ............. i~.y[ -YIN 9. Operator only affected party ................... Y N 10. Operator has appropriate bond in force ........... N 11. Permit can be issued without conservafion order ..... N 12. Permit can be issued without administrative approval N 13. Can permit be approved before 15-day wait. ....... N PROGRAM: exp [] dev [] reddl [] se~--'~'wellbore seg [] ann. disposal para req ON/OFFSHORE REMARKS / 14. Conductor string provided ................... ~) N 15. Surface casing protects ail known USDWs ......... ~..N 16. CMT vol adequate to circulate on conductor &surf csg ' ' ! ' Y~'~'~~r~'~ 17. CMT vol adequate to tie-in long s~ing to surf csg ..... 18. CMl' will cover ail known productive hodzons ........ 19. Casing designs adequate for C, T, B & permafrost. ..... 20. Adequate tankage or reserve pit. ............... I 21. If a re-drill, has a 10-403 for abndnmnt been approved... 22. Adequate wellbore separation proposed ........... ~ N 23. If diverter required, is it adequate ................ N 24. Ddiling fluid program schematic & equip list adequate .... 25. BOPEs adequate ............. ._,, ......... 26. BOPE press rating adequate; test to ,~~ psig.~ 27. Choke manifold complies w/APl RP-53 (May 84) ....... ~ 28. Work will occur without operation shutdown ......... ~ N 29. Is presence of H2S gas probable .............. '.~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~ 31. Data presented on potential overpressure zones ....... Y 32. Seisroic analysis of shallow gas zones ............. /Y/ N 33. Seabed condition survey (if off-shore) ........... ./Z.Y N 34. Contact name/phone for weekly progress repoT., . . ./'.. Y N lexp[oramry omyj GEOLOGY: ENGINEERING: COMMISSION: BEW~,., -/'/~?60WJ ~ JDH ~ JDN TAB ~ Coroments/Instructions: HOW41~ - A,'~FOR~ist rev 4/96 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. MICROFILMED _ * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAME : MPE- 17 FIELD NAME : MILNE POINT BOROUGH · NORTH SLOPE STATE : ALASKA API NUMBER : 500292268700 REFERENCE NO : 97067 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/02/10 ORIGIN · FLIC REEL NAME : 97067 CONTINUATION # : PREVIOUS REEL : COI~4ENT : B.P. EXPLORATION, MILNE POINT MPE-17, API #50-029-22687-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/02/10 ORIGIN : FLIC TAPE NAME : 97067 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : B.P. EXPLORATION, MILNE POINT MPE-17, API #50-029-22687-00 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUN~ER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MPE-17 500292268700 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES lO-FEB-97 BIT RUN1 BIT RUN2 BIT RUN3 97067 97067 97067 BOSSE BOSSE BOSSE ANGLES ANGLES DIXON SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 25 13N iOE 3664 1775 53.60 53.60 24.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9. 625 9178.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 3RD STRING PRODUCTION STRING REMARKS: Well drilled 05-DEC through 22-DEC~96 with CDR and Al)N. Ail data was collected in three bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE ' 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED ICZERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUP~4ARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (ME~SUREDDEPTH) START DEPTH STOP DEPTH 4890,0 16559.0 BASELINE DEPTH 15653.0 15615.5 15599.0 15538.5 15494.5 15480.0 15471.5 15466.5 15430.5 15424.5 15419.0 15404.0 15358.0 15278.5 15232.5 15205.0 15191.5 15184.0 15161.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... 15647 0 15610 5 15593 0 15533 5 15489 0 15474 0 15465.0 15461.5 15424.5 15420.5 15413.5 15398.0 15352.5 15272.5 15224.0 15198.5 15187.5 15179.5 15155.