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195-145
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251107 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-26 50283201820000 220058 9/20/2025 AK E-LINE Perf BRU 212-35 50283100270000 162018 10/12/2025 AK E-LINE TubingPuncher BRU 234-27 50283202070000 225065 7/17/1905 AK E-LINE CBL-02-October BRU 234-27 50283202070000 225065 10/6/2025 AK E-LINE CIBP/Perf GP 42-23RD 50733201140100 195145 10/26/2025 AK E-LINE TubingPunch GP ST 42-23RD 50733201140100 195145 10/9/2025 AK E-LINE JetCut MPL-54 50029236070000 218066 10/16/2025 READ CaliperSurvey MPL-57 50029236090000 218072 10/27/2025 READ CaliperSurvey MPU B-21 50029215350000 186023 10/25/2025 AK E-LINE RBP NCIU A-07 50883200270000 169058 10/10/2025 AK E-LINE JetCut NCIU A-17A 50883201880100 225089 10/10/2025 AK E-LINE Perf NCIU A-17A 50883201880100 225089 10/14/2025 AK E-LINE Perf PBU 01-10A 50029201690200 225055 8/29/2025 HALLIBURTON RBT PBU 05-11A 50029202520100 196097 10/11/2025 BAKER RPM PBU 05-31B 50029221590200 210085 10/14/2025 BAKER SPN PBU F-06B 50029200970200 225054 9/27/2025 BAKER MRPM PBU F-42A 50029221080100 207093 10/27/2025 BAKER RPM PBU H-07B 50029202420200 225064 9/29/2025 BAKER MRPM PBU L5-27 50029236270000 219046 10/7/2025 BAKER SPN PBU Q-06A 50029203460100 198090 8/22/2025 YELLOWJACKET SCBL SD-06 50133205820000 208160 7/23/2025 YELLOWJACKET GPT-PERF SRU 222-33 50133207150000 223100 7/15/2025 YELLOWJACKET PERF Please include current contact information if different from above. T41066 T41067 T41068 T41068 T41069 T41069 T41070 T41071 T41072 T41073 T41074 T41074 T41075 T41076 T41077 T41078 T41079 T41080 T41081 T41082 T41083 T41084 GP 42-23RD 50733201140100 195145 10/26/2025 AK E-LINE TubingPunch GP ST 42-23RD 50733201140100 195145 10/9/2025 AK E-LINE JetCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.07 15:03:51 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Eric Dickerman Subject:20251023 1622 APPROVAL PTD 195-145, Sundry 325-563, Granite Point St 42-23RD, Punch old tubing tail due to stuck plug Date:Thursday, October 23, 2025 4:23:59 PM Attachments:image001.png Eric, Hilcorp is approved to punch the tubing tail as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Eric Dickerman <eric.dickerman@hilcorp.com> Sent: Thursday, October 23, 2025 2:54 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 195-145, Sundry 325-563, Granite Point St 42-23RD, Punch old tubing tail due to stuck plug Mr. Rixse, As discussed on the phone regarding Sundry 325-563, we have completed the rig workover steps of the program and are currently trying to fish the tubing tail plug set in the X nipple at 11,170’ md. We are currently on day three of fishing. If we are unable to recover the tubing tail plug, Hilcorp is requesting approval to punch the tubing tail between the old production packer at 11,131’ and the tubing tail plug in the X nipple at 11,170’. This will allow the well to produce through the tubing punches and will not compromise tubing integrity since we ran a new production packer and tail pipe. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GRANITE PT ST 42-23RD JBR 11/14/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 2 7/8" and 3 1/2" test joints used for testing. The pipe rams (VBR) failed on the intial and were functioned for a pass. 20 pre- charge bottles ranging from 950 psi to 1200 psi. Test Results TEST DATA Rig Rep:T. RentonOperator:Hilcorp Alaska, LLC Operator Rep:H. Soule Rig Owner/Rig No.:Hilcorp 404 PTD#:1951450 DATE:10/4/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC251002192606 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 699 Sundry No: 325-563 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5.5" V FP #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 1 3 1/8" 5000 P Kill Line Valves 3 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P2000 200 PSI Attained P21 Full Pressure Attained P110 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1850 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P26 #1 Rams P4 #2 Rams P4 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 Granite Pt Platform 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 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): 13,940 12,500 (fill) Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,090psi Production 7,020psi Liner 7,250psi 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: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: 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 N/A Other: GL Completion Granite Point Middle Kenai Oil Same 10,421 13,734 10,394 699psi 13,734 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 AOGCC USE ONLY 8,290psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018761 195-145 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20114-01-00 Hilcorp Alaska, LLC Granite Pt St 42-23RD Length Size Proposed Pools: L-80 TVD Burst 11,202 8,160psi MD 5,750psi 3,090psi 418' 3,368' 5,469' 418' 3,995' 10,373'7" 18" 13-3/8" 418' 9-5/8"7,234' 3,995' 13,563' Perforation Depth MD (ft): 7,234' 11,296 - 13,725 13,563' 5" 9,212 - 10,397 9/29/2025 13,740'282' 2-7/8" 10,399' Halliburton VSR Pkr & Camco TRSSSV "X" profile SSSV 11,131 (MD) 9,056 (TVD) & 329 (MD) 329 (TVD) No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:07 pm, Sep 15, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.09.15 15:21:19 - 08'00' Dan Marlowe (1267) 325-563 DSR-9/23/25 * BOPE test to 2500 psi. 48 hour notice to AOGCC for opportunity to witness. * See appended procedure steps 8-12. 10-404 MGR24SEP2025 A.Dewhurst 16SEP25JLC 10/2/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.10.03 08:21:15 -08'00'10/03/25 RBDMS JSB 100625 Replace tubing string RWO Well: GP 42-23RD Well Name:GP 42-23RD API Number:50-733-20114-01-00 Current Status:Offline, Gas Lift Producer Leg:Leg 3 (E corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:195-145 First Call Engineer:Eric Dickerman (907) 564-4061 (o) Second Call Engineer:Casey Morse (907) 777-8322 (o) Maximum Expected BHP:1,709 psi at 10,100’ TVD – Static bottomhole pressure survey 2/19/21 0.17 psi/ft, 3.3 ppg EMW Max. Potential Surface Pressure:699 psi – 0.1 psi/ft gas gradient to surface Brief Well Summary GP 42-23RD is a gas lift producer that was completed in February 1996 in the Middle Kenai interval. The well has been a steady producer since that time, apart from a shut in due to the Mt. Redoubt eruption in 2009. On 8/30/25 the tubing and casing pressures rapidly equalized, indicating tubing by inner annulus communication and the well was shut in. A pressure/temperature survey on 8/31/25 indicated the leak was shallow ~135’. Further slickline diagnostics on 9/9/25 confirmed that the 2-7/8” tubing has parted at 135’. The deeper stub has dropped 8’ – 10’. Slickline attempted to set a plug deeper in the well, but was unable to enter the stub. Objective: Rig workover to fish current 2-7/8” tubing string and replace with new 2-7/8” gas lift completion. Notes on wellbore condition: Due to formation compatibility concerns the workover fluid is planned to be diesel (6.8 ppg). 12/1995 -02/1996: Exit parent bore and drill 42-23RD MIT-IA passed 2,500 psi (2/22/1996) 12/12/2002: Gas lift valve changeout. 01/18/2003: Replace orifice gas lift valve. 8/20/2004: AOGCC witnessed no flow test passed. 10/2005 – 11/2005: Gas lift valve change out. 02/12/2006: Caliper and MTT log. No significant metal loss on the ID of the tubing, possible external metal loss. 05/23/2006: Gas lift valve changeout. 03/01/2009: Granite Point platform shut in for Mt. Redoubt eruption. 02/19/2021: Static bottomhole pressure survey. 08/30/2025: Tubing and IA rapidly equalized. Well shut in. 08/31/2025: Slickline tagged 339’ with 2.34” swedge. Pressure temperature survey indicated tubing leak at 135’. 09/09/2025: Slickline made multiple attempts to drift tubing to set a tubing tail plug. Unable to enter stub looking up at ~145’, kept getting on outside of stub. Confirmed subsurface safety valve control line is still holding pressure. Replace tubing string RWO Well: GP 42-23RD Pre-rig Procedure: 1. Fill well with diesel. Utilize lubricate and bleed method. a. 2-7/8” Tubing Volume = 65 bbl. b. IA Volume = 411 bbl c. Liner Volume = 88 bbl Proposed RWO Procedure: 2. MIRU HAK 404 3. Confirm well is dead. Establish fill rate, fill well as needed. a. Work over fluid will be diesel (6.8ppg) 4. Set BPV/TWC, ND tree, NU BOP stack. b. Top down: annular, 2-7/8” x 5-1/2” VBRs, Blinds, Flow cross. c. Notify AOGCC 48 hours in advance for witness. d. Test to 250 psi Low / 2,500 psi High / 2,500 psi Annular. e. Submit completed 10-424 within 5 days of BOPE Test. f. BOPE will be used as needed to circulate the well. 5. Pull BPV/TWC. 6. MU landing joint or spear. BOLDS. Pull hanger to floor. 7. Lay down 2-7/8” tubing to the part, approximately 135’. Inspect recovered end. 8. PU 3-1/2” work string, overshot tubing stub at ± 145’ then PUH 8’ to get tubing to neutral. 9. RU Eline and pressure control equipment. 10. RIH with tubing cutter, no go in subsurface safety valve to place cutter in the first full joint below the subsurface safety valve, then cut tubing ~10’ below subsurface safety valve. a. Potential for gas underneath the subsurface safety valve. Circulate gas out of the well as needed. b. Eline toolstring top down configuration will be: fluted no go, weight bar, tubing cutter. c. If eline cutter toolstring is stuck across the subsurface safety valve, pull out of weak point. The fluted no-go will allow recovery of eline toolstring with tubing. 11. RD eline. 12. Lay down the 2-7/8” tubing to the cut and spool up control line. 13. RBIH, overshot 2-7/8” tubing at ~339’, PUH 8’ to get tubing to neutral. 14. RU slickline. 15. Attempt to set a tubing tail plug in the X nipple at 11,170’. X nipple profile in XA sliding sleeve at 11,100’ can be used as a backup. 16. If successful in setting tubing tail plug, test the 7” 29# casing to 1,500 psi. 80% of Burst pressure = 6,528 psi. 17. RD slickline. 18. RU eline. 19. Cut 2-7/8” tubing at ± 11,072’. 20. RD eline. 21. Circulate surface to surface. 22. Lay down 2-7/8” tubing to the cut. PUW expected at 75k # in diesel. 23. Contingent step if slickline is not able to set tubing tail plug. - RIH with test packer on workstring to ± 11,050’. 24. Contingent step if slickline is not able to set tubing tail plug. - Test 7” 29# casing to 1,500 psi. a. 80% of Burst pressure = 6,528 psi. See appended procedure for steps 8-12. mgr Replace tubing string RWO Well: GP 42-23RD 25. POOH, lay down workstring. 26. RIH with 2-7/8” gas lift completion. g. Target packer at ± 11,000’ md (8,932’ tvd) h. Tubing Retrievable subsurface safety valve planned at ± 400’ md. Water depth at MLLW = 75’. i. Completion to be ran with live GLV’s. 27. Land tubing hanger. 28. Drop packer setting prong, and set packer. 29. MIT-T to 1,500 psi for 30 charted minutes. 30. CMIT-TxIA to 1,500 psi for 30 charted minutes. 31. Set BPV/TWC. 32. ND BOPE. 33. NU tree and test. 34. Pull BPV/TWC. 35. RDMO RWO crew and equipment. Post Rig Slickline: 36. Pull packer setting prong, RHC body, and tubing tail plug at 11,170’ (if set). Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Wellhead Diagram 4. BOP Drawing 5. 404 Fluid flow diagram 6. RWO Sundry Change Form Granite Point Platform Well #: GP 42-23RD Completion Date: 02/24/1996 PTD: 195-145 API: 50-733-20114-01 Revised by EPD 09/15/2025 SCHEMATIC TD @ 13,940’ PBTD @ 13,734’ RKB to MLL= 105’ 1 6 2 3 4 5X XA 18” 13-3/8” 9-5/8” 7” 5” Tag @ 12,500’ Approx. 6/1/2012 DV Collar @ 2,281’ CASING DETAIL Size WT Grade Conn ID Top Btm 18” 70.59 B Ventura Surf 418’ 13-3/8” 61.0 J-55 BTC 12.515” Surf 3,995’ 9-5/8”43.5 N-80 LT&C 8.755” Surf ~87’ 40 N-80 LT&C 8.835” ~87’ 7,234’ KOP 7” 29 L-80 BTC 6.184” Surf 13,563’ 5” 15 L-80 BTC 4.408” 13,458’ 13,740’ TUBING DETAIL 2-7/8” 6.4 L-80 BTC 2.441” 47’ 11,202’ PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date C-2 11,296’ 11,350’ 9,212' 9,263' 54’ 6 2/20/1996 C-5 11,574' 11,724’ 9,469' 9,600' 150’ 6 2/20/1996 C-6 11,838’ 11,914’ 9,692' 9,752' 76’ 6 2/20/1996 C-7 12,190’ 12,365’ 9,955' 10,063' 175’ 6 2/20/1996 C-7 12,420’ 12,524’ 10,092' 10,143' 104’ 6 2/20/1996 C-7 12,833' 12,885’ 10,255' 10,267' 52’ 6 2/20/1996 C-7 12,922’ 13,122’ 10,274' 10,311' 200’ 6 2/20/1996 C-6 13,278’ 13,426’ 10,331' 10,352' 148’ 6 2/20/1996 C-5 13,557' 13,725’ 10,372' 10,397' 168’ 6 2/20/1996 JEWELRY No Depth MD Depth TVD ID OD Item 41’ 41’ FMC Tubing hanger w/ Type “H” BPV Profile & 2-7/8” BTC Top 1 135’ 135’ Tubing part 2 329’ 329’ 2.313” 4.700” Camco TRSSSV “X” Profile SSSV 3 11,100’ 9,027’ 2.313” 3.941” Halliburton “XA” Sliding Sleeve 4 11,111’ 9,038’ 2.350” 3.250” No-Go Locator w/ 8.5’ seal assembly and mule shoe guide 11,113’ 9,039’ 3.250” 5.451” Upper PBR Assembly 11,131’ 9,056’ 3.880” 6.000” Halliburton “VSR” Packer 5 11,170’ 9,093’ 2.313” 3.250” Halliburton “X” Nipple 6 11,202’ 9,124’ 2.445” 3.495” Wireline Re-Entry Guide GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,149’ 2,098’ 2.347” Camco MMM 16 DOME 980 2005 2 3,966’ 3,352’ 2.347” Camco MMM 16 DOME 970 2005 3 5,818’ 4,510’ 2.347” Camco MMM 16 DOME 960 2005 4 7,288’ 5,505’ 2.347” Camco MMM 16 DOME 950 2005 5 8,072’ 6,102’ 2.347” Camco MMM 16 DOME 940 2005 6 8,701’ 6,696’ 2.347” Camco MMM 16 DOME 930 2005 7 9,329’ 7,305’ 2.347” Camco MMM 20 DOME 920 2005 8 9,925’ 7,887’ 2.347” Camco MMM 20 DOME 910 2005 9 10,556’ 8,506’ 2.347” Camco MMM 20 DOME 900 2005 10 11,058’ 8,987’ 2.347” Camco MMM 24 Orifice (Nova)4/25/08 Granite Point Platform Well #: GP 42-23RD Completion Date:TBD PTD: 195-145 API: 50-733-20114-01 Revised by EPD 09/15/2025 PROPOSED SCHEMATIC TD @ 13,940’ PBTD @ 13,734’ MLLW = 75’ 1 6 7 8 2 3 4 5 X XA 18” 13-3/8” 9-5/8” 7” 5” Tag @ 12,500’ Approx. 6/1/2012 DV Collar @ 2,281’ X CASING DETAIL Size WT Grade Conn ID Top Btm 18” 70.59 B Ventura Surf 418’ 13-3/8” 61.0 J-55 BTC 12.515” Surf 3,995’ 9-5/8”43.5 N-80 LT&C 8.755” Surf ~87’ 40 N-80 LT&C 8.835” ~87’ 7,234’ KOP 7” 29 L-80 BTC 6.184” Surf 13,563’ 5” 15 L-80 BTC 4.408” 13,458’ 13,740’ TUBING DETAIL 2-7/8” 6.5 L-80 EUE 8RD 2.441” Surface 11,072’ 2-7/8” 6.4 L-80 BTC 2.441”11,072’11,202’ PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date C-2 11,296’ 11,350’ 9,212' 9,263' 54’ 6 2/20/1996 C-5 11,574' 11,724’ 9,469' 9,600' 150’ 6 2/20/1996 C-6 11,838’ 11,914’ 9,692' 9,752' 76’ 6 2/20/1996 C-7 12,190’ 12,365’ 9,955' 10,063' 175’ 6 2/20/1996 C-7 12,420’ 12,524’ 10,092' 10,143' 104’ 6 2/20/1996 C-7 12,833' 12,885’ 10,255' 10,267' 52’ 6 2/20/1996 C-7 12,922’ 13,122’ 10,274' 10,311' 200’ 6 2/20/1996 C-6 13,278’ 13,426’ 10,331' 10,352' 148’ 6 2/20/1996 C-5 13,557' 13,725’ 10,372' 10,397' 168’ 6 2/20/1996 JEWELRY No Depth MD Depth TVD ID OD Item Tubing hanger with Type “H” BPV Profile 1 400’ 400’ 2.313” 4.700” SLB TRMAXX-5E TRSSSV, with 2-7/8” X nipple 2 11,000’ 8,932’ 7” x 2-7/8” Production Packer 3 11,042’ 8,971’ 2.313” 3.250” 2-7/8” X nipple 4 11,072’ 9,000’ 3.500” 5.900” Northern Solutions non-sealing overshot/scoop 5 11,100’ 9,027’ 2.313” 3.941” Halliburton “XA” Sliding Sleeve 6 11,111’ 9,038’ 2.350” 3.250” No-Go Locator w/ 8.5’ seal assembly and mule shoe guide 11,113’ 9,039’ 3.250” 5.451” Upper PBR Assembly 11,131’ 9,056’ 3.880” 6.000” Halliburton “VSR” Packer 7 11,170’ 9,093’ 2.313” 3.250” Halliburton “X” Nipple 8 11,202’ 9,124’ 2.445” 3.495” Wireline Re-Entry Guide GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date TBD Granite Point Platform 42-23rd 05/10/2013 The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8" Spherical Annular Height: 46" Weight: 12,806 13-5/8" LWS Double BOP Height: 37" Width: 93" Weight 9,900 lbs. TOP RAMS 2-7/8" TO 5-1/2" MULTI- RAMS BOTTOM RAMS 13-5/8" Mud Cross W/ 4- 1/16" outlets Height:28.5" Width 31" Dual 4-1/16" Manual Gate valves W/ DSA to 2-1/16" 4-1/16" Manual Gate valve & 4-1/16" HCR W/ DSA to 2- 1/16" Full Mud Cross Assy. width w/ valves installed Width: 98.5" Weight: 2200 lbs. Kill side Choke side Height Addition for Ring Gaskets: 0" BOP Total Height: 111.5" BOP Total weight: 24,906 lbs. 13-5/8" 5m BOP Package W/ 4-1/16" Valves Blinds HILCORP ALASKA, LLC Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Granite Pt St 42-23RD (PTD 195-145)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Eric Dickerman To:Rixse, Melvin G (OGC) Subject:Granite Pt St 42-23RD, PTD 195145 Date:Monday, September 29, 2025 10:22:39 AM Mel, Regarding the planned rig workover on Granite Pt St 42-23RD, please see the well control/kill plan if gas is experienced underneath the subsurface safety valve flapper. I have included the original sundry verbiage, and the additions are in red text. 8. PU 3-1/2” work string, overshot tubing stub at ± 145’ then PUH 8’ to get tubing to neutral. Close BOPE on workstring. 9. RU Eline and pressure control equipment (lubricator, pump in sub, head). 