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Home My WebLink About185-034Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/2/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240202 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 213-26 50283201920000 223069 11/5/2023 AK E-LINE PERF KU 13-06A 50133207160000 223112 12/28/2023 AK E-LINE CBL MPU B-09 50029212970000 185034 1/26/2024 READ Caliper Survey MPU B-19 50029214510000 185230 1/26/2024 READ Caliper Survey PBU W-08A 50029219060100 202090 12/27/2023 HALLIBURTON WFL-TMD3D SRU 222-33 50133207150000 223100 12/16/2023 AK E-LINE CBL Please include current contact information if different from above. T38477 T38478 T38479 T38480 T38481 T38482 2/2/2024 MPU B-09 50029212970000 185034 1/26/2024 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.02 15:40:47 -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: Prep for CTD Sidetrack 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,750'9,447' (Fill) Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL 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: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Bker 'HB' and N/A 9,326 MD/ 6,831 TVD and N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 103' 13-3/8" 9-5/8" 7" 6,210' 9,726' MD N/A 3,520psi 7,240psi 4,722' 7,127' 6,210' 9,726' Length Size Proposed Pools: 103' 103' 9.3# / L-80 / BTRS TVD Burst 9,377' MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047437 185-034 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-2129700-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2/8/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT B-09 KUPARUK RIVER OIL 7,144' 9,644' 7,066' 2,203 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.01.23 10:49:34 - 09'00' Taylor Wellman (2143) 324-031 By Grace Christianson at 2:09 pm, Jan 23, 2024 MGR01FEB24 2,203 DSR-1/26/24 * BOPE test to 2500 psi. * 24 hour notice to AOGCC for witness of MIT-IA to 2500 psi. , ADL0047438 SFD 10-404 SFD 1/30/2024JLC 2/5/2024 2/5/24Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.02.05 14:39:16 -09'00' RBDMS JSB 020624 Well: MPB-09 CTD Setup PTD: 185-034 API: 50-029-21297-00-00 Well Name:MPU B-09 API Number:50-029-21297-00-00 Current Status:Long-Term SI Producer Rig:ASR #1 Estimated Start Date:February 8, 2024 Estimated Duration:8 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:185-034 First Call Engineer:Scott Pessetto 801-822-2203 Second Call Engineer:Todd Sidoti 907-632-4113 AFE Number: Current Bottom Hole Pressure:1,334 psi @ 6,886’ TVD 3.73 PPGE | SBHP 7/30/2018 Maximum Expected BHP:2,903 psi @ 7,000’ TVD 7.97 PPGE | 68 day SI 5/1/2007 Max. Anticipated Surface Pressure:2,203 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.75” @ 9,364’ MD Camco D Nipple Brief Well Summary MPB-09 was drilled as a Kuparuk B and C-sand producer. MPB-09 was completed in 1985. The well has primarily been produced as a cycle well due to a high gas oil ratio. The well has not consistently produced since 2018. The well was never hydraulically stimulated. It is now proposed the MPB-09 wellbore be used to drill a CTD sidetrack to create an injection lateral to support offset producers. Hilcorp requests a variance to 20 AAC 25.412(b) requirement of placing the packer within 200’ measured depth of the top perforation is requested. After the CTD lateral is drilled and cemented back to the parent well, it will not be possible to have the 4-1/2” x 7” packer within 200’ MD of the perforations. Planned packer set depth is 179’ MD shallower than previous packer depth of 9,326’ RKB and will be 257’ MD above the current top perforation at 9,404’ MD. An Area of Review will be submitted with the CTD sidetrack permit to drill. Estimated 7” casing TOC is 7,399’ MD. The March 19, 1985 cement job noted 82 barrels Class G cement pumped, plug bumped, floats held, full returns throughout cement job. Objective 1.Pull 3-1/2” gas lift completion and packer. 2.Run new 4-1/2” injection string to allow for CTD sidetrack and injection. Notes on Well Condition x Verified FMC tubing bowl can fit a 4-1/2” tubing hanger x Last tag 9,457’ MD on 1/19/2015 (current CTD KOP planned for 9,441’ MD) x Camco TRDP-1A-SSA SCSSV locked out 12/3/1986 at 1,801’ MD. x MPB-15 noted 50K over string weight to pull similar seals out of PBR. Procedure: Slickline (Non-Sundried Work) 1. MIRU slickline. Pressure test PCE to 250 low / 2,500 psi high. 2. Confirm TRSV flapper is locked open. Run flapper checker. 3. Drift and tag as deep as possible to confirm whipstock setting depth is not covered. 4. Run a memory GR/CCL/Caliper from tag depth to surface. 5. RIH to 9,400’ MD / 6,886’ TVD, obtain 30 minute pressure reading. 6. PUH to 7,975’ MD / 5,886’ TVD for 10 minute station stop. 7. PUH to 6,465’ MD / 4,886’ TVD for 10 minute station stop. 8. Set CA2 plug in 2.75” D nipple at 9,364’ MD. 9. RIH pull BK-Orifice from GLM at 9,273’ MD. 10. Perform CMIT-IA to 2,500 psi for 30 minutes, charted. 11. Pull CA2 plug from 2.75” D nipple 9,364’ MD. 12. RDMO slickline. Well: MPB-09 CTD Setup PTD: 185-034 API: 50-029-21297-00-00 Pump and Well Support (Non- Sundried Work) 13. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 14. RD well house and flowlines. 15. MIRU pumpers and PT lines to 250 psi low / 3,500 psi high. 16. Add 1% lubricant to KWF to reduce string weight. 17. Circulate at least one wellbore volume down tubing taking returns up casing to tank. 18. Confirm well is dead and FP if necessary. 19. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 20. NU BOPE house. Spot mud boat. Brief RWO Procedure (Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If required, kill well w/ 8.4 ppg source or produced water with 1% lube prior to setting CTS plug. 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 ram on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure off casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well w/ 8.4 ppg source or produced water as needed. Pull BPV. Ensure fluids balanced TxIA. a. If indications show pressure underneath BPV, lubricate out BPV. 2023 Thunderbird MPB-15 Parameters During Release of Baker “HB Retrievable RH Release Packer” Similar packer depth 8700’ MD, 48° inclination, 3-1/2” tubing with GLMs, and BOT HB Hydraulic Packer - String Weight: Up/Down 68/50K - Unseated hanger (50K over), pulled free from PBR (70K over) - Picked up to 160K (90K over) in 20K intervals after spearing PBR. - Worked down 31 total turns. - Packer started moving at 128K (60K over) 5. MU landing joint or spear and PU on the tubing hanger. a. Pickup and slack off weights were not recorded during the 1985 completion. b. Tubing was not cut pre-rig. c. Expected string weight ~80,000 pounds. d. Do not exceed 80 percent (165 klbs) of 3-1/2’’ tubing e. If hanger will not pull to floor, call out E-Line for a mechanical cut. Cut mid joint in the first full joint above PBR. 6. Confirm hanger free, lay down tubing hanger. 7. POOH and lay down the 3-1/2” tubing. a. Discard all tubing and jewelry. b. Call out spooler for ~1,800’ of TRSV control line. 8.If a tubing cut was required: pickup overshot BHA (with needed jars/intensifiers) to fish 3-1/2” tubing stub looking up. a. Attempt to release packer without pulling the seals out of the PBR. b. Expected fishing string weight is 93K. c. Confirm 1% lubes were added to kill weight fluid to reduce string. Well: MPB-09 CTD Setup PTD: 185-034 API: 50-029-21297-00-00 9. Perform straight pull to set overshot. 10. Right hand rotate to free packer. 11. If rotation fails to free packer, proceed with jarring to pull Seals/PBR/packer. a. If the seals come free without the PBR/packer: i. Lay down seals ii. RIH with spear to catch PBR barrel. iii. Proceed to jar/rotate packer free. b. If increased overpull is needed, contact OE to discuss rigging up casing jacks. i. Verify workstring tension limits prior to attempting an overpull. 12.If tubing was retrieved without a cut: a. RIH with spear to catch PBR barrel. b. Proceed to jar/rotate packer free. 13. If all packer retrieval methods fail a. RIH with overshot and latch on PBR b. Rig up E-Line and cut PBR just above the packer. c. POOH. d. RIH and burn over / mill packer until it releases. e. Fish packer out of hole. 14. Once packer is released, close the annular element and circulate two bottoms up to remove any trapped gas below the packer. a. Circulate at max rate down the work string taking returns up the annulus. b. If unable to maintain returns, keep pumping down workstring keeping the workstring full and wait two hours to allow any gas to migrate to surface. c. Ensure at least 30 minutes have passed to allow for packer elements to relax. 15. POOH with packer and tailpipe. 16. Observe for solids, corrosion, or schmoo on outside of pulled to tubing to dictate whether a 7” scraper run is needed across the packer setting interval in the 7” casing. a. Pending updated SL tag, a clean out run may be required to ensure whipstock setting depth is achievable. 17. Pick up new 4-1/2” injection completion and RIH to ~9300’ MD. Nom. (OD)Length Item Lb/ft Material Notes 4-1/2"41 Mule Shoe Jt 12.6 L-80 Bottom @ ~9,300' 4-1/2"41 4-1/2" jt 12.6 L-80 4-1/2"10 4-1/2" Pup 12.6 L-80 5.03"2 3.813" X Nipple - RHC Installed L-80 ~9,208’ 4-1/2"10 4-1/2" Pup 12.6 L-80 4-1/2"41 4-1/2" jt L-80 4-1/2"10 4-1/2" Pup 12.6 L-80 6"10 7" x 4-1/2" Packer L-80 ~9,147 4-1/2"10 4-1/2" Pup 12.6 L-80 4-1/2"41 4-1/2" jts 12.6 L-80 4-1/2"10 4-1/2" Pup Jt 12.6 L-80 5.6"2 4-1/2" Sliding Sleeve, 3.813" X, open down L-80 4-1/2"10 4-1/2" Pup Jt 12.6 L-80 4-1/2"9000 4-1/2" jts 12.6 L-80 4-1/2"10 Space out pup 12.6 L-80 Well: MPB-09 CTD Setup PTD: 185-034 API: 50-029-21297-00-00 30 4-1/2” Tubing hanger L-80 18. Record slackoff and pickup weights prior to landing hanger. 19. Space out and land hanger. 20. RILDS. Lay down landing joint. 21. Pump 160 barrels of 1% KCL with 1% by volume corrosion inhibitor (CI) down the IA, taking returns up the tubing. a. This is to inhibit the entire inner annulus. 22. Displace CI with 52 barrels of diesel freeze protect down the annulus. 23. Consult OE/WSL on whether to FP tubing prior to RDMO. 24. Drop ball and rod and pump to seat in X-nipple below the packer. Set the packer per vendor setting procedure. 25. Pressure test the tubing to 3,000 psi, charted for 30 minutes. 26. Pressure test the IA to 2,500 psi, charted for 30 minutes. a. Provide 24 hour notice to AOGCC for MIT-IA witness. b. 0.25 psi/ft x 6,936’ TVD = 1,734 psi 27. Set CTS. 28. RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS. 6. RD crane. Move 500 bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to wells group for CTD prep. Slickline 1. Spot Slickline unit and RU. 2. Pressure test PCE to 250 psi low and 2,500 psi high. 3. Pull ball and rod. 4. Pull RHC profile. 