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15147.0 15140.5 15137.5 15131.5 15099.5 15094.5 15050.5 15044.5 15043.0 15035.5 15025.5 15016.5 15011.5 15004.0 14984.5 14979.0 14947.5 14942.5 14866.0 14859.5 14814.5 14807.5 14754.0 14746.0 14723.5 14716.0 14720.5 14712.5 14718.0 14711.0 14653.5 14646.0 14642.5 14634.5 14633.0 14625.5 14619.5 14613.5 14616.0 14608.5 14572.5 14564.5 14536.5 14529.0 14529.0 14522.0 14508.5 14502.0 14493.0 14485.5 14474.0 14465.0 14469.0 14459.5 14437.0 14429.0 14386.5 14378.0 14364.5 14355.5 14304.0 14295.0 14293.5 14283.5 14290.0 14281.0 14238.0 14230.0 14204.0 14195.5 14193.0 14185.0 14178.0 14167.0 14152.5 14143.0 14139.5 14130.5 14094.5 14084.0 14065.0 14056.5 14052.5 14043.0 14040.5 14027.5 14019.5 14008.0 14015.0 14006.5 13992.0 13982.0 13960.0 13952.5 13955.5 13948.5 13904.5 13896.0 13900.0 13891.0 13889.5 13882.5 13877.5 13870.0 13871.0 13861.0 13863.0 13854.5 13848.0 13839.0 lO-FEB-1997 15:25 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13832 5 13822 5 13803 0 13769 0 13760 0 13750 0 13721 0 13703 5 13676 0 13673.0 13661.5 13622.0 13616.5 13611.5 13603.0 13595.5 13570.5 13567.0 13550.5 13541.5 13531.0 13506.0 13503.0 13484.5 13472.0 13455.0 13443.0 13427.5 13418.0 13386.5 13369.5 13343 0 13282 0 13278 0 13232 5 13222 5 13217 5 13216 0 13212.0 13204.5 13186.0 13174.5 13151.0 13118.5 13088.5 13081.0 13057.0 13044.5 13023.5 13016.5 13000.5 12949.0 12940.5 12934.0 12906.5 13825.0 13814.5 13794.5 13760.5 13752.5 13741.5 13713.0 13695.0 13665.5 13663 5 13652 0 13613 0 13607 5 13601 5 13593 0 13587 0 13559 5 13558.0 13541.5 13534.5 13523.5 13495.5 13493.0 13475.5 13464.5 13447.0 13433.5 13414.5 13406.0 13377.0 13359.0 13332.5 13269.5 13266.0 13222.5 13211.0 13208.0 13206.0 13199.5 13193.5 13175.5 13164.5 13140.5 13109.0 13076.5 13070.5 13047.0 13036.5 13015.5 13009.0 12989.5 12936.0 1293 O. 5 12923.5 12894.5 lO-FEB-1997 15:25 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12892.5 12885.0 12845.0 12833.0 12751.0 12704.0 12661.5 12644.5 12603.5 12590.0 12553.5 12526.0 12515.5 12498.0 12476.0 12474.5 12463.5 12441.5 12412.0 12406.0 12366.5 12339.5 12323.0 12309.5 12269.5 12254.5 12246.0 12228.5 12208.5 12161.0 12139.5 12135.0 12119.5 12094.5 12058.5 12030.5 11958.5 11936.0 11917.5 11890.0 11824.0 11803.0 11756.0 11729 5 11714 5 11702 0 11680 0 11635 5 11619 0 11610 0 11561 0 11474 5 11393 5 11389 0 11364 5 12881.5 12876.5 12833.5 12820.5 12738.5 12692.0 12650.5 12633.0 12591.5 12579.0 12541.0 12515.5 12503.5 12485.0 12464.5 12462.0 12450.5 12431.5 12400.5 12393.0 12354.5 12327.0 12309.5 12296.5 12257.5 12239.5 12234.5 12212.5 12194.0 12149.5 12127.0 12121.5 12107.5 12083.5 12045.0 12019.0 11945.0 11922.0 11904.0 11876.5 11812.0 11791.5 11743.5 11718.0 11702.0 11688.0 11665.5 11620.5 11602.5 11593.0 11545.5 11461.0 11380.5 11375.0 11349.0 lO-FEB-1997 15:25 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11355.0 11338.0 11319 0 11290 0 11280 5 11233 5 11192 0 11157 5 11140 0 11099 5 11094 0 11079 0 11051 0 10994 0 10978 0 10966 0 10952 0 10923 0 10916 5 10907 5 10901 0 10895 5 10890 5 10853 0 10838 5 10832 0 10817 5 10725 0 10707 0 10686 5 10654.5 10622.5 10618.5 10576.5 10558.5 10470.5 10401.5 10366.0 10340.5 10335.5 10296.5 10277.0 10212.0 10191.0 10187.0 10096.5 10083.5 10066.0 10056.5 10048.5 10032.0 9986.5 9952.5 9940.0 9937.0 11339.0 11324.0 11306.0 11276.0 11265.0 11218.5 11174.5 11138.0 11122.0 11084.5 11079.5 11066.5 11041.0 10980.5 10966.5 10955.5 10940.0 10909.5 10903.5 10895.0 10887.5 10882.5 10878.0 10839.0 10826.5 10822.0 10804 0 10712 5 10693 0 10672 0 10642 5 10612 0 10609 0 10566.5 10549 5 10458 5 10387 0 10350 5 10328 0 10322 5 10284 5 10265 5 10198 0 10177 5 10171 5 10081 5 10069 5 10053 5 10046 0 10039 0 10021 0 9976 5 9941 0 9929 5 9927 5 lO-FEB-1997 15:25 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9931.0 983 6.5 9766.5 9748.5 9741.5 9709.0 9672.0 9656.5 9596.0 9508.5 9339.0 9325.0 9303.5 9277.0 9264.5 9259.5 9246.0 9195.5 9177.0 9110.0 9055.5 9024.5 8840.5 8729.0 8634.0 8629.0 8601 0 8583 5 8541 0 8529 0 8498 5 8460 0 8440 0 8332 5 8201 5 8193 0 8126.5 8013 0 7881 5 7877 5 7725 5 