10. RIH with tubing cutter, no go in subsurface safety valve to place cutter in the first full joint below the subsurface safety valve, then cut tubing ~10’ below subsurface safety valve. a. Potential for gas underneath the subsurface safety valve. Circulate gas out of the well as needed. If trapped gas/pressure under subsurface safety valve: 1. If the weight of eline tools does not open the subsurface safety valve flapper, pump down workstring/tubing to equalize pressure until flapper opens and tools pass through. 2. Bleed any pressure off to production and/or through choke to gas-buster depending on pressures and volume. Eline tools will be holding flapper open. 3. Refill tubing/hole, monitor and assure tubing and IA are static, proceed with cutting procedure. 4. After cutting the tubing below the subsurface safety valve, circulate a hole volume through choke. Monitor pressures, then proceed with procedure. b. Eline toolstring top down configuration will be: fluted no go, weight bar, tubing cutter. c. If eline cutter toolstring is stuck across the subsurface safety valve, pull out of weak point. The fluted no-go will allow recovery of eline toolstring with tubing. 11. RD eline. 12. Lay down the 2-7/8” tubing to the cut and spool up control line. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ¢~-~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by: Beverly D~than Lowell Isl [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • w w��\\I Tit s� THE STATE Alaska Oil and Gas � 0f LAS ( Conservation Coissi® 1 -,-4).____ _ =_-:,44t, GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0i, P Anchorage, Alaska 99501-3572 ALAS* Main: 907.279.1 433 Fax: 907.276.7542 Dan Taylor Operations Engineer Hilcorp Alaska, LLC lq5-14-s- 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 42-23RD Sundry Number: 313-518 Dear Mr. Taylor: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair, ommissioner DATED this gliA-/ day of October, 2013. Encl. ik- • S • ye'14:r\ RECEIVED STATE OF ALASKA 0 2 2013/ ALASKA OIL AND GAS CONSERVATION COMMISSION hT S 101 q/ (3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair We❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pun Tubing. Time Extension❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing] I Other. Run Kill String l]. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development El_ 195-145• 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic CI Service CI 6.API Number: Anchorage,Alaska 99503 50-733-20114-01. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Granite Pt St 42-23RD• Will planned perforations require a spacing exception? Yes ❑ No❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018761 • Granite Point Field/Middle Kenai Oil• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 13,940 . 10,421. 13,734 . 10,398. 13,734'(cement) 12,500'(fill), Casing Length Size MD ND Burst Collapse Structural Conductor 371' 18" 418' 418' Surface 3,321' 13-3/8" 3,995' 3,368' 3,090 psi 1,540 psi Intermediate 7,187' 9-5/8" 7,234' 5,469' 5,750 psi 3,090 psi Production 13,516' 7" 13,563' 10,373' 8,160 psi 7,020 psi Liner 282' 5" 13,740' 10,399' 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic , See Attached Schematic 2-7/8" 6.4#/L-80 11,202 Packers and SSSV Type: HES"VSR"Pkr Packers and SSSV MD(ft)and ND(ft): 11,131'MD,9,056'ND CAMCO TRSSV"X"Profile 329'MD,329'ND . 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphi[J Developmentt l]• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/25/13 Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylorahilcori .com Printed Name Dan T,,gre ' Title Operations Engineer Si.nature _,A11111' Phone 907-777-8319 Date 9/30/2013 �' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31.3—5/3- Plug Integrity ❑ BOP Test CC/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,.CO /1 . ...c.,„,„"&-/ cip 02,c.ra.49 r 7 (.4-.1-J reet.‘._ 'e)e- P"' Y. � ���+ S OCT 1 0 2Q Spacing Exception Required? Yes ❑ No Ld Subsequent Form Required: Q-yoy � / APPROVED BY Approved by: f-i �v✓ COMMISSIONER THE COMMISSION IGINAL Date: /Q— -f 3 Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate S • Well Prognosis Well: GP-42-23RD Hilcorp Alaska,L.■ Date:09/30/2013 Well Name: Granite Point St#42-23RD API Number: 50-733-20114-01 Current Status: Oil Producer Leg: 3 Estimated Start Date: October 25, 2013 Rig: N/A Reg.Approval Req'd? Moncla Rig 301 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 195-145 First Call Engineer: Dan Taylor (907) 777-8319 (0) (907) 947-8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: -2,100 psi @ 9,150' TVD Pressure build up test May 2011 Maximum Expected BHP: -2,100 psi @ 10,180' ND Pressure build up test May 2011 Max.Allowable Surface - 1,185 psi Based on BHP = 2,100psi and gas Pressure: filled well with gradient= 0.1 psi/ft Brief Well Summary The GP 42-23RD was drilled and completed as a gas lifted oil well in the Tyonek sands in 1996. It is currently producing 316 bpd with a 13%water cut. The current recompletion plan is to pull the gas lift completion and install a kill string in preparation for future well stimulation. Pre-Rig Up 1. Prior to rig move, stop lift gas to well and bleed off casing pressure. 2. Shoot fluid level. Procedure 1. Set back pressure valve in profile. / VC_ Kt...;F bf a. Inspect and prepare BPV profile to accept a 2-way check valve. 2. Nipple down tree/nipple up BOP. MoNGL4 3 0/ 3. Pressure test BOP to 250 psi low/2,50 psi high as per AOGCC. a. Notify AOGCC 24hrs before BOPE test. b. Record pressures, fill out form 10-424 and submit. 4. Test Gas Alarms. 5. Double check all rams and valves, for correct operating position. ,7 6. Release tubing hanger and lay down. - IA s -F/s-- es-- a. If landing threads are corroded, clean profiles with Muriatic acid, a wire brush and/or wheel. 7. Pick up handling tools to pull 2 7/8" 6.4#BTC production tubing. 8. Pull out of seal anchor(11,130ft): a. Pull tubing to +/-5K over string weight(+/-71.2KIbs). b. Rotate 12-15 rounds to the right. c. If seals pull free move up hole+/-5ft and circulate one hole volume (+/-349 bbls). i. Continue to Step 9. d. If seals do not come free rig up jet cutter on e-line , run in hole to 1.5 joints above packer to (+/- 11,055ft) and cut tubing. i. Pull out of hole and rig down e-line. ii. Pull up hole+/-5ft and circulate one hole volume. iii. Go to step 10. 9. If seals pull free: a. Pull out of hole laying production tubing, SCSSV, control line, and gas lift mandrels. b. Continuously check for NORM. 10. If tubing was cut: a. Pull out of hole laying production tubing, SCSSV, control line, and gas lift mandrels. • • Well Prognosis Well: GP-42-23RD Hilcorp Alaska,LL Date:09/30/2013 b. Continuously check for NORM. c. Pick up overshot/jarring assembly. d. Trip in hole to top of tubing stub/engage fish/ pull and work anchor latch free. e. Pull out of hole, lay down seal assembly and overshot. 11. Insert Wear Bushing. 12. Pick up/make up packer milling assembly. • 13. Trip in hole to top of Halliburton VSR Packer at 11,131 ft 14. Burn over packer. 15. Wash and work packer down 20ft. 16. Circulate bottoms up and pull out of hole. 17. Pick up packer retrieving assembly. 18. Run in hole and spear fish. 19. Pull out of hole laying down retrieving assembly, Halliburton VSR packer, "X" nipple, and wireline re- entry guide. 20. Pick up and run in hole with hydrostatic bailer bottom hole assembly. 21. Work Bailer until full, drop bar for knock out sub, and pull out of hole. a. Repeat runs until full depth attained. 22. Pull out of hole and lay down bailer assembly. 23. Pick up 6in junk mill, 7in 29ppf casing scraper, and clean out assembly. 24. Trip in hole and clean out to top of 5in liner 13,458ft. 25. Circulate 2 bottoms up or until hole is clean. 26. Pull out of hole and lay down bottom hole assembly. 27. Pick up 4.25in junk mill and clean out assembly. 28. Run in hole and clean out to PBTD, 13 29. Circulate 2 bottoms up until hole is clean. 30. Pull out of hole and lay dawn bottom hole assembly. 31. Pick up and run in hole with 7in 29ppf test packer to 11,200ft. a. Test casiig to 1,500 psi for 30 min and chart. V 32. Pull out of hole with test packer and lay down the same. 33. Rig up e-line. 34. Pick up and run in hole with GR/CCL log to 13,725ft. a. Correlate on depth with provided GR/CCL log. 35. Pull out of hole with GR/CCL tools. 36. Rig down e-line. 37. Pick up and run in hole with 2 500ft of 2-7/8inaf_kill.string. �1 38. Land hangar. a. Test hangar to 2,000psi and chart 20min. 39. Set back pressure valve. 40. Nipple down BOP and install tree. 41. Remove back pressure valve. 42. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic • • Granite Point Platform Well #: GP 42-23RD SCHEMATIC Completion Date: 2/24/96 nir." arts,:,.Ili PTD: 195-145 API: 50-733-20114-01 RKB to Hanger=47' CASING DETAIL 4PI#5I-733-7.1,14-01,, Size WT Grade Conn ID Top Btm 1 18" 70.64 Conductor 47' 418' I [ 13 3/8" 61.04 1 55 12.515" 47' 3,995' 18" 9-5/8" 40&29443.54 N-80 8.755" 47' 7,123345'60 P 7" L-80 BTC 6.184" 47' 2 IS" 154 L-80 BTC 4.408" 13,458' 13,740' TUBING DETAIL 3 2-7/8" 6.44 L-80 BTC 2.441" 47' 11,202'al 13-3/8" 4 JEWELRY Z. 9-5/8" 5 No Depth ID Item III 6 FMC Tubing hanger w/Type"H"BPV Profile& 47' 2-7/8"BTC Top 7 1 329' 2.313" Camco TRSSSV"X" Profile SSSV 2 2,149' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 8 3 3,966' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 4 5,818' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 9 5 7,288' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 6 8,072' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 10 7 8,701' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 8 9,329' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 11 9 9,925' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 12 10 10,556' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel 13 P'I'r31 depth is@ 11 11,058' 2.347" 2-7/8"Camco"MMM"Gas Lift Mandrel =4 -t 12 11,100' 2.313" Halliburton"XA"Sliding Sleeve IN 14 13 11,131' 3.880" Halliburton"VSR"Packer 15 14 11,170' 2.313" Halliburton"X"Nipple 15 11,202' 2.445" Wireline Re-Entry Guide PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date TOF @ C-2 11,296' 11,350' 9,212' 9,263' 54' 6 2/20/1996 12,500' _ C-5 11,574' 11,724' 9,469' 9,600' 150' 6 2/20/1996 Approx. = C-6 11,838' 11,914' 9,692' 9,752' 76' 6 2/20/1996 6/1/2012 = C-7 12,190' 12,365' 9,955' 10,063' 175' 6 2/20/1996 = C-7 12,420' 12,524' 10,092' 10,143' 104' 6 2/20/1996 X X C-7 12,833' 12,885' 10,255' 10,267' 52' 6 2/20/1996 L C-7 12,922' 13,122' 10,274' 10,311' 200' 6 2/20/1996 7" = C-6 13,278' 13,426' 10,331' 10,352' 148' 6 2/20/1996 C-5 13,557' 13,725' 10,372' 10,397' 168' 6 2/20/1996 5"/ 1/17/03-2.20"Gauge Ring ran -Sat Down @ 12,610'WLM(12,651' KB). TD @ 13,940' PBTD @ 13,734' Revised by DMA 10-26-12 • Granite Point Platform H • Well #GP 42-23RD PROPOSED Completion Date: Future PTD: 195-145 mt.., 14.1:1 .:,.I.LI API: 50-733-20114-01 RKB to Hanger=47' CASING AND TUBING DETAIL Al P #50'33-20114-0' FF SIZE WT GRADE CONN ID TOP BTM. 1 18" 70.6# Conductor 47' 418' 13 3/8" 61.04* 1-55 12.515" 47' 3,995' 9 5/8" 40&43.5# N-80 8.755" 47' 7,234'KOP 7" 29# L-80 BTC 6.184" 47' 13,563' 5" 15# L-80 BTC 4.408" 13,458' 13,740' Tubing: 2-7/8" 6.4# 47' ±2,500' JEWELRY DETAIL NO. Depth ID Item 1 47' FMC Tubing hanger w/Type"H"BPV Profile&2-7/8"BTC Top L 7,234' it 1/17/03-2.20"Gauge Ring ran -Sat Down @ 12,610'WLM(12,651'KB). PERFORATION DATA ZONE TOP BTM TOP BTM AMT SPF DATE (MD) (MD) (TVD) (ND) C-2 11,296' 11,350' 9,212' 9,263' 54' 6 2/20/96 C-5 11,574 11,724' 9,469' 9,600' 150' 6 2/20/96 C-6 11,838' 11,914' 9,692' 9,752' 76' 6 2/20/96 C-7 12,190' 12,365' 9,955' 10,063' 175' 6 2/20/96 C-7 12,420' 12,524' 10,092' 10,104' 104' 6 2/20/96 C-7 12,833 12,885' 10,255' 10,267' 52' 6 2/20/96 C-7 12,922' 13,122' 10,274' 10,311' 200' 6 2/20/96 C-6 13,278' 13,426' 10,331' 10,352' 148' 6 2/20/96 C-5 13,557' 13,725' 10,372' 10,397' 168' 6 2/20/96 g XI L 13,563' TD @ 13,940' PBTD @ 13,734' Updated by:.ILL 09/30/13 • • • • ll Granite Point Platform Rental BOP 03/11/2013 Hilenrp;►Ixan.1.1.6. Granite Point Platform 2013 Workovers BOP Drawing(Moncla) 4.54' Hydril GK 13 5,°-5000 in 111 111,11111 III III ill 111 111 4.67' - CI ni _. ,�- 2 7/8-5 variables 13 5/8-5000 — Blind iii i hut] it1 it!lit 111 111 111; 2.00' 01 l cN'°, 2 1/16 5M Choke and Kill . nl Itullil' 1 valves II III I11 2.00 Drill deck 19.75' Riser 13 5/8 5M FE X 13 5/8 5M 413 API hub Top of wellhead @ 19.75'below deck S Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor @hilcorp.com> Sent: Monday,October 07, 2013 4:04 PM To: Schwartz, Guy L(DOA) Subject RE:GP 42-23RD (PTD 195-145) Guy, We are pulling the current completion in order to prepare it for later fracture stimulation. We currently have the west side crane on GPP down for repairs. We will need that in order to position our frac equipment. I expect that it will be repaired and fully functional by the time we finish fishing the well. However, if we are not we will need to place a kill string in the well before we can move on to other well operations. I did not place in the procedure the circulation of 6%KCL. Assuming the "XA" sliding sleeve will shift we will RIH and shift it and begin circulating (one annular volume"325bbls). Thank you Guy and please let me know if there is any other information you need. Regards, /�w 5-5P b C( b`" Dan Taylor Operations Engineer 217;9.13 Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mm aiitoLquy.schwartztyaiaska.gov_] Sent: Friday, October 04, 2013 11:48 AM To: Daniel Taylor Subject: GP 42-23RD(PTD 195-145) Dan, I can't quite follow your procedure for 42-23RD. Are you pulling the current completion in order to do a FCO only? Why run back in with just a kill string on not another GL string so you are ready to stimulate or put the well back on line. With just the kill string you lose the wells ability to flow. It was making 300 BOPD before. Also, in your beginning steps(no.5 or so) you should have KWF fluid circ around before you pull the hanger and know what your fluid level is. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 1 • • Chevron boosts Granite Point production Company reports improved platform performance following volcano- induced shut -in; Cook Inlet operators provide unit updates to state Wesley Loy � Cl�l For Petroleum News MOW DE Chevron is reporting improved performance from its Granite Point platform in Alaska's Cook Inlet following an unusual shut -in during 2009. Oil production "actually increased throughout the year" in 2010, rising from 530 barrels per day in January to 662 barrels in October, Chevron recently told the state in an update on the South Granite Point unit. The increase was the result of two major factors, Chevron said. First, the Granite Point wells continued to show improvement after being shut -in for over four months due to volcanic eruptions at nearby Mount Redoubt, on the west side of Cook Inlet, in 2009. Second, a more efficient use of gas lift helped improve well performance, Chevron said. "The Granite Point gas lift compressor was designed to lift much more fluid than the field is currently producing," Chevron told the state. "As wells have failed and production has declined over time, the compressor's output of gas lift gas has exceeded well demand. This has resulted in wells being overlifted which results in reduced fluid production." Attempts to reduce gas lift output in the past resulted in unstable compressor performance, Chevron said. The company overcame the problem by recycling excess gas through the gas lift valves in a pair of wells including GP 31 -13, which had been shut -in since 1990. "The ability to recycle as much as 4 mmcfpd of excess gas thru wells GP 31 -13 and GP- 50 allowed the gas lift gas volumes to be reduced in the remaining producers," Chevron 1s5_ MS said. "Well GP 42 -23RD showed the greatest benefit from reduced gas lift. The gas lift volume was reduced by 50% in this well which resulted in an increase in oil production of 70 bopd or a 46% increase over production at the higher gas lift rates. In September the owners agreed to a permanent restage of the compressor to reduce overall output and eliminate the need for cycling excess gas. This project will likely take place in the second quarter of 2011." • i Unocal, a Chevron subsidiary, operates the South Granite Point unit, in which ExxonMobil owns a share. First production from the unit was in 1967. Chevron's unit update also said the Hemlock oil reservoir is "a potential target for future development." Chevron operates most of Cook Inlet's offshore platforms. The company announced in mid- October, however, that it plans to sell its Cook Inlet assets as a package. Cook Inlet unit highlights Operators of several other Cook Inlet units recently provided updates to the state. Here are some highlights: • Pioneer Natural Resources reported completing well workover, diagnostic and testing operations at its Hansen 1A -L1 well in the Cosmopolitan unit during the period November 2009 through September 2010. The well was suspended. "Results of this work enhanced Pioneer's understanding of the reservoir and will be incorporated into future plans," Pioneer said. The Cosmopolitan unit takes in eight state leases and two federal leases in Cook Inlet offshore the west bank of the Kenai Peninsula. Pioneer has talked of a development that could peak at 8,000 barrels a day of oil production. • Marathon, in its 53rd plan of development and operations submitted Dec. 16, said it has no plans to drill new wells in its Kenai gas unit, but is contemplating other work. "Several existing wells in the field continue to be evaluated for non -rig remedial activities including the installation of velocity strings, foamer capillary strings and other de- liquefaction methods to assist with water removal, and improve gas production," Marathon said. • Chevron reported "on -going efforts to farm -out the Red prospect" in the Nikolaevsk unit on the Kenai Peninsula. • Marathon said it's working to "resolve ownership issues" related to the Spurr platform and its associated wells. "Marathon hopes that a resolution to this situation can be reached in time to facilitate the abandonment of Spurr wells in the 2012/2013 timeframe," the company said. The Spurr platform hasn't produced oil since 1992 and is slated for decommissioning. The question of who will pay the decommissioning costs has been the subject of a court fight. @.