5. Run 4.5” x 7” whipstock drift to 9,457’ RKB. E-Line 1. MIRU Electric line 2. Pressure test PCE to 250 psi low, 2,500 psi high 3. RIH with 4.5” x 7” whipstock 4. Set whipstock a. Confirm WS set depth and orientation with OE Scott Pessetto – (801) 822-2203 5. RDMO Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. BOP Drawing DATE REV. BY COMMENTS TREE: 3 1/8" - 5M FMC w/ 3 1/2“ Otis Quick Union WELLHEAD: 11“ 5M FMC w/ 3 1/2” ‘H’ BPV profile. MILNE POINT UNIT WELL B-09 API NO: 50-029-21297 9 5/8", 36#, K-55 BTRC 6210‘ PERFORATION SUMMARY Hilcorp Alaska LLC PBTD (Float Collar) 7" 29 # Shoe MP B-09 9644‘ 9726' Fish: 5“ Van Perforating gun Calculated top is 9547‘ MD Note: The Camco TRDP-1A-SSA was locked out of service 12/3/86. # 1“ x 3 1/2” KBUG w/ BK latch md tvd dg 7 5083 3989 51 6 5841 4480 49 5 6620 4987 49 4 7346 5466 48 3 8071 5951 48 2 8735 6403 45 1 9273 6792 42 8 4106 3382 52 9 3193 2784 47 10 2222 2092 37 Baker ‘HB’ Packer (2.89“ ID)9326‘ WLEG 9377‘ WLEG (ELMD)‘ Camco 2.750 ‘D’ nipple 9364‘ Baker ‘PBR’ Seal Assy (3.00“ ID)9311‘ MK-1 2 5/8 12 9404 - 9426‘ 6889 - 6905‘ MK-2 2 5/8 12 9440 - 9469’ 6915 - 6936‘ Zone Size SPF MD’ TVD’ Fill tagged w/ wireline on 4/3/02 at 9447‘ MD All but 7’ of MK-2 covered 13 3/8“, 48#, K-55 BTRC 103‘ Camco TRDP-1A-SSA SCSSV 1801‘ 4/4/04 Lee Hulme Create Canvas drawing KOP @ 500' MAX Hole Angle: 52 DEG @ 4300‘ DRIFT ID: 2.867" 3 1/2" , 9.3#, BTRS, L-80 TUBING CAPACITY: 0.0087 BBL/FT 7" , 29#, L-80, BTRC Casing DRIFT ID: 6.059" CAPACITY w/ tbg: .0252 bpf Fish: 13‘ of 3/4“ sucker rod SCSSV prong lost 7/8/93 KB Elev. = 59‘ Nabors 27E GL Elev. = 35’ Nabors 27E (DIL Log dated 3/12/85) X XTubing RA Tag 9242‘ Casing RA Tag 9357‘ Fish: 1“ OGLV w/ BK latch lost 8/18/04 _____________________________________________________________________________________ Revised By: TDF 1/9/2024 PROPOSED Milne Point Unit Well: MPU B-09 Last Completed: 3/24/1985 PTD: 185-034 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / BTRC 12.715” Surface 103’ 0.1571 9-5/8" Surface 36 / K-55 / BTRC 8.921” Surface 6,210’ 0.0773 7” Production 26 / L-80 / BTRC 6.276” Surface 9,726’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958” Surface ±9,300’ 0.0152 JEWELRY DETAIL No Depth Item 1 ±9,087’ 3.813” X Sliding Sleeve 2 ±9,147’ 7” x 4-1/2” Packer 3 ±9,208’ 3.813” X-Nipple 4 ±9,290’ WLEG – Btm @ ±9,300’ PERFORATION DETAIL Sand Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size MK-1 9,404’ 9,426’ 6,889’ 6,905’ 26’ 3/20/1985 Open 5” MK-2 9,440’ 9,469’ 6,915’ 6,936’ 29’ 3/20/1985 Open 5” Gun Detail: 5”, 12spf, JSPF Vann Guns WELL INCLINATION DETAIL KOP @ 500’ Max Angle is 52 deg. @ 4,300’ OPEN HOLE / CEMENT DETAIL 17-1/2” 100 ct Perm Cement 15” 806 bbls Arctic Set III, 56 bbls Class G & 15 bbls Arctic Set II 9-1/4” 82 bbls Class G TD = 9,750’(MD) / TD =7,144’(TVD) Initial KB Elev.: 59.0’ / GL Elev.: 35.0’ 7” 3 13-3/8” 1 2 Kuparuk Sands PBTD = 9,644’ (MD) / PBTD =7,066’(TVD) 4 9-5/8” Gas Lift Valve w/o Latch TREE & WELLHEAD Tree 5M FMC 4-1/2” FMC Wellhead 11” 5M FMC w/ 3.5” ‘H’ BPV Profile GENERAL WELL INFO API: 50-029-21297-00-00 Initial Completion by Nabors 27E- 3/24/1985 Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR .&kPu 3-oq Regg James B (CED) ft 18503+0 From: Regq, James B (CED) ZI vl l Sent: Monday, February 8, 2021 11:51 AM,\4-,�� q "I To: David Haakinson Cc: Rixse, Melvin G (CED) Subject: RE: Hilcorp MPU B-09 (PTD#185-034) IA Pressure Exceedance Attachments: C0496 - MPU SCP.pdf Conservation Order 496, Rule 6 requires that pressures be bled before placing online to avoid exceeding the 2000 psi limit: "before a shut-in well is placed in service, any annulus pressure must be relieved to a sufficient degree (a) that the inner annulus pressure at operating temperature will be below 2000 psig and (b) that the outer annulus pressure at operating temperature will be below 1000 psig." A copy of the CO is attached for your reference. Jim Regg Supervisor, Inspections AOGCC 333 W. 7" Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: David Haakinson <dhaakinson@hilcorp.com> Sent: Monday, February 8, 202111:15 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Chad Helgeson <chelgeson@hilcorp.com>; Alaska NS - Milne - Foreman <AlaskaNS-Milne-Foreman@hilcorp.com>; Alaska NS - Milne - Field Operator Leads <AlaskaNS-Milne- Fie ldOperatorLeads@hilcorp.com> Subject: Hilcorp MPU B-09 (PTD#185-034) IA Pressure Exceedance Mel and Jim, Over the weekend, producer MPU B-09 (PTD 185-034) was brought online and sustained an inner annulus pressure of 2,300 psi on 2/6, exceeding our 2,000 psi pressure limit. The IA pressure increased from 1,960 psi before start-up to 2,300 psi. The well is naturally flowing and the pressure exceedance is a result of thermal increase. On 2/8, the IA pressure was bled, and has stabilized with T/I/O = 2413/1590/100. As of now, the IA pressure is decreasing as the well cools. At the time of this email, the T/I/O = 2400/1323/100. Operations will continue to monitor the IA pressure. If any IA pressure increase is seen that is not in line with thermal increase, the well will be shut in and diagnostic TIFL or well -work performed. Thank you, David Haakinson Operations Engineer I Nath Slope Asset Team Hilcorp Alaska, LLC Office: (907) 777-8343 1 Cell: (307) (60-4999 04/25/08 5chlumber~er NO. 4673 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ni..u ht` w Inn rlncrrinfinn Data RI Cnlnr CD 2-52/S-14 11846807 PRODUCTION PROFILE (REDO) 08/18/07 1 1 F-22 12005209 MEM TEMP SURVEY 04/08/08 1 1 MPB-09 11963093 MEM PROD PFOFILE ~ 04/13/08 1 1 MPL-33 11963090 MEM INJECTION PROFILE ~ 04/11/08 1 1 MPF-89 11963092 MEM TEMP SURVEY 04/12/08 1 1 L5-29 11963087 MEM TEMP SURVEY Q 04/04/08 1 1 5-26 12071843 SBHP SURVEY ~ 04/03/08 1 1 06-15 11962594 LDL ~ - (0 04!09!08 1 1 W-30 12034892 PROD PROFILE /'l5~-/~ /(„/•(~ 04/11/08 1 1 L-221 11962592 USIT/CBL ~ ~~ ~tj^~ _ ( /(off 04/07/08 1 1 4-14AlS-37 11970818 CH EDIT PDC GR JEWELRY '~_ / 03/24/08 1 18-326 11978442 MCNL tel. C 02/26/08 1 1 G-24A 11660525 MCNL - 'tk 02/02/07 1 1 F'LtA,t AI:ICNV WLCUGt tl ClalF'1 CT AIUNINU ANU rStl UrS1VtIVU VIVO {..V1'f CHI.I'1 I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center ~R2-1 ~~ejAi~CC9 A hp 900 E. Benson Blvd. O~DBLt 6iid Hf R g 2Q~8 Anchorage, Alaska 99508 Date Delivered: r9,~,,~~ <, ri~~~~ ___ Alaska Data & Consulting Service 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2838 ATTN: Beth `_~-- - Received by: ~~ e Job Lo!! Description Date BL o or D 1-21/K-25 11226008 LDL 10/02/06 1 B-27A 11414394 LDL 09/30/06 1 M-24A 11216213 MEM PROD PROFILE 09/30/06 1 MPB-09 11212889 PROD PROF/GLS 10/06/06 1 X-08A 11414278 USIT 09/26/06 1 C-01A 11414279 USIT 09/27/06 1 K-11 11414765 USIT 10/01/06 1 A-17A 11414283 USIT 10/02/06 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WII ì15~--O:3¿¡ # 10/19/06 NO. 4001 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CI C . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: c Alaska Data & Consulting 2525 Gambell Street, S~t~f:: Anchorage, AK 99503-~(,t_.. ATTN: Beth .. . ~··í )\ s(;A~N.t:;. Received by: ""j}r-~;';ç "; ~lj\;'\,/ \\ ,'.) "\ ~,¡ ¡,\;\i)tril,~~~,":E\~5 ¡'i· r, ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ IO/It(O+- DATE: Wednesday, September 29, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B-09 MILNE PT UNIT KR B-09 tC6G ~Ð3 if' FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Cfß(l. JÙI(~lo+ Comm Well Name: MILNE PT UNIT KR B-09 Insp Num: mitJJ040927115218 Rei InspNum: NON-CONFIDENTIAL API Well Number: 50-029-21297-00-00 Permit Number: 185-034-0 Inspector Name: Jeff Jones Inspection Date: 9/2612004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B-09 Type Inj. N TVD 6831 IA 1400 2520 2470 2460 P.T. 1850340 TypeTest SPT Test psi 2500 OA 80 90 100 100 Interval OTHER PIF P Tubing 0 0 0 0 Notes: A TTP was set below the packer @ 9364' MD to facilitate an MIT performed to verify casing integrity following repair (dummied gas lift mandrel check valves) of a known TxIA leak. and sustained abnormal IA pressure noted while the well was shut in. 1 well house inspected; no exceptions noted. SCANNED NOV 0 S 2004 Wednesday, September 29, 2004 Page 1 of 1 , ") TREE: 3 1/S" - 5M FMC w/3 112" Otis Quick Union WELLHEAD: 11" 5M FMC w/3 1/T 'H' BPV profile. 133/8",48#, K-55 I 103' 1- ~ BTRC 9 5/8", 36#, K-55 BTRC I 6210' I - ~ KOP @ 500' MAX Hole Angle: 52 DEG @ 4300' 3 1/2" . 9.3#, BTRS, L-80 TUBING DRIFT ID: 2.867" CAPACITY: 0.00S7 BBUFT 7" . 29#, L-80, BTRC Casing DRIFT ID: 6.059" CAPACITY wI tbg: .0252 bpf Tubing RA Tag I 9242' 1 Casing RA Tag 1 9357' 1 PERFORATION SUMMARY (DIL Log dated 3/12/85) Zone Size SPF MD' TVD' MK-1 25/8 12 9404 - 9426' 6889 - 6905' MK-2 25/8 12 9440 - 9469' 6915 - 6936' DATE 4/4/04 MP 8-09 - - REV. BY COMMENTS Lee Hulme Create Canvas drawing ) KB Elev. = 59' Nabors 27E GL Elev. = 35' Nabors 27E Cameo TROP-1A-SSA SCSSV I 1801' I ~ Note: The Cameo TROP-1A-SSA was locked out of service 12/3/86. ~ 1" X 3 112" KBUG wI BK latch # md tvd dg 10 2222 2092 37 9 3193 2784 47 8 4106 3382 52 7 5083 3989 51 6 5841 4480 49 5 6620 4987 49 4 7346 5466 48 3 8071 5951 48 2 8735 6403 45 1 9273 6792 42 Baker 'PBR' Seal Assy (3.00" 10) I 9311' I Baker 'HB' Packer (2.89" 10) 1 9326' I Camco 2.750 'D' nipple 19364' I 1 9377' I I ' I WLEG WLEG (ELMD) - - , _Fish: 1" OGLV wI BK latch lost 8/18/04 - Fill tagged wI wireline on 4/3/02 at 9447' MD All but 7' of MK-2 covered Fish: 13' of 3/4" sucker rod SCSSV prong lost 7/8/93 Fish: 5" Van Peñorating gun Calculated top is 9547' MD PBTD (Float Collar) 7" 29 # Shoe 19644' I 19726' I MILNE POINT UNIT WEI.I R-09 API NO: 50-O~9-71 ?97 BP EXPLORATION (AK) . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0,7:) DATE: July 12, 2000 Commissioner' 0 //o/éc~ THRU: Blair Wondzell, ~~ P. I. Supervisor ' êf ~(ÕCJ FROM: ~t!t¡ Jeff Jones ,'---' SUBJECT: Safety Valve Tests Petroleum'l sp c r Milne Point Unit B & C Pads Julv 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. ' SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 JvO... r~-hz-7f- 21 well houses were inspected, no failures. .". Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 HPS N/ A 7/9/00 N t-....) N 11~1~U{r ., .' -",'d. - - ": ";:{:<':':"':""~:i~;' :_~::>"-::.;' :Pii~ti .; '.:I:,.\'~}J;.;,:'~:.:::~;:'. ;~. '::~$ ,V''; < .~SSV.-; . . . . -'.. Well::.Type'.- . Well.D.atå;~;~ ;~:'<.. .. .' . ," . .r. Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE B-02 1811420 B-03 1820560 140 100 115 P P OIL B-04 A 1821000 140 100 95 P P OIL B-06 1850130 140 100 90 P P OIL B-07 1850620 B-09 1850340 140 100 95 P P OIL B-10 1850170 140 100 90 P P OIL B-13 1850930 B-15 1851210 140 100 95 P P OIL B-16 1851490 B-19 1852300 B-20 1860050 140 100 95 P P OIL B-21 1860230 140 100 95 P P OIL B-22 1853020 140 100 100 P 4 OIL B-23 1890160 9 Components: 18 Failures: 1 Failure Rate: 5.50/0 090 Day Wells: Remarks: Three well SV's recorded slow closing times; B-04A(3:20), B-03(3:03),B-06(3:30). Some of the wells on this pad do not have well signs on them. Larry Niles, theBP representative, said he would have these items corrected. R/7/00 Page 1 of 1 Vvo43m1 t.xls BP r EXPLORATION ARCO Alaska, Inc. To: AOGCC From: Zeljko Runje MB 12-1 Prudhoe Bay Drilling Subject: Plug and Abandonment of Well DS 18-3 ( Revision #1 ) December 29, 1994 1. Move in drilling rig. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. . , Pull BPV. Bullhead @ 100 bbls SW down 3.5" tbg. ( Note: Tbg capacity is @ 75 bbls. Be aware of the pressures because there is a PXN plug stuck inside of tubing @ 8259' MD. W/L was able to pump @ 3 BPM at 1800 psi at the start and @ 800 psi at the end of the job.) Install a BPV and test tree plug. ( After ensuring that the well is dead please remove the production tree ) 4. Install BOP's and test to 250/5000 psi. Remove the test plug and BPV. 5. Puli and lay down the 3-1/2" tubing. Records do not indicate that the seal assembly was/was not sheared. PUW was 87,000# SOW was 77,000# ) , P/U bridge plug. RIH and set it ~ 200' ( at 8480' ) below proposed 9-5/8 section. P&A well by using down squeeze method. ( To be witnessed by AOGCC) ao Establish injection rate prior to pumping cement Pump total of 16 bbis of P & A cement Unsting out of bridge plug and POOH. The objective of this P & A is: a. Squeeze away 5 bbls of cement slurry ( 5 bbls ) Cover up peals and up to 120' MD above the perfs ( 7.5 bbls ) Will pupm 30% of excess ( 3.5 bbls ) Total of 16 bbls of slurry RECEIVED RECEIVED ~,,,~,,~ ~ ~ ~¢aS" -~it & Gas Corl:~. C0r, mi$$10~`~ska 0il & Gas C0ns' C0mmissi0" ,., 7'" ~ ' '-" Anchor~,-.~ ' Anchor~ , Prepared bY:urilling Engineerc°'~/perat°rs' Prudhoo Bay Unit BP Exploration (Alaska), Inc. ^RCO Alaska, Inc. Post Office Box 196612 Post Office Box 100360 Anchorage, Alaska 99519-6612 Anchorage, Alaska 99510-0360 Telephone (907) 561-5111 Telephone (907) 276-1215 STATE OF ALASKA --' A~..,KA OILAND GAS CONSERVATION COMMIL aN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon × Suspend · Operation Shutdown__ Re-enter suspended well __ Alter casing Repair well __ Plugging X Time extension __ Stimulate __ Change approved program X Pull tubing __ Vadance __ Perforate __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1184' SNL, 161' WEL, Sec. 24, T11N, R14E At top of productive interval 1314'NSL, 991' WEL, Sec. 24, T11N, R14E At effective depth 1129' NSL, 1072' WEL, Sec. 24, T11N, R14E At total depth 1110' NSL, 1072' WEL, Sec. 24, T11N, R14E Plugback f/RedrllL... REV. #1 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB=46.15 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-3 9. Permit number 85-34 10. APl number 50- 029-20776 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured . true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9685 feet Plugs (measured) 8894 feet 9622 feet Junk (measured) 8835 feet Length Size Cemented 80' 20" 2940 # Poleset 2554' 13-3/8" 2400 sx Fondu & 400 sx PF 'C' 8872' 9-5/8" 500 SX 'G" & 300 sx 1078' 7" 340 SX Class "G" measured 9549'- 9579' (Open) 9520' 9530', 9540'-9549', 9579'-9580' (Squeezed) true vertical 8767'- 8795' (Open) 8740'- 8749', 8758'- 8767', 8795'- 8796' (Squeezed) Tubing (size, grade, and measured depth) 3-1/2" L-80 tubing to 8651' MD DUPLICATE Measured depth True vertical depth 110' 2600' 110' 2600' 8918' 9665' 8178' 8875' RECEIVED JAN 9 1995 Alas~ .0il .& Gas Cons. Commission '. Anchora-' Packers and SSSV (type and measured depth) BOT 3-H packer @ 8536' MD; 3-1/2" Camco TRDP-lA SSSV @2208' MD 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 1/10/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~C)~,U~//"'~ ~'--.- Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ¢ BOP Test Location clearance__ Mechanical Integrity Test__ Subsequent fo,,rm required 10---"'~/'() '"? ,' g nal Signed By W. Johnston Approved by order of the Commission Date //[./~ ,~ I Approva, No. Approved Copy . Returned Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Alaska, Well: 18-03 Spud Date: 7/30/82 Original RKBE: 46' Top of Formation: 9060' Annular Fluid: Diesel/9.6 NaCl Reference Log: BHCS Inc. - Prudhoe Bay API %: 50-029-20776-00 Conlolet ion: 10/27/87 Hanger Type: McEvoy Gan III Max Hole Angle: 33° @ MD: 6400' Date: 8/13/82 Tie In: Type: PRODUCER Status: Workover Hanger: 2 9' Angle @ TS:22° Angle @ TD: 19° Date: 00/00/00 ALL DEPTHS AI%E ~ DRILLIN~ MD TO TOP OF EQUIPMENT EXCEPT WHERE Jewelry Depth 37' 2208' 8516' 8536' 8640' 8650' 8651' 8636' 8259' (~) Description Crossover 5-1/2" x 3-1/2" 3-1/2" Camco TRDP-1A SSSV Nipple ID=2.812" 3-1/2" BOT PBR Assembly 9-5/8" x 3-1/2" B0T 3-H Packer 3-1/2" Otis LNNipple ID--2.75" 3-1/2" BOT Shearout Sub 3-1/2" Tubing Tail ELM Tubing Tail (Logged 05/23/88) FISH: 2.2!1" Otis Grapple & Pxn Plug (Lost 12/16/92) J-9 G-1 I-1 J-3 J-4 ID: 3-1/2" Otis XN Nipple ID=2.75" Casing and Tubing (C) Size Weight Grade Top 1 13-3/8" 72# L-80 0' 2 9-5/8" 47# 3 7" 29% L-80 8587' 5-1/2" 179 L-80 0' 3-1/2" 9.69 L-80 37' NOTED. RECEIVED J-5 J-6,7 C-2 ~as Lift Information (G) MD TVD Stn Mandrel Valve 8289' (7605') 10T-LBX TE Stn 1: Double Check Valve JAN - 9.1995 Oil & Gas Cons. Commission Anchom ~ Bottom Description 2600' Casing 8918' Casing 9665' Liner 37' Tubing-PC 8551' Tubing-PC Port TRO Date 1/2" ORIF 07/20/92 Port P-1 Type Latch 02-20R T-2 Chemical Injection Information (I) MD TVD Stn Mandrel Valve Type 8406' (7710') 2 CA-K~MG-LTS CA BK 8460' (7759') 3 CA-K~MG-LTS CA BK Latch BK-2 BK-2 C-3 Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF Date 1 9520- 9530 lB I0 0 06/16/92 9540- 9549 lB 9 0 06/16/92 9549- 9579 lB 30 6 07/03/92 9579- 9580 lB 1 0 06/16/92 SQZ . Datum 8600' SS= 9422' MD PBTD=- 9622' 8700' SS= 9528' MD TD= 9685' TRO Date 07/22/91 07/22/91 Revision Date: 05/21/93 by PTB Reason: 4D CONVERSION Previous Reason: 03/06/93 Well 18-03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend ~ Operation Shutdown __ Re-enter suspended well __ Alter casing_ Repair well__ Plugging x Time extension __ Stimulate __ Change approved program __ Pull tubing ~ Variance __ Perforate ,,, Other x __ Plugback for redrlll 2. Name of Operator 5. Type of Well: ARCO Alaska, Inc. Development x E xplorato ry __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service __ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1184' SNL, 161' WEL, SEC. 24, T11N, R14E At top of productive interval 1314'NSL, 991' WEL, SEC. 24, T11N, R14E At effective depth 1129' NSL, 1072' WEL, SEC. 24, T11N, R14E At total depth 1110'NSL, 1072' WEL, SEC. 24, T11N, R14E 12. Present well condition summary Total depth: measured true vertical 9685 feet Plugs (measured) 8894 feet 6. Datum elevation (DF or KB) KBE = 46' feet 18-3 9. Permit number 85-34 10. APl number 50- 029-20776 11. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured true vertical 9622 feet Junk (measured) 8835 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 20" 2940 # Poleset 2554' 13-3/8" 2400 sx Fondu & 400 sx PF "C" 8872' 9-5/8" 500 sx "G" & 300 sx "C" 1078' 7" 340 sx Class "G" measured 9549'-9579' (Open) 9520'-9530', 9540'-9549', 9579'-9580' (Squeezed) true vertical 8767'-8795' (Open) 8740'-8749', 8758'-8767', 8795'-8796' (Squeezed) Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 8651'MD Measured depth 110' 2600' 8918' 9665' True vertical depth 110' 26OO' 8178' 8875' RECEIVED AUG -2 1994 Naska 0il & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) BO T 3-H packer @ 8536' MD; 3-1/2" Camco TRDP-1A SSSV @ 2208' MD 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 9/1/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~t,~ ~ ~ Title Drilling Engineer Supervisor _ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance~ Mechanical Integrity Test ~ Subsequent form required 10- ,/-f o 7' Original Signed By Approved by order of the Commission David W. Johnston Date I Approval No. ~,/-//--,,2// Commissioner Date Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE BP EXPLORATION ARCO Alaska, Inc. To: Mike Shoemake/John Smart July 26, 1994 From: Zeljko Runje MB 12-1 Prudhoe Bay Drilling Subject: DS 18-3 Pre-rig Work inc'l P & A Scope Nabors 2ES will be moving on to DS 18-3 after completing DS 7 sidetrack program on December 1st, 1994. Contact the Nabors 2ES supervisor for moving schedule updates. Listed below please find the work scope that must be completed prior to Nabors 2ES MIRU: 1. Lock open the Camco TRDP-1A SSSV. Valve was set at @ 2208' MD. NOTE; Otis grapple and 'PXN' plug are stuck inside of tbg at @ 8259' MD. Both will have to be recovered prior to commencing P & A operations. . Lay a cement plug starting from PBTD to a minimum of 100' above the top of the perforations. Use full bore method it saves @ $ 75,000 (Note: Notify an AOGCC representative prior to commencing plug-back operations) . With an AOGCC representative on location to witness the operation, please tag the top of cement to ensure sufficient cement is in place. Please set the plug in the tbg tail if the top of cement is not within 100' of the tbg tail. . RIH and cut 3-1/2" L-80 tubing with chemical cutter at the middle of the first full joint above the packer. (Packer is set @ 8536' MD) 5. Displace tubing and wellbore to 8.5 ppg seawater. Freeze protect to 2000' w/diesel. 6. Bleed tubing and annuli pressures to zero. Set a Back-pressure valve. 7. Remove the well house and flowlines. If necessary, level the pad and dig out the cellar. Please provide total well preparation cost on the handover form. / Prepared by: f~ E in~eer Drilling Kirk White MB 12-1 T. Jordan MB 12-1 T. Torczon ATO 1555 Approved by: Drilling Engineer _S.uQv,., AUG - 2 1994 0il & Gas Cons. Commission Anchorage Co-Operators, Prudhoe Bay Unit BP Exploration (Alaska), Inc. Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 561-5111 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 March 30, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. B-9, B-10, and C-7. If you require additional information concerning these well histories, please contact Don Girdler at 564-7637. Yours very truly, E. D. W~lson Sr. AdmSn±strat±ve CoordSnator DRG/vv B-9, B-10, C-7 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.9- CONFIDENTIAL (9,532'-Kuparuk River) AFE 10-61-1104 AP1 No. 50-029-21297. Ak. Permit No. 85-34. Elevation: 54' KB. Location: 348' FSL, 819' FWL, Sec. 18, T13N, RilE, Umiat Meridian 03-03-85: Move rig from B-10 to B-9. 03-04: Unthaw fuel lines. Nipple up diverter. Mix spud mud. Strap B.H.A. Pickup, service MWD and orient same. Test diverter. Diverter valve leaking. Repair. Test diverter to 200 psi. Drill and survey 103' to 701'. Rig accepted 1500 hours. 03-05: Drill & survey 701' to 975'. TOOH 975' to surface, change bit. TIH to 608'. Ream from 608' to 975'. Drill & survey, 975' to 1282'. Loss of 400 psi surface pressure. TOOH, 1282' to surface. Found no washout. TIH to 1282'. Drill & survey 1282' to 2270'. Run single shot survey on wireline to verify MWD. 03-06: Drill & survey 2270' to 2749'. Wireline survey w/single shot. TOOH. Change BHA, bit, MWD and service and orient new MWD. TIH, surface to 2749'. Drill & survey 2749' to 4098'. Change out motor on conveyor. Drill & survey 4098' to 4600'. 03-07: Drlg. & survey from 4600' to 6226'. Circ. short trip from 6226' tO 4215'. Circ. & condition mud. POOH, tight spot @ 4220', continue POOH to 2214' (tight to 2400', pull 60-70k over). RIH to 3250' hit bridge, PU Kelly, rotate thru bridge, TIH slow to 6226'. Circ. & condition mud. 03-08: Circ. & condition. Pump pill, POOH, L/D BHA. RU to run 9 5/8" K-55 36#/ft shoe @ 6210'. F.C. @ 6126'. Ran 48 bow type centralizers. 