7497 5 7446 5 7423 0 7379 5 7276 0 7233 5 7222 0 7211 5 7167 0 7034 0 6985 5 6946 5 6889.5 6785.0 9920.0 9822.0 9760.5 9740.0 9731.0 9692.5 9656.5 9640.5 9579.0 9493.5 9322.0 9308.5 9286.0 9260.0 9248.0 9243.5 9229.5 9178.0 9159.5 9088.0 9033.0 9001.5 8818.5 8707.5 8613.5 8610.0 8578.0 8561.5 8517.0 8505.5 8477.0 8439.0 8418.0 8310 0 8181 5 8172 0 8105 0 7991 0 7862 5 7860 0 7705 5 7476.0 7427 0 7400 0 7358 0 7252 0 7209 5 7197 5 7187 5 7143 5 7010 0 6960 0 6921 5 6865 5 6759 5 lO-FEB-1997 15:25 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 6762.0 6748 5 6721 0 6714 0 6701 5 6624 0 6587 0 6551 0 6498.5 6487.5 6376.0 6363.5 6310.0 6285.0 6233.5 6167.0 6091.0 6048.5 6031.5 6017.5 6008.5 5968.5 5950.0 5928.0 5913.0 5873.5 5806.5 5742.5 5660.0 5629.5 5604.5 5527.5 5502.5 5473.0 5412.5 5381.5 5306.5 5297.0 5277 5 5270 0 5251 0 5238 0 5214 5 5191 0 5152 5 5129 0 5065.5 5036.5 5033.0 4959.5 4946.0 $ MERGED DATA SOURCE LDWG TOOL CODE 6735.0 6722.5 6695.5 6687.5 6675.5 6598.5 6561.0 6526.5 6473.0 6463.0 6351.0 6338.0 6282.0 6258.0 6207.0 6141.5 6065.5 6025.5 6009.5 5994.5 5984.5 5944.0 5926.0 5901.0 5885.0 5846.0 5778.5 5715.0 5632 0 5602 5 5578 5 5501 0 5474 5 5445 5 5385 5 5355 0 5278 5 5271.5 5253.5 5243.5 5225.5 5213.5 5189.5 5165.5 5127.5 5105.0 5042.0 5014.0 5009.5 4932.5 4919.5 BIT RUN NO. MERGE TOP MERGE BASE LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: MWD 1 4890.0 8123.0 MWD 2 8050.0 9160.0 MWD 3 9030.0 16559.0 $ REMARKS: The depth adjustments shown above reflect the MWD GR to the CBT GRCH logged by SWS. All other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03~ RH04 in the LDWG listing. The other outputs (Delta Rho, PEF, Max. Density) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/ PEL/PER, and ROMB/ROMU/ROML/RO~. The LDWG outputs of CALA and CALS are HDIA and VDIA respectively. The RPM output is TRPM. $ LIS FORMAT DATA ** 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 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 10 ** 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 ELEM CODE (HEX) DEPT FT 039090O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 039090 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0P~4~039090 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~i~ 039090 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~i~ 039090 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~ 039090 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 0H~94 039090 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 039090 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 039090 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 039090 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 039090 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 039090 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 039090 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 039090 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 039090 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 039090 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 039090 O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN 039090 O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN 039090 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 039090 O0 000 O0 0 1 1 1 4 68 0000000000 TRPMMWD RPM 039090 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 16559.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD GR.MWD -999.250 RHOB.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD DCAL.MWD -999.250 CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD TRPM. MWD -999.250 DEPT. 4890.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD GR.MWD 84.497 RHOB.