~)' lrll fíi\ ìTu. ~ îñì rÞ Q¿ u L~ ll. l1LJ u I~ n IE' ~ r~~ /E\ ¿f-.J lb LfJ \l) u \~ lFÜ / / i ! ! I í j / I I í FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATI ON COMMISSION August 24, 2004 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verifications Granite Point State 32-13RD, PTD 192-020 Granite Point State 42-23RD, PTD 195-145 Dear Mr. Johnson: On August 20, 2004, AOGCC Petroleum Inspector Lou Grimaldi witnessed "no flow tests" for Unocal's Granite Point State Wells 32-13RD and 42-23RD located on the Granite Point Platform. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy. There was only a slight flow of gas and no liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells 32-13RD and 42-23RD. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Granite Point platform. Sincerely, ~rg~ ' James B. Regg ~ 1 Petroleum Inspection Supervisor cc: Bob Fleckenstein MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg,. ? ~4 slu'/~ P. I. Supervisor \\~ l( DATE: August 20,2004 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: No-Flow Test Unocal, Granite Point platform 42-23 Granite Point Field PTD #195-145 NON-CONFIDENTIAL Friday, AUQust 20, 2004: I witnessed No-Flow verification on the Granite Point platform in the Granite Point Field, well #42-23. Following is a timeline and well status during test. 1115 Arrive location, Well 42-23 Shut-in at <1 psi 1200 Open well to flow meter @ 550 scf. 1205 Well flowing @ <180 scf. 1215 Well flowing @ bare whisper. Well shut-in @ <1 psi. 1315 Well Shut-in @ 2.5 psi, Open well to flow @ 1100 scf. 1320 Well Flowing @ 800 scf & 1.5 psi. 1325 Well flowing @ 300 scf & < 1 psi. 1330 Well flowing @ 300 scf & < .5 psi. 1335 Well flowing @ < 180 scf & <.5 psi. 1345 Well flowing gas at bare whisper. Shut well in. 1445 Well Shut-in @ 2.5 psi, open well to flow @ 1100 scf 1455 Well flowing @ < 180 scf. 1500 Well flowing @ bare whisper. 1530 Well flowing @ bare whisper. I turned well back over to production at this point. During this test there was no evidence of fluid made. SUMMARY: I witnessed No-Flow verification on UNOCAL's Granite Point Field well #42-23 on the Granite Point Platform. NON-CONFIDENTIAL CC: Dwight Johnson (UNOCAL) No-Flow GPF 42-23 08-20-04 LG.doc MEMORANDUM TO: Julie Heusser, ~;~ H' Commissioner 3)/~/o/ THRU: Tom Maunder, P. !. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 10, 2001 Safety Valve Tests Granite Point Platform Granite Point Field May 10, 20.0!; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of regular maintenance and much fresh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The SSSV on GP-50 failed to close. This is a repeat of the previous tests failure; I'expressed the AOGCC's concern for the repair & retest of the failures. The AOGCC test report is attached for reference. SummarY~ ! witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field, Granite Point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. Attachment: SVS Granite Point Pit. 05-10-01jc NON-CONFIDENTIAL SVS Granite Point Plt. 05-10-01jc Alasga Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Ted Medley AOGCC Rep: John Crisp Submitted By: John_Crisp . Date: Field/Unit/Pad: Granite Point Field &Plt. Separator psi: LPS 60 HPS 5/10/01 t i i . ii _1 i i i i :--.i_:i."'Well Da{a::-¢~;;, !:! :~: :$SV ssSV Retest ..... Well Type Ill I I I! II Well Permit Separ Set L/P Test Test Test Date oa, w~G, g~J, _Number Number PSI PSI Trip Code Code Code Passed G~SorC¥CnE l l-13RD 1911330i 60 40 33 e ~ -:4 P oiL i3-i3 1670210i 60 40 40 P e P ......... oiL 31-13 1660550 31-14RD2 10026601 ................ 3'1-23 1670840 ' '60 40 40i ~ i) " P ' OIL 32-13RD 1920200 60 40' ' 40 p ' P ' 'p' " OiL 42-23RD 1951450 "~0 '~0 34 e P e.... 0~L 44-14 1670620 60 40 36 P P P OIL 50 1920410 60 40 33 P P 8 oIL 51 1920q20 60 40 3~' 'e P P ' OIL 54 ' 1960130 '60 " 40 ' 54 e e '"P .... OIL Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.~% [2] 90 my Remarks: SSV on well 11-13 failed to hold DP.. ,This gate valve will be serviced & re-tested..._.SS: on well GP-50 failed to close, Ted Medley will contact Unocal Supervisors about iA',C3G.C. C'S concern for the repair & re-test of Ge50's SSSV. RJF 1/16/01 Page 1 ofl SVS Granite Point Pit. 5-10-01jc MEMORANDUM TO: THRU: Julie HeuSser,---~?' Commissioner TomMaunder, ~__-j-~~ P. I. SuPervis°r t)~,,. ~,-5,3c~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 7, 2000 FROM: John Crisp, Petroleum Inspector SUBJECT: Safety Valve Tests Granite Point Platform Granite Point Field December 7, 2000; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean Platform with sign's of regular maintenance and much fresh paint in evidence The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to w°rk with. The AOGCC test report is attaChed for reference. summary; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite Point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. Attachment: SVS Granite Point Pit. 12-07-00jc NON-CONFIDENTIAL SVS Granite Point Pit. 12-07-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report OPerator: nocal Operator Rep: Ted Medley AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Granite Point Field &Plt. Separator psi: LPS 60 HPS 12/7/00 Well Permit Separ Set L/P Test Test Test Date oil, WAG, GIN J, Number NUmber PSI PSI Trip Code Code Code Passed GAS or CYCLE ll-13RD 1911330 60 40 33 P P P OIL 13-13 1670210 60 40 37 P {r5-) P 12/8/00 OIL 31-13 1660550'~-~.~ ~ k-~ ~.\ ~,,~. 31-14RD2 1002660 31-23 1670840 661 4o 35 p P OIL , 32-13RD 1920200 60! 40 35 P P P OIL 42-23RD 1951450 60 40 40 P P P OIL 44-14 1670620 60 40 35 P P P OIL 50 1920410 60 ~ 40 35 P P ( 8 ) fn2,~s,~_\~,r~ OILi i51 1920720 60 40 35 P P ~ OIL i54 1960130 60 40 36 p p p " OIL'l Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.7% Elg0 r>av Remarks: Well 31023.is a no flow. 12/13/00 Page 1 of 1 SVS Granite Point Pit. 12-07-00jc.xls MATERIAL UNDER THIs COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 M PL A T E E W IA L UNDER I H IS M A R K E R C :LORIXMFILM.DO C PERMIT AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 02/25/98 DATA T DATA PLUS RUN RECVD T 95-145 7060 ~ GR [ 3~W3 ~ /~7~ 03/26/96 95-145 7061 ,-4~'~CET/CNL/GR/AMS /~C7.,-~ ~q7~/ 03/26/96 95-145 BRIDGE PLUG LI~SEPIA~ ~0%0''~ ''~V0~ 1 02/14/96 95-145 MUD LOG ~SEPIA. 7~)- ---)5~'/~ 02/14/96 95-145 CN/GR ~L/MYLAR G ~0 -- / ~;~3k 1 02/23/96 95-145 SQUEEZE DERF ~/MyLAR /6/~00 ~- ;~60 1 02/23/96 95-145 GR ~/~MYLAR [%~OO -q)~gTk 1 02/23/96 95-145 CET/GR ~tf/MYLAR Q ~ ~0 - /2J-3 k 1 02/23/96 95-145 PERF DEPTH ~L~FILM-I%~oo -- [2f00 1 06/11/96 95-145 SS -9m~6 DRY ~S-~7260-13940 06/07/96 10-407 C~Pf'-COMPLETION DATE ~ ~//f~ / ~ 0~/~ / DAILY WELL OPS R /)~/2Q/gj~/ TO ~/2~[ /~-~[~;~/ Are dry ditch samples required? yes ~k And received? Was the well cored? yes ~ Analysis & description received? Are well tests required? lyes ~ Received? Well is in compliance .~ Initial COMMENTS .r Unocal Energy Resources Di 909 West 9th, P.O. BOX 1962-,. Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 NO£AL C~erk DATA TRANSMITTAL 96-13 June 6.1996 To: Howard Oakland 3001 Porcupine I Anchorage, AK 99501 L..A!aska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. Granite Point / Anna-21 Granite Point / Anna-26 Granite Point / Anna-36 Granite Point / 42-23 RD Trading Bay Unit K-26 RD Trading Bay Unit M-5 Trading Bay Unit M-25 Trading Bay Unit M-25 Trading Bay Unit G-21 Trading Bay Unit G-21 Trading Bay Unit G-21 Trading Bay Unit G-21 Tradinq Bay Unit G-21 Trading Bay Unit G-21 Trading Trad,ng Trading 9ay Unit G-21 May Unit G-21 Bay Unit G-21 I-~/~ c ~. 3 ~ -,4 filCf'~ blackline f'fl'm / blackline ~' ~m ,/blackline" blackline,/' fil .mq'blackline,,' ¢if"m / blackline~- Completion Record Tubing Packer Setting Record Completion' Record Perforating Depth Control Main Pass (Collar Locator) Completion Record ~ / blackline,-- ~ / blackline~ I~,~blackline~' f~¢'/blackline--'1 41'1'm / blackline.-"l I'/blackline~ / blackline--' I m / blackline~- /blacklin~-" ' / blackline,-' I blackline/' I cf I'm / blackline ,- ~ompletion Record ~Sompletion Record CCL/Gamma Ray Cement Retainer Completion Record Completion Record Completion Record 4/01/96 Gamma Ray/Temperature Tubing Cutter Completion Record 4~20~96 5/20~96 2/17/96 3/23/96 2/14/96 4~24/96 4~30~96 4/03/96 4~08~96 4/13/96 4/18/96 4/22/96 Completion Record 4/25/96 (",,--,,~r'~,-,!.-,.f;~ ~ 0 ~,-.,~,-,4 !~ -~, .,2...--_ ~. ~.,--, r-. ~,.., ,- ..~-.,--, 4/; 0/96 4/08/96 5/17/96 P!e3se acknowledge rgCeipt by §igning and/etuming one copy of this transmilt~al or FAX to (~07) 253-7828. Received by: Date: ........ Alsska 0il & 6as 6~ns. Cornm~sion Anci~orage Unocal Energy Resources DJ',._ zn 909 West 9th, P.O. BOX 196247 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96-10 June 4,1996 To: From: Howard Oakland Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal Transmitting the following items. Granite Point / 22-13 RD dry samples 6660 - 8400 Granite Point / 22-13 RD dry samples 8400 - 10200 Granite Point / 22-13 RD dry samples 10200 - 11370 Granite Point / 22-13 RD dry samples 11370 - 12036 Granite Point / 22-13 RD ST1 dry samples 11340 - 13320 Granite Point / 22-13 RD ST1 dry samples 13320 - 13821 Granite Point / 42-23 RD dry samples 7260 - 9270 Granite Point / 42-23 RD dry samples 9270 - 11100 Granite Point / 42-23 RD ST1 dry samples 11100 - 12900 Granite Point / 42-23 RD dry samples 12900 - 13940 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Union Oil Company of California (Unocal) 95-145 ~. Address ' 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20114431 4. Location of well at surface Granite Point Platform.' Eel~.l~3~'S[ol~ ~ :3 ...... ~ 9. Unit or Lease Name Granite Point Field At Top Producing Interval 11,296' MD/9209' TVD ~[~';~'/~(e i _ . .~,' ~-~.,:~;?~· :..~ ~ 10. Well Number 1547' FNL, 1745' FEL, Sec. 23, T10N, R12W, SM 'v'~[,-"~7..3 ~ 42-23 Reddll ADL 18761 At Total Depth 13940'MD/10416' TVD ~ ! i.. 'i 11. Field and Pool 12174' FNL, 1507' FWL, Sec. 23, T10N, R12W, SM --:._.. · Granite Point Field 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. Middle Kenai 115 RKB above MSL! ADL 18761 1~_ Date Sp.ddod la. Date T.D. Rea~h~ I 14. Date Co~p.. Suop. orA~nd, i 15. Water Depth. ,, o,~o~e I 16. ~o. or Comp,eti0n~ 12/26/95 1/27/96 2/24/96 75 feet MSL 1 17. Total Depth {MD*TVD) 18. Plug Baok Depth {MD+TVD) i 1~. Directional Survey ! 20. Depth where SSSV ~et I 21. Thiokale~s o[ Permafrost 13940'MD/10416' TVD 13734' MD/10394' TVD Yes: x No: 323' feet MD JN/A 22. Type Electric or Other Logs Run GR/CBT/CET/CNL/CCL 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18" 70.59 B 47 418' 456 ft3 0 13-3/8" 61 J55 47 3995' 2635 fi3 0 9-5/8" 43.5/40 S95/N80 47' 7234' Win 2200 fi3 0 7" 29 L80 47' 13563' 8-1/2" 1265 fi3 0 5" 15 L80 13456' 13740' 8-1/2" 144 It3 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) 3-3/8" TCP at 6 JSPF SIZE DEPTH SET (MD) PACKER SET (MD) Measured Depth True Vertical Depth 2-7/8" 6.4f¢ L-80 11202 11131 11296'-11350' 9209'-9260' 11574'-11724' 9465'-9596' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11838'-11914' 9688'-9748' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12190'-12365' 9951'-10059' 12420'-12524' 10088'-10139' None 12833'-12885' 10250'-10261' 12922'-13122' 10269'-1~ 13276'-13426' 10326'-10347' 13557'-13725' 10367'-103..q'z 27. PRODUCTION TEST ,, Date First Production I Method of Operation (Flowing, gas liE, etc.) 3/7/96I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS'OIL RATIO 3/28/96 12 TEST PERIOD => 216 129 50I 596 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. '135 670 24-HOUR RATE => 431 257 99 41 28. CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ORIGINAL Form 10-407 Rev. 7-1 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. C-2 Sand 11288 9204! C-5 Sand 11602 9494 C-6 Sand 11827 968zl C-7 Sand 12227 9979 C-7 (repeat) 13102 10307 C-6 (repeat) 13420 10351 C-5 Sand (repeat) 13656 10387 31. LIST OF Aq-I'ACHMENTS 32. I hereby"~ert~f;y that the f~recjPing~is true and correct to the best of my knowledge ~,_l?/~'' ' [/lJ~ [i~'~j~]* ' .i~ i '; J ~--~' i ' . , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 space 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 productin 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 GRANITE POINT PLATFORM GPP 42-23RD COMPLETION . . . . . . 2-7/8" 6.4# Lr80 BTC TBG 0' - 11,131' CAMCO TRSSSV "X" PROFILE ~ 329~ CAMCO MMM GLM #10 ~ 2149' CAMCO MMM GLM #9 (~ 3966' CAMCO MMM GLM #8 ~ 5818' CAMCO MMM GLM #7 (~ 7288' CAMCO MMM GLM ~6 ~ 8072' CAMCO MMM GLM #5 ~ 8701' CAMCO MMM GLM fi4 ~ 9329' 10. CAMCO MMM GLM #3 ~ 9925' 11. CAMCO MMM GLM #2 ~ 10556' 12. CAMCO MMM GLM #1 ~ 11058' 13. HES "XA" SLIDING SLEEVE 14. HES "VSR" PACKER ~ 11131' 15. 16. lIES "X" NIPPLE ~ 11170' WIRELINE RE-ENTRY GUIDE ~, 11202' PERFORATIONS VANN 3-3/8" 6 JSPF C-2 11,296' - 11,350' C-5 11,574' - 11,724' C.-6 11,838' - 11,914' C-7 12,190' - 12,365' 12,420' - 12,524' 12,833' - 12,885' 12,922' - 13,122' C-6 13,278' - 13,426' PBTD 13,734' TD 13.940' C-5 13,557' - 13,725' 18" 70.6//CASING ~ 418' 13-3/8" 61# J-55 CASING ~ 3995' 9-5/8" 40# & 43.5# N-80 CASING ~ 7234' KOP TOP OF 5" LINER (~ 13,458' T' 29//L-80 CASING F/13,563' - SURF. 5" 15# L-80 LINER F/13740' - 13,~45.8.~' ..... .-~ ... ? r:..,~ !Created by : jones Dote plotted : 29-Jan-96 Plot Reference is 4-2-25 Rd Veto;on j~12. Coordinates ore ~n feet reference slot t3--7. True Ve~,~dcal Depths ore reference RKB --- Baker Hugl'~s INTEQ --- 520O 0 0 0 KOP 0 Cxi 5600 .. (~ 6000 __ -1 8400 ('- 6800 UNOCAI Structure : GRANITE POINT Platform Well : 42-23Rd Field : Granite Point Field Location : Cook Inlet. Alaska <-- West 5700 5400 5100 4800 4500 4200 3900 5600 5300 I, II I I I I I I I I I I I I I I I I V 760O 80O0 840O 88OO 96OO I04( 10800 Begin Build & Turn Tgi ~1 - B/ C-7 Snd (F~r~l Projected Oat __ Tgt .~2 - TI) I I I I I 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 Scale 1 · 200.00 Verfical SecfJon on 220.14 azimufh wifh reference 0.00 N, 0.00 E from slof #$-7 3O0O I I Scale 1 · 150.00 270O 2400 2100 I I I I I 3000 3300 _3600 _5900 _ _4200 _ _45O0 _4800 _5100 _ _5400 _ .5700 I I V ir ............ SURVEY CALCULATION AND FIELD WL. .KSHEET ~ I . ' ' Job No. 0450-74225 Sidetrack No. 1 Page, ... 1 of .... 4 . I ..... il;iii~=.|:~1~ Company UNOCAL Rig Contractor & No. Nabors Alaska Drlng - Rig: #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP42-23RD Survey Section Name SIDETRACK- MWD j~jllllt~/~ .............. .... BHI Rep. TOM DUNN WELL DATA ..................... ' Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2391.74 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE] ssE~ Target Description Target Coord. E/W Slot Coord. F_/W 1372.03 Magn. Declination 22.290 Calculation Method MINIMUM CURVATURE ~_:Target Direction (DD) Build\Walk\DL per: lOOffr~ 30m[-] lOmE] Vert. Sec. Azim. 220.14 Magn. to Map Corr. 22.290 Map North to: OTHER SURVEY DATA ................. Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical ... ---Depth Angle Direction Length -TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FI') (Per lO0 Fr) Drop (-) Left (-) GMS 7236.00 46.18 212.64 5467.22 4073.37 -3420.07 -2261.64 TIE IN POINT 01 -JAN-96 MWD 7367.00 49.40 211.84 131.00 5555.22 4168.75 -3502.14 -2313.58 2.50 2.46 -0.61 Magnetic Interference , 01 -JAN-96 MWD 7473.00 46.70 211.64 106.00 5626.07 4246.75 -3569.10 -2355.17 2.55 -2.55 0.00 Magnetic Interference ...... 