100% returns while TIH. Install cementing head & circ. 720 bbls. of 9.7 ppg mud while reciprocating pipe. Pump 40 bbl 11 ppg Zeogel preflush. Pump 806 bbl 12 ppg Arctic Set III. Pump 56 bbl 15.8 ppg Class G w/l% CaC1. Displace w/463 bbl of 9.7 ppg mud, bump plug w/1500 psi - floats held. Lost returns w/231 bbl of displacement pumped. N/D diverter, run 1/2" pipe into annulus to perform top job. 03-09: Pump 15 bbl Arctic Set II for top job. Install trash barrier & screw on cap, remove valves from unihead & run thru rotary to wellhead, install same. NU valves & bull plugs. Torque speed head to 24,000. NU BOP, flowline & choke line, fill BOP w/water for test. Test annular to 3500 psi, test upper & lower pipe rams, blind rams, HCR valves, choke manifold, TIW valve, inside BOP Kelly & upper Kelly cock to 5000 psi. Function test accumulator test witnessed by Ben LeNorman, AOGCC. PU BHA, TIH to float collar & pressure test csg. to 1500 psi, hold for 30 min. Drill green cement & 20' of new hole to 6246'. Repair stand pipe valves & perform equivalent MW test to 11.9 ppg, hel 10 min., lost 25 psi. Drlg. from 6246' to 6250'. Pump pill. POOH for bit change & MWD and mud motor. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.9- CONFIDENTIAL (9,532'-Kuparuk River) AFE 10-61-1104 API No. 50-029-21297. Ak. Permit No. 85-34. Elevation: 54' KB. Location: 348' FSL, 819' FWL, Sec. 18, T13N, RllE, Umiat Meridian 03-10: PU new BHA & orient MWD. TIH to 6250', break circ. Drlg from 6250' to 8570' & survey. 03-11: Drlg. from 8570' to 8740'. POOH. Change BHA, PU new bit, TIH to 6200'. Slip & cut 108' drill line. TIH to 8740'. Drlg. from 8740' to 9265'. 03-12: Drlg. from 9265' to 9276', survey. Pump pill, POOH for bit trip. RIH, fill pipe. Drlg. from 9376' to 9740'. 03-13: Drlg. from 9740' to 9750'. 38 std. short trip to shoe & return. Circ. & condition mud. POOH, service MWD. RU G.O., run DIL, CNL, GRL, 6210'-9743'. RD G.O. PU bit. TIH to 9750'. 6 std. short trip to 9210'. Circ. & condition mud. POOH. LD drill pipe. 03-14: LD BHA. Change rams to 7". RU csg. crew. Run 7" casg., break circ. @ 6210' & 7970'. Hit tight spot @ 9222'. Work csg. & attempt to circ. - packed off. Attempting to brk. circ., unstick pipe. LD jnts of 7" csg. Circ. while loosing returns, attempt to return to bottom. Hit tight spot @ 9066'. POOH w/7" csg. 03-15: Pull 7" csg., 2 Bow Cents. left in hole. Change top set of rams to 7", set bushing & strap new BHA. TIH, observe gas migration. Chk for flow. TIH while observing gas migration. Shut well in, observe for pressure buildup, none found. TIH, brk circ. @ 4270'. PU D.P. Cut drill line, circ. and increase mud wt. to 10.2 ppg @ 6200'. TIH to 8000', circ. mud wt. up to 10.4 ppg. Wash into hole slow, observe 1000# pressure drop. POOH, looking for washout from 8300'. 03-16: TIH w/bit #9 to 8300'. Wash & ream to clean hole to 8450'. Work stuck pipe. Wash & ream to 8578'. Wash & ream, work stuck pipe, circ. high viscosity pill. Wash & ream, work stuck pipe. Wash & ream, circ. high viscosity pill to 8682'. 03-17: .Wash & ream from 8682' to 9690'. Hard spot observed 9190'. Hole continues to be sticky. Pumping visous sweeps as needed. 03-18: Wash & ream to 9750'. Circ. & condition mud. Pull 5 jnts. - stuck @ 9591', PU Kelly wash free. Short trip to 8000', TIH, pull & run slow. Circ. & condition mud. Pump pill. POOH slow to 6210'. RIH slow. Circ. & condition mud. POOH. LD DP, pull 1st 38 stds slow. Repair rig. POOH. LD DP. Pump lubrication pill 1 std. above shoe. LD DP. Change rams, remove W. bushing, RU csg. Crew PU shoe jnt. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.9- CONFIDENTIAL (9,532'-Kuparuk River) AFE 10-61-1104 API No. 50-029-21297. Ak. Permit No. 85-34. Elevation: 54' KB. Location: 348' FSL, 819' FWL, Sec. 18, T13N, RllE, Umiat Meridian 03-19: Run 246 jnts of 7" 26#/ft L-80 csg. w/ buttress threads. Shoe @ 9726'. Float collar @ 9644'. ECP(s) @ 9604' & 9538'. Full returns while running pipe - 1 min/joint, recip, pipe 15'. RU hanger & pack, ff. Circ. 50 spm & recip, pipe. Pump 60 bbl spacer 3000 w/5% NaC1 @ 12 ppg. Pump 82 bbl Class G w/0.8% D 60 @ 15.8 ppg. Displaced w 370 bbl 9.7 ppg NaC1 brine. Landed csg. Bumped plug w/500 psi over circ. press. Floats held. Full returns for entire job. Tested csg. to 2000 psi. Cement in place @ 11:15 p.m. RD Dowell, blow down lines. LD landing int. Run in lockdown screws for packoff & RD Camco. 03-20: RU to run tubing. Run GeoVann & Brown oil tool equipment. Run 3 1/2" tbg. & gas lift mandrels. Run 295 jnts of 3 1/2" 9.2#/ft L-80 tbg. w/buttress threads. Run 51 feet of loaded 12 JSPF Vann Guns. Perf interval 9404'-9426' & 9440'-9469'. Packer set @ 9325'. D-nipple @ 9364' SSSV @ 1796' GLMs @ 9273' 8735' 8071' 7346' · · , , , , 6620', 5841', 5082', 4105', 3192', 2221'. PU tbg. hanger, RU Camco to run G.R. Wireline w/Camco. Space out tbg. w/10.05' of pups. Wireline w/Camco & RU to displace w/diesel. Displace tbg. w/diesel. Pressure up on tbg. to 2000 psi to close circ. Vent; pressure up to 3000 psi & hold to inflate packer. Pressure to 3800 psi to open production vent. Test packer w/1500 psi top & bottom. Test SSSV w/2500 psi. SSSV req'd. 7000 psi control & 3500 tbg press, to open. 03-21: ND BOP stack. NU tree and test to 5000 psi. RIG RELEASED 1400 hrs. Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Mi!ne Point. ACTIVE: B-3, E-4A, B-6, B-9, B-10,_X-ll, B-13,~ x-!5,_. ~-16,_ C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-!3, C-i4, C-i6 STATIC: B-20, B-21, B-22 C-17, C-i8 All active production wells will be freeze protected by disoiacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. %he annular fluid levels will be monitored zor iea~ing gas ~zt valves. If necessary the~ production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SC$SVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive ~ater injection wells in the Milne Point Unit. ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-l; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. If you have any cues'ions on the shutdown procedure please contact Don Girdler at 564-7637. Yours very truly, ~ ~.~ Painter /~J~/v ~is ion Manager .--'- STATE OF ALASKA -'- ALAS, OIL AND GAS CONSERVATION COMI, .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown Re-enter suspended well [] Alter casing [~] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate E] Other 2. Name of Operator Conoco Inc. 3'AdS~S¢l C Street, Ste. 200, Anchorage, Alaska 99503 4. Location of well at surface 348' FSL, 819' FWL, Sec. 18, T13N, RilE, U.M. At top of productive interval 2746' FNL, 4170' FEL, Sec. 24, .Ti3N, R10E, U.M. At effective depth N/A At t~¢PP~NL, 4395' FEL, Sec. 24, T13N, R10E, U.M. 5. Datum elevation (DF or KB) 54' KB 6. Uni,t ¢r~ Prop,_,erty n. arp, e ,. tvt3_.~ne rob. nc un~_~: 7. Well number B-9 8. Permit number 85-34 9. APl number 50-- 029-21297 10. ?OO~uparuk River feet 11. Present well condition summary Total depth: measured true vertical 9750 feet 7144 feet Plugs (measured) Effective depth: measured N/A true vertical feet feet Junk (measured) Casing Length Structural Conductor 80' S u rface 617 5 ' Intermediate Production 9692' Liner Perforation depth: Size Cemented Measured depth 16" To Surface 115' 9 5/8" 877 bbls 6210' 7" 82 bbls measured 9404'-9426'; 9440'-9469' true vertical 6889'-6905'; 6915'-6936' Tubing (size, grade and measured depth) 3½", L-80, 9377' True Vertical depth Il5' 4721' 9726' 7126' T.R. SCSSV @ 1801'; 'HB' Pkr. @ 9326' Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal ,~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~c~-t~fy that the foregoing is true and correct to the best of my knowledge Commission Use Only Date Conditions of approval Approved by Form 10-403 Rev 12--1:85- .... Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner by order of " the commission Date/.//.~?,:.:,, ,:, c-.. Subrflit in triplicate ., ,--~, STATE OF ALASKA ~ ALASK )IL AND GAS CONSERVATION Co~MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '// ~AI ~ 1. Status of Well Classification of Service Well ,, OIL E~. GAS [] SUSPENDED [] ABANDONED ~ SERVICE [] :2. Name of Operator 7. Permit Number Conoco Inc. 85-34 3. Acjdress 8. APl Number 3201 C Street, ste., 200, Anchorage, Alaska 99503 50-029-21297 4. Location of well at surface 9. Unit or Lease Name 348' FSL, 819' FWL, Sec. 18, T13N, RllE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 2746' FNL, 4170' FEL, Sec. 24, T13N, R10E, U.M. B-9 At Total Depth 11. Field and Pool 2809' FNL, 4395' FEL, Sec. 24, T13N, RIOE, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 59' KB ADL 47438 Kuparuk River 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 3-3-85 3-13-85 3-24-85I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD)i 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9750" (7144') 9644" (7066') YES ~ NO [] 1801 feet MD 1800+ 22. Type Electric or Other Logs Run DILiCDL-CNL-BRL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE iTOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ]~ ~/~ 48¢~ H-4O 0 i03' 17~" 100 cf Perm Cmt q 5/g ~6~ K-55 0 6210' 15" 8.06 bbls Arctic Set III 56 bbls Class G and 15 bbls Arctic Set I1 7" 26¢J L-80 0 9726' 9¼" 82 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3~" 9.2¢~ L-~,0 9377' 9325' _ 9404'-9426' (6889'-6905') MK-1 9440'-9469' (6915'-6936'), MK-2 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 5" Hollow Carrier 22 gram 12 spf 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 11-4-85I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ]--?] -RE 6 TEST PERIOD Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GASiMCF WATER-BBL OIL GRAVITY-APl (corr) 48O 164 24 Press. ]8[} ].CII35 !24-HOUR RATE 28. CORE DATA Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-$0 CONTINUED ON REVERSE SIDE Submit in duplicate~ 29. KA MA NA~ OA: OB NAME M. Kuparuk L. 'Kuparuk 31. LIST OF ATTACHMENTS 32. GEOLOGIC MARKERS MEAS. DEPTH 4920 5301 5619 5779 5863 9404 9698 TRUE VERT. DEPTH 3887 4147 4335 4440 4494 6889 7106 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~J~ ~---f/~ Title ~,~X~,~ 'l 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 cement- ing and the location of the cementing tool. : II~em 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10i407 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Conoco ]:nc. 85-34 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 4. Location of Well 348' FSL, 819' FWL, Sec 18,. T13N, RllE, U.M. 99503 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 6. Leas~rS~ation and Serial No. 8. APl Number 5o- 029-21297 9. Unit or Lease Name Milne Point Unit 10. Well Number B-9 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 11-2-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my know:ledge. S,gned ....... :~¢-~- ~ .~-~ ~'- ~,-~;¢~'~-- ~~--~'¢'~''''"' Title ~,~ace b~w for Commission use Conditio~of APproval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, Alaska 4. Location of Well 99503 7. Permit No. 85-34 8. APl Number 50- 029-21297 9. Unit or Lease Name OTHER [] 348' FSL, 819' FWL, Sec'. 