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD DCAL.MWD -999.250 CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD TRPM. MWD -999.250 -999.250 159.309 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE . FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE ' 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~BER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 4916.0 8149.5 LOG H~ER 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 CDR RESIST./GR $ 22 -DEC- 96 FAST 4.0 4.0 MEMORY 16565.0 4916.0 16565.0 60 68.5 71.1 TOOL NUMBER CDR8-039 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 12 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 9178.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) '. 10. O0 MUD VISCOSITY (S) : 47.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OB?4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1.710 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 430 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN1 - DRILLED 4992' TO 8150'*** BIT TO GR=75.95', BIT TO RES = 65.37' *** RUN2 ~ DRILLED 8150' TO 9195'*** RES TO BIT: 63.20'; GR TO BIT: 73.78' *** RUN 3 - DRILLED 9195' TO 16565'*** NEU TO BIT: 116.51'; DEN TO BIT: 112.39' TNPH CORRECTED FOR HOLE SIZE, HI, SALINITY, TEMP GR CORRECTED FOR HOLE SIZE, MUD WEIGHT $ LIS FORMAT DATA 68.0 68.0 * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 13 TYPE REPR CODE VALUE 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039090 O0 000 O0 0 2 1 1 ATR LW1 OH~I 039090 O0 000 O0 0 2 1 1 PSR LW1 OHMM 039090 O0 000 O0 0 2 1 1 ATVR LW1 Otfi~ 039090 O0 000 O0 0 2 1 1 PSVR LW1 OH~ff4039090 O0 000 O0 0 2 1 1 DER LW1 Otfi~4039090 O0 000 O0 0 2 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ROPE LW1 F/HR 039090 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 039090 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8149.500 ATR.LW1 -999.250 PSR.LW1 -999.250 ATVR.LW1 PSVR. LW1 -999. 250 DER. LW1 - 999. 250 ROPE. LW1 23 . 842 GR. LW1 DEPT. 4916. 000 ATR. LW1 PSVR . LW1 ~ 999.250 DER. LW1 -999.250 PSR.LW1 -999.250 ATVR.LW1 -999.250 ROPE.LW1 -999.250 GR.LW1 -999.250 -999.250 -999.250 80.404 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION . O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 14 **** FILE H~ER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO I~ST FILE : FILE H~ER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUN3NkRY VENDOR TOOL CODE START DEPTH STOP DEPTH 8076.0 9195.0 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 CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 22-DEC-96 FAST 4.0 4.0 MEMORY 16565.0 4916.0 16565.0 60 68.8 71.2 TOOL NUMBER CDR8 - 039 8.500 9178.0 LSND 10.00 47.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 15 FLUID LOSS (C3): RESISTIVITY (OHT4M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 1. 710 1. 430 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN1 - DRILLED 4992' TO 8150'*** BIT TO GR=75.95', BIT TO RES = 65.37' *** RUN2 - DRILLED 8150' TO 9195'*** RES TO BIT: 63.20'; GR TO BIT: 73.78' *** RUN3 - DRILLED 9195' TO 16565'*** NEU TO BIT: 116.51'; DEN TO BIT: 112.39' TNPH CORRECTED FOR HOLE SIZE, HI, SALINITY, TEMP GR CORRECTED FOR HOLE SIZE, MUD WEIGHT $ LIS FORMAT DATA 68.0 68.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 16 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039090 O0 000 O0 0 3 1 1 4 ATR LW2 OHSff4 039090 O0 000 O0 0 3 1 1 4 PSR LW2 OH~4M039090 O0 000 O0 0 3 1 1 4 ATVR LW2 OHIO4 039090 O0 000 O0 0 3 1 1 4 PSVR LW2 0t~4~ 039090 O0 000 O0 0 3 1 1 4 DER LW2 0H~I~039090 O0 000 O0 0 3 1 1 4 ROPE LW2 F/HR 039090 O0 000 O0 0 3 1 1 4 GR LW2 GAPI 039090 O0 000 O0 0 3 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9195.000 ATR.LW2 -999.250 PSR.LW2 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE.LW2 DEPT. 8076. 000 ATR.LW2 -999.250 PSR.LW2 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE.LW2 -999.250 ATVR.LW2 93.999 GR.LW2 -999. 250 ATVR. LW2 -999. 250 GR. LW2 -999.250 -999.250 -999.250 106.037 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION ' O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 17 BIT RUN NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUNMARY VENDOR TOOL CODE START DEPTH MWD 9055.0 $ 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 .......... 