01 -JAN-96 MWD 7564.00 45.31 211.84 91.00 5689.28 4311.53 -3624.72 -2389.70 1.53 -1.53 0.00 Magnetic Interference 01-JAN-96 MWD 7659.00 42.21 211.84 95.00 5757.89 4376.54 -3680.53 -2424.36 3.26 -3.26 0.00 Magnetic Interference 01 -JAN-96 MWD 7754.00 39.02 211.84 95.00 5829.99 4437.73 -3733.06 -2456.98 ' 3.36 -3.36 0.00 - 02-JAN-96 MWD 7846.00 33.85 213,33 92.00 5903.98 4491.86 -3779.10 -2486,36 5.70 -5,62 1.62 - 02-JAN-96 MWD 7940.00 30,84 214.79 94.00 5983,39 4541.86 -3820.77 -2514.50 3,31 -3.20 1.55 - -- 02-JAN-96 MWD 8033,00 28.40 215,77 93.00 6064,23 4587.66 -3858.30 -2541,03 2,67 -2,62 1,05 02-JAN-96 MWD 8127.00 25.20 217.71 94.00 6148.13 4629.95 -3892.28 -2566.34 3.53 -3.40 2.06 - 03-JAN-96 MWD 8219.00 22.47 220.36 92.00 6232.27 4667.11 -3921.18 -2589.71 3.19 -2.97 2.88 03-JAN-96 MWD 8313,00 19.79 220.37 94.00 6319.95 4700,99 -3946.99 -2611.66 2.85 -2.85 0.01 03-JAN-96 MWD 8407.00 17.97 218,42 94,00 6408.89 4731,40 -3970,48 -2630.98 2,05 -1,94 -2.07 03-JAN-96 MWD 8501.00 15.61 216.16 94.00 6498.87 4758.51 -3992,06 -2647.45 2,60 -2.51 -2,40 03-JAN-96 MWD 8594.00 13.86 223.49 93.00 6588.82 4782.12 -4010.24 -2662.51 2.75 -1.88 7.88 - .'~ 03-JAN-96 MWD 8688.00 13.38 224.70 94.00 6680.18 4804.20 -4026.14 -2677.91 0.59 -0.51 1.29 - 03~JAN-96 MWD'.J 8783.00 13.17 226.08 95,00 6772.64 4825.92 -4041.46 -2693.43 0.40 -0.22 1.45 04-JAN-9~'~ MW~.. 8877,00 13,79 223,81 94.00 6864.05 4847.75 -4056,97 -2708.90 0.87 0.66 -2.41 04-JAN-96. M ,D~'~ 8969.00 13.95 226.43 92.00 6953.37 4869.72 -4072.53 -2724.53 0.70 0.17 2.85 - 04-JAN-9(~ MWb'~. ',,_. 9064.00 14.09 221.43 95.00 7045.54 4892.66 -4089.09 -2740.48 1.28 o. 15 -5.26 · · 04-JAN-96:' MWD, i 9159,00 14,01 210.63 95,00 7137.71 4915.57 -4107.66 -2753,99 2.76 -0.08 -11.37 04-JAN-96 MWD..· .." 9253.00 13.95 211.70 94.00 7228.93 4938,00 -4127.09 -2765.74 0,28 -0.06 1,14 .... 04-JAN-96~ MWD 9346.00 13.86 205.23 93.00 7319.21 4959.85 -4146.71 -2776,38 1.67 -0 10 -6.96 04-JAN-96 MWD 9438.00 13.77 205,57 92,00 7408,55 4981,10 -4166.55 -2785.80 0.13 -0,10 0.37 i SURVEY CALCULATION AND FIELD W~,. ,KSHEET Job No. 0450-74225 Sidetrack No. 1 Page 2 of ..4.,_ Company UNOCAL Rig Contractor & No. Nabors Alaska Drlng - Rig: #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP42-23RD Survey Section Name SIDETRACK- MWD BHI Rep. TOM DUNN WELL DATA I Target TVD (FO Target Coord. N/S Slot Coord. N/S -2391.74 Grid Correction 0.000 Depths Measured From: RKB ~ MSL['-] SS~ Target Description Target Coord. E/W Slot Coord. ENV 1372.03 Magn. Declination 22.290 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30mD lomE~ Vert. Sec. Azim. 220.14 Magn. to Map Corr. 22.290 Map North to: OTHER i i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+)/W(-) DL Build (+) Right (+) Comment ,, Type Drop (-) Left (-) (FO (DD) (DD) (FT) (FO (FO . . (FO (Per 100 FT) · 04-JAN-96 MWD 9530.00 13.61 205.73 92.00 7497.93 5002.18 -4186.18 -2795.23 O. 18 .43.17 0.17 ,,, 06-JAN-96 MWD 9628.00 12.97 208.91 98.00 7593.31 5024.14 -4206.20 -2805.55 0.99 -0.65 3.24 06-JAN-96 MWD 9723.00 11.97 212.49 95.00 7686.07 5044.36 -4223.84 -2816.00 1.33 -1.05 3.77 06-JAN-96 MWD 9818.00 11.55 211.22 95.00 7779.08 5063.52 -4240.28 -2826.22 0.52 -0.44 -1.34 06-JAN-96 MWD 9914.00 10.58 213.08 96.00 7873.29 5081.76 -4255.88 -2836.01 1.08 -1.01 1.94 , , 06-JAN-96 MWD 10008,00 10,54 211,13 94,00 7965,70 5098,81 -4270,48 -2845,16 0,38 -0.04 -2,07 06-JAN-96 MWD 10104,00 10.98 216,55 96.00 8060,01 5116,61 -4285,34 -2855,15 1,15 0,46 5,64 06-JAN-96 MWD 10197,00 10.95 229,12 93,00 8151,33 5134.18 -4298,23 -2867,10 2,57 -0.03 13,52 06-JAN-96 MWD 10292.00 11.06 235.08 95.00 8244.58 5151.89 -4309,35 -2881,40 1.20 0,12 6,27 06-JAN-96 MWD 10388,00 11.1 5 242,76 96,00 8338,79 5169,36 -4318.88 -2897,20 1.54 0.09 8,00 07-JAN-96 MWD 10416.00 11.26 244,00 28.00 8366,26 5174,36 -4321,31 -2902,06 0.94 0,39 4,43 08-JAN-96 MWD 10510.00 12.28 242.62 94.00 8458.28 5191.99 -4329,93 -2919.19 1,1 2 1.08 -1.47 ,_ 08-JAN-96 IVIWD 10605.00 14.15 238.04 95.00 8550.76 5212.38 -4340.73 -2938.01 2.25 1.97 -4.82 ~" 08-JAN-96 MWD 10702.00 15.38 240.49 97.00 8644.56 5235.72 -4353.34 -2959.27 1.42 1.27 2.52 08-JAN-96 MWD 10796.00 16.13 240.31 94.00 8735.03 5259.66 -4365.95 -2981.46 0.80 0.80 -0.19 ,, ,08-JAN-96 MWD 10892.00 17.63 237.54 96.00 8826.89 5286.06 -4380.36 -3005.31 1.77 1.56 -2.88 0~-JAN-96 M~ 10985.00 18.10 237.50 93,00 8915,41 5313,28 -4395,68 -3029,38 0,50 0,50 -0,04 .. 09-JAN';~ MV~[~ 11080,00 18,95 238,71 95,00 9005,48 5341,99 -4411,62 -3055,01 0,98 0,89 1,27 '-09-JAN-~ MWD :i 11176,00 19.26 239,73 96,00 9096,20 5371,68 -4427,70 -3082,00 0,47 0,32 1,06 ! 0-~JAN-96' M~)". 11271,00 18,89 241,62 95,00 9185,98 5400,76 -4442,90 -3109,07 0.76 -0,39 1,99 10~AN-96 MWD" 11365.00 20,03 240,07 94,00 9274,61 5430,05 -4458,17 -3136,41 1,33 1,21 -1,65 10-JAN-96 MW.D,.` 11459.00 23.31 239.32 94,00 9361,95 5462.76 -4475.69 -3166,36 3,50 3,49 -0.80 10-'JAN-96 MWD 11555,00 25,68 243,95 96.00 9449.31 5499.74 -4494.52 -3201.39 3.18 2,47 4,82 .. . 12-JA N-96 MWD 11637,00 28,48 243.56 82.00 9522,32 5533,94 -4511,04 -3234.87 3.42 3.41 -0.48 -' [I~ 'JI Company UNOCAL Rig Contractor & No, Nabors Alaska Drlng - Rig: #156 Field GRANITE POINT FIELD Well Name & No, GRANITE POINT PLATFORM/GP42-23RD Survey Section Name SIDETRACK- MWD BHI Rep, TOM DUNN WELL DATA · , Target TVD (F'r) Target Coord, N/S Slot Coord, N/S -2391,74 Grid Correction O,O(X) Depths Measured From: RKB ~ MSL~ SSI~ Target Description Target Coord. E/W Slot Coord, F_./W 1372,03 . Magn, Declination 22,290 Calculation Method MINIMUM CURVATURE 'Target Direction (DP) Build\Walk\DL per: lOOft~ 30mI~ 1OmOVert, Sec, Azim, 220,14 Magn, to Map Corr, 22,290 Map North to: OTHER ......... sURVEY DATA ......... , , Survey Survey Incl, Hole Course Vertical Total Coordinate' Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) ,,(Fr') (FT) (Per 100 FT) Drop (-) Left (-) 12-JAN-96 MWD 11724,00 34,00 241,62 87,00 9596,68 5575.64 -4531,85 -3274.87 6.45 6.34 -2,23 13-JAN-96 MWD 11820,00 37,10 245,46 96.00 9674,78 5626,81 -4556,64 -3324,84 3,98 3,23 4,00 13-JAN-96 MWD 11916,00 38,38 246,12 96,00 9750,70 5679,78 -4580,73 -3378,44 1,40 1,33 0,69 ,, 15-JAN-96 MWD 12005,00 40,37 245,46 89,00 9819,49 5730,67 -4603,89 -3429,93 2,28 2,24 -0,74 15-JAN-96 MWD 12099,00 44.14 245.85 94,00 9889,05 5787,70 -4629,94 -3487.51 4,02 4,01 0,41 16-JAN-96 MWD 12194,00 48.50 247,43 95,00 9954,65 5849,16 -4657,14 -3550,57 4,74 4,59 1,66 17-JAN-96 MWD 12274,00 51,53 247,45 80,00 10006,05 5903,62 -4680,65 -3607,17 3,79 3,79 0,02 17-JAN-96 MWD 12369,00 56.26 246,86 95,00 10062,02 5971,98 -4710,46 -3677,88 5,00 4,98 -0,62 18-JAN-96 MWD 12465.00 60.39 247.88 96.00 10112.42 6044.60 -4741.87 -3753,28 4.40 4.30 1,06 18-JAN-96 MWD 12561,00 63,77 250,20 96.00 10157,37 6118,83 -4772,18 -3832,48 4,12 3,52 2,42 18-JAN-96 MWD 12655,00 67.60 251,30 94',00 10196,06 6192,54 -4800,40 -3913,34 4,21 4,07 1,17 19-JA N-96 MWD 12742.00 71.91 251.81 87.00 10226.16 6262.18 -4826,22 -3990,76 4.98 4.95 0.59 ~,_ 20-JAN-96 MWD 12838,00 77.00 254.26 96,00 10251.88 6339,79 -4853,17 -4079.19 5.84 5.30 2,55 22-JAN-96 MWD 12917,00 78.33 254.57 79,00 10268,76 6403,56 -4873,91 -4153.53 1.73 1,68 0.39 22-JAN-96 MWD 13012.00 79.28 254.09 95.00 10287.21 6480,65 -4899,08 -4243.26 1,12 1,00 -0,50 23-JAN-96 MWD 13108.00 80.50 254.23 96.00 10304.06 6558,98 -4924,87 -4334.17 1,28 1,27 0,14 23-JAN;96 MWD 13203.00 83,35 256,05 95.00 10317,40 6636.02 -4948,99 -4425.08 3,55 3.00 1,92 23-jAN~96 . MWD ?.'-;t~2<:JS,00 82.67 258.30 95,00 10328,96 6711,28 -4969,92 -4517,01 2,46 -0,72 2,37 - 24-al_AN'96 'I~WD. ~ '. ~ .~3~3~ 91..00 80.81 258.63 93.00 10342.32 ~783.48 -4988.32 -4607.18 2.03 -2.00 0.~ !., 24-~AN~96 .K, IWD ;'1'3486.00 81.40 260.13 95.00 10357.01 ~8~.17 -5005.~ -4699.43 1.68 0.~2 1.58 . , . 27-dAN-96 MWO -ii 3~86.00 81.27 ~62.00 100.00 10372.08 ~930.8~ -5020.97 -4797.08 1.8~ -0.13 1.87 .... 26-dAN~9~ I~WD i.l'~::,~k3.00 80.49 260.01 97.00 1038?.46 7003.29 -5035.94 -4891 .~7 2.18 -0.80 -2.05 · . . 2?-dAN-96 MWD '13~.00 85.39 2~1.31 94.00 10399.01 7074.18 -5051.07 -4963.~9 §.39 5.21 1.38 2?-dAN-9~ MWD 1 ~870.00 83.01 262.00 93.00 10408.41 7143.45 -5064.50 -5075.23 2.66 -2.~ 0.74 " SURVEY CALCULATION AND FIELD WL,.,KSHEET Job No. 0450-74225 Sidetrack No. 1 Page 4 of 4 Company UNOCAL Rig Contractor & No. Nabors Alaska Drlng- Rig: #156 Field GRANITE POINT FIELD Well Namo & No. GRANITE POINT PL~TFORM/GP42-23RD Survey Soction Name SIDETRACK- MWD BHI Rep. TOM DUNN !~ WELL DATA ' Target 'I'VD (~-r~ Target Coord, N/S Slot Coord. N/S -2391.74 Grid Correction 0.000 Depths Measured From: RKB ~ MSL [-] SSI- Target Description Target Coord. E./W Slot Coord. E/W 1372.03 Magn. Declination 22.290 Calculation Method MINIMUM CURVATURE Target Direction (DD) Builc~Walk\DL per: lOOff[~ 30m~ 1Omi"] Vert. Sec./~im. 220,14 Magn. to Map Corr, 22.200 Map North to: OTHER SURVEY DATA -,, Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'B/D Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) ,(DD) (FT) (FT) (FT) (FT) (Per lO0 FT) Drop (-) Left (-) t- 27-JAN-96 MWD 13902.00 83.58 262.00 32.00 10412.14 7167.12 -5068.92 -5106.70 1.78 1.78 0.00 27-JAN-96 MWD 13940.00 84.20 262.00 38.00 10416.19 7195.26 -5074.18 -5144.12 1.63 1.63 0.00 Projected Data - NO SURVEY : ,, · ,,~ · ,: : _ ., - ... GRANITE POINT FIELD GPP #42-23 ADL 18761 REDRILL DAY 9 (12/26/95) ACCEPT RIG F/22-13RD @ 0600 HRS 12/26/95. PRESSURE TEST TREE, OK. ND SAME, NU RISER AND BOP. DAY 10 (12/27/95) TEST BOP, HUB CONNECTION LEAKING. NP BOP & REPLACE APl RING. NU BOP. TEST BOP. RIH W/GAUGE RING & JUNK BASKET ON WL. RIH & SET ClBP @ 7260' ON WL. RIH AND SET CIBP AT 7260' ON WL. PU WHIPSTOCK W/MWD AND RIH. DAY 11 (12/28/95) CONT. RIH WI WHIPSTOCK TO 7100'. CHANGE OVER TO OBM. ORIENT WHIPSTOCK AND SET SAME AT 7258'. SHEAR OFF WHIPSTOCK AND MAKE STARTER MILL RUN F/7236' - 7238'. POOH. -DAY 12-15 (12/29/95- 1/1/96) CONT. POOH LD 3-1/2" DP. LD BHA #1. STARTER MILL LOOKS O.K. PU WINDOW MILL BHA & RIH. MILL F/7234' - 7244' MILL APPEARS TO BE ROLLING OFF WINDOW. POOH. RIH W/STRING MILL BHA, DRESS AND ELONGATE WINDOW & DRILL F/7246' - 7266'. CONDUCT LOT, 12.2 EWM. POOH. RIH W/STEERABLE DRILLING ASSBY W/PDC BIT. DRILL 8-1/2" HOLE F/7266' - 7552'. HIGH TORQUE AND TROUBLE GETTING WEIGHT TO BIT. POOH. BIT 1/2" OUT OF GAUGE, SCARRED BHA. RIH W/STIFF MILL ASSBY & DRESS WINDOW. POOH. RIH W/DRILLING ASSBY. DRILL 8-1/2" HOLE F/7552' - 7845'. DAY 16 (1/2/96) DRILL 8-1/2" HOLE F/7845' - 8194'. OBSERVED 750 PSI LOSS IN PUMP PRESSURE. POOH. FOUND PUMP OUT SUB WASHED OUT. RIH W/NEW BIT. .,_ ~:: ;'- ~,' .. '~ .~ !- . GP 42-23 Page 2 DAY 17 (1/3/96) CONT RIH. REAM 120' TO BTTM. DRILL 8-1/2" HOLE F/8194' - 8851' DAY 18 (1/4/96) DRILL 8-1/2" HOLE F/8851' - 9573'. DAY 19- 21 (1/5/96- 1/7/96) DRILL 8-1/2" HOLE F/9573' - 9605'. POOH F/BIT. DRILL 8-1/2" HOLE F/9605' - 10429'. POOH F/BIT & BHA. DRILL 8-1/2" HOLE F/10429' - 10525'. DAY 22 (1/8/96) DRILL 8-1/2" HOLE F/10525' - 10975'. DAY 23 (1/9/96) DRILL 8-1/2" HOLE F1 10975' - 11038'. POOH F/BIT. DRILL 8-112" HOLE F/11038' - 11230'. DAY 24 (1/10/96) DRILL 8-1/2" HOLE F/11230' - 11601' DAY 25 (1/11/96) TRIP F1 BIT. DRILL 8-1/2" HOLE F1 11601'- 11675'. TRIP F/BIT DUE TO SLOW ROP. DAY 26 - 28 (1/12/96 - 1/14/96) CHANGE OUT BIT AND RIH. DRILL 8-1/2" HOLE F/11680' - 12019'. POOH F/BIT. DRILL 8-1/2" HOLE F/12019' - 12033'. MWD NOT WORKING. DAY 29 (1/15/96) POOH TO CHANGE OUT MWD. DRILL 8-1/2" HOLE F/12033' - 12218' ~.~.. : . -'; ii ' · ( ~.~.. .. GP 42-23 Page 3 DAY 30 (1/16/96) DRILL 8-1/2" HOLE F/12218'- 12314'. ENCOUNTERED HIGH PUMP PRESSURE. POOH TO CHANGE OUT MOTOR. DAY 31 (1/17/96) CONT. TRIP TO CHANGE OUT BIT AND MOTOR. DRILL 8-1/2" HOLE FI 12314' - 12468'. DAY 32 (1/18/96) DRILL 8-1/2" HOLE F/12468' - 12675'. DAY 33 - 35 (1/19/96 - 1/21/96) DRILL 8-1/2" HOLE F/12675' - 12726'. TRIP F/BIT. F/12726' - 12961'. TRIP F/BIT. DRILL 8-1/2" HOLE DAY 36 (1/22/96) CONT. TIH W/BIT #12. DRILL 8-1/2" HOLE F/12961'- 13108'. DAY 37 (1/23/96) DRILL 8-1/2" HOLE F/13108' - 13339'. DAY 38 (1/24/96) DRILL 8-1/2" HOLE F/13339' - 13537'. CCH F/BIT TRIP. DAY 39 (1/25/96) CONT CCH. TOH F1 BIT. HOLE APPEARS TO BE KEY SEATING 7830' - 7750'. TIH W/BIT. DRILL 8-1/2" HOLE F/13537' - 13579'. DAY 40 - 42 (1/26/96 - 1/28/96) DRILL 8-1/2" HOLE F/13579' - 13672'. LSOT 150 BBLS MUD @ 13672'. STRING IN LCM & STOPPED LOSSES. DRILL 8-1/2" HOLE F/13672' - 13940'. MOTOR FAILED. CONFIRED W/TOWN & CALLED TD. CCH F/LOGS. SPOT LCM PILL ON BOTTOM. TOH. RU WIRELINE LOGGERS & RIH W/RUN #1. GP 42-23 Page 4 DAY 43 (1/29/96) CONT RIH W/RUN #1, SET DOWN @ 7330'. POH & INSERTED KNUCKLE. RIH W/RUN #1, SET DOWN @ 7330', COULD NOT WORK ANY DEEPER. POOH F/PCL TOOLS. RIH W/PCL TOOLS, SET DOWN @ 7328', COULD NOT WORK DEEPER. CONFIRED W/TOWN & DECIDED TO FOREGO OPEN HOLE LOGS. POOH LD PCL TOOLS. DAY 44 (1/30/96) RIH W/CLEANOUT BHA. SET DOWN @ 7330' & WORKED THROUGH. CONT RIH & SET DOWN @ 7838' & WORKED THROUGH. CONT RIH. HUNG UP PIPE IN COAL @ 10675', JAR FREE. TOH & CHANGE BHA. RIH. DAY 45 (1/31/96) CONT RIH. HUNG UP PIPE IN SAND @ 11672', JAR FREE. WASH & REAM F/11672' - 13228'. DAY 46 (2/1/96) 9.6 PPG COMPLETE REAMING TO BOTTOM. PUMP HI WEIGHT/HI ViS SWEEP TO CLEAN HOLE. SHORT TRIP TO WINDOW WITH MINOR OVERPULL. NO PROBLEMS, RIH. CIRCULATE WELL CLEAN. DAY 47 -49 (2/2~96 - 2/4/96) POOH LD CLEANOUT ASSBY. CHANGE RAMS IN BOP & TEST SAME. RUN 7" CASING TO SHOE. CCH. CONT RIH W/7" CASING, BROKE ClRC @ 12662'. CONT RIH W/7" CASING. STUCK CASING @ 13563'. LOST CIRCULATION WHILE ATTEMPTING TO FREE CASING, UNABLE TO MOVE PIPE. CEMENT 7" CASING W/225 BBLS CMT, NO RETURNS. BUMP PLUG, FLOATS HELD. BROKE OFF RISER & BOP. SET SLIPS, CUT OFF CASING, & INSTALL & TEST PACKOFF & TUBING SPOOL. NU & TEST BOP. DAY 50 (2/5/96) LD 5" DRILL PIPE. MU CLEANOUT ASSEMBLY. GP 42-23 Page 5 DAY 51 (2/6/96) RIH W/6" CLEANOUT ASSEMBLY PU 3-1/2" DRILL PIPE. CHANGE OVER TO 9.6 PPG BRINE. DAY 52 (2/7/96) CONT CHANGE OVER TO 9.6 PPG BRINE. WASH DOWN F/13230' - 13480'. TAG FRIM CEMENT @ 13480'. PRESSURE TEST CASING TO 3500 PSI F/30 MINUTES. POOH. RIH W/PERF GUNS ON DRILL PIPE TO 10687'. PUMP IN WET CONNECT. DAY 53 (2/8/96) GR LOG F/10750' - 13465'. PERF 7" CASING @ 13072' - 13068'. EST INJ @ .5 BPM & 1034 PSI, NO RETURNS TO SURFACE. ATTEMPT TO PUMP DOWN 7"X 9-5/8" ANNULUS W/O SUCCESS. PERF CASING 11182' - 11186'. POOH. RIH W/CEMENT RETAINER. DAY 54- 56 (2/9/96 - 2/11/96) SET CEMENT RETAINER @ 11236'. EST INJ INTO 11182'-11186' PERFS TAKING RETURNS THROUGH PERFS 13068'-13072' @ .5 BPM & 380 PSI. SI DRILL PIPE AND EST INJ INTO LOSS ZONE @ 5 BPM @ 2540 PSI. SPOT 520 SX CMT TO END OF DRILL PIPE, SHUT IN ANNULAR AND SQZ THROUGH PERFS 11182' - 11186'. POOH TO 9830', ClRC DRILL PIPE CLEAN, DOWN SQZ 16 BBLS CMT & WOC. POOH. RIH W/CLEAN OUT ASSBY. DRILL CMT & RET F/11106'- 11236'. PUSH RET TO BOTTOM. POOH. RUN CET/CNL/GR F/12522' - 7000'.RIH WI CLEANOUT ASSBY. DRILL ON RET @ 13476' DAY 57 (2/12/96) CONT DRILLING RET @ 13477' - 13481'. CLEAN OUT SHOE AND RATTY CEMENT F/13481' - 13720'. PUH & PERFORM LOT. LEAK OFF @ 1630 PSI, LOST 1080 PSI IN 15 MIN. RIH TO 13720'. CCH. GP 42-23 Page 6 DAY 58 (2/13/96) POOH W/CLEAN OUT ASSY FOR 5" LINER. P/U 5" LINER ON BAKER HMC LINER HANGER SYSTEM W/H-ISOLATION PACKER. RIH TOOK WEIGHT 5675'. ATTEMPT FREE NO SUCCESS. RUNNING TOOL CAME LOOSE. POOH RECOVER RUNNING TOOL, LINER LEFT IN HOLE. DAY 59 (2/14/96) PU FISHING ASSY #1: SPEAR W/4.23" GRAPPLE. RIH. ENGAGE FISH @ 5.414' & ATTEMPT TO JAR LOOSE W/NEGATIVE RESULTS. ATTEMPT TO BACK OFF PACKER SETTING SLEEVE. POOH. FOUND SPEAR HAD BACKED OFF AND WAS LEFT IN HOLE. RIH SCREW INTO SPEAR FISH AND WORK LINER FISH FREE. L/D FISHING TOOLS & LINER ASSY. 100% RECOVERY. PERFORMED WEEKLY BOPE TEST. MU 6" BIT & MUD MOTOR. RIH. DAY 60 (2/15/96) RIH W/5" C/OUT ASSY TO 7" SHOE AT 13,563. WASH TO 13,720'. POOH MU 7" SCRAPER ASSY. MILL & MOTOR. RIH TOOK WT THRU CASING COLLAR AT 13,048' - 13,563'. POOH. RIH W/5" LINER. DAY 61 -63 (2/16/96 - 2/18/96) RIH WI 5" LINER ON 3-1/2" DP TO 13720' DPM. CEMENTED SAME W/ 25 BBLS CLASS "G". SET HANGER & POOH. RIH W/6" BIT & CLEANED OUT CEMENT TO TOL @ 13458'. POOH. RIH W/4-1/8" MILL & CLEANED OUT CEMENT TO 13714' ETD DPM. RAN GR CORRELATION AND CORRELATED ETD TO 13734' WLM. CHANGE WELL OVER TO 3% KCL. POOH. DAY 62 (2/19/96) RIH W/2624' 3-3/8" TCP PERFORATING ASSEMBLY. PLACED GUNS ON DEPTH W/CHAMP PACKER @ 11141' WLM. RU TEST HEAD & MANIFOLD. GP 42-23 Page 7 DAY 63 (2/20/96) PERFORATED TYONEK @ 11296'-11350', 11574'-11724', 11838'- 11914', 12190'-12365', 12420'-12524', 12833'-12885', 12922'-13122', 13278'-13426', 13557'-13725' W/6 JSPF. FLOWED WELL 1 HR, FL ROSE 2200' . REVERSED OUT WATER CUSHION AND OIL RETURNS. COULD NOT RE-OPEN OMNI VALVE. PERFORATE DRILL PIPE @ 11050'. ClRC WELL W/DIESEL. DAY 64 (2/21/96) ._ UNSET PACKER & POH W/TCP ASSEMBLY. ALL GUNS FIRED. FOUND SAND IN GUNS AND OMNI VALVE. PU TAIL PIPE & PACKER AND RIH W/3-1/2" DRILL PIPE. DAY 65 (2/22/96) PLACE PACKER ON DEPTH @ 11131' DPM WITH END OF TUBING @ 11202' DPM. DROP BALL AND SET PACKER W/3500 PSI. TEST PACKER AND ANNULUS TO 2500 PSI. SHEAR OUT BALL AND POH LD 3-1/2" DRILL PIPE. RIH W/2-7/8" COMPLETION STRING. DAY 66 -67 (2~23/96 - 2~24/96) CONT RIH W/2-7/8" COMPLETION STRING. LATCH INTO PACKER @ 11131' AND TEST. SHEAR OUT SEAL ASSBY. SPACE OUT AND LAND TUBING. ND BOP, NU & TEST TREE. RIG RELEASED @ 0600 HRS 2/24/96. OFF REPORT. Unocal Energy Resources ~ion 909 West 9th, P.O. BOX 1 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96-7 March 26, 1996 To: From: Larry Grant Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal Transmitting the following items. GP 42-23 RD TAPE & LISTING FILE #1 GP 42-23 RD TAPE & LISTING MAIN LOG=FILE 1 REPEAT = FILE 2 Ii Please acknowledge rec~i~by si. gping and returning one copy of this transmittal or FAX to (907)26~8~.'i~'j V ~ D Received by: Date: ('~A~ 2 ~.; 19 6 A.