18, T13N, R11E, U.M. 5. El~v~l~iork'~ feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 47438 Milne Point Unit 10. Well Number B-9. 11. Field and Pool Kuparuk River Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate E~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject well is proposed for an acid simulation treatment to improve the productivity from the Middle Kuparuk formation. The acid treatment has been successful on the Middle Kuparuk formation in offset wells. The proposed date of commencement is January~ 27; '1986. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' Title The space below fo~'Commission use Date Conditions of Approval, if any: Approved by BY LOill iF. A Al)proved Copy , Returned - By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 October 11, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3OO1 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No.~CFP-1, CFP-2, B-5A, B-6, B-7, B-8, B-9, B-10, B-11, B-12, B-13, B-14, B-15, and B-16. If you require additional information concerning these completion forms, please contact Jim Hand at 564-7640. Very truly yours, hn R Kemp laska Operations lb RECEIVED OC"rA 1985 Alaska Oil & Gas Cons. Commission Anchorage ' " ?< STATE OF ALASKA ALASKA, ,L AND GAS CONSERVATION C.~,VlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED E~: ABANDONED [] SERVICE [] 2. Nar, m of Operator 7. Permit Number CONOCO, INC. 85-34 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21297 4. Location of well at surface 348' FSL, 819' FWL, Section 18, T13N, RllE, U.M. At Top Producing Interval 2746' FNL, 4170' FEL, SectiOn 24, T13N, R10E, U.M. At Total Depth 2809' FNL, 4395' FEL, Section 24, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 59' KB I ADL 47438 12. Date Spudded 13. Date T.D. Reached 3/3/85 3/13/85 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-I-VD)I I 9750' (7144') 9644' (7066') 22. Type Electric or Other Logs Run DIL-CDL-CNL-BRL 9. Unit or Lease Name Milne Point Unit 10. Well Number B No. 9 11. Field and Pool Kuparuk River Field Kuparuk River 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 3/24/85 N/A feet MSLI 1 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES ~ NO [] 1801 feet MD I 1800 ' TVD 23. CASING SIZE 13-3/8" 9-5/8" CASING, LINER AND CEMENTING RECORD WT. PER FT. 48# GRADE H-40 TOP 7" 26# L-80 24. Perforation interval, size and number) 9404-9426' (6889-6905') MK1 9440-9469' (6915-6936') MK2 SETTING DEPTH MD BOTTOM i 103' HOLE SIZE 17-1/2" CEMENTING RECORD 100 cZ Perm Cmt AMOUNT PULLED 36# K-55 0 6210' 15" 806 bbls Arctic Set III 56 bbls Class G and 15 bbls Arctic Set II 0 9726' 9-1/4" 82 bbls Class G open to Production (MD+TVD of Top and Bottom and 5" Hollow Carrier 22 gram 12 spf 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.2~ L-80 9377' 9325' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Flow Tubing Press. Hours Tested Casing Pressure PRODUCTION FORtOIL-BBL TEST PERIOD I~ IOI L-BBL CALCULATED 24-HOUR RATE GAS-MCF GAS-MCF WATER-BBL WATER-BBL CHOKE SIZE IGAS-OILRATIO OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. FECEiVE Alaska 0il & A~chora? Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 29. 3O. NA OA OB NAME M. Kup aruk L. Kuparuk GEOLOGIC MARKERS MEAS. DEPTH 4920 5301 5619 5779 5863 TRUE VERT. DEPTH 3887 4147 4335 4440 4494 6889 9404 9698 7106 FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ ~ f~ Title Engineer Date 10--22-85 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 A PETROLANE COMPANY SUB-SURFACE DIREC TIONA L SURVEY CONOCO, INC. COMPANY WELL NAME Milne Point' North Slope, Alaska LOCATION JOB NUMBER A0385G0195 SURVEY BY B JAHN TYPE OF SURVEY Gyro Multi-Shot .... DATE " Alaska Oii& (;as Corm. Oommissior~ Anchot'age OFFICE Anchorage, Alaska · PPORM ~""]e~' ~ Eastrn. an 5ate; April 23, 1985 Conoco, Inc. 3201 C. Street ..... Suite-200 Anchorage, Ai~-~:kr~ ...... 9-9503 (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 Well Number: Pad B, Well No: 9 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 13-MAR-85 Method of Computation: Radius of Curvature Surveyor: B JAHN Job Number: A0385G0195 Atten: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the original and one copy of the Gyro Multi- Shot survey run on the above mentioned well. To date~ the following distribution has been accomplished: A. 1 copy delivered to drilling for in-house distribution. B~ 9 copies noted for oil company representatives. C. 3 copies for E/W permanent well files. ~..~ wish to tak~ ...... t~is ?pp~tunity. to thank you fo~ using Eastman Whipstock and look forward to being of service in the future. TOM J.~E~ ' Dis tr i~r~ Coord inator Technical cc/file cc: L.A. Dinges - Offshore Exploration Conoco O.G. Kiel- P.E.S. Reservoir Section Conoco H.E. Gilliland - P.R.D. Reservoir Section Conoco William Van Alert - Alaska Oil and Gas Conservation Co~ission J.L. Weaver - Chevron U.S.A. , Inc. Dave Engstrom - Chevron U.S.A., Inc. Concord Office Dale Bossert - Champl~n ?etroleum Co. C.E. Seery, Jr. -Reading and Bates Petroleum Co. Neil Buttram - Cities Service Oil a~d Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide CONOCO, INC:. PAD B, WELL NO: 9 GMS dOB NO: AO3:=:5GO195 MILNE PT., NORTH SLOPE, ALASKA GM'.--;., 0-?.)644 MD, SURVEYOR: B JAHN, DATE RUN: 13-MAR-85 CAMERA NO: 07'.:.), GYRO NO: 2'~1, 'PO BEG A/U NO: 1566 VERTIE:AL SECTION C:ALC:I_ILATE1] IN PLANE OF FR_iF J.:,AL l'lI RE..] ION S 60 BEG. 0 MIN· W REC:ORr~ OF SURVEY RAi]II_IS OF CLIRVATLIRE METHOD ,Eastman I]:ClNI''11'':1]1~ INC. ' '" .. 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(2)8 1 o 78 2,50C). 42 45 S 43 0 W 2/.:, (:)0. 4,_,L('). :~:; 4-50 W 27 C)('). 4/.:,15 :--; 4/.:,0 1,4 '2:?,00. 4.7 14 :--; 47 :?,0 ~J 2'.-i'~(')C). 45 4.5 :--; 4'.-T~ ¢) W 501.56 S 562.64 W 753·74 S 46:17 W 551.86 S '611.21 W 823.49 S 47 55 W 602.3:9 '.2; 662.63 W :=:'F~ 5.51 '._:; -% 7 4. 4 W 6.L:~ .-' '-"-' . - · · .:,:. 8 715 67 W 9/:.'.=:. :2:::3 :'=; 47 :'::'~> W 700.58:2; 76'?. 78 W 1040.8 !l; '.:J; 4- 7 42 W 2.69 :::. :','1. 0.7/.:, 1.47 1. :2:.]. _ Eastman Whipstock A P~"TRC~ANE COMPANY CONOCO, INF:. 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PAD B-, WELL NO: '.:'.,' GMS; MILNE F'T·, NOR]'H SLOF'E, ALASKA JOB NO: AO385G017'5 TRUE SUBSEA MEA'._:;URED VERT I CAL VERT I CAL DEP'¥H DEF'TH DEPTH FEET FEET FEET :_::2'F~3.3'.-} 61 O0. O0 6041.00 :"-': 44-1..3 :E.: /_-, 200.00 6141.00 ' 85:::7.96 6300. O0 6241. O0 F:: 7 ::: 0. :--..: 7 640 (]. 00 6 :':: 4-1.00 :3:370.92 6500.00 6441.00 'F/O 10.42 /_-,600.00 6541.00 9147.97 6700.00 6641.00 '.:'.~2:--::::. 58 /:,800.00 6741.00 'F-'41 ':.'-~. 43 6'F.'00.00, 6841.00 :. ..... , ._,. 17 7 ,[')(")',F~. 00 /-, ':.':' 4.1 · ("~ 0 ':.-.' 6'~) 0.27 7100.00 7 (:) 41.00 R E E: T A N G I.I L A R C 0 0 R D I N A T E._,'::"- F:'EE'F 2723.44 S 4304.02 W 2777.94 S 43'.--.*:--:. 43 W 283:3.4'.:.:' S 447)0.15 W 28r::7.52 S 457A.77 W 2':.::.':3'.-.-'~. 29 S 4660.03 W 2'F..'88.50 S 4743.f:,'0 W 30:31. ~:'~.. i-,_ ._,':' 4. :::.~ 27 . '..,-,~. :'::_ W '- ( ...... :'"'] '.'-.~ 1 · :: .)6 / ...... S 4- 1. '77 N :307.~7.10 S 49'?'.~. 10 W :'::121.93:3 5087.45 W :314. 6.0 R_ S.., ~' 17.5. o=' '-' W r.: L El._,c' LI R E D I .:, T A N _. [: D I R I.','.' C T I I"l N FEEl' D M 50'.-.-'3. 30 S 57 41 W · =;'..:'(')2 '-"-' ':::' 57 4 :':: W - ,. .,, ..' ..:,._, · 5:'::c)'i;".44 S 5"7 /-l. 5 W .... '"i - 5 5411 '=;'.:' :_:: ._74. W · 550'F.'.~:'17S 5'7 46 W 5606.76 S 57 47 W 57()().81 S .5'7 52 W 57'F.~1.30 S 58 I W -'="-"-":' 7:3 ':' ':~'::' 1 :':: W ._,,-.,,:.:, .). ._, ._ ,_, 59/-,:::. 'F~'7':'":i':,:' '-"::' 6 (.).:, :,, .Z'.=* ._, 5 8 4 2 W _ ,Eastman - -,.., :.. . FINAL' $ ON,!'~ DEPTH 9"50 liD.: ?i44:'22' SO. AI'~o 3J Ss. 81 I~EST .' 52 CLOSUREI6094.94 S 58 48 21 , ~ , : , ~.:.$.i~-~L ~ ~. 5236 ~~ ~N~ - : - ~ , . ~ · . , , - ~. ~ . · = .. ~ ~ , ] ~ ~ ~ '~ · ~ ' ' , : .... ~ · ~ ' ~ ~' ~ . , ., . ~ .. iSC^L~ .DEPTH -I~g:tQ. EEEI'I: N CATORt Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAblE AND NUMBER Reports and Materials to be received by: ~-~..~-'~.~'-- Date Required Date Received Remarks Completion Report ~e S a mpI~ s : Mud Log - ..... Core Chips Core Description Registered Survey Plat . , Drill Stem TeSt Reports Production Test Reports ~r~.&~- Log Run ,, Ve..,..~ ¢-:;- ::", JK . ::5 i AI 1- (DP ALASKA i~.~ ALASKA O~J,I L AND GAS CONSERVATION COJ~IMISSION ~.~. MONTHLY REPORT F DRILLING AND WOFt,..OVER OPI;;RATIONS. 1. Drilling well J~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 85-34 3. Address 3201 C Street, Suite 200, Anchorage, Ag: 99503 4. Location of Well at surface 348'FSL, 819'FWL, Section 18, T13N, RllE, U.M. 5. Elevation in fe~ (indh~3te KB, DF, etc.) 59' KB 6. Lease Designation and Serial No. ADL 47438 .7 8. APl Number 50-029-21297 9. Unit or Lease Name Milne Point Unit 10. Well No. B No. 9 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. May .19 85 12. Decth at ~ o! month, footage dritle~i, fishing jobs, directional drilling problems, spud date, remarks None. 13. Cas~,<] or ~ine~ run ar~ quantities oB cement, results of pressure tests None. 14. Cori~j resume aha O~ief desc~ii3tion None. 15. Lc<~ run and cleoCtt w~ere run None. 16. DST data. pe~forat;ng data, shows of H2S. m~sceilaneous data None. Well suspended. Completion report to follow. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE -Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev. 7-1-80 · ~.. STATE OF ALASKA ~. ~(~ ~ ALASKA AND GAS CONSERVATION C( MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~( Workover operation [] 2. Name of operator Conoco Inc 7. Permit No. 85-34 4. Location of Well ~rf'ac~sL, 819' FWL, Section 18, T13N, RllE, U.M. 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50_029-21297 9. Unit or Lease Name Milne Point Unit 10. Well No. BNo. 9 5. Elevation in feet59.(indicateKB KB, DF, etc.) 16. Lease Design~t~)~.n and_ 47438Serial No. 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. March ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud 3/3/85 9750' TD 13. Casing or liner run and quantities of cement, results of pressura tests Si ze Wt . Grade From To 9 5/8" 36 # K-55 0' 6210' 7" 26 # L-80 O' 9726' Cement 806 bbls, 12ppg, Arctic Set III, 56bbls, 15.8 ppg, Class G cmt, Top job 15 bbls, Arctic Set III 82 bbls, Class G cmt 14. Coring resume and brief description NONE 15. Logs run and depth where run Dual Induction - Laterolog - GR Compensated Density/ Neutron Gr- Neutron (in casing) 6208' - 9743' 8700' - 9724' 4700' - 6200' DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED. /~' /'/~ .~m-.~'~,, TITLE ,.,¢~.,~,,....~$,~ //~ J, ,~',%~,.. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I TY L(S' DESCRIPTION RECEIVED: DATED: Copy sent to sender YES ~ NO _ THRU: FROM' M EMORAN L)UM State of Alaska ALASKA OIL A/qD GAS CONSERVATION COMMISSION DATE: TO: C. erton : , March 18, 1985 Cha :~rl~gn'-~' / i --" FILE NO: Lonnie C. Smith /?~:- ~> D.BHL.18 Commissioner .