16565.0 22-DEC-96 FAST 4.0 4.0 MEMORY 16565.0 4916.0 16565.0 70 67.9 72.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN DENS./NEUT. $ TOOL NUMBER RGS-022 ADN-044 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 9178.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 47.0 MUD PH: MUD CHLORIDES (PPM) : 1500 FLUID LOSS (C3): RESISTIVITY (OPff~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 710 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 430 MUD CAKE AT (MT): 68.0 68.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 18 REMARKS: *** RUN1 - DRILLED 4992' TO 8150'*** BIT TO GR=75.95', BIT TO RES = 65.37' *** RUN2 - DRILLED 8150' TO 9195'*** RES TO BIT: 63.20'; GR TO BIT: 73.78' *** RUN3 - DRILLED 9195' TO 16565'*** NEU TO BIT: 116.51'; DEN TO BIT: 112.39' TNPH CORRECTED FOR HOLE SIZE, HI, SALINITY, TEMP GR CORRECTED FOR HOLE SIZE, MUD WEIGHT $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 108 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039090 O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 OH~M 039090 O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 Otfi~M039090 O0 000 O0 0 4 1 1 4 68 0000000000 ATVR LW3 OI~4M 039090 O0 000 O0 0 4 1 1 4 68 0000000000 PSVR LW3 Otfl~4039090 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW3 OH~4 039090 O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW3 F/HR 039090 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI 039090 O0 000 O0 0 4 1 1 4 68 0000000000 ROMB LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 19 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) O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 039090 ROBR LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 DRHU LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 DRHL LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 PEU LW3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 PEL LW3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 039090 O0 000 O0 0 4 1 1 4 68 0000000000 CALNLW3 IN 039090 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 PU 039090 O0 000 O0 0 4 1 1 4 68 0000000000 DCALLW3 IN 039090 O0 000 O0 0 4 1 1 4 68 0000000000 HDIA LW3 IN 039090 O0 000 O0 0 4 1 1 4 68 0000000000 VDIA LW3 IN 039090 O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 RPM 039090 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 16565. 000 ATR. LW3 -999. 250 PSR. LW3 -999. 250 ATVR. LW3 PSVR.LW3 -999.250 DER.LW3 -999.250 ROPE.LW3 159.309 GR.LW3 ROMB. LW3 -999. 250 ROBB. LW3 -999. 250 ROBU. LW3 - 999. 250 ROBL. LW3 ROBR. LW3 -999. 250 DRHB. LW3 -999. 250 DRHU. LW3 - 999. 250 DRHL. LW3 DRHR.LW3 -999.250 PEB.LW3 -999.250 PEU. LW3 -999.250 PEL.LW3 PER.LW3 -999.250 CALN. LW3 -999.250 TNPH.LW3 -999.250 DCAL.LW3 HDIA.LW3 -999.250 VDIA.LW3 -999.250 RPM.LW3 -999.250 DEPT. 9055. 000 ATR. LW3 PSVR . LW3 -999. 250 DER. LW3 ROMB. LW3 -999. 250 ROBB. LW3 ROBR. LW3 -999. 250 DRHB. LW3 DRHR. LW3 -999. 250 PEB. LW3 PER. LW3 -999. 250 CALlV. LW3 t{DIA. LW3 -999. 250 VDIA. LW3 -999 250 -999 250 -999 250 -999 250 -999 250 8 500 -999.250 PSR. LW3 - 999. 250 ATVR. LW3 ROPE. LW3 - 999. 250 GR. LW3 ROBU. LW3 - 999. 250 ROBL. LW3 DRHU. LW3 -999. 250 DRHL. LW3 PEU. LW3 - 999. 250 PEL. LW3 TNPH. LW3 -999.250 DCAL.LW3 RPM. LW3 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 97/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-FEB-1997 15:25 PAGE: 2O * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 97/02/10 ORIGIN : FLIC TAPE NAME : 97067 CONTINUATION # : 1 PREVIOUS TAPE : COI4~_d~T : B.P. EXPLORATION, MILNE POINT MPE-17, API #50-029-22687-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 97/02/10 ORIGIN ' FLIC REEL NAME · 97067 CONTINUATION # : PREVIOUS REEL : CO~R4F2TT : B.P. EXPLORATION, MILNE POINT MPE-17, API #50-029-22687-00