~chora~e Unocal Energy Resources [' 'on 909 West 9th, P.O. BOX 1 Anchorage, AK 99519-6247 ................ , - ~-- .................. Telephone (909) 276-7600 ~-":i..,.. :... · ;. - · Fax (907) 263-7828 : Debra Childers C~erk t0: , L.a. rr,/Grant 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas 96- 5 February 21, 1996 From: Debra Childers 909 W. 9th Avenue Anch.orage, AK 99519-6247 Unocal Transmitting the following items. GP A-~ ' BLACKLiNE/FILM i 2/ 4/96' TUBING PACKER SETTIN~ RECORD ! A26 COIL TUBING W/O GP 42-23 RD 'BLA~3KLINE / FILM 2/11/96 cOMPENSATED NEUTRON / eR z... GP 42-23 RD BLACKLINE / FILM r"~./08/96 SQUEEZE PERFORATING RECORD .¢.... (:3P 42-23 RD 8LACKLINE / FILM 2/08/96 DRILLPIPE CONVEYED GAMMA RAY GP 42-23 RD BLACKLINE / FILM 2/11/96 CEMENT EVALUAT'I'ON LOG / GR~ Please acknowlec~e r~e~t by sig~ng and/~ping one ~y of Bis ~nsmi~l or F~ to (907) Date: .............. ...... --_-- ; :-~:---;: .... :"¢ '; i : ;: .......... .,..-.: ..... Unocal Energy Resour¢ 909 West 9th, P.O. BO',,. Anchorage, AK 99519-o'247 Telephone (909) 276-7600 Fax (907) 263-7828 'iv;" = q ~2~, Debra Childers Clerk DATA TRANSMITTAL 96- 4 February 13, 1996 To: Larry Grant 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Chiiders 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. SRU 32A-33 ~,/BLUELINE / SEPIA 12/5/95 PERFORATING RECORD SMGS #3 BLACKLINE / SEPIA 12/28/95 COMPLETION RECORD .SMGS #3 ~,dgLUELINE / FILM 1/9/96 COMPLETION RECORD GP 42-23 RD ~,dgLUELINE / SEPIA 12/27/95 BRIDGE PLUG SETTING RECORD GP 42-23 RD BLUELINE / SEPIA 12/29/95 MUDLOG - FORMATION SCU 43-4 ,/ BLUELINE / SEPIA 12/21/95 PERFORATING RECORD SCU 343-33 u/BLUELINE / SEPIA 12/5/95 COMPLETION RECORD SCU 321-9 ~/BLUELINE / SEPIA 12/21/95 PERFORATING RECORD 't 4 ' 996 Please acknowledge receipt by signing and returning one copy of this transmittal or.~.,~~~~ ....... Received by: Date: TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~DIISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 26, 1995 G. Russell Schmidt Union Oil Company of California P O Box 196247 Anchorage, AK 99519 Re: Well # Company Permit # Surf~.Loc Btmhole Loc Granite Pt Field 42-23 Redrill ADL-18761 Union Oil Company of California 95-145 2380'FNL, 1371'FWL, Sec 13, T1 ON, R12W, SM 2302'FNL, 1200'FWL, Sec 23, T1 ON, R11W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to re-ddll the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. David W Chairman BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ,---..STATE OF ALASKA ALASKA _AND ~S CONSERVATION COIV. $SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill [~ 1 lb. Type of well. Exploratory r-] Stratigraphic Test ~ Development Oil Re-Entry E:] Deepen ~I Service ~ Development Gas r~ Single Zone ~ Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 115' RKB above MSL feet Granite Point Field 3. Address 6. Property Designation Middle Kenai P.O. Box 196247, Anchorage, AK 99519 ADL 18761 4. Location of well at su'face GranitePt. PItLeg#3, SLot#7 7. Unit or property name 11. Type Bond (SEE 20 ACC 25.025~ 2380'FNL & 1371' FWL, Sec. 13, T10N, R12W, SM Granite Pt Field AK Statewide Oil & Gas Bond At top of productive interval 8. Well number Number 1871' FNL & 2077' FEL, Sec 23, T10N, R12W, SM 42-23 Redrill ADL-18761 U-8004647 At total depth 9. Approximate spud date Amount 2302' FNL& 1200' FWL, Sec. 23, TION, R12W, SM 11-30-95 $300,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (M~,,dTW) property line 3100 feet (Well #32-23) 493 feet 5089 13910' MD/lO600' 'rVD feet 16. To be completed for deviated wells 17. Anticipated Pressure(s=, 30AAC 25.035(,~(~) Kickoff depth 3995 feet 78 Maximu'n holeangle Ma~mumsurf, ce 1005 pslgAtto~depth(TVD) 4240 psi~ 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29 L80 3utt 11453 47' ~,7' 11500 9504 1200 cu. ft. 6" 5" 15 L80 Butt 2610' 11300' ;)337' 13910 10600 600 cu. ft. 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured 14544 feet Plugs (measured) true vertical 10777 feet Effective depth: measured 9581 feet Junk (measured) TOC proposed in P&A procedure. true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structu'al Conductor 381' 18" 456 cu.ft. 418 Surface 3958' 13-3/8" 2635 cu.ft 3995' ~.' "- - '~ ~ Intermediate 9974' 9-5/8" 2200 cu.ft 10011' ~..., l.~ i Production 3754' 7" 70 sx 9781 '- 13535' Liner 1211' 5" 2505x 13329'- 14540' StP '~ '~ Perforation depth: measured Plug & Abandoned per previous proposal. AjaSt~3 0[~ & Gas Cons. true vertical Anchorage 20. Attachments Filing fee ~1~ Property plat E~ BOP SketchE~ Diverter Sketch r-} Drilling program ~ Drilling fluid program ~[ Time vs depth plot [~ Refrac. tjpn analysis ~ Seabed report ~] 20 AAC 25.050 requirements 21. ! hereby certify that the foregoing iS, t~e and'c~t to~,~.best of my knowledge '--'.~"-';Signed Date ' Commission Use Only Permit Number APl number IApproval date ISee cover letter c~.,.~"_,,,//4Z_~z"' 50-,~'.J~,.~ - .~__0//~'---,C:~ / I ~" ~ ' ~'-' Ifor °ther recluirements Condition~ of approval Samples required r"] Yes .1~ No Mud Icg required ~ Yes ~ No Hydrogen suffide measures ~ Yes r~ No Directional survey required 1~' Yes ~] No Required workingpressureforBOPE ["] 2M; E~ 3M; ~ 5M; ~ 1OM; [--] 15M Other: '~r~inat Signed By bytheorder of ,., , Approved by W. Johnston Commissioner the commission Date ///'~Y}V Form 10-401 Rev. 12-1-85 cate SE?-25-95 NON 10' 43 UNOCAL - ANCHORAGE Granite Pt. 42-23 (Redrill, Tyonek C-7) AFE 751119 Option A "Cut & Pull Csg" Drilling Hazards: Lost Circulation zones: None Ab/Sub normal pressure zones: None Shallow Gas zones: None TimeEst, Cum Time Procedure: 1 1 0.5 1.5 2.75 4,25 1.5 5.75 2 7.75 0.5 8,25 0,5 8.75 2,6 11,25 1.5 12.75 15 27.75 1 MIRU R156, Leg #3, Conductor#7 & Kill well. 2 Remove tree, Install 13-5/8" BOPE and test same. 3 RU WL & cut tbg at 13000', circ out contaminated mud. 4 POOH and recover tbg. RIH with scrapers to TOF, 5 Abandon perfs with cement as required, Dispose of contaminated mud. 8 RU WL, run CBL, gyro, and csg inspection logs. 7 Set retainer at 4200' inside 9--518" 8 Cut & pull 9-5/8" csg from 4150'. 9 Lay kickoff plug from 4200' to 3800'. 10 Directlonaily drill 8-1/2" hole from approx 4000'-11500' (Top of C-5). ROP=900 fpd (f/3500'-7500') ROpe390 fpd (f/7500'-11500') KOP DL$ Angle Range 3995 3 56-33 0,75 28.5 2 30.5 7 37,5 11 Run open hole logs; DIL-Phasor-GR 12 Run & cement 7" casing back to surface. 13 Directionally drill 6" hole from ti 500'-i 3909'. ROP--350' KOP DLS Angle Range 11500 3 33-78 1,5 39 0.75 39.75 1,5 41,25 I 42.25 1 43,25 0.75 44 1 45 0.5 45.5 1 46,5 0.5 47 1 4B 14 Run ddllpipe conveyed logs; DIL-Phasor-GR~SP/LDT.CNL. 15 RIH, CCH for 5" liner 16 Run & cement 5" liner from 11300'-13909'. 17 Clean out inside 5" liner. 18 Run CET/GR log from ETD to TOC In 7" casing, 19 Install liner top packer & test "Draw-down" same. 20 PU 2-7/8'tubing, RIH. Change well overto dlese[. 21 Make up TCP guns / packer / GLM and single 2-7/8" tbg completion. 22 RIH w/2-7/8" tbg completion, land same. 23 Set BPV. Nipple down BOP's. Install wellhead. 24 Achieve underbalance, detonate guns. Release rig. Notes: Directional plan based on BHI version # 8 Cut & pull of the 9-518" is assumed to be achleveable. Approx 600+ rotating hours in the 9-5/8" csg 1Yom lhe odginal and workover, V, U~'/U5 Revised 9/22/95 REDRLEST.XLIS SEP ?~ 5 1995 A~as~.~ U'~ & Gas Cons. Commission Anchorage TT NOCAL j Strucfure : GRANITE POINT Platform Well : 44-23Rd J ' I i Irield : Granite Point FieldLocation : Cook Inl®t, .Alaska , i Point End of Drop End of Hold ~rorget T'orget End of Build Target End 0f Hold WELL PROFILE DATA ..... © 3000 O O .. 3600 _ ~ 4200 Wes± 6000 5500 5000 4500 4000 3500 5000 2500 2000 9cale 1 : 2..50.00 4800 0 5400 6000 KOP - Sidetrack Point 45.01 40.01 35.02 End Angle Drop '500 1000 500 6600 7200 _ -- 7800 _ - 8400_ -- 9000 _ 9600 _ 10200_ 10800_ 11400 MD Inc Dir ~/D North East DEL/1 5995 56.24 212.95 .3364 -1350 -935 0.00! 4899 33.66 214-.34 4-000 - 1879 - 17862.50i 10688 33.66 214.34 8818 -4528 -3996 O.OOi 11499 3..3.66259.05 9504 -4760 -3449 3.00~ 12172 48.66 259.05 10009 -4845 -3882 2.23! t3156 78.12 257.0, 10445 -5025 -,~ .3.0o, S 35.92 DEG W 15710 78.12 257.07 10559 -5147 -5251 0.001 15910 71~.12 ~7.07 10600 --5190 --5 ~-52 0.0o{ 7402'(TD) ***PLANE OF ProPOSAL*** //~ /? % ~ ,- ¢~'.~ ~.' ~ ~%J~~O*'/ .//Begin Turn_ to Target, {"--q 'e, e°o / SEC. 23, T1SN. R12W TD LOCATION: 2302'FNL, 1200' FWL AVERAGE33.66 DEGANGLE'X ~. ~,o., ~2w ,,\ Tgt ,1-'/ C:5- 7 Csg (Begin {qnc, Build)~.5~.::~ (Continue 5uild / Turn) ' .~ ?;ina, ~ EOC Tgt ~5 - T/ C5 ~2 ~~ TD - 5 Csg Pt KOP - 5;¢euack / End Angle 7 TARGET ANGLE 78.12 DEG _1000 - .. _1500 o g _2000 _2500 0 _ (-- ! _3000 -- _3500 I -- _4000 I V 4500 I I I I I I I I ~ I I I I i I I I I I I I I I I 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Scale 1 ' 300.00 VerticalSection on 215.92 ozimufh wifh reference 0.00 N, 0.00 W from sial #3-7 5000 55OO Created by : jones For: L LOHOEFER IOote plottea : 1J-Aug-95 Plot Reference is 42--2,3 Rd Version #8. Coordinates ore in feet reference slot #3-7.1 !True Vertice~ ,Depths ore reference RKB. I I V iCreated by :jones jDate plotted : 15-Aug-95 Plot Reference is 42--2,~ Rd Version #8. JCoordinates are in feet reference slot JTrue VerUcal Depths are referetqce RKB. --- Baker Hughes iNTEO --- Structure : GRANITE POINT Platform Well : 42-25 Field : Granite Point Field Location : Cook Inlet, Alaska <-- West lOO.OO 4000 3800 ZC--O0 5400 5200 3000 2800 2600 2400 2200 £:C0 1800 1600 1400 1200 tO00 800 600 I I I I I I I I I I ~ I I I I I I I I I I I I I I I I I I 92 _ 020~.~oo 9600( --~]00 - 1 ooo0L - 10400~00 _ 600 O0 4200 ./ ,~20 4600 0 /~400 4800 gO0 0 5200 / /~80 5400 ~00 b~O0 5~ - 6200~/' 10600 ~02~ -~ 7 82~8~ _ _ - ~2oo/~°~ ~~ ~2oo // .~o/ ~-~z S EP l l 1995 /~o o~oo/ //~ // 9800 / 8600 / ~ '-.~ ~ch0mga I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I 4000 3800 ~6~0 34~ 3200 3000 2800 2600 2400 2200 2CC0 1800 1600 1400 1200 1000 800 ;00 <-- Wesf · , o.oo ~missi0n -- i~reated by : jones iDote plotted : 13-Aug--95 iPIot Reference is 42--23 Rd Version ~Coordinates are in feet reference slot iTrue VerUcol Depths ere reference RKB. --- Baker Hughes INTEQ -U- OCAL Structure : GRANITE POINT Platform Well: 42-23 Field : Granite Point Field Location : Cook Inlet, Alaska < W e s f ~co,~ 1 ' 100.00 5600 5400 5200 5C~,..~4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 0 3200_ 0 0 .. 3400 3600_ _ 3800_ 4000. 4200_ (;- _ I 4400_ 0 4600_ _ 4800_ I J 5000_ V - 5200_ 5400_ 5600_ _ 5800_ _ 6000_ 6200_ _3200 o _ _3400 " CD _ _3600 CD CD 3800 i _I_.OO ~/~oo ..... ~ //~ooo,v~ h~oo / / ~0 4800 ~ ,/ - ~oa °o / ' _ ~2~ ~_-~°° 0 _ 5400 00 . ~ 5~00 ¢ ooo SEP 1 1 1995 ~ ~it ~ 6as Cons. Commission _~ooo oo '--~ ~h0rags ~:oo I I I I I I I I I I I i I I ; i I I II I I 4800 4600 4400 4200 4000 ~800 ~6~ ~ 5200 ~000 2800 2600 ~-- Wesf ~,~ ~ · ,oo.oo 0 c' I I V FILL-UP 3 FLOW KILL LINE ANNULAR BOP 13%"3000 psi PIPE RAMS 13%"5000 psi BLIND RAMS 13%"5000 psi · ~ [ DRILLi?NG [ ~ ' SPOOL --rb... ~,: ~3.4sooo ps~ CHOKE. LINE ~ I 4" 5000 ps~ i PIPE RAMS i, 13%"5000 psi "RISER ~ 13~s'' 5000 DSi COOK INL I PLATFORMS BOP STACK 13 %" 5000 psi 6" - 150 LB HEADER SECTION FRONT VIEW 4~' - 5000~ BUFFER TANK FRONT VIEW TOP TRANSMITTER GAUGE FLANGE BEHIND HEADER ,ee Lohoefer - Unocal At=achmen= II Grani=e Point - Cho~e ~An~fold' Item# 1 3A ? I ~scriD~on Buffer Tank per Drawing Blind Flange, 4 1/16" - 5000# Adapter, 4 1/16" - 5000# Flg X 4" NPS L~j. Flg. Ac~Cer. 4 1/16" - 5000# Flg. X 4" NPS Sm. Swivel AdaD=mr. 4 1/16" - 5000# Flg. X 3" NPS N~pple 90 Adap=mr, 3 1/~6' - lQ000# Flg. X 3~ NPS N~Ir~le Adap=er, 3 1/16" - 10000# Flg. X 3~ NPS AdaFcer. 2 1/16" - 5000# Flg. X 2" NFS NipDle Transm~==er Fi~. 2 1/16" 5000% W/ 2 - 2" LPT willis Choke w/ N'PS ends 9 I 10 2 Swaco Choke 2 9/16" - 10,000# remote opera=ed choke wl~h panel 11 3 5 '- way NPS flow block, 4X4X3X3X2 Lee Lohoefer - Unocal ]/24/95,mg2 Grani=e Point - C~ok~ Mani£old (cont'd) 3 1,~ 2 15 2 16 ].7 1 18 8 19 1 20 21 1 23 10 B]~n~ Flange Blind Flange 8' S~cer T~e Flg X Nipple way bl~k 8" Spacer ~e 8" Spaaer ~e ~d V~ve 2" V~ve 3" SEP '11 1995 6as Cons. Commissior~ Anchorage 18" csg. @ 418' (9 its., B, 70.59#) WELL S~TCH - G?.~NITE POINT WIW #42-23X DV collar @ 2,281' 13-3/8" csg. @ 3,995' (96 jts. J55, 9-5/8" Casinz 43.5~.;, S95 - 713 ' 40~'~, NS0 - 9212' 43.5#, N80 - 42 ' 7" liner top @ 9,781' 9-5/8" csg. @ 10,011' 7" perm. packer @ 13,212' (WR, 4" bore) · 7" liner 88 its., 29~, N80 .! Tubinm Assembly Description Depth Elevation 39' 428 jts. 3-1/2", 9.2#, NS0, Sp. CI., butt 3-1/2" x-o sleeve x 2.75" ID(closed)13,210' Otis.Locator Sub wo/latch (wt. not released) 13,211' Otis seals 4" OD (20') 13,212' 2-7/8" 'N' nipple x 2.31" ID (2.25" no-go) 13,250' 2-7/8"Mule Shoe 13,251' Fish Assemblv Top @ Dual Hydraulic Packer @ 2-3/8" nipple @ Baker Trip Sub @ 2-3/8" x-o sleeve @ 2-3/8" x-o sleeve @ 5" Hydraulic Packer @ 2-3/8" 'N' nipple @ Otis Trip Sub @ (2-3/8" AR}[CO Sealock tbg.) Note: 13,327 13,327 13,337 s.s. 13,338 s.s. 13,370 1.s. 13,848 1.s. 13,889 1.s. 14,396'1.s. 14,400'1.s. Tools would not go below 13,345' through the fish. Perforations 13,275' - 13,305' 'A' Zone 5" liner top @ 13,329' 7" liner @ 13,535' 5" liner 28 ]ts., 17.93#, NS0 PBTD@ 14,422' 5" liner @ 14,540' TD @ 14,544' 13,556' - 13,671' 13,710' - 13,840' 'B' Zone 14,108' - 14,213' 14,240' - 14,300' 14,326' - 14,401' 'C' Zone 11-8-72 Gas Cons. Commissio. Anchorage 33"@ 26"@ ( 105' BML) RT 114.75' RKB 1!5.75' TOPOFL 62' ~,. '~. -~ ~. ~ ,~ ~ !~') (75' WATER DEP1 ~ pLk A Gas Cons. Commi~iO~ ~ '~, ~Omge S~ L~EL (MLL 75' ~ Top 26" ~ 1~' R~ ~r (only on 3 inner ~uotors) MUD ~ 29' R~ ~ (40' BML) ~' R~ ~ Note: O~er 9 conductors have 26" back to su~ace DECK LEG ,) LINE inner 3 slots are different. See attached plan view. GRANITE POINT WELLBORE CONDUCTOR STATUS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL File: GPCOND. drw DATE: 07-21-95 FR'r 7:09 M--! ~RILLING AK P. 02 DRILLinG FLUID PROGRAM UNOCAL GRAN1T~ POINT 42,-23 REDRILL _pLUO b~ Aa~N'MR]~rI' ~CT~O _N. MUD TYPI~ Inlet Water w/NaCl or Generic Mud #2 MUD WEIGHT 8.5- 10.0 PPG FUNNEL VISCOSITY 8.5 - 10.0 PPG PLASTIC VISCOSITY 5- 10 YIELD POINT NIC MUD PRODUCTS Salt/FLO-VIS/Gel/Barite/SodaAsh/Bica. rb _REDRILL SECTION HOLE SIZE 8-1/2" ~4000' - 11,500' 6" 11,500' - 13,909' MUD TYPE Versaclean w/Conoco LVT 200 MUD WEIGHT 7.5- 10.0 PPO FUNNEL VISCOSITY 45- I00 PLASTIC I0- 20 YIELD POINT 10- 40 FLUID HPHT 10 or les~ MUD PRODUCTS VE R S AMU L/VER S AM O D/VE R S A HRP/VERSAWET/VBRSACOAT/ VG-69/B afitedI~wate/LhnedConoco LVT 200/CaCl~ Depth (2,000) (4,000) - (6,000) - -- (8,000) - (~ o,ooo) - (12,000) - (14,000) - File:4223RD.CH1 GP 42-23 RedrillI Depth vs. Days August 1995 Cut & Pull 9-5/8' Csg. Drill 8-1/2' OH (ROP=g~)~ Drill 8-1/2' OH (ROP=390~ P&A Wellbore 10 20 Estimate I 30 Days Actual Run E-Logs & 7' Csg. Drill 6' OH (ROP=350') Run E-Logs & 5' Csg. 40 50 60 S EP 1] ]995 Alaska Oil & Gas Cons. Commission Anchorage ! 18' 70# Grd 'B" ~ @418' 13-3/8' 61 # J55 @ 3995' TUBING DETAIL: 2-7/8', 6.4#, N-80, SC BUTI' 1) SSSV ~ 295' 2) GAS UFT MANDRELS as required 3) 'XA' SLEEVE as required 4) PERM PACKER as required 5) 'XN' NIPPLE as required 6) TCP GUNS as required Prod. Tree Assembly (2-9/16' 5M) Lower Master Valve Upper Master Valve Tee with Actuator Swab valve Tree cap 5" TOL @ 11300' 7' 29# LBO @ 11500' ~/~ 5" L @ 13910' 15# L80 Granite Pt. 42-23 Redrill PROPOSED COMPLETION Unocal Energy Resources Alaska DRAWN: CLL SCALE: NONE DATE: 08-04-95 File: 4223RD95.drw CASING DESIGN SPREADSHEET WELL: GPP 42-23 Rd FIELD: GRANITE POINT Hole Sect. 1 MUD WT. I 8.5 PPG Hole Sect. 2 MUD WT. II 8.5 PPG Hole Sect. 3 MUD WT. II 0 PPG INTERVAL Sect. CASING SIZE BO'FI'OM TOP LENGTH WT.._..~ 1 7" 11500 47 11453 29 TVD 9504 47 2 5" 13910 11300 2610 15 TVD 1O600 9337 DATE: 31-Aug-95 DESCRIPTION GRADE THREAD DESIGN BY: Lee Lohoefer M.S.P.. 901 psi 1005 psi 0 psi TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS ~ RESIST. W/O BF SECTION TENSION Bo'FrOM TENSION LBS LBS i 000 I,,BS TDF PSI* PSI L-80 BTC 332137 332137 676 2.04 2718 7020 L-80 BTC 39150 39150 350 8.94 3032 7250 CDF 2.58 2.39 BURST MINIMUM PRESSURE YIELD PSI** PS..._!I 2120 8160 2120 8290 I~DF 3.85 3.91 Notes: See attachment for calculation of MS.P. including assumptions and estimates. * Collapse pressure is calculated; Difference between two cement slurries (i.e. Avg ora 15.8 ppg (tail) 8, 14.2 ppg (lead) = 15 ppg, subtract a mud of 9.5 ppg = 5.5 ppg - .286 psi/It gradient X TVD of the casing string). ** Burst pressure is calculated; (BHP {~ depth next csg X TVD next csg) X (0.5 half evacuated). 