~~HONE NO: Ben LeNorman SUBJECT: Petrolemn Inspector Witness BOPE Tests on Conoco's Milne Pt. B-9 Sec. 18, T13N,RllE,UM, Milne Point Unit. Thursda__~arch 7, 198.5_: I departed my home at 6:00 am for a 6:30 am Sh~p ~-d 7.--30-'~ ~eparture via Alaska Airlines, Flt. #55 for Deadhorse arriving at 9:10 am. Weather: -Ii°F, light wind, light SI1OW. Proving of meters and oil quality tests at ARCO's CPF-2 were completed, the subject of a separate report. Frida~ l~rch 8, 1985: BOPE tests on Conoco's Milne Pt. B-9 began ~E ~ ~-m and ~re~"~ompleted at 7:40 pm. BOPE inspection report is attached. Saturda_gy_z March 9, 1.985: Plugging for abandonment of Chevron's Ka9&~a-~P0in~- #32"25~egan at 4: 00 pm . . . ~March 12, 1985: . . . and was completed at 12:00 noon, the ~f a '~'~p~rA~"~eport' I departed Deadhorse via Alaska Airlines, Flt. #56 at 5:40 pm arriving in Anchorage at 7:20 pm and at my home at 7:50 pm. In s,mmmary, i witnessed successful BOPE tests on Conoco's Milne Pt. B-9. Attachment 02-00IA(Rev. 10179) . "O&G #4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Operator ~ ~ 0~(:~ Representative Location: Sec /~ T/~R//~ M ~J~ M~'~asing Set Drilling Contractor ~~~,~- Rig #~-~- Representative Location, General ~'~ Well Sign ~' General Housekeeping ~"~ Rig ,-~ Reserve Pit ~,' Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: psig psig. ~ f~'o o rain /~sec. / min/~sec. Controls: Master Remote Kelly and Floor Safety Valves Upper Kell~ Test Pressure Lower KellM Ball Type Inside BOP Choke Manifold No. Valves Test Pressure Test Pressure Test Pressure Test Pressure No. flanges Adjustable Chokes ~ Hydrauically operated choke Test Time -~ ~ hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor March I, 1985 James B. Fox Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Milne Point Unit, .B-9 Conoco Inc. Permit No. 85-34 Sur. Loc. 348' FSL, 819' FWL, Sec. 18, T13N, RllE, UM. Btmhole Loc. 3202' FNL, 4670' FEL, Sec. 24, T13N, R10E, UM. Dear Mr. Fox: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size.chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per. 20 A_AC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys o Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of'Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to co~encing installation of the blowout prevention Mr. J~mes B. ~x Htlne PoEt Unit -2- March 1, 1985 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~aere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, . ~" ., /.~.~-~ .~ 7~ C. V. C~'~tterton Chairman of Alaska Oil and Gas Conservation Co~i~sion BY ORDER OF THE COFR~IISSION lc Enclosure CC: Department of Fish & Ga~ne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery .Oco) John FI. Kemp Manager of Alaskan Operations Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 February 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill applica- tion for Milne Point B-9. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Jim Fox at ~-~t-}. Very truly yours, John R. Kemp Manager of Alaskan Operations JBF/kr cc: MP B-9 Correspondence File RECEIVED Alaska Oil & Gas Cons, CommjssJorl Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C _.,MMISSION I £RMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, AK~ 99503 4. Location of well at surface : 9. Unit or lease name 348' FSL, 819' FWL, Sec 18, T13N, RILE, U.M. , '~' i,.'"f:i~ ,f'] Milne Point Unit At top of proposed producing interval .:P~i?.i!/~' 2900' FNL, /,200' FEL, Sec 2/+, T13N,R10E, U.MJdi~6.kO At total depth ~. I 3202' FNL, ~670' FEL, Sec 2~, T13N, R10E, U.M. ~;?~f. ' I 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and semal R[~ 59' Pad 2/+' /+7/+37 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-5/+ 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi NW of Deadhorse miles 2,380' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10,O~O~ MD 7322'TVD feet 2,560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 650 feet. MAXIMUM HOLE ANGLE /+8 Ol(see20AAC25.035 (c) (2) 10. Well number BNo. 9 11. Field and pool Kuparuk River Amount $200,000.00 15. Distance to nearest drilling or completed B-10 well 58 feet 18. Approximate spud date 3101185 3000 . psig@ Surface 3800 psig~0,239 ft. TD~ 21 Proposed Casing, Liner and Cementing Program SIZE Hole 12¼" 8½- Casing · s s/~ 9 5/~ 7,! ' Weight " fi8 ' 36 26 CASING AND LINER Grade Coupling Length H-~o PELtI K-55 BTRSI 6157' L-80 BTRSI SETTING DEPTH MD TOP TVD 35' [ 35' 35' I 35' I I 35' I 35' MD BOTTOM TVD 115'1 115' 6192'1 /+750' 73~? QUANTITY OF CEMENT (include stage data) ±100 cf Pmfrs. Cmt ±1675 SxS Pmfrst. Cmt ±275 SxS Class G. Cmt. ±300 SxS Class G Cmt. 22. Describe proposed program: Conoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River Field. The mud system will be non-dispersed, low solids with a minimum mud weight in surface hole of 9.0 PPG. Mud weight at T.D. will · be 10.2 PPG. A 2000 PSIG RSRRA BOPE stack will be used on surface casing. PreSsure tests will be performed as per State Regulations. Maximum anticipated surface pressure was based on a fluid column at T.D. of 80% gas and 20% oil. Casing will be tested to 1500 PSIG. B No. 9 is no closer than 58' from another well bore. The southwes trending B-9 will cross below the northwest trending B-lO well bore at a depth of ±1/+00' TVD and a distance of 58'. Arctic Pack will be placed in the 7" x 9 5/8" annulus after disposing of the test oil and excess drilling fluid. The perforation and completion assemblies will be run before releasing the drilling rig. The perforating guns will be detonated and the well flow tested once the drilling rig has moved off the well. 23. I here~ertify that the foregoing is ,,. / . trot to the best of my knowledge The space ~l~)w for Commission use ! TITLE Engineering Technician CONDITIONS OF APPROVAL Samples required Mud log required [ D~ctionalSurvey required I APl number r-]YES .~"~O L-JYES ,[~J~O J~YES []NO 50- 0 2 9 - 2 1 2 9 7 I Permit number Approval date 'SEE COVER LETTER FOR OTHER REQUIREMENTS ~-'~/,/~ [, .,-"D J3"Sq 0~ 8.~ ....'/ .j~ // ~~~ 1/' ~ ~ APPROVED BY {// '//( ~~~~ ~ DATE March 1, 1985 COMMISSIONER~ ~ . ~w/~ ~ by order of the Commission Form 10~01 Submit in triplicate Rev. 7-1-80 SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. B-9 Conoco Inc. 3201 'C' Street, Suite 200 Anchorage, Alaska 99503 I. CEMENTING PROGRAM A. The 13 3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. Be Ce The 9 5/8" surface casing will be cemented with ~ 1675 sacks of Permafrost "E" cement followed by ±275 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. ~~~ The 7" production ca~ng will be cemented in two stages. The first stage will consist of ±300 sacks of Glass "G" cement pumped around the casing~hoe (estimated ±1700' of annular cement, assuming an AHS--4~). The second stage will consist of ±]80 sacks of permafrost cement followed by ±60 barrels of A~tic Pack, pumped down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at +1700'_ 4500' - TD Predominately shale until the Kuparuk Sands - expected at ~6800' subsea TVD. III. FORMATION EVALUATION A. Sidewall cores to be taken as determined by onsight geologist. Be Wireline logs for the 8¥' hole from T.D. to ±5700' MD will include: Dual Induction Log; Spherically Focused Log; Formation Compensated Density, Compensated Neutron Log, and Gamma Ray-caliper. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system O' - 1000' Low solids non-dispersed gel/water mud system 1000' - TD V. DIRECTIONAL PROGRAM The well will be drilled to a proposed KOP of 650', then. angle will be built in a south 57.1° west direction. The closest that the B-9 wellbore will come to another wellbore is as the proposed well course crosses under the existing B-10 wellbore at a depth of ±1400' TVD and a distance of ±58'. N LOCATION IN SECTION FROM S. LIN FROM W. UNE 212' ~ 978' __~___ _ SEC. 18 SEC. 19 STATE PLANE CO~:)RD$. 6EODETI¢ NDRTHINGS EASTINGS LATITUDE 572 ,058.98 70028 S I M PSON LA(:; OON Z' M~LNE PT. UNIT BOLtNDAR¥ CONOCO MILNE POINT UNIT EXISTING DEVELOPMENT STATE PLANE CO.ORDINATES ARE ZONE 4. Ill ~. ~LL oEoo~,,c .osiT,o.s A.E ~ASED O. N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. rC 2' 910' G,02~, 121.76 5T I, 989.77 'S 49' ~ 1129' ,02~, 077. O0 572,209. I0 IG5"~ !158' G, 02Z ~ 960.76 572 , Z$9.11 POSITION LONGITUDE 149° 24'41.176' W. 70°28' 24.4~9" N. 149024'43.151' W. 70028. 25.978" N. 149024' 36.714' W. 70°2-8'22-a32"N. ~49°24' 35.865"W. DATE CHECKED - 6 -BZ L.K. -6 - 82 L.K. 4 -22-8a L. 4-22-82 L.K. FIELD BOOK 09-82 09 09 -8 2 09 IlB-5 ~ eB' II10' $,025, 195.2t 572, 179.11 70°28'25.124"N: 149~24':57. SG3'W. 7-24-82 L K. IG -82 J B-6 I1~', 7~-Z~LZ~.5~',.' I~'-~.l~ 1I-5-R4 J.H. D [".,o l ~ G97 731 &,oz3. B/~.gO G71 B03.~5 7~-Z~-3/. gl~'u 149-24'.~4~6~ II-A 84 -3 U [5-~ F S46' ~lq' G OZS 470 47i 57t', ~94 7Z 70'-Z~'-Z7 ~Tb,' ~ ' ' ' ., ' ~, ' ' ~ _ . - , , - ~ · ] 49.z4-4~.847_ II- 5-~ ~.it. I I ~' ~ / I~ .~ II/ ~ ~JJIlII ! -q Ju~sss,o,;~c ~' ~ ..... . i Il · -- L~;~ Ill I SECT, 19. ALL ~HERS FROM S. LINE PAD B. WELL NO, 9 RE!VSED PROPOSAL HILNE PT.. NORTH SLC ':. ALASKA EASTHAN ~H[PSTOCK. [NC. 0 . SURFACE: 1.000 _ 2000 _ 3000_ 4000_ . 5000_ 6000_ .... ZOO0 _ KOP TVD=650 TMD=650 DEP=O $ 10 _ 8000, 0 20 25 30 3~ BUILD 2 1/2 DEG ....... PER 100 FT ....................... ~ ...... 4O 4S EOB TVD=2368 TMD=2593 DEP=?Z5 9 5/8" CSG PT TVD=4750 TMD=61 92 DEP=3474 AVERAGE ANGLE 48 DEG 34 TARGET TVD=6960 TMD=9532 DEP=5978 "TENTATIVE' TD TVD=ZI90 TMD=9880 DEP=6239 1 000 2000 3000 4000 5000 VERTICAL SECT[ON I 6000 I ZOO0 CONOCO. !NC' .......... PAD B. WELL NO, 9 RE[vsED PROPOSAL MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. 1000 7'000 6000 5000 z 1 000 _ o c) '~' 2000 _ 3000 _ 4000 _ 4000 I S 57 DEG 5 MI N W 59?8' (TO TARGET) TARGET TVD=6~O TMD=9532 DEP=5978 WEST'EAST 3000 I , SOUTH 3248 WEST 5019 2000 I '~ooo o SURFACE LOCAT! ON ~ 348' FSL (4932' FNL) 819' FWL (4392' FEL) SEC, 18, T13#. Rtl TARGET LOCATION~ 2900' FNL. 4200' FEL SEC. 24. T13N. RtOE 1000 I 300 .800 __ 700 __ 400 500 ! NORTH 600 700 I, I 800 900 100C I I ~ CONOCO. INC. PAD B, WELL NO~ 9 REVISED PROPOSAL HILNE PT., NORTH SLOPE, ALASKA EASTHAN WHIPSTOCK. INC. -' _. NOTE~ WELL PATHS EXTEND .................................................................................................................... BEYOND THIS VIEWING WINDOW .__600___ ' 3232 -' ' 28?8 ..400 .... · :300 ............... I ?$1 .............. ~ ~, I$11 1 $28 t 200 ...... 1882 . CALCULATION OF LEA.ST DISTANCE BETWEEN WELLS WELL i CONOCO, INC. FILE 2628 PAD B, WELL NO: SJ REIVSED F'ROF'OSAL MILNE PT., NORTH SLOPE, ALASKA COORDINATES: 348.00 N 817/.00 E KB = WELL 2 --- CONOCO, INC. FILE 2538 F'AD B, WELL NO: 10 CHRISTENSEN Mwd MILNE PT., NORTH SLOPE, ALASKA ~ ...... ~'~' 00 E KB = COORDINATE~,. ~c:~.OO N ,:,~o. RANGE OF MEAc._RED DEPTH ( C D C ) WELL 1 0. FT TO WELL 2 O. FT TO ~4~(). FT WITH A 5.0 FT INTERVAL 2474. FT WITH A 5.0 FT INTERVAL MEASURED TVD DEPTH RKB ~1 NS: EW ~-~= 277 WEL. L 1 14~.j.00 1410 34 ..... u, N 710.15 E WELL c~ 1411 .00 1 .:,o~. S/7 263.~.'-'~ N 6..7~ . ~,~'~ E i- I.--.TANCE BETWEEN POINTS I '~ ='-~ · -~ ._,,-~. 