8131/954223CSG.XLS Granite Pt. Platform Maximum Surface Pressure Calculations GPP # 42-23 Reddll 31-Aug-95 Hole Section I Depth Interval: 4000'-11500' (Top of Tyonek C-5 on East Flank) 8-1/2" hole size 7" casing from surface to 11500' Maximum Surface Pressure Calculation; Mud Weight ............................................. Shoe (9 5/8'7 Depth ................................ Estimated Fracture Gradient (9 5/8" shoe) Total Depth .............................................. Bottom hole pressure gradient ................... Gas gradient (assume worst case) ............. 8.5 ppg 4000 feet MD 11500 feet MD 0.442 psi/ft 3364 feet TVD 0.8 psi/ft 9504 feet TVD 0.4 psi/ft 0.1 psi/ft Wellbore volume with gas kick situation, is assumed to be 60% mud and 40% gas in a 8-1/2" hole at 11500' MD. Maximum surface pressure=Bottom hole pressure-hydrostatic pressure MSP = BHP - (60% mud +40% gas) MSP = (9504'.40)-((0.60'(9504'.44))+(0.40'(9504'0.1))) MSP = 901 psig Therefore the greatest hydrostatic pressure at the 9 5/8" shoe (HPsh) is when the gas bubble reaches the shoe, if a constant BHP is applied. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the casing depth (HP csg) HPsh = MSP + HPcsg HPsh = MSP + (TVD x MW) HPsh = 2388 psi This (HPsh = 2388 psig) is less than the fracture pressure at the same shoe. (FPsh = 0.80 psi/ft * 3364' = 2691 psig) and thus sufficiently adequate to handle a well kick. HPsh - Pore Pressure @ shoe is less than (<) Internal yield of the 13-3/8", 61#, J55 csg. 2388 - (3364*0.40) < 3090 psi 1042 < 3090 psi Page 1 4223MSP.XLS Granite Pt. Platform Maximum Surface Pressure Calculations GPP # 42-23 Redrill 31-Aug-95 Hole Section 2 Depth Interval: 11500'-13909' 6" hole size 5" casing from 11300' to 13909' Maximum Surface Pressure Calculation; Mud Weight ............................................. Shoe (7'7 Depth ................................ Estimated Fracture Gradient (7" shoe) Total Depth .............................................. Bottom hole pressure gradient ................... Gas gradient (assume worst case) ............. 8.5 ppg 11500 feet MD 13909 feet MD 0.442 psi/ft 9504 feet TVD 0.9 psi/ft 10600 feet TVD 0.4 psi/ft 0.1 psi/ft Wellbore volume with gas kick situation, is assumed to be 60% mud and 40% gas in a 6" hole at 13909' MD. Maximum surface pressure=Bottom hole pressure-hydrostatic pressure MSP -- BHP - (60% mud + 40% gas) MSP = (10600'.40)-((0.60'(10600'.442))+(0.40'(10600'0.1))) MSP = 1005 psig Therefore the greatest hydrostatic pressure at the 7" shoe (HPsh) is when the gas bubble reaches the shoe, if a constant BHP is applied. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the casing depth (HP csg) HPsh = MSP + HPcsg HPsh = MSP + (TVD x MW) HPsh = 5206 psi This (HPsh = 5206 psig) is less than the fracture pressure at the same shoe. (FPsh = 0.90 psi/ft * 9504' = 8554 psig) and thus sufficiently adequate to handle a well kick. HPsh - Pore Pressure @shoe is less than (<) Internal yield of the 7" 29~, N80 csg. 5206 - (9504*0.40) < 8160 psi 1404 < 8160 psi Page 2 SEP '11 1995 0il & 6as Cons. Commission ~ ~chorage 4223MSP.XLS *4- 14 I + to,mo* ~-, fi-IS 1 Si-la ~8-10 6O PROP. LOC. ~2-18RD 18 PROP. LOC. 42-~JRD + 19 2000 FEET, UNOCAL GRANITE POINT Ptatform 42-23 slot #3-7 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes I NTEQ Your ref : 42-23 Rd Version #8 Our ref : prop1362 License : Date printed : 13-Aug-95 Date created : 1-Aug-95 Last revised : 13-Aug-95 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 Slot location is n60 57 29.192,w151 19 52.279 Slot Grid coordinates are N 2544538.000, E 263405.000 Slot local coordinates are 2391.74 S 1372.03 E Reference North is True North Vii & Gas Cons. Commission Anchorage UNOCAL GRANITE POINT Platform,42-23 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 42-23 Rd Version #8 Last revised : 13-Aug-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 3995.00 56.24 212.95 3364.30 1349.80 S 935.40 W 0.00 4000.00 56.11 212.96 3367.08 1353.29 S 937.66 W 2.50 4100.00 53.61 213.06 3424.63 1421.86 S 982.21 W 2.50 4200.00 51.12 213.18 3485.69 1488.18 S 1025.48 ~ 2.50 4300.00 48.62 213.30 3550.14 1552.12 S 1067.39 ~ 2.50 1641.88 KOP - Sidetrack Point 1646.03 1727.69 1806.78 1883.15 4400.00 46.12 213.44 3617.86 1613.56 S 1107.85 W 2.50 4500.00 43.62 213.59 3688.7'5 1672.38 S 1146.80 W 2.50 4~00.00 41.12 213.75 3762.60 1728.46 S 1184.16 W 2.50 4700.00 38.63 213.93 3839.34 1781.71 S 1219.86 W 2.50 4800.00 36.13 214.12 3918.80 1832.02 S 1253.82 W 2.50 1956.64 2027.12 2094.46 2158.52 2219.19 4899.02 33.(>6 214.34 4000.01 1878.85 S 1285.68 5000.00 33.66 214.34 4084.06 1925.06 S 1317.26 5500.00 33.66 214.34 4500.24 2153.8~ S 1473.60 6000.00 33.66 214.34 4916.43 2382.65 S 1629.94 6500.00 33.66 214.34 5332.61 2611.45 S 1786.28 2.50 2275.81EnclAngle Drep 0.00 2331.75 0.00 2608.76 0.00 2885.77 0.00 3162.77 7000.00 33.66 214.34 5748.80 28/+0.25 S 1942.62 7500.00 33.(>6 214.34 6164.98 3069.05 S 2098.96 8000.00 33.66 214.34 6581.16 3297.84 S 2255.30 8500.00 33.66 214.34 6997.35 3526.64 S 2411.64 9000.00 33.(>6 214.34 7413.53 3755.44 S 2567.98 W 0.00 3439.78 W 0.00 3716.78 W 0.00 3993.79 W 0.00 4270.80 W 0.00 4547.80 9500.00 33.(>6 214.34 7829.72 3984.24 $ 2724.33 10000.00 33.66 214.34 8245.90 4213.04 S 2880.67 10500.00 33.66 214.34 8662.08 4441.83 S 3037.01 10687.92 33.66 214.34 8818.50 4527.82 S 3095.77 10700.00 33.54 214.97 8828.57 4533.32 S 3099.57 0.00 4824.81 0.00 5101.82 0.00 5378.82 0.00 5482.93 Begin Turn to Targets 3.00 5489.62 10800.00 32.70 220.24 8912.33 4576.60 S 3132.86 lC~00.00 32.10 225.72 8996.78 4615.78 S 3169.35 11000.00 31.74 231.36 9081.68 4650.76 S 3208.92 11100.00 31.63 237.07 9166.80 4681.44 S 3251.48 11200.00. 31.77 242.77 9251.90 4707.74 S 3296.91 W 3.00 5544.19 W 3.00 5597.32 W 3.00 5648.87 W 3.00 5698.69 W 3.00 5746.64 11300.00 32.17 248.39 9336.75 4729.60 S 3345.08 11400.00 32.80 253.85 9421.12 4746.94 S 3395.86 11499.06 33.66 259.05 9504.00 4759.62 S 3448.60 11589.14 35.67 259.05 9578.08 4769.35 S 3498.90 11689.14 37.90 259.05 9658.17 4780.73 S 3557.68 3.00 5792.60 3.00 5836.44 3.00 5877.65 Tgt #1 - T/ C5 - 7" Csg (Begin Finat Bu 2.23 5915.04 2.23 5958.75 11789.14 40.13 259.05 9735.86 4792.69 S 3619.48 11889.14 42.36 259.05 9811.05 4805.21 $ 368/+.19 11989.14 44.58 259.05 9883.62 4818.28 S 3751.74 12C~9.14 46.81 259.05 9953.46 4831.8~ S 3822.00 12171.72 48.66 259.05 10009.00 4843.49 S 3~2.00 2.23 6004.69 2.23 6052.80 2.23 6103.02 2.23 6155.25 2.23 6199.86 Tgt #2 - T/ C7 (Continue Build / Turn) 12200.00 49.50 258.97 10027.52 4847.57 S 3902.97 W 3.00 6215.47 12300.00 52.49 258.71 10090.45 4862.61 S 3979.20 ~ 3.00 6272.37 12400.00 55.49 258.48 10149.23 4878.60 S 4058.49 ~ 3.00 6331.85 12500.00 58.48 258.26 10203.71 4895.51 S 4140.61 W 3.00 6393.72 12600.00 61.48 258.05 10253.74 4913.28 S 4225.35 W 3.00 6457.83 !2700.00 64.47 257.86 10299.17 4931.87 S 4312.46 W 3.00 6523.99 12800.00 67.47 257.67 10339.88 4951.22 S 4401.70 W 3.00 6592.02 12900.00 70.46 257.50 10375.77 4971.28 S 4492.85 W 3.00 ~1.75 13000.00 73.46 257.32 10406.73 4992.01 S 4585.64 ~ 3.00 6732.97 13100.00 76.45 257.16 10432.68 5013.33 S 4679.82 W 3.00 6805.50 S EP 1 1 1995 At~sk~ Oi~ & Gas Cons. Commission Anchorage All data is in feet unless otherwise stated Coordinates from stol ~fS,? and TVD from RKB (109.00 Ft above mean sea level). Vertical section is from wet[head on azimuth 215.92 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the mininu~ curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform,42-23 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 42-23 Rd Version Last revised : 13-Aug-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 13155.52 78.12 257.07 10444.90 5025.41 S 4732.61 W 13500.00 78.12 257.07 10515.83 5100.83 $ 5061.16 W 13709.67 78.12 257.07 10559.00 5146.74 S 5261.14 W 13909.67 78.12 257.07 10600.18 5190.53 $ 5451.89 W 3.00 6846.25 Final EOC 0.00 7100.10 0.00 7254.61Tgt #3 - T/ C5 #2 0.00 7401.9<2 TD - 5" Csg Pt S EP 995 Gas Cons. Commission Anchorage Ali data is in feet unless otherwise stated Coordinates from slot #3-7 and TVD from RKB (109.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 215.92 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform,42-23 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : 42-23 Rd Version Last revised : 13-Aug-95 Comments in wellpath MD TVD Rectangular Coords. Con~nent 3995.00 3364.30 1349.80 $ 935.40 4899.02 4000.01 1878.85 S 1285.68 10687.92 8818.50 4527.82 S 3095.77 11499.06 9504.00 4759.62 S 3448.60 12171.72 10009.00 4843.49 S 3882.00 13155.52 10444.90 5025.41 S 4732.61 13709.67 10559.00 5146.74 S 5261.14 13909.67 10600.18 5190.53 S 5451.89 KOP - Sidetrack Point End Angle Drop Begin Turn to Targets Tgt #1 - T! C5 - 7" Csg (Begin Final Build) Tgt #2 - T/ C? (Continue Build / Turn) Final EOC Tgt ~r5 - T/ C5 #2 TD - 5" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3364.30 1349.80S 935.40~ 3995.00 3364.30 1349.80S 935.40W 13 3/8" Csg n/a 3364.30 1349.80S 935.40N 11499.06 9504.00 4759.62S 3448.60W 7" Casing n/a 3364.30 1349.80S 935.40~ n/a 10600.18 5190.53S 5451.8914 5" Liner Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 42-23 T/C5 Alternate 259860.000,2539850.000,0.00009504.00 4759.62S 3448.60~ 1-Aug-95 42-23 T/C5#2 Rvsd 28 258040.000,2539500.000,0.000010559.00 5146.74S 5261.14N 19-Jan-95 42-23 T/C7 Rvsd 28-J 259425.000,2539775.000,0.000010009.00 4843.49S 3882.00N 19-Jan-95 All data is in feet unless otherwise stated Coordinates from slot #3-7 and TVD from RKB (109.00 Ft above mean sea level). Bottom hole distance is 7527.60 on azimuth 226.41 degrees from wellhead. Total Dogleg for we[lpath is 91.44 degrees. Vertical section is from wellhead on azimuth 215.92 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minim~ curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform,42-23 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 42-23 Rd Version #8 Last revised : 13-Aug-95 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 3995.00 56.24 212.95 3364.30 3741.54 S 436.63 E 0.00 4000.00 56.11 212.96 3367.08 3745.03 S 434.37 E 2.50 4100.00 53.61 213.06 3424.63 3813.60 S 389.82 E 2.50 4200.00 51.12 213.18 3485.69 3879.92 S 346.55 E 2.50 4300.00 48.62 213.30 3550.14 3943.86 S 304.64 E 2.50 1641.88 KOP - Sidetrack Point 1646.03 1727.69 1806.78 1883.15 4400.00 46.12 213.44 3617.86 4005.29 S 264.18 E 4500.00 43.62 213.59 3688.73 4064.11 S 225.23 E 4600.00 41.12 213.75 3762.60 4120.20 S 187.87 E 4700.00 38.63 213.93 3839.34 4173.45 S 152.18 E 4800.00 36.13 214.12 3918.80 4223.76 S 118.21 E 2.50 1956.64 2.50 2027.12 2.50 2094.46 2.50 2158.52 2.50 2219.19 4899.02 33.66 214.34 4000.01 4270.59 S 86.35 E 5000.00 33.66 214.34 4084.06 4316.80 S 54.78 E 5500.00 33.66 214.34 4500.24 4545.59 S 101.56 W 6000.00 33.66 214.34 4916.43 47-/4.39 S 257.91 W 6500.00 33.66 214.34 5332.61 5003.19 S 414.25 ~ 2.50 0.00 0.00 0.00 0.00 2275.81 End Angle Drop 2331.75 2608.76 2885.77 3162.77 7000.00 33.66 214.34 5748.80 5231.99 S 5?0.59 7500.00 33.66 214.34 6164.98 5460.78 S 726.93 8000.00 33.66 214.34 6581.16 5689.58 S 88~.27 8500.00 33.66 214.34 6997.35 5918.38 S 1039.61 9000.00 33.66 214.34 7413.53 6147.18 S 1195.95 0.00 3439.78 0.00 3716.78 0.00 3993.79 0.00 4270.80 0.00 4547.80 9500.00 33.66 214.34 7829.72 6375.98 S 1352.29 10000.00 33.66 214.34 8245.90 6604.7-/ S 1508.63 10500.00 33.66 214.34 8662.08 6833.57 S 1664.98 10687.92 33.66 214.34 8818.50 6919.56 S 1723.73 10700.00 33.54 214.97 8828.57 6925.06 S 1727.54 0.00 4824.81 0.00 5101.82 W 0.00 5378.82 W 0.00 5482.93 Begin Turn to Targets 3.00 5489.62 10800.00 32.70 220.24 8912.33 6968.33 S 1760.83 10900.00 32.10 225.72 8996.78 7007.51 S 1797.31 11000.00 31.74 231.36 9081.68 7042.49 S 1836.89 11100.00 31.63 237.07 9166.80 7073.18 S 1879.45 11200.00 31.7'/ 242.77 9251.90 ?09<2.48 S 1924.88 3.00 5544.19 3.00 5597.32 3.00 5648.87 3.00 5698.69 3.00 5746.64 11300.00 32.17 248.39 9336.75 7121.33 S 1973.05 11400.00 32.80 253.85 9421.12 7138.67 S 2023.83 11499.06 33.66 259.05 9504.00 7151.36 S 2076.57 11589.14 35.67 259.05 9578.08 7161.09 S 2126.86 11689.14 37.90 259.05 9658.17 7172.46 S 2185.65 3.00 5792.60 3.00 5836.44 3.00 5877.65 Tgt #1 - T/ C5 - 7" Csg (Begin Final Bu 2.23 5915.04 2.23 5958.75 11789.14 40.13 259.05 9735.86 7184.42 S 2247.44 11889.14 42.36 259.05 9811.05 7196.95 S 2312.16 11989.14 44.58 259.05 9883.62 7210.02 $ 2379.70 12089.14 46.81 259.05 9953.46 7223.62 S 2449.96 12171.72 48.66 259.05 10009.00 7235.23 S 2509.96 2.23 6004.69 2.23 6052.80 2.23 6103.02 2.23 6155.25 2.23 6199.86 Tgt #2 - T/ C7 (Continue Build / Turn) 12200.00 49.50 258.97 10027.52 7239.30 S 2530.94 W 3.00 6215.47 12300.00 52.49 258.71 10090.45 7254.34 S 2607.17 ~ 3.00 6272.37 12400.00 55.49 258.48 10149.23 7270.34 S 2686.46 W 3.00 6331.85 12500.00 58.48 258.26 10203.71 7287.24 S 2768.58 ~ 3.00 6393.72 12600.00 61.48 258.05 10253.74 7305.02 S 2853.31 W 3.00 6457.83 12700.00 64.47 257.86 10299.17 7323.60 S 2940.42 W 3.00 6523.99 12800.00 6?.47 257.67 10339.88 7342.96 S 3029.67 ~ 3.00 6592.02 12900.00 ?0.46 25?.50 10375.7'/' 7363.02 S 3120.82 W 3.00 6661.75 13000.00 73.46 257.32 10406.73 7383.74 S 3213.60 ~ 3.00 6732.97 13100.00 76.45 257.16 10432.68 7405.07 S 3307.78 W 3.00 6805.50 All data is in feet unless otherwise stated Coordinates from #W Corner of Sec. 13, TI~, R12W SM and TVD from RKB (109.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 215.92 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform,42-23 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 42-23 Rd Version Last revised : 13-Aug-95 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 13155.52 78.12 257.07 10444.90 7417.14 S 3360.57 W 3.00 13500.00 78.12 257.07 10515.83 7492.57 S 3689.13 W 0.00 13709.67 78.12 257.07 10559.00 7538.48 S 3889.10 W 0.00 13909.67 78.12 257.07 10600.18 7582.2? S 4079.86 ~ 0.00 6846.25 Fina[ EOC 7100.10 7254.61Tgt ~ - T! C5 #2 7401.99 TD - 5" Csg Pt Alaska Oil & Gas Cons. Commission Anchorage All data is in feet unless otherwise stated Coordinates from N~ Corner of Sec. 13, TION, R1214 SM and TVD from RKB (109.00 Ft above mean sea [ever). Vertical section is from wellhead on azimuth 215.92 degrees. Declination is 0.00 degreesr Convergence is -1.17 degrees. Calculation uses the minin~J~ curvature method. Presented by Baker Hughes INTEQ UNO~,AL GRANITE POINT Platform,42-23 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : 42-23 Rd Version Last revised : 13-Aug-95 Comments in wellpath MD TVD Rectangular Coords. Co~lnent 3995.00 3364.30 3741.54 S 436.63 E 4899.02 4000.01 4270.59 S 86.35 E 10687.92 8818.50 6919.56 S 1723.73 W 11499.06 9504.00 7151.36 S 2076.57 W 12171.72 10009.00 7235.2~ S 2509.96 ~ 13155.52 10444.90 7417.14 S 3360.57 ~ 13709.67 10559.00 7538.48 S 3889.10 ~ 13909.67 10600.18 7582.27 S 4079.86 W KOP - Sidetrack Point End Angle Drop Begin Turn to Targets Tgt #1 - T/ C5 - 7" Csg (Begin Final Build) Tgt #2 - T/ C7 (Continue Build / Turn) Final EOC Tgt ~r5 - T/ C5 #2 TD - 5" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3364.30 3741.54S 436.63E 3995.00 3364.30 3741.54S 436.63E 13 3/8" Csg n/a 3364.30 3741.54S 436.63E 11499.06 9504.00 7151.36S 2076.57~ 7" Casing n/a 3364.30 3741.54S 436.63E n/a 10600.18 7582.27S 4079.86W 5" Liner Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 42-23 T/C5 Alternate 259860.000,2539850.000,0.00009504.00 7151.36S 2076.57W 1-Aug-95 42-23 T/C5#2 Rvsd 28 258040.000,2539500.000,0.000010559.00 7538.48S 3889.10W 19-Jan-95 42-23 T/C7 Rvsd 28-J 259425.000,2539775.000,0.000010009.00 7235.23S 2509.96W 19-Jan-95 SEP l l ]995 Alaska 4Jii & Gas Cons. Commission Anchorage All data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 13, TION, R12W SM and TVD from RKB (109.00 Ft above mean sea level). Bottom hole distance is 7527.60 on azimuth 226.41 degrees from wellhead. Total Dogleg for wellpath is 91.44 degrees. Vertical section is from wellhead on azimuth 215.92 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform 42-23 slot ~f5-7 Granite Point Field Cook Inlet, Alaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 42-23 Rd Version #8 Our ref : prop1362 License : Date printed : 13-Aug-95 Date created : 1-Aug-95 Last revised : 13-Aug-95 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 Slot location is n60 57 29.192,w151 19 52.279 Slot Grid coordinates are N 2544538.000, E 263405.000 Slot local coordinates are 2391.74 S 1372.03 E Reference North is True North Main calculation performed with 3-D Minimum Distance method Object wel[path GMS <O-10874'>,,31-13,GRANITE POINT Platform GMS <O-11011'>,,31-14Rd#1,GRANITE POINT P[atfo GMS/MSS <O-8876'>,,31-14,GRANITE POINT P[atfor GMS <O-10191'>,,31-14Rd#2,GRANITE POINT P[atfo GMS <O-11800'>,,11-24,GRANITE POINT Platform GMS <O-10850'>,,44-14,GRANITE POINT Platform GMS/MSS/GMS <O-12471'>,,44-11,GRANITE POINT PI GMS <O-11200'>,,31'23,GRANITE POINT Platform GMS <9200-11410'>,,33-14Rd,GRANITE POINT P[atf GMS <O-11473'>,,33-14,GRANITE POINT Platform GMS <O-10560'>,,24-13,GRANITE POINT Platform GMS <9700-10640'>,,24-13Rd,GRANITE POINT Platf GMS <O-12200'>,,12-24,GRANITE POINT Platform GMS <0-10830'>,,MUC I-2,GRANITE POINT Platform PGMS <O-12163'>,,GP-50,GRANITE POINT Platform GMS <0-118~9'> ,,GP-51,GRANITE POINT Platform GMS/MSS <0-11150-15715'>,,MUC I-1,GRANITE POIN PGMS <O-11560'>,,11-13Rd,GRANITE POINT P[atfor GMS <4025-11653'>,,11-13,GRANITE POINT Ptatfor GMS <8900-11986'>,,32-23Rd,GRANITE POINT P[atf GMS <O-12000'>,,32-23,GRANITE POINT Platform MSS <8630-11376'> ,,33-23,GRANITE POINT P[atfo GMS <0-10572'>,,13-13,GRANITE POINT Platform GMS <2700 - 11450'>,,33-13,GRANITE POINT Platf PGMS <0-10200'>,~32-13wGRANITE POINT Platform PMSS <8478 - 12563'>,,32-13Rd~2,GRANITE POINT PMSS <9437 - 10270'>,,32-13Rd,GRANITE POINT Pl GMS <0-10225'>,,22-13,GRANITE POINT Platform GMS/MSS/GMS (0-14544'>,,42-23,GRANITE POINT P[ Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 22-May-91 2180.8 3995.0 4899.0 22-May-91 1713.4 3995.0 11691.5 22-May-91 1713.4 3995.0 10856.5 22-May-91 1713.4 3995.0 4899.0 22-May-91 873.4 3995.0 3995.0 22-May-91 877.1 3995.0 7100.0 22-May-91 1993.4 3995.0 11499.1 22-May-91 547.2 3995.0 11689.1 22-May-91 1071.9 3995.0 11499.1 22-May-91 1071.9 3995.0 11499.1 22-May-91 1542.9 3995.0 9700.0 22-May-91 1542.9 3995.0 9700.0 22-May-91 1232.3 3995.0 10925.0 22-May-91 1827.1 3995.0 11822.5 2-0ct-92 1564.5 3995.0 9055.8 11-Aug-95 1647.4 3995.0 11499.1 22-May-91 2553.2 3995.0 4899.0 11-Aug-95 1659.7 3995.0 4899.0 11-Aug-95 1659.7 3995.0 4899.0 22-May-91 492.5 3995.0 10700.0 11-Aug-95 492.5 3995.0 9220.0 11-Aug-95 492.5 3995.0 11075.0 11-Aug-95 1564.2 3995.0 6893.3 13-Aug-95 1661.1 3995.0 4899.0 13-Aug-95 1717.8 3995.0 11499.1 13-Aug-95 1717.8 3995.0 11424.8 13-Aug-95 1717.8 3995.0 11424.8 22-May-91 1899.4 3995.0 4899.0 22-May-91 0.0 3995.0 13909.7 ..... ' STATE OF ALASKA ALAS~... OIL AND GAS CONSERVATION COMMIS,..,JN ,,~ APPLICATION FOR SUNDRY APPROVALS ~ i Type of request: Abandon X_ Suspend __ Operations shutdown__ Re-enter suspended well _ Alter casing__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing Variance __ Perforate __ Other 2. Name of Operator 5. Type of Well: 6. Datum elevalJ~)n (DF or KB) Development -- UNION OIL COMPANY OF CALIFORNIA (UNOCAL) F_xpk~.atory __ KB 105 feet 3. Address Strafigraphic __ 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 service X Union-Mobil State #1 __ 4. Location of well at surface Granite Point Platform, Leg #3, Slot 7. 8. Well number 2380' S & 1371' E F/NW Corner Sec. 13, T10N, R12W, S.M. 42-23 ADL-18761 At top of productive interval 9. Permit number 68 -42 At effective depth 10. APl number 50-133-20114 At total depth 11. Field/Pool 6969' S & 5575' W of surface location Granite Pt. / Middle Kenai 12. Present well condition summary Total depth: measured 14544 feet Plugs (measured) /~,!'~ I f'~ I k ! A / true vertical 10777 feet L Effective depth: measured 14422 feet Junk (measured) ~ ~.~,..~ true vertical 10668 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 381' 18' 456 cu.ft. 418' Surface 3958' 13-3/8" 2635 cu.ft. 3995' Intermediate 9974' 9-5/8' 2200 cu.ft. 10011' P roduction 3754' 7" 70 sx 9781'- 13535' Liner 1211' 5" 250 sx 13329'- 14540' Perforation depth: measured See attachment -;'; 'ED ['. ~. I.., w true vertical AUG 2 9 1995 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N80 @ 13251' Packers and SSSV (type and measured depth) 7" Otis Perm Pkr @ 13212' /aJas~ u~l & Gas Cons. : A nr, h0ra..~ _..,--' 13. Attachments Description summary of proposal X Detailed operations program_ _ BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: September 21,1995 16. If proposal was verbally approved Oil Gas __ Suspended __ Name of approver Date approved Service Water Injection 17' I hereby certifY that the f°~i~;l°'qg is tr'¥@ i~~t° the best °f my kn°wledge'',: d Signed G. RussellSchmidt~:~~//~-i~tle Drilling Manager Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug Integrity ~/~ BOP Testm ~ Location clearance c~,,~-''~/,.~:~ Mechanical Integrity Test Subsequent form required 10- /_f ~ ~' /::7e~L~.~,~e_ 7~p ~.r,_ c,.~ rz~_,~ -~-~ ~Z/-. Approved Copy Returned Original Signed B:y ~/,'[://¢ ~ Approved by the orderofthe Commission David W. Johnston ' - Commissioner- Date Form 10-403 Rev 06/15/88 SUBMIT Ih; TRIPLICATE WELL PERMIT CHECKLIST , , PROGRAM: exp [] der [] redrll~ aery [] ~ ,~], ON/OFF SHORE O~.'~ ADMINISTRATION ENGINEERING 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... GEOLOGY Conductor string provided ................ y Surface casing protects all known USDWs ......... Y CMT vol adequate to circulate on conductor & surf csg.. Y CMT vol adequate to tie-in long string to surf csg . . . Y 14. N 15. N 16. N 17. N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... i~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate .......... .y N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~'~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... .~~ 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... ~/N 32. Seismic analysis Qf shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /y N ' 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW~o - A:~FORMS~cheklist rev 03/94 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 C?_FEER * ....... SC~HLUMBERGER ....... COMPANY NA~E : Union Sil Company of California WELL NAME : GP 42-23 Redrill FIELD NAME : Graniue Point BOROUGH · Kenai STATE : Alaska API NUMBER : 50-733-20114-01 REFERENCE NO : 96084 Date~ LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen~er 20-MAR-1996 11:20 PAGE: **** REEL HEADER SERVICE NAME : CPLAYA DATE : 96/02/1 6 ORIGIN : CSU REEL NAME : CONTINUATION # .. O0 PREVIOUS REEL : CO~4ENT : SCHLUMBERGER ~LL SERVICES CSU TAPE **** TAPE HEADER **** SERVICE NAME : CPLAYA DATE : 96/02/16 ORIGIN : CSU TAPE NAME : CONTINUATION # : O0 PREVIOUS TAPE : COI~4ENT : SCHLUMBERGER WELL SERVICES CSU TAPE **** FILE HEADER ***~ FILE NAME : TCH .001 SERVICE : PLAY VERSION : 44.2 DATE : 96/02/08 MAX REC SIZE : 1024 FILE TYPE : CR LAST FILE : ** DATA FORMAT SPECIFICATION RECOP_D ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 54 4 66 1 5 66 1 6 73 49 7 65 INCH 8 73 60 9 65 .1 IN 11 66 18 12 68 13 66 1 14 65 . liN 15 66 73 16 66 1 0 66 0 LiS Tape Verification Listing Szhlumberger Alaska Computing Center 20-MAR-1996 11:20 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API APi API FILE ~KIF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CL'---cS MOD NUM~ SAMP ELE~ CODE (HEX) TOD TCH S 30 000 03 0 1 i 1 4 73 4200000000 TIME TCH MS 30 636 22 0 1 i 1 4 68 4000000000 ETIM TCH S 30 636 22 0 I ! 1 4 68 4000000000 CS TCH F/HR 30 636 21 0 1 ! 1 2 49 4200000000 DIFF TCH F 30 636 22 0 1 i 1 4 68 4000020000 TENS TCH LBF 30 635 2! 0 1 ! 1 4 68 4000000000 MARK TCH F 30 150 Oi 0 1 I 1 2 49 4000000000 RGR TCH GAPI 30 310 O! 0 1 1 1 2 49 4000020000 GR TCH GAPI 30 310 Ol 0 1 i 1 2 49 4400000000 STSG TCH 30 000 O0 0 1 1 1 2 79 0000000000 RCCL TCH 30 150 Oi 0 I 6 1 I2 49 4000020000 CCL TCH 30 150 O! 0 1 6 1 12 49 4400000000 ** DATA ** ** DEPTH = 13443.000 FEET ** TOD.TCH 508217882 TIME. TCH 2267.000 £TIM. TCH 2673.997 CS. TCH DIFF. TCH 12000.000 TENS.TCH 2505.000 Y~RK. TCH 0.000 RGR.TCH GR.TCH 12.391 STSG. TCH 0 RSCL.TCH 0.061 CCL.TCH ** DEPTH = 13000.000 FEET ** TOD. TCH 508216881 TIME. TCH 705.000 ~'TIM. TCH 1673.956 CS. TCH DIFF. TCH -1.100 TENS. TCH 1530.000 N-ARK. TCH 0.000 RGR.TCH GR.TCH 20.281 STSG. TCH 0 RCCL.TCH -0.149 CCL.TCH ** DEPTH = 12000.000 FEET ** TOD.TCH 508213003 TIFiE. TCH 846.000 ETIM. TCH 3183.247 CS.TCH DIFF. TCH -0.700 TENS.TCH 1475.000 :.LARK. TCH 0.000 RGR.TCH GR.TCH 38.875 STSG.TCH 0 RSCL.TCH -0.030 CCL.TCH ** DEPTH = 11000.000 FEET ** TOD. TCH 508210754 TIME. TCH 623.000 ETIM. TCH 934.353 CS.TCH DIFF. TCH -0.200 TENS. TCH 990.000 Y-ARK. TCH 0.000 RGR.TCH GR.TCH 12.648 STSG.TCH 0 RCCL.TCH -0.014 CCL.TCH DEPTH= 10766.000 FEET ** TOD.TCH 508209853 TIME. TCH 33777.000 ETIM. TCH 33.777 CS.TCH DIFF. TCH -0.050 TENS. TCH 560.000 :~K. TCH 0.000 RGR.TCH GR.TCH 4.500 STSG.TCH 0 RCCL.TCH -0.032 CCL.TCH ** END OF DATA ** 1420.000 11.328 0.122 2614.000 15.742 -0.298 2037.000 32.813 -0.061 3026.000 11.859 -0.027 53.281 14.367 -0.095 LIS Taue Verific=_uion Listing Schlumberger Alaska Computing Center 20-MAR-1996 IL :20 **** FILE _-7_~_~ILER **~* FILE NAME : TCH . 001 S~VICE : PLAY VF~gSION : 44.2 DATE : 96/02/08 MAX REC SIZE : 1024 FILE TYPE : CR LAST FILE : **** TAPE _-7_~_~ILER **** SERVICE NAME : CPLAYA DATE : 96/02/16 ORIGIN : CSU TAPE NAME : CONTINUATION = : O0 PREVIOUS TAPE : COMMENT : SCHLUMBERGER WELL SERVICES CSU TAPE **** REEL .---~-~ILER **** SERVICE NAME : CPLAYA DATE : 96/02/16 ORIGIN : CSU REEL NAME : CO~%UfINUATION = : O0 PREVIOUS REEL : COI~4~aYT : SCHLUMBERGER WELL SERVICES CSU TAPE COMPANY N;_'~ : Union Oil Compan}, of California WELL NAME : GP 42-23 Redrill FIELD N~ : Granite Poin= BOROUGH : Kenai STATE : Alaska API NUMBF~:. : 50-733-20114-01 REFERF~ICE :iQ : 96084 LiS Tape Verifica~-on Listing SchlumCoer~er Alaska Computing Cen~er 20-MAR-!996 12:52 PAGE: .... REEL HEZuOER **~ SERViSE NAME : CPLAYA DATE : 96/02/16 ORIGi2; : CSU REEL 2;~=~E : CONTi2~ATiON ~ : 30 PR~Zi3US REEL : CO~=~E-',"C : SCHLOWBERGER WELL SERVICES CSU TAPE **'' TAPE J%~ADER **** SERVi3E .¥;~.E : 3PLAYA DATE : 96/02/1 6 ORIGIN : CSU TAPE NAME : CONTI:KIATION # : O0 PREVIOUS TAPE : CO~ : SCHLUMBERGER WELL SERVICES CSU TAPE ***' FiLE HEJODER ***' FILE :;ABLE : TCH . 30 ! SERVICE : PLAY VERSi3N ' 44.2 DATE : 96/02/1! MAX P~C SIZE : !024 FILE ?YPE : CR LAST FILE : DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE .=.EPR CODE VALUE ! 66 0 2 66 0 3 79 494 4 66 1 5 66 1 6 73 36 7 65 INCH 8 73 60 9 65 .1 IN !! 66 2 !2 68 13 66 24 65 . liN 15 66 73 i6 66 1 0 66 0 LIS Tape Verifica~-ion L~s-_ing Schlumberger Alaska Cc.-.gu=ing Cent. er 20-MAR-1996 12:51 PAGE: ** SET !-..?E - CH.~%' *~ NAME SERV O?IIT SE~%'iCE APi API API API FILE NUMB NUMB SIZE AEgR PROCESS iD ~=-~= = LSE TYPE CLASS MOD NUMB S~IP EL~! ZZiE (HEX) TOD TCH S 42 000 O0 0 i I 1 4 75 8200000000 TIME TCH MS 42 636 21 0 1 I 1 4 5~ ~000000000 ETIM TCH S 42 636 21 0 ! 1 1 4 ~5 8000000000 CS TCH F/HR 42 636 22 0 1 1 1 2 49 8200000000 DIFF TCH F 42 636 21 0 1 ! 1 4 6~ 8000020000 TENS TCH LBF 42 635 2! 0 1 1 1 4 6~ 8000000000 ~D~RK TCH F 42 ~50 Ol 0 I 1 i 2 49 8000000000 D~-~;I TCH EEG 42 620 12 0 1 1 ! 2 49 8000000000 RB TCH DEG 42 631 il 0 1 i 1 2 49 8000000000 W1T1 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W2T1 TCH 42 000 O0 0 1 3 1 6 49 ~000000000 W3T1 TCH 42 000 O0 0 ! 3 1 6 49 8000000000 AGT1 TCH DB 42 000 O0 0 1 3 1 6 49 8000000000 DTTI TCH US 42 000 O0 0 1 3 1 6 49 8000000000 W1T2 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W2T2 TCH 42 000 O0 0 1 3 I 6 49 8000000000 W3T2 TCH 42 000 O0 0 ! 3 i 6 49 8000000000 AGT2 TCH DB 42 000 O0 0 1 3 1 6 49 8000000000 DTT2 TCH US 42 000 O0 0 1 3 1 6 49 8000000000 WiT3 TCH 42 000 O0 0 1 3 i 6 49 8000000000 W2T3 TCH 42 000 O0 0 1 3 ! 6 49 ~000000000 W3T3 TCH 42 000 O0 0 1 3 1 6 49 8000000000 AGT3 TCH DB 42 000 O0 0 1 3 1 ~ 49 8000000000 DIT3 TCH US 42 000 O0 0 1 3 1 6 49 8000000000 W1T4 TCH 42 000 O0 0 1 3 I 6 49 8000000000 W2T4 TCH 42 000 O0 0 ! 3 1 6 49 8000000000 W3T4 TCH 42 000 O0 0 1 3 i 6 49 8000000000 AGT4 TCH DB 42 000 O0 0 1 3 1 6 49 8000000000 DTT4 TCH US 42 000 O0 0 i 3 1 6 49 8000000000 W1T5 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W2T5 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W3T5 TCH 42 000 O0 0 1 3 1 6 49 8000000000 AGT5 TCH DB 42 000 O0 0 I 3 1 6 49 ~000000000 DTT5 TCH US 42 000 O0 0 1 3 1 6 49 8000000000 W1T6 TCH 42 000 O0 0 1 3 1 ~ 49 8000000000 W2T6 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W3T6 TCH 42 000 O0 0 1 3 1 6 49 8000000000 AGT6 TCH DB 42 000 O0 0 ! 3 1 6 49 8000000000 DTT6 TCH US 42 000 O0 0 1 3 1 6 49 8000000000 WIT7 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W2T7 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W3T7 TCH 42 000 O0 0 i 3 1 6 49 8000000000 AGT7 TCH DB 42 000 O0 0 1 3 1 6 49 8000000000 DTT7 TCH US 42 000 O0 0 1 3 1 6 49 8000000000 W1T8 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W2T8 TCH 42 000 O0 0 1 3 1 6 49 8000000000 W3T8 TCH 42 000 O0 0 ! 3 1 6 49 8000000000 AGT8 TCH DB 42 000 O0 0 1 3 1 6 49 ~000000000 DTT8 TCH US 42 000 O0 0 1 3 1 6 49 8000000000 W1T9 TCH 42 000 O0 0 1 3 1 6 49 8000000000 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cenrer 20-MAR-1996 12:51 NAME SERV UNIT SERVICE API API APIAPI FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE ii_%SS MOD ~HIMB SAMP ELEM CODE (HEX) W2T9 TCH 42 005 :3 0 1 3 1 6 49 3900000005 W3T9 TCH 42 009 23 0 1 3 1 6 49 8000000000 AGT9 TCH DB 42 000 iO D 1 3 1 6 49 ~000000000 DTT9 TCH O'S 42 000 30 0 1 3 1 6 49 8000000000 ~a~ TCH 42 OOO ~3 0 ! 3 1 6 49 8200000000 ECCE TCH iN 42 000 ~0 0 1 3 1 6 49 8200000000 CALU TCH IN 42 280 59 0 1 3 1 6 49 8200000000 W2F9 TCH 42 000 30 O 1 3 1 6 49 ~000000000 W3F9 TCH 42 000 DO 0 1 3 1 6 49 8000000000 CS~4~ TCH 42 000 90 0 1 1 1 2 49 8200000000 CSf4~ TCH 42 000 90 0 1 1 1 2 49 8200000000 AW2 TCH 42 000 90 0 1 1 1 2 49 8000000000 AW3 TCH 42 000 DO 0 1 1 1 2 49 8000000000 AAG1 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AWll TCH 42 000 90 0 1 1 1 2 49 9000000000 AW21 TCH 42 000 SO 0 1 1 1 2 49 9000000000 AAG2 TCH 42 000 20 0 1 1 1 2 49 9000000000 AW12 TCH 42 000 90 0 1 1 1 2 49 9000000000 AW22 TCH 42 000 DO 0 1 1 1 2 49 9000000000 AAG3 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW13 TCH 42 000 90 0 ! 1 1 2 49 9000000000 AW23 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AAG4 TCH 42 000 90 0 1 1 1 2 49 9000000000 AW14 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW24 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AAG5 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW15 TCH 42 000 DO 0 1 1 1 2 49 9000000000 AW25 TCH 42 000 O0 0 1 1 1 2 49 9000000000 ~G6 TCH 42 000 DO 0 1 1 1 2 49 9000000000 AW16 TCH 42 000 O0 0 1 1 ! 2 49 9000000000 AW26 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AAG7 TCH 42 000 30 0 1 1 1 2 49 9000000000 AW17 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW27 TCH 42 000 DO 0 1 1 1 2 49 9000000000 AAG8 TCH 42 000 30 0 1 1 1 2 49 9000000000 AW18 TCH 42 000 ~0 0 1 1 1 2 49 9000000000 AW28 TCH 42 000 30 0 1 1 1 2 49 9000000000 AAG9 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW19 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW29 TCH 42 000 90 0 1 1 1 2 49 9000000000 AW31 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW32 TCH 42 000 DO 0 1 1 1 2 49 9000000000 AW33 TCH 42 000 90 0 1 1 1 2 49 9000000000 AW34 TCH 42 000 00 0 1 1 1 2 49 9000000000 AW35 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW36 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW37 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW38 TCH 42 000 O0 0 1 1 1 2 49 9000000000 AW~9 TCH 42 000 O0 0 1 1 1 2 49 9000000000 T~rRA TCH 42 420 O1 0 1 1 1 4 68 8440000000 RTArR TCH 42 420 O1 0 1 1 1 4 68 8040020000 LIS T=-=e Verification LisUing Schlu--i~erger Alaska Computing Cen~er 2 5-!,~AR-1996 '2:51 PAGE: N.'-_'.~ SERV ~?¢IT SERVICE API API API API FILE :F~"..~ NUMB SIZE REPR PROCESS iD O~LDER # LOG TYPE CLASS M~D NIIMB ~:.'2.:P ELEM CODE (HEX) P.S?? TCH g_uS 42 420 O1 ~ l ~2_~ TCH ZPS 42 420 O1 ~ 1 T.'-~P TCH 42 890 O0 ~ 1 C_--~_S TCH SPS 42 420 O1 2 1 C:$T_E TCH SgS 42 420 O1 ~ 1 ~PH TCH V;'V 42 890 O0 3 1 A~m2R TCH V/V 42 890 O0 ~ 1 NPHi TCH ','.." V 42 890 O0 $ 1 RGR TCH SAPI 42 310 O1 9 1 GR TCH EAPI 42 310 O1 O 1 STSg TCH 42 000 O0 0 1 HT~--~I TCH £BF 42 000 O0 9 1 P~%~-TE TCH LBF 42 000 O0 0 1 I.~S TCH ~74~ 42 000 O0 3 1 MT~, TCH DEGF 42 000 O0 ~ 1 A_~ TCH ~EGC 42 000 O0 9 1 DT~ TCH ZC/K 42 000 O0 3 1 RCEL TCH 42 150 O1 3 1 CCL TCH 42 150 O1 0 1 ICJ TCH F3 42 282 O1 0 1 ik-Z TCH F3 42 282 01 ~ 1 1 4 68 8000020400 1 4 68 8000020400 1 4 68 8200020400 1 4 68 8800000400 1 4 68 8800000400 1 4 68 8240002400 1 4 68 8240002400 1 4 68 8240000000 1 2 49 8000020000 1 2 49 8400000000 1 2 79 8000000000 1 2 49 8000000000 1 2 49 8000000000 1 2 49 8000000000 1 2 49 8000000000 1 2 49 8400000000 i 2 49 8000000000 1 12 49 8000020000 1 12 49 8400000000 1 2 49 8400000000 1 2 49 8400000000 ** DATA ** ** DEPTH 12557.500 FEET ** TSD. TCH 5~8495017 TIME. TCH 1043.000 ETiM. TCH DIFF. TCH 12000. 000 TENS. TCH 4375. 000 ~L~i4. TCH .:~. TCH 164.750 Wi TI. TCH - O. 992 W2 T2. TCH AG Ti. TCH -O. 992 DTT1. TCH O. 000 WI-_2. TCH W3T2. TCH O. 000 AGT2. TCH O. 000 DT~.2. TCH W273. TCH -32768. 003 W3T3. TCH -32768. 003 AGT5. TCH WI T4. TCH 32752. 001 W2T4. TCH 32752. 001 rW3T4. TCH DTT4. TCH 92752. 001 W1T5. TCH -32768. 003 W2TS. TCH AGTS. TCH -32768. 003 DTT5. TCH -32768. 003 W2T~. TCH W3T6. TCH 32752. 001 AGT6. TCH 32752. 001 DTT"5. TCH W277. TCH -23144. 001 W3T7. TCH -13144. 001 AGTT. TCH WI T~. TCH O. 734 W2 T8. TCH O. 734 W5 T~. TCH DTTS. TCH O. 734 W1T9. TCH -6.230 W2T~. TCH AGT~. TCH -6. 