37 F T Eastman ,---, v ,~ FROM MUD IP · 'U FoLD" :.' KILL FROM REMOTE HIGH ' ~ Itl-"' ~ REINIOTE PRESSURE GAGE SENSOR PRESSURE PUMP --" "----LU "~-'~ lr--UJ ',~ NOTE: ' ' ~ HYDRAULIC CONTROLLED I. HYDRAULIC CONTROL SYSTEII FOR BOP STACK 6 CHOKE ,~ REI~OTE OPERATED MANIFOLD TO INCLUDE (5) STATION CONTROL MANIFOLO LOCATED REI,!'OTELY WITH 5000 PSI ACCUMULATOR a 160 GAL. RESER'~lR a AUX. ENERGY SOURCE. (,5) ST,&. CONTROL MANIFOLD PLUS VARIABLE CNOK[ CONTROL TO BE LOCATED ON RIG FLOOR. : . .(~ DRILLING Z KILL ~ CHOI~ MANIFOLDS TO MEET AP! RPS$ C'L. SPOOL 5¥ Sl'gS. · ~ HYDRAULIC CONTROLLED ~._.~RE~OTE OPERATEREMoTED PRESSURE GAGE SENSOR m - · ~ . BLEED LINE TO ATMOSPHERIC TO PIT MUD/GAS SEPARATJ~ '~ o,,-z "' .: ..,'~,:,,.... ' .... - '- ...... CHOKE 8 KILL ~ANIFOLDS FOR c1~/8'~ & ?" OD CASING BOP STACK I~ ~ '? BOP LIANIFOLD LAYOUT - CONOCO, INC. L: ;'"' ,, , .... , ~ , , CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK 6" Relief Line Fill-up Line ~~ --~Flow Line i20" 2000 psiI ~ ~nular : ! Preventer HCR HCR ~: J Valve Valve~- . _ ~ ~ I Drilling L___~ * ~ ~ ) spool ( 6" Relief Valve 120" x 20" ~ 2000 psi t Assembly 0 · ,, o- ~. Saver Sub ~ o As s emb ly · '° '° · :Star'~i~g i .'o ° ' ' ~ · ~ Head ~ ' - ' , ~ I I Casinm / f'4,~.~ ' ~ I ° / 12-~.. ":'::?,,. . o '. · .: :.". .... .''.0..., , ......,-. · . .%,~'~:, 1. Relief lines from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with AP1 specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. · Depending on rig contracted, the two. 6" lines may be replaced by a single 10" line wi~h a downstream tee. DRG 7-17-84 Fill-up Preventer --~Flow Line CONOCO IN~. MILNE POINT UNIT BOP STACK (1) B.O.P'. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated .... (2) BOPE to be operated on each trip ~i,'~-- & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 '~ ' gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet AP1 RP 53 class 5M requirements. RA~M 13 5/8" - 5000 13 5/8" - 5000 2" - 5000 Side Outlets 3" - 5000 Side Outlets 3"- 5000 Side Outlets . .. 1-3 5/8" - 5000 11" - 5000 l/7 2 C^SI:;G ~TR I~;G CASI:;J SIZE HSL2 SIZE CObq,~Y STA'_'--Z · ~TfD GR. i . ,~fJ~ '~T. I ! DESIGN BY fT/.~. :<fD. GR. II #, ?:i/f:. :.:.S.?. i ~LqVA L ~ctt'cn .Top Wt. Grade ~read V.-£ i SH'£ W/ E? -top of W?O E-F-- seaticn ___ lbs lbs CDP YIELD '2LF --. &lf . o g Co~_~c resistance in tension = X (Collapse pressure ratify) ~.25P + D~pth ( Hya. Gr. II --.~) ZF (Bcuy~ncy Factor) = ]..co- (0.0;53): '.-'=~ wt. ~) Calculatisn$: CHECK LIST FOR NEW WELL PERMITS Company ~c~c~-~ Lease & Well No. ~ ~ ITEM APPROVE DATE (1) Fee ~,: ....... ~ ...... (2) Loc <<~ ........ ~- ~ (2 thru 8) (:4) Casg (13 thru 21) '(22 th'ru 26) (6) Add :~. ~ ,~? 13. 14, 15. 16. 17. 18. 19. 20. 21. 22. 2'3. 24. ~5. :6. YES NO i Is the permit fee attached "~ · leeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee~eeeeee 2. Is well to be located in a defined pool ............................ 3. is well located proper distance from property line .: ................ 4. Is well located proper distance from other wells .... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ~.. 7. Is operator the only affected party ................................. ~. Can permit be approved before ten-day wait . ;~:/<~ .... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ...................................... Is enough cement used to circulate on conductor and surface ..... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................. Will surface casing.protect fresh water zones ................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate wellbore separation proposed .......................... Is a diverter system required .................................... ~ Are necessary diagrams of diverter and ~ equipment attached . Does BOPE have sufficient pressure rating - Test to ,~)~ psig ,.~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) ......... Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS Additional Remarks: o ~z Geology~ Engineering:. :cs WVA JKT ~ HJH '~' rev: 10/29/84 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . . . ............................ . ....... SCHLUMBERGER ....... . COMPANY NAME : BP EXPLORATION WELL NAME : MPG- 09 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : AK API NUMBER : 500292277900 REFERENCE NO : 98562 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1998 10:52 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/12/ 1 ORIGIN : FLIC REEL NAME : 98562 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/12/ 1 ORIGIN : FLIC TAPE NAME : 98562 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINELOGS WELL NAME: MPG-09 API NUMBER: 500292277900 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 1-DEC-98 JOB NUMBER: 98562 LOGGING ENGINEER: OLTMANNS OPERATOR WITNESS: THACKERY SURFACE LOCATION SECTION: 27 TOWNSHIP: 13N RANGE: IOE FNL: FSL: 1605 FEL: 3342 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 58.20 GROUND LEVEL: 29.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 8945.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1998 10:52 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... CONTAINED HEREIN IS THE GR/TENS/CCLU DATA ACQUIRED ON BP EXPLORATION WELL MPG-09 ON 20-FEB-98 WITH THE ULTRA- SONIC CEMENT IMAGING TOOL (USIT) . NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SOI~;zARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8813.0 3106.0 CET 8846.0 3106.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CET LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1998 10:52 PAGE: REM_ARKS: THIS FILE CONTAINS THE CLIPPED GR/TENS/CCLU DATA FROM THE USIT MAIN PASS. NO DEPTH CORRECTIONS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 16 1 0.5 FT 64 0 FT 68 1 0 ** 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 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CET V 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8846.000 GRCH. CET -999.250 TENS. CET 3082.000 CCL.CET O. 205 DEPT. 2992.000 GRCH. CET 34.203 TENS. CET 1354.000 CCL.CET 0.298 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1998 10:52 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SO!V~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8847. $ 2989.0 USIT $ LOG HEADER DATA DATE LOGGED: 20-FEB- 98 SOFTWARE VERSION: 8B1-129 TIME LOGGER ON BOTTOM: 1813 20-FEB-98 TD DRILLER (FT) : 8900.0 TD LOGGER (FT) : 8845.0 TOP LOG INTERVAL (FT) : 3000.0 BOTTOM LOG INTERVAL (FT) : 8844.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1998 10:52 PAGE: GR GAi~I~A RAY USIT CE~IENT EVALUATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) SGT-L USIT-A 8.500 8945.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE 8.80 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: USIT LOGGED AS PRIMARY DEPTH CONTROL LOG. MAX DEVIATION: 77.56 DEGREES AT 7941 '. SOME CHANNELING EVIDENT FOR MOST OF LOGGED INTERVAL. PROPOSED PERF INTERVAL: 8660-8770. NO REPEAT PASS AS PER CLIENT REQUEST DUE TO WELL DEVIATION. THIS FILE CONTAINS THE RAW GR/TENS/CCLU DATA FOR THE MAIN PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1998 10:52 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 GR LOG GAPI 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 TENS LOG LB 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 CCL LOG 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 * * DA TA * * DEPT. 8847.500 GR.LOG DEPT. 2989.000 GR.LOG 64.962 TENS.LOG 2825.000 CCL.LOG 29.611 TENS.LOG 1350.000 CCL.LOG -0.076 -0. 005 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1998 10:52 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/12/ 1 ORIGIN : FLIC TAPE NAME : 98562 CONTINUATION # : 1 PREVIOUS TAPE : COGENT · BP EXPLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/12/ 1 ORIGIN : FLIC REEL NAME : 98562 CONTINUATION # : PREVIOUS REEL : COF~4ENT : BP EXPLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 DIRECT DIGITAL LOGGING COMPUTER PROCESSED ANALYSIS Compmnp CONOCO Wmll MILNE POINT UNIT 8.-9 Fimld KUP~R~k Countp ..... NO.~RTH. SLOPE:~ Statm ALASKA Countrp U.=,A CLIENT FOR'MAT DATA TAPE LOG I NFORMAT'I ON STANDARD FORMAT ( L . I . S W~i! No.: CONOCO P~.pth.~: 4691 . O0 9762,.¢0 Name: MiLNE POif.4T U~4ZT E~-9 Field: KUPARUK Date: 29 MA~_~z 4985 Ti~m: ?:~8 'AM FRI, Page: ~ k ! TAPE .RECORC, S HEADER RECORD'~ Reel name: 282013 Continuation TAPE HEADER mm~:~ Service name: &GSFO1 Previous tape: Date: 85?03?29 Origin: Comments: Tape. name .' ,...~,=01 3 Continuation ~: Ol EOF Film nature: &G5~.01.'001 Maximum length: '102.4 HEADER RECORDS File t~p¢: LO V~r~ion ~: Pag~ MNEM C N WN FN COUN STAT 'CTRY SECT TOWN RANIS EK8 EDF EGL PD LMF DMF RUN LCC SON LUN FL LUL ENGi WITN DL TLI BLI TCS TLAB iHT MRT liT MViS RM RMF MFST MFSS RMC MCST MCSS 1 NFORMAT i ON RECORDS CONTENTS .CONOCO M,I,LNE POINT UN'i,T 8-9 KUPARUK NORTH SLOPE ALASKA USA t 3N ........... 'il E 58,000 SE Kg., KD 28201 3 .. 7611 NORTH SLOF'~ NORTH SLOPE HUPP DAVIES 9750,0 00 9747,000 62 08 . 000 .... 9743, .OOO i ,0'1 0 . 0 00 .... i554. 000 .... i 56 , O0 i 56,000 DISP, FLOWL I NE 42,000 2,760 2. 270 57.~00 MEAS. . 2,890 58. 000 MEAS, · ltl[fill t lalllal t t s . s . illllla ail;SI' · S , UN I T TYPE CATG C 0 D E P .,aim COMMENT RECORDS Thi~ LIS tape wms written by ~earhart Industr. ies Wireline. Services. mm Alt corvm and tool mnemonics u~md mr.m those which most closml~ match ** Qea,-hmrt curvm mhd tool mnemonics. ** GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT TENS MER~E MV TENS MERGE MV SP MERGE APl SP MERGE AP! GR MERGE GAPI GR MERGE GAPI XCAL MERGE INCH CALl MERGE tN COL. COMPUTED DPHI .... ILD MERGE OHMM ILD MERGE OHMM ILM .MERGE OHMM ILM MERGE OHMM LL3 MERGE OHMM LL3 MERGE OHMM FFDC MERGE CPS FFDC MERGE CPS NFDC MERGE CPS NFDC MERGE CPS RHOB MERGE G?C3 RHOB MERGE G?C3 DRHO MERGE G?C3 DRHO MERGE G?C3 NPHI MERGE PU NPHi MERGE PU FCNL MERGE CPS FCNL MERGE CPS NCNL MERGE CPS NCNL MERGE CPS RAT COMPUTED RAT NPHD MERGE ~ DOL NPHi MERGE PU NPH$ CILD HERGE HERGE SAND NHHO N'PH! MERGE CILD MERGE Pti MMHO [~ A T A ENTRY 8LOCKS ENTRY FORMA TYPE T SPECIFICA aE CODE ::0 I 6'6 TIO ¸NS ENTRY BLOCK LEGENO **** TYPE DESCRIPTION .0 Tmrminator ( no morm mntrims ) D A'T A F 0 R M A l' DATUM SPECIFiCATiON 8L,OCKS **** MNEM SERVICE SERVICE iD .ORDER ~i AP1 AP1 AP! AP! FILE UNiT LOG TYPE CLASS MOD ~ DEPT TENS SP GR CALl DPHi iLD iLM LL3 FFDC NFDC RH08 DRNO NPH! Fr:NL NCNL RAT NPH i NPH i CiLD 282013 MERGE 2820i 3 MERGE 282:0 i 3 MERGE 282:013 MERGE 282 Oi 3 2820i3 MERGE 2820i 3 MERGE 282Oi 3 MEF.:GE 282,01 3 .MERGE 28201 3 MERGE 282013 MERGE 2820i ~ · MERGE 282013 · MERGE 2820i S MERGE 282013 MERGE 28201 3 282'81 3 MERGE 28201 ~ MERGE 2820i3 MERGE 282 0 i :3 F T :0 ,0 0 0 0 M ¥ 2:0 ::0 O 0 0 AP :I 20 i 0 i 0 0 · GAP i 20 54 I 0 O IN ,~ u 24 2 0 0 ..... 0 0 0 O OHMM 20 12.0 46 :0 O OHMM 20 i 20 44 0 0 0 H M M 20 220 6 0 0 CPS 2.0 98 2 0 0 ~..P~ ~ 98 1 0 0 O/.C.3 2 0 ' 94 I O G/C3 2 0 i O0 i 0 0 PU 20 i 22 2 0 '0 CPS 20 78 3 ~ 0 0 CPS 20 78 ..... 0 0 PU 20 68 i 0 O PU 2.0 " b o 3 0 0 M N H 0 20 68 46 0 0 oPECIFICATION _ PRO # SiZE LVL SMPL 68 68 6"-'o 68 68 68 68 68 68 68 68 68 68 68 6,8 68 68 68 68 68 ~Kuu~ iNDiCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O000OO 000000 000000 000000 000000 000000 O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 0.00000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 Pag~ OEPT LL3 RAT TENS FFDC NPH i SP NFDC NPHI DA GR RH08 CiLD TA RECORDS CALl DP, HO DPH I NPHi iLD FCNL ILM NCNL Pagm' 9762. :000 t , 000 -999,250 000 0.000 500 0,000 O. 000 · -i O. O00 0.000 0,000 i000.000 .0. 000 O. 000 I60,606 6. 000 ~ ,000 O, 000 .g. ~50 0.000 9662 . 000 4,560 2.i83 9562. ~000 6.457 2. 254 4738.000 462,7,0'0 22,~5 4606.00'0 464.000 22,467 63,600 643,80'0 29,350 6 t. 900 62 O, 8 00 29,430 8 ° 700 2,437 254,6,'''~ 80,000 2.394 i&6.34i 9.900 . :070 9,940 ,02i t2,909 25,350 iS,SiS 25,430 .3,926 i20,300 6,:012 li7,900 4,t40 268,500 6,109 252,300 9'462.:000 29,85.4 1.99i 4504,0 O0 549,300 18,9i 2 40,500 ~5I. OOO 25,9 45 00 2.295 9,100 ,0i2 21.515 2i.9i0 ~,379 i62,500 25,586 320.300 9.,362.0 O 0 '" 432 2 , ..~ -..~ 'i 4387,000 449,700 29,026 55. 200 64i . 000 35,720 112,7:00 2.452 459,i9e iO.6iO .04.8 12,000 31,720 2,178 81.700 2 '~70 206,700 · ~2e .,---. 000 3. 793 2,522 4352. O00 466,700 32, i 39 47,000 703,000 38,580 110,500 2,453 357,273 12,170 . i04 11,939 34,580 2,799 89.400 3,020 225,000 9t62,000 2.i63 2,734 4284.000 571 .800 33,330 45, O00 706,0:00 39. 650 134,40'0 2, .322 496.592 9.610 1-t-.7.-7 . %. ! 19.879 35,650 2,014 66,000 U.. i 181 , 5; 00 9 062,0 00 2.i88 2,640 4260, OOO 587,2.00 48.446 43. 300 68 i . 6.00 52.050 I09,600 2,282 535,796 8,770 .046 22,303 48.05 O 1,866 68.900 2.06i i62, i O0 8962, 00 O 2,460 44i6.000 539,400 42.747 36.1 O0 7.01 , i O0 47.6.~0 127,5'00 2,352 450.8i7 9.590 .076 18,06! 43.630 '2,2!8 64,300 2,275 i85,200 DEPT LL~ RAT TENS l-~ D C NPHi SP NFDC NPH i GR RHOB CiLD TA RECORD CALl DRHO DPHI NPHi ILD FCNL i Lbt f,i C iq L. 8862.0'00 3,690 2.8,45 876 2. ,0 O 0 '.3,74 i 2 51:" , '8662,000 2,992 ~ 627 8562,000 2,'623 8462, :000 i 80~' 8362,000 2,449 2,560 8262, 000 3,532 2,472 816o ,. , 000 2,773 2,7i8 8062,000 3,034 2,480 4'074,'000 539,600 40,447 39'96,.0'00 45.2,200 32.96t 4250.000 482,300 34.900 4i72,0'0'0 577.400 30,94'i 4021.000 534,500 30.821 39'08,000 52 i..900 31 ,896 3,. ~3. 000 477,900 26, 127 ._~4~.000 494. O00 3586,000 490,500 26,672 30,200 686,i00 45,760 36,1-..00 620,i00 39,320 7i .3bo 72,6.0 O 41 . 040 74,600 684.700 37,490 71.300 68i.i00 37.380 68,300 67i,000 3:3.360 60,300 690.i00 32.980 64,000 689,700 34.940 63,800 681,000 33,500 i 7'7,8:08 727,34i I 17.600 2,408 338,844 t58,200 2,42i 346,73.7 192,900 2,~37 714.496 i56,500 2,403 426,580 125,300 2,392 462,38t li4, lO0 2,436 276. 058 96,400 2,422 , ,..} .-'. "2 374., .., 97. 700 2,4i2 334, i95 9,950 ,060 9,920 , U'~ 11 . 160 ,079 9,980 ,032 9,960 ,080 i2,500 ,07i Ii,870 ,087 i 1,700 , ii,530 ,07'? I8,242 41,760 14.667 35,.$'-ZU t3,879 37,040 i8,970 33.490 i4,970 33,380 15,636 34,360 12,978 28,980 i3,8i8 30.94 0 i4,424 29,500 66,600 2,95~ i0i,000 o 884 78.700 i ,400 72,5'00 2,344 76,400 2, '163 88,200 3.622 88.200 '2,667 76.400 2,992 84.000 ~.000 2.66i .oO,.~OO 2,9 ._~ ::¢ 205, 000 I .400 t 98. 000 2,000 i88,200 2,!48 227.400 3,565 2ii,700 '2,67' .3 2i8,000 3, 027 o06 DEPT LL.~ R A T 7962 , ':000 2..,"' 48 2. 7862,i000 2,793 2.566 2,8i2 7662.000 4,246 2,432 7562.:008 2.8i2 2.607 7462,:000 2,630 2,517 ?362. O0 -0 2,77._'3 2,488 7262,000 3,656 2.543 7162.000 4,064 2. 455 D A T A RECORD""o TENS FFOC NPHi SP NFDC NPHi GR RHOB C'i LD CALl DRHO DPHi NPHi ILD FCNL 3508, '000 508,0:00 27,578 63,280 703,50,0 800 078 ~i.400 15,8i8 o 754 86.280 3528,000 25,:'"' 58,00 O :696, O0 0 32. 820 1 '09,500 ._,~ 92 .349. ~ 40 11.290 ,088 ~,636 28,820 2,864 88,200 3474,'000 567,808 27,i35 ~,-, 4'00 674,400 3:3,940 88,700 36'0.579 290 056 20.788 29.940 2,773 79,00,0 34.69,000 467,500 2= G:O, 9:0 0 725,000 32,0.30 :04,1 00 2,47J i 3 796 iO,G60 ,i20 t O. 849 28. 030 4.677 99,000 3489.0:00 523.200 29.456 60,4.0:0 G68. lO0 36 .i20 82,000 2,353 353,i83 i 0,640 .046 i8,000 32.i20 2,831 86,000 3381,000 521 . 50.0 30,473 59,700 684,900 37,060 78 °00 2,377 386,367 10,960 .077 16,545 33.060 2.588 89.500 3469. 000 61 0,600 · 30, i 9i 56,500 73,5,600 36,800 95,7:00 2,330 356,45i 10,840 ,i19 19.394 .32,800 2.805 8;3.600 3430,000 594,300 28.023 56,200 708,200 34.780 89.900 2.295 ~..e 448 9,510 21 .515 30.780 87,500 3357,000 58i.000 23,i6i 53,500 727,500 86,400 2,324 259.4i8 55 0 080 i9,758 26,110 89,700 I LM NCNL 2 204,000 2.877 222. 000 2,780 98,000 4.645 038 O00 2,858 2 '26,008 222.400 2.7:30 2t4,200 224. 400 3,828 237.500 Page i 0 DEPT LL3 RAT TENS FFDC NPNI SP NFDC NPHi . D A'T A GR RHOB CILD RECORDS CALl DRHO DPHI NPHi ILO FCNL, I L H NCNL P a g e .,. 0 e,--. , 000 2,992 ,686 3284,000 549,90'0 28,9g0 :5 5.1 00 69 7.4 O 0 35.630 99.i00 2,.~57 338,065 i O, 250 ,094 758 ,630 2,958 77,0'00 228.500 6962, '~000 3,0 06 2,626 6862,000 3.436 2,344 ~:000 296 7 O 7 6662. 000 2.979 2 .. 6562,:'000 2,649 2,644 6462, :0 O0 2,449 2,626 6362, 000 2,50G 2. 728 6 '262,000 4,093 2,407 3142,000 .525. i 0 O 26.0:33 5i i, 24,941 301,0.000 500,800 32,983 2962,000 ~7,9.00 34,695 2942,000 b~8 26,998 2903,0.00 637,900 3i.i60 2732,000 58i,700 ,~0 266~.0"00 577,700 28.983 52,800 694,900 32,890 46.7.00 645,800 31,84.0 47,200 641 . 5 O0 39,340 4.6,6:00 667,300 40. ',36'0 44, 'I 0 0 6'62,2 O0 33,81 0 46,1.00 778.100 37.690 37,.000 674,900 40,530 33,500 678,800 35,680 82,900 2,366 3i6,957 91 ,200 2.341 288.4:0:3 '~ 5:00 2,365 287,078 88,300 2.320 309.'03:0 84,9'0'0 2,337 361,4i0 85,6.00 2.310 442,589 77,200 2.28i 429,537 77.900 2,269 2~1.372 10,300 · 028 .680 · 036 I0.620 · 03:5 11 ,220 ,047 1 0. 280 .128 10.570 .045 ~0,440 ,03[7 17.212 28,890 18,727 27.840 17,273 35, ~40 20,000 36,860 18.970 29.810 20.606 J3,690 22,364 36.530 23,091 3i.680 3, 155 89· 50'0 3 · 467 i 00. 000 3,483 79,500 3,236 .... ~OO 2,767 78,400 2.259 80.700 2,328 76. 000 4,966 94,900 3,069 244,000 3.516 ~..4,..,, 300 3 , 4~..~, 3. t84 ":' Ct i '~ ,=.. , ,~ O 0 2 217,.700 2. 193 2i9.600 2.3i2 2i5,600 4,764 226,200 D'A T A RECORDS DEP T TEt,IS SP GR CALI [)PHI ! LO · .I.L..~. LL~ FFDC i, iFDC RH08 DRHO NPH i F C.' ~.~ L r,~ ~.; ~-~ ~_ RAT NPHI t~PHI C,ILD Page **** FiLE TRAILER *~*~ File na~: &G5FOl,OOi Haximum l~ngth: i~2.4 TRAILER RECORDS Verzion ~: Date: Film type: LO N~xt ~itm: EOF *~* FiLE HEADER -File n~me.: ~G~FO~ ,002 M.-~xi,mum length: i024 .HEADER RECORD~ Service n~m~: Vet. zion :~: File type: LO Prmvious ~iie: P.~ge. i4 MNEM CN WN FN COUN STAT CTRY SECT TOWN RANG EKB EOF EQL PD ~LM.F' DHF RUN LCC SON iLUN FL LUL ENC~i WI'TN DD DL TLi 8LI TLA8 8NT MRT MT MSS MViS RM RMF MFST MFSS RMC MCST MCSS I NFORMA C 0 N T E N T S CONOCO MiLNE POINT UNiT 8-9 KUPARUK NORTH SLOPE ...... 'ALASKA ..... LiSA t 'i E ........... 5'9, O0.O .......... , 58,0 O0 .......... · 24,0'0:0 ......................... K~ .................... ....... 282.0 i ~ 76~ 1 ............ NORTH ~LOP~ NORTH SLOPE NUPP , , , ..... DAVIES 9750, O00 ....... 9747 000 t 0 i 0 000 155~. 000 ..................... 156 000 ~5~,000 ...................... DI~P .......... FLO~LIN~ .......... ~2~ 000 ....................... 2.7~0 ........................ 2,270 .......................... 57.~00 2.~0 ........................... ~ ~. 000 ME~S TION RECORDS UNIT I!Ii · I it &l ii ·1 i ii I ii TYPE CATG SIZE CODE 0 0 40 6o 0 0 40 .~5 0 0 40 ~=' 0 0 20 ~5 0 0 20 6.:_; 0 0 20 ~l 5 0 0 2 0 0 3 0 0 ~ 65 FT 0 .'3 4 68 F T 0 .3 4 6 8 FT 0 3 4 69 0 3 2 65 O 3 2 65 0 3 2 65 · O O 2 79 0 0 2 79 O . 0 10 65 0 0 10 0 0 20 ~5 0 0 20 65 0 0 20 65 0 0 20 65 FT O 3 4 68 FT 0 3 4 6,8 FT 0 3 4 68 FT 0 ,3 4 68 HR 0 2 4 68 HD. 0 4 4 68 DEGF O ! 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 CP 0 2 4 GO OHMH O 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 i2 65 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 15 C 0 M M E N T RE,CORDS · m This LIS ~tmpm was writtmn bp Gearhart !ndustrims Wipmlinm Smrvicms, ~m · * All curvm and tool mnmmonics u.smd arm thosm which most closml~ match ~m m. ~marhart curvm and tool mnemonics, ** ******************************************************************************** ********************************************************************************** GEARHART TO .SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT RATi COMPUTED RAT ...... TENSI MERGE MV TENS MERGE MY GRi MERGE GAPI GR MERGE GAPI NPHDi MERGE .~ DOL NPHI MERGE PU NPH$1 MERGE ~ SAND NPHI MERGE PU NCNL. i MERGE CPS NCNL MERGE CPS FCNLi MERGE CPS FCNL MERGE CPS NPHIi MERGE PU NPHI MERGE PU Pmgm 16 DATA ENTRY BLOCKS ENTRY ~m~m ENTRV BLOCK LEGEND TYPE DESCRIPTION 0 Tmrminator ( no more entrimz ) FORMAT ,_~PEC 1 FI CA TYPE ~' olZE CODE 0 i 66 TiONS 17 DA T A F 0 R M A T '~PEC- I'F i CAT I~ON'~'o t8 SERS.~ICE SERVICE APl AP1 APl 'APl FiLE MNEM iD ORDER ~ UNiT LOG TYPE CLASS HOC, ~ PRC ~ SiZE LVL SMPL R... PROCES~ ~ iNDiCATORS DEPT 2820i 3 FT 0 0 0 0 0 RAT 28201..'3, 0 0 0 0 i TENS MERGE 2820'i3 MV 2:0 0 0 .0 1 GR MERGE 282 0 i 7 GAP i 20 5,4 i 0 1 NPH I MERGE 282 0 t ._'3 PU 2.0 68 1 .0 t NPHi MERGE 2820i 3 PU 20 68 7 0 i NCNL MERGE 2820 i ~ CPS 2'0 78 ~0 0 i FCNL MERGE 282 0't 7 CP9 20 78 :~1 0 i NPHi MERGE 282'0i7 PU 20 122. 2 0 1 4 0 i 68 4 0 i 68 4 0 i 68 00000'0 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 .000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT N P H i 629I ,..000 5,400 619 ~ , :000 45. ;;'80 6091 . 0 00 40. 250 599! . '000 43.630 5891 . :0 O0 48,490 5791 . ~:000 45. i80 5691 . :0 O 0 42. 780 559'I . ..000 4i ,7i0 5491,0 00 44.200 .~. i 4 i, '05 O ,.,~ .~ 1 000 45.i00 519i . 000 46.820 RAT TENS -999. 250 2806, 000 DA TA R E C 0 R D '" GR NPH I NPH T HL. H,.. FCHL 0,000 2.96i ~,400 Page t 9 O. 000 O, 000 3. t->0 .... R. . . ,.. z~ 000 61.600 45.47i 49.780 15,3 400 50 500 2,929 2659,00'0 46,000 38,633 44.250 t59,400 54.000 2,888 2610.000 68. t00 42 .747 47. 630 165. 3.068 2610,000 50,8.00 49,0~5 52,490 164.200 5i .500 2, '3..42.. .._<"~..~-":',,., -, =. 000 40 ,900 44 ,702 49 , t80 162 .200 58 , lO0 41 . 694 3. O 03 2.5 t .., ~ , 000 33.400 , , 54,'000 40.386 2866 2518 000 2.888 2493,0'00 55,400 43.46i 2.939 2420.000 40.600 39.589 46 780 45 7i0 48 200 45 050 , 23.,,7 000 2 87._-4 · ~ , 44.600 49 100 46.821 50 820 54,000 2 _:-'.' 2342 000 28,300 164.200 50.5'00 160.200 56.500 168 300 H', -, ...~ 500 157. i O0 54. 500 160,000 57.100 148,400 54.600 D TA RECORDS Pag~ ~.0 DEPT RAT TENS GR NPHI NPHI NCHL FCNL NPH i 5.091 OOO ~ ~1i ~08 OOO :~4 400 ~" ~' ~ . .~,~, ~4o 57 640 i5° 500 45 800 53,64'0 49gt ~000 2 ~91 2264 000 "':' ...... ~,7,400 42,46i 47.400 i41 ,600 44, .,~ 00 43,400 4 89i , 0'00 ~ 1 g i ~' ~'' ~- ' Z~O0 000 48 lO0 55 0.~,~ 56 820 5"2.82.0 4791,00.0 3,048 22:00,000 55 700 55 649 57 2..,0 i5i,500 5i,000 23.0 4691 {~O0 3 18~1 21 42 000 55 600 '-'='" - ....... o,=.., 25 t 54,840 iSz,O00 47,900 50,84 O FiLE TRAILER **** File na~: &GSF01~O02 Maximum imngth: 1'024 TRA I LER RECORD~ Service name: Film t~pm: LO Vets i on #: Nmx't Date: Pag~ '2i EOF S er, vice name: &GSFOi Nmxt tape.: Date: 8570S/29 Comments: · Origin~ Tape name: 28201g Continuation ~ Oi REEL TRAILER Date.: 85/0~/29 gommentz,: TRA I L'ER Or. igin: RECORDS Reel name: Continuation ~: Oi 22 EOF EOF