230 DTT9. TCH -6. 230 r,~-~?4. TCH CAGU. TCH 1223. 000 W2F9. TCH 1. 000 W3F~. TCH C?.~. TCH 4160. 000 AW2. TCH O. 000 AW3. TCH AWil. TCH O. 000 AW21. TCH O. 000 AAG2. TCH AW22. TCH -O. 752 AAG3. TCH -O. 792 AWl 3. TCH AAG4 . TCH O . 000 AW14. TCI~ O . 000 AW24. TCM AW!5. TCH O. 000 AW25. TCH O. 000 AAG6. TCH AW26. TCH 32752. 000 AAG7. TCH O . 000 AWl 7. TCH AAGS. TCH -32768. 001 AW18. TCH -32768. 001 A~2~. TCH AWl9. TCH 32752. 000 AW29. TCH 32752. 000 AW31. TCH 12 808 0 000 -0 992 0 000 0 000 -32768 003 32752 001 -32768 003 32752 001 32752 001 -13144.001 0.734 -6.230 0.603 1.000 0.000 -0.752 -0.792 0.000 32752.000 0.000 -32768.001 0.000 CS.TCH DEVI.TCH W3 TI. TCH W2 T2. TCH W1 T3. TCH DTT3. TCH AGT4. TCH W3 T5. TCH W2 T6. TCH W1 T7. TCH DTT7.TCH AGT8.TCH W3T~.TCH ECCE. TCH CS~N. TCH AAG1.TCH AW12.TCH AW23.TCH AAGS.TCH AW16.TCH AW27.TCH AAG~.TCH AW32.TCH 1786.000 35.938 -0.992 0.000 -32768.003 -32768.003 32752 001 -32768 003 32752 001 -13144 001 -13144 001 0 734 -6 230 1524 000 4160 000 0 000 -0 752 -0 792 0 000 32752000 0.000 32752.000 -0.752 LIS Tape Verifica:iz.-. Listing Schlumberger Alaska ismpu~ing Cen~er 20-MAR-1996 12:52 PAGE: AW33. TSH AW37.73H RTNR. TSH CFTC. NPHI. TSH HTEN. TEH AMTE. TEH ICV. TSH TOD. TCH DIFF. Tf"H RB TCH AGT1 TCH W3T2 TEH W2T3 TCH WI T4 TCH DTT4 TC"H AGT5 TCH W3 T6 TCH W2T7 TCH Wi T8 TCH DTT8 TCH AGT9 TCH CALU. TC"H CSMX. TCH AW11. TCH AW22. TCH .~04. TCH AW15. TCH AW26. TCH AAG8. TCH A Wi 9. TCH AW33. TCH AW37. TSH RTNR. TCH CFTC. TEH NPHI. TSH HTEN. TCH A~FfE. TCH ICV. TCH TOD. TCH DIFF. TCH RB. TCH AGT1. TCH W3 T2. TCH W2T3. TCH W1 T4. TCH DTT4. TCH AGTS. TCH W3 T6. TCH _' 792 ' $00 ' 769 -F 530 -- $50 259 575 5 riO0 2454 SOO 2552 SOO 2925 200 54 900 - 300 2727.300 2£72.000 2555.500 54.781 5. 200 5. 223 5E2. 750 2666.000 2.282 5.$00 '.167 5.200 2525.200 '.348 -.242 2.588 £~F.975 -.221 ~£9.500 32752.D01 * * EEPCT~. = 50~49~!72 -5.100 297.375 4.900 2466.000 3J~2.200 £~.$00 £~.375 -.300 2525.000 AW34.TCH 0,000 AW35.TCH AW38.TCH -32768,001 AW39.TCH RCFT. TCH 1202.290 RCNT. TCH ENTC. TCH 2142,085 TNPH. TCH ~GR.TCH 37,438 GR.TCH ,~%'TE. TCH -1137.000 MRES. TCH DTE~,TCH 0,000 RCCL.TCH iHV, TCH 0.000 12000.000 FEET TIME. TCH · TENS TCH W1 Ti TCH DTT1 TCH AGT2 TCH W3T3 TCH W2T4 TCH WI T5 TCH DTT5 TCH AGT6 TCH W3T7 TCH W2T8 TCH W1T9 TCH DTT9 TCH W2F9 TCH AW2 TCH AW21 TCH AAG3.TCH AW14.TCH AW25.TCH AAG7.TCH AW18.TCH AW29.TCH AW34.TCH AW38.TCH RCFT. TCH CNTC. TCH RGR.TCH RHTE. TCH DTE~.TCH IHV. TCH 11000.000 FEET TIME. TCH TENS. TCH W1 Ti. TCH DTT1. TCH AGT2. TCH W3 T3, TCH W2T4. TCH W1 T5 . TCH DTTS. TCH AGT6. TCH 1001.000 9155.000 2050.000 53.500 5.000 2608.000 3330.000 1873.000 56.000 6.000 2108.000 2412.000 1924.000 47.375 1.000 1.328 1.525 6,000 1924.000 1 273 3 000 1898 000 0 211 1 342 1 213 528 O87 1388 422 61 594 -130 250 0 000 32752 001 1017.000 8510.000 1717.000 54.500 5.000 2416.000 1965.000 1822.000 55.688 7.O00 ETIM. TCH MARK. TCH W2 T1. TCH W1 T2 . TCH DTT2. TCH AGT3. TCH W3 T4. TCH W2T5. TCH W1 T6. TCH DTT6. TCH AGT7. TCH W3 T8. TCH W2T9. TCH [~fM. TCH W3 F9. TCH AW3. TCH AAG2. TCH AW13. TCH AW24. TCH AAG6. TCH AW17. TCH AW28. TCH AW31. TCH AW35. TCH AW39. TCH RCNT. TCH TNPH. TCH GR. TCH MRES. TCH RCCL. TCH ETIM. TCH N~ARK. TCH W2T1. TCH W1 T2 . TCH DTT2. TCH ACT3. TCH W3 T4. TCH W2T5. TCH Wi T6. TCH DTT6. TCH 32752.::9 2141.557 5.224 43.229 0.:£2 i144.223 3178.S~0 1919.~0 52.550 6.509 2540.~19 2268.~D 1694.~ 57.~20 3.SD9 2198.S50 419.759 0.923 1.$30 1.243 5.030 1936.$~0 1.656 6,320 1657.520 1,299 1.22B 1,165 0.246 1327.251 0.221 74.625 0.322 -0.~57 3168 076 0 000 1776 030 1890 $39 53 594 5 000 2334 030 2196 050 1702 990 56.189 AW36.TCH TNRA.TCH TALP. TCH NPOR.TCH STSG.TCH MTEM. TCH CCL.TCH CS.TCH DEVI.TCH W3 T1. TCH W2 T2. TCH W1 T3. TCH DTT3. TCH AGT4. TCH W3TS.TCH W2T6.TCH W1T7.TCH DTT7.TCH AGTS.TCH W3T9.TCH ECCE. TCH CS~N. TCH AAG1.TCH AW12.TCH AW23.TCH AAGS.TCH AW16.TCH AW27.TCH AAG9.TCH AW32.TCH AW36.TCH TNRA.TCH TALP, TCH NPOR.TCH STSG. TCH MTE~.TCH CCL.TCH CS. TCH DEVI TCH W3T1 TCH W2T2 TCH W1T3 TCH DTT3 TCH AGT4 TCH W3T5 TCH W2T6.TCH W1T7.TCH 32752.000 1,693 0.447 0.114 176 173.375 -0.033 1795.000 35.938 2646.000 2318.000 1926.000 53.094 5.000 2134.000 1712.000 1677.000 56.688 5.000 466.500 0.081 0.000 4,000 1923.000 1,434 7.OOO 1676.000 1,263 9.000 1,285 1.051 2,616 0,433 0.235 176 170.375 -0.014 1759 000 15 500 1987 000 2066 000 1759 000 53 688 3 000 2208 000 2136 000 1884.000 LIS Tape Verification Lis~ing Schlumberger Alaska Compucing Cenier 20-MAR-1996 12:51 PAGE: W2T7. TCH Wi T8 . TCH DTT8. TCH AGT~. TCH CALU. TCH CSFDC. TCH AW11 TCH AW22 TCH AAG4 TCH AW15 TCH AW26 TCH AAG8 TCH AW19 TCH AW33 TCH AW37 TCH RIW-R TCH CFTC. TCH NPHI. TCH HTEN. TCH AMTE. TCH ICI/. TCH TOD. TCH DIFF. TCH RB. TCH AGT1. TCH W3 T2 . TCH W2 T3. TCH W1 T4. TCH DTT4. TCH AGTS. TCH W3 T6. TCH W2 T7. TCH W1 T8. TCH DTT8. TCH AGT9. TCH CALU. TCH CSMX. TCH AWll TCH AW22 TCH AAG4 TCH AW15 TCH AW26 TCH AAG8 TCH AW19 TCH AW33 TCH AW37 TCH RT1TR. TCH CFTC. TCH NPHI. TCH HTEN. TCH AMTE. TCH ICV. TCH 2080.003 1998.009 55.000 ~ 000 6 229 539 5©3 2735 OOS i 236 3 1793 000 i 281 1679 000 ! 400 I 323 2 623 497 586 0 225 969 000 7! 500 32752 001 DEPTH = 508501074 -0.050 204.500 6.000 2200.000 1881.000 1990.000 55.094 7.000 2048.000 !413.000 1781.000 54.781 8.000 6.223 2408.000 1662.000 1.075 4.000 1703.000 0.948 5.000 1599.000 1.271 1.035 2.714 608.078 0.188 954.500 65.750 32752.000 W3T7 W2T8 W1 T9 DTT9 W2F9 AW2 AW2! iii-'. AAG3 AW14 AW25 AA G 7 AW18 AW29 AW34 AW38 RCFT. CNTC . RGR . RHTE. DTE~4. IHV. 10000.$i$ FEET TIME. TENS. Wi Ti. DTT1. AGT2 . W3 T3 . W2 T4. W1T5. DTTS . AGT6. W3 T7. W2TS . Wi T~. DTT9 . W2F~. AW2. AW21. AAG3 . AW14. AW25. AAG7 . AW18. AW29. AW34. AW38. RCFT. CNTC. RGR . RHTE . DTEM. IHV. 2444.000 2680.000 1677.000 47 594 1 000 1 284 1 250 5 000 1850 000 1 038 5 000 1943 000 0 196 1 198 1 353 440 642 1262 659 31 141 19 422 0 000 32752 001 1035.000 7650.000 1973.000 53.688 5.000 2186.000 2384.000 1709.000 56.375 8.000 1836.000 979.500 1597.000 47.781 1.000 0.979 0.917 6.000 1551.000 1.094 5.000 1786.000 O. 182 1 207 0 928 590 632 1486 280 50 969 4 742 0 000 32752 000 AGT7.TCH W3 T8. TCH W2T9. TCH ~%~'~q. TCH W3F9.TCH AW3.TCH AAG2.TCH AW13.TCH AW24.TCH AAG6.TCH AW17.TCH AW28.TCH AW31.TCH AW35.TCH AW39.TCH RCNT. TCH TNPH. TCH GR.TCH MRES.TCH RCCL.TCH ETIM. TCH MARK. TCH W2T1. TCH WI T2 TCH DTT2 TCH AGT3 TCH W3 T4 TCH W2 T5 TCH W1T6 TCH DTT6 TCH AGT7 TCH W3T8 TCH W2T9.TCH ~gWM. TCH W3F~.TCH AW3.TCH AAG2.TCH AW13.TCH AW24. TCH AAG6. TCH AW17. TCH AW28. TCH AW31.TCH AW35.TCH AW39.TCH RCNT. TCH TNPH. TCH GR.TCH MRES.TCH RCCL.TCH 5,003 2676.00~ 332.000 0.~65 1.00~ 1.265 5.009 1750.003 1.060 7.000 1937.000 1.292 1.231 1.180 0.203 1262.634 0.236 33.438 0.013 -0.009 1835.492 0.000 1872.000 1780.000 53.781 6.000 2332 000 1899 000 1953 000 57 094 5 000 1218 000 296 000 0 657 1 000 1 104 5 000 1730 000 1.235 8.000 i922.000 0.585 1.012 1.211 0.187 1518.651 0.222 53.719 O. 013 -0. 017 DTT7.TCH AGT8.TCH W3T9.TCH ECCE. TCH 3SPCN. TCH A~G1.TCH AW12. TCH AW23. TCH A~GS. TCH AW16. TCH AW27. TCH AAG9. TCH AW32.TCH AW36.TCH TNRA.TCH TALP. TCH NPOR.TCH STSG.TCH MTEM. TCH CCL.TCH CS TCH DEVI TCH W3 T1 TCH W2 T2 TCH W1 T3 TCH DTT3 TCH AGT4 TCH W3TS.TCH W2T6.TCH W1T7.TCH DTT7.TCH AGTS.TCH W3T9.TCH ECCE. TCH CSI4N, TCH AAG1.TCH AW12.TCH AW23.TCH AAGS.TCH AW16.TCH AW27.TCH AAG~.TCH AW32.TCH AW36.TCH TNRA.TCH TALP. TCH NPOR.TCH STSG.TCH MTEM. TCH CCL.TCH 56. 000 6. 000 342. 250 0.047 2.354 4. 000 1895. 000 1. 923 7. 000 1702. 000 1.319 8. 000 1.337 1.150 2. 636 O. 412 0.236 176 160. 750 -0. 019 1745 000 7 785 2116 000 1945 000 1769 000 54 000 6 000 2070.000 1786.000 1908.000 56.500 5.000 299.250 0.065 206.875 4.000 1771.000 1.098 7.O00 1939.000 0.827 8.000 1.242 1.122 2. 401 O. 465 0.216 176 150.375 -0.033 lis Tape Verification Listing S~hlumberger Alaska Computing Cen~er 20-MAR-£996 12:51 ** DEPTH = 9000.000 FEET TOD. TCH 508504115 DIFF. TCH -0.050 RB.TCH 292.625 AGT1.TCH I0.000 W3T2.TCH 2156.000 W2T3.TCH 2352.000 W1T4.TCH 2771.000 DTT4.TCH 55.875 AGT5.TCH 23,000 W3T6. TCH ' 857 . 000 W2T7. TCH 2654 . 000 W1T8. TCH 1838. 000 DTT8.TCH 53.688 AGT9.TCH 13.000 CALU. TCH 6.215 CSNiX. TCH 500.000 AWll. TCH ~634.000 AW22.TCH i.585 AAG4.TCH 9,000 AW15.TCH 1986.000 AW26.TCH 1.249 AAG8.TCH !!.000 AW19.TCH 1708.000 AW33.TCH 1.201 AW37.TCH 1.295 RTN-R.TCH 3.125 CFTC. TCH 436.931 NPHI.TCH 0.261 HTEN. TCH 1006.500 AMTE. TCH 60,250 ICV. TCH 32752.001 ** DEPTH TOD. TCH 508506198 DIFF. TCH - O. 050 RB. TCH 192. 250 AGT1 . TCH 11 . 000 W3T2. TCH 2600. 000 W2T3. TCH 2562. 000 W1T4 . TCH 1812. 000 DTT4. TCH 56. 094 AGTS. TCH 12. 000 W3T6. TCH 2043. 000 W2T7. TCH 2314. 000 W1T8. TCH 1708. 000 DTT8. TCH 55. 000 AGT9. TCH 13.000 CALU. TCH 6. 219 CSMX. TCH 1611 . 000 AWll. TCH 1878. 000 AW22. TCH 1. 640 TIME. TCH TENS. TCH W1 TI TCH DTT1 TCH AGT2 TCH W3 T3 TCH W2 T4 TCH W1 T5 TCH DTT5 TCH AGT6 TCH W3 T7 TCH W2T8 TCH Wi T9 TCH DTTg. TCH W2Fg. TCH AW2. TCH AW21. TCH AAG3. TCH AW14. TCH AW25. TCH A~AG7. TCH AW18. TCH AW29. TCH AW34. TCH AW38. TCH RCFT. TCH CNTC. TCH RGR. TCH RHTE. TCH DTEM. TCH IHV. TCH 8000.000 FEET TIME. TCH TENS.TCH W1T1.TCH DTT1.TCH AGT2 TCH W3T3 TCH W2 T4 TCH Wl T5 TCH DTT5 TCH AGT6 TCH W3T7 TCH W2TS.TCH W1T9.TCH DTT9.TCH W2Fg. TCH AW2.TCH AW21.TCH AAG3.TCH 2313.000 6925.000 2999.000 52,594 9,000 £245.000 2786.000 2950.000 57,188 11.000 2380.000 2998.000 '709,000 47.781 1,000 1.442 1.482 i0.000 '902.000 1.461 10.000 '695.000 0.192 1,199 1.271 412.696 2236.574 69.313 56.719 0.000 52752.001 2326.000 5865 000 2929 000 53 000 il 000 2965 000 2224 000 2707 000 58.188 12.000 2270.000 2!88,000 '621.000 48,188 1.000 1,397 1.599 12.000 ETIM. TCH Y~IRK. TCH W2T1 TCH W1 T2 TCH DTT2 TCH AGT3 TCH ;'I3 T4 TCH W2T5 TCH W1 T6. TCH DTT6. TCH AGT7. TCH W3 T8. TCH W2 T9. TCH WWM. TCH W3F9. TCH AW3. TCH AAG2. TCH A Wi 3. TCH AW24. TCH AAG6. TCH AW17. TCH AW28. TCH AW31. TCH AW35. TCH AW39. TCH RCNT. TCH TNPH. TCH GR. TCH ~qRES. TCH RCCL. TCH ETIM. TCH ,VJL~K. TCH W2T1 TCH W1T2 TCH DTT2 TCH AGT3 TCH W3T4 TCH W2T5 TCH W1T6 TCH DTT6. TCH AGT7.TCH W3T8.TCH W2T9.TCH WWM. TCH W3Fg. TCH AW3.TCH AAG2.TCH AW13.TCH 1818.093 0.000 3030.000 1579.000 53.375 10.000 2118.000 2784.000 1634.000 57.594 10,000 2368.000 332.000 0.996 1.000 1.239 11.000 1716.000 1 376 11 000 1865 000 1 511 1 256 1 241 0 212 1262 574 0 279 76 813 0 015 -0 007 3900,990 0.000 3006.000 1933.000 52.281 12.000 1786.000 2260.000 1732.000 58.688 11.000 1951.000 297.250 0.937 1.000 1.132 11.000 1818.000 CS. TCH DEVI, TCH W3 T1. TCH W2 T2. TCH W1 T3. TCH DTT3. TCH AGT4. TCH W3 TS. TCH W2 T6. TCH WI T7. TCH DTT7. TCH AGT8. TCH W3 T9. TCH ECCE. TCH CSN2V. TCH AAG1. TCH AW12. TCH AW23. TCH AAGS. TCH AW16. TCH AW27. TCH AAG g . TCH AW32. TCH AW36. TCH TNRA. TCH TALP. TCH NPOR. TCH STSG. TCH MTE~. TCH CCL. TCH CS. TCH DEVI. TCH W3 T1. TCH W2 T2. TCH W1 T3. TCH DTT3. TCH AGT4. TCH W3 TS. TCH W2 T6. TCH WI T7. TCH DTT7. TCH AGT8. TCH W3 T9. TCH ECCE. TCH CS~4N. TCH AAG1. TCH AW12. TCH AW23. TCH 176~ 000 22 188 2462 000 225~ 000 1716 000 54 094 9 000 2380 000 2043.000 1895.000 55,688 !3.000 370.500 9.083 0.000 ~.000 1~69.000 ~.251 23.000 1629.000 1.486 23.000 1.365 1.139 2.836 0.458 0,272 176 140.500 -0.014 1749.000 26,703 2366.000 3154.000 1904.000 53,875 £9.000 1839.000 2324.000 1986.000 57.281 ll. O00 307.250 3,110 $.000 1!.000 1848.000 1,365 LIS Tag=_ Verification Listing Schlum2~erger Al-aska Computing Center 20-MAR-1996 12:5! PAGE: AAG4 TCH AWl 5 TCH AW26 TCH AAGE TCH AW19 TCH AW35 TCH AW37 TCH RI?,~ TCH CFTS TCH NPHi. TCH HT~L TCH AJTTE,=. TCH I CZ. TCH TOD. TCH DIFF. TCH RB. TCH AGTi. TCH W3 T2. TCH W2T3. TCH W1 T4. TCH DTT4. TCH AGTS. TCH W3 T6. TCH W2T7. TCH W1 TS. TCH DTTS. TCH AGTg, TCH CALU. TCH CS~. TCH AW11. TCH AW22. TCH AAG4. TCH AW15 TCH AW26 TCH AAG8 TCH AW19 TCH AW33 TCH AW37 TCH RTNR TCH CFTC. TCH NPHi. TCH HT~. TCH AMTE. TCH IC/. TCH TOD. TCH DIFF.-. TCH RB. TCH AGT1. TCH W3T2. TCH £ O. 000 AW14. TCH £ £59. 000 AW25. TCH L. 400 AAG7. TCH ' ' . 000 AW18. TCH - :-22 . 000 AW29. TCH I . 059 AW34. TCH I . 063 AW38. TCH 3 . ill RCFT. TCH 553 . 002 CNTC. TCH O. 268 RGR. TCH ?~6. 500 RHTE. TCH $4 . 500 DTEM. TCH 52-52. 001 IHV. TCH ** iEPTH = 7000.000 FEET 553508207 0.050 £-5.500 9.000 2432.000 2-98.000 £-47.000 ~7.000 £3.000 2532.000 5~76.000 £~91.000 53.594 23.000 6 203 2399 000 £~42 000 i 549 £$ 000 £337 000 I 236 £I 000 ££Z2 000 9 982 ! 345 7.000 ££9.306 0.832 ~97.000 49.344 52~52.000 ** 2EPTH = E3~508259 9.050 276.750 9.000 2292.000 TIME. TCH TENS. TCH W1 Ti. TCH DTT1. TCH AGT2. TCH W3 T3. TCH W2T4. TCH W1 TS. TCH DTTS. TCH AGT6. TCH W3 T7. TCH W2T8. TCH Wi Tg. TCH DTT9. TCH W2F9. TCH AW2. TCH AW21. TCH AAG3. TCH AW14. TCH AW25. TCH AAG7. TCH AW18. TCH AW29. TCH AW34. TCH AW38. TCH RCFT. TCH CNTC. TCH RGR. TCH RHTE. TCH DT~. TCH IHV. TCH 6974.000 FEET TIME. TCM TENS. TCH W1 TI. TCH DTT1. TCH AGT2. TCH 1719. 000 AW24. 1. 362 AAG6. TEH 11 . 000 AW17. ! 660. 000 AW28. O. 183 AW31. --iH O. 968 AW35. 1 · 144 AW39. 334. 403 RCNT. TEH 984 · 797 TNPH. TEH 38. 188 GR. TSH 26.969 MRES. O. 000 RCCL. 32752. 001 978.000 5080.000 1650.000 52.094 11.000 1623.000 2540 000 1903 000 58 281 12 000 2542 000 2098 000 1612 000 48 094 1 000 1 393 1 563 10.000 1776.000 1.411 13.000 1691.000 0.184 1.089 1.190 110.790 647.386 9.148 -152.875 0.000 32752.000 977,000 5075,000 1722.000 51,375 11,000 ETIM. T_~H,, MARK. T 3H W2 T1. TCH W1 T2. DTT2. T3H AGT3. TSH W3 T4. T~H. W2TS. T~H WI T6. DTT6. TSH AGT7. TSH W3 TS. TCH W2 T 9 . T~H WWM. TCH W3F9 T~H AW3 TCH AAG2 TUH AW13 TSH AW24 TS3-[ AAG6 AW17 TSH AW28 AW31. TSH AW35. TSH AW39. T3H RCNT. T~H TNPH. TCH GR. TC'Td MRES. TS:q RCCL. TUH ETIM. T~ MARK. T~H W2 T1. TCH W1 T2 . TtJ~ DTT2. TCH 1.311 !2. 000 1833. 000 1.341 1.243 i. 062 0.176 1039.942 0.273 48. 625 O. 016 0.009 5910. 959 O. 000 3020. 000 1806. 000 52. 188 10.000 1981. 000 2848. 000 1709. 000 58.000 13. 000 1999. 000 302.500 1. OO3 1. 000 1 196 11 000 1606 000 ! 435 12 000 1948 000 ! 209 1 279 1 226 0 146 621. 741 1.139 12. 273 O. 016 O. 026 5960,795 0.000 1612.000 1700.000 51.281 AAGS.TCH AW16. TCH AW27. TCH AAG9. TCH AW32.TCH AW36.TCH TNRA.TCH TALP. TCH NPOR.TCH STSG. TCH MTEM. TCH CCL.TCH CS.TCH DEVI.TCH W3 Ti. TCH W2 T2. TCH W1 T3. TCH DTT3.TCH AGT4.TCH W3TS.TCH W2T6.TCH W1T7.TCH DTT7.TCH AGT8.TCH W3Tg. TCH ECCE. TCH CS~N. TCH AAG1 TCH AW12 TCH AW23 TCH AAG5 TCH AW16 TCH AW27 TCH AAG9 TCH AW32 TCH AW36 TCH TNRA TCH TALP TCH NPOR TCH STSG TCH MTEM. TCH CCL.TCH CS. TCH DEVI. TCH W3 TI. TCH W2 T2. TCH Wi T3. TCH !2.000 1719.000 1.188 23.000 2.313 1.178 2.875 3.359 0.254 176 130.125 0.018 1844.000 35.938 2266.000 2904.000 1596.000 54.781 10.000 2394.000 2124.000 1870.000 56 000 11 000 234 750 0 112 0 000 9 000 1757 000 1 066 13 000 1686 000 ! 619 !3 000 1.372 1.147 5.969 0.898 1.182 176 120.875 0.053 1839.000 35.938 2106.000 2492.000 1697.000 LIS Tape Verification Lis~ing Schlumberger Alaska Ccmpu~ing Cer.-_er 20-MAR-1996 12:51 PAGE: W2T3.TCH W1T4.TCH DTT4.TCH AGT5.TCH W3 T6. TCH W2T7. TCH W! T8 . TCH DTT8.TCH AGT9.TCH CALU. TCH CSIViX. TCH AWll. TCH AW22.TCH AAG4.TCH AW15. TCH AW26. TCH AAG8. TCH AW19. TCH AW33. TCH AW37.TCH RTNR.TCH CFTC. TCH NPHI.TCH HTEN. TCH AMTE. TCH ICV. TCH 1783.SS0 57.394 1932 £35 2728 232 1778 53 238 23 6 207 2068 1726 I 470 22 1607 0~0 I 22! 12.000 1612.030 0.~91 '.227 4.462 218.276 0.5!1 847.000 49.2!9 32752.001 W3 T3 W2T4 W1 T5 iSH DTT5 iSH AGT6 W3T7 TSH W2TE TSH W1 T9 iSH DTT9 i~ W2F9 AW2. T~ AW21. TSH ~G3. T~ AW14. i~ AW25. T~ ~G7. TCH AW18. T~ AW29. TCH AW34. T~ AW3 ~ . TSH RC~. T~ C~C. T~ RGR. T~ ~TE. TCH DT~. T~ I~. T~ 1514. 000 3168. 000 1614. 000 59. 281 12. 000 2084. 000 2182. 000 1609. 000 48. 000 1. 000 1. 438 1. 495 11. 000 1804. 000 1.399 12. 000 1844. 000 0 185 1 181 1 118 184 620 868 406 34 563 -103 000 0 000 32752 001 AGT3. TCH W3 T4. TCH W2TS. TCH W1 T6. TCH DTT6. TCH AGT7. TCH W3 T8. TCH 'W2T9. TCH r,'TWM. TCH W3 F9 . TCH AW3. TCH AAG2. TCH A Wi 3. TCH AW24. TCH AAG6. TCH AW17. TCH AW28. TCH AW31. TCH AW35. TCH AW39. TCH RCNT. TCH TNPH. TCH GR. TCH MRES. TCH RCCL. TCH 11.000 2016.000 2286.000 1655.000 58.500 12.000 2022.000 299.500 0.942 1.000 1.167 11.000 1651.000 1.756 12.000 1729.000 1 148 1 214 1 205 0 148 851 593 0 464 35 094 0 016 0 015 DTT3.TCH AGT4.TCH W3TS.TCH W2T6. TCH W1T7.TCH DTT7.TCH AGT8.TCH W3T9.TCH ECCE. TCH CS~N. TCH AAG1.TCH AW12.TCH AW23. TCH AAG5. TCH AW16. TCH AW27. TCH AAGg. TCH AW32.TCH AW36.TCH TNRA.TCH TALP. TCH NPOR.TCH STSG.TCH MT~.TCH CCL.TCH 54.375 12.000 1985.000 2046.000 1637.000 56.375 12.000 242.000 0.141 0.000 9.000 1687.000 1.214 12.000 1661.000 1.536 13.000 1.286 1.198 4.207 0.493 0.474 176 120.500 0.029 ** END OF DATA ** **** FILE TRAIL~ **** FILE NAME : TCH .001 SERVICE : PLAY VERSION : 44.2 DATE : 96/02/11 MAX REC SIZE : I~24 FILE TYPE : CR LAST FILE : ***~ FILE HEADER **** FILE NAME : TCH .002 SERVICE : PLAY VERSION : 44.2 DATE : 96/02/11 MAX REC SIZE : 1024 FILE TYPE : CR LAST FILE : LiS Tape Verification Lisuing Sshlumberger Alaska Co~uu~ing Cen~er 20-MAR-1996 12:51 PAGE: 10 DATA FORMAT SPECIFICATION RECS?~9 SET TYPE - 64EB ** TYPE .qEPR CODE VALUE ! 66 0 2 66 0 3 79 494 4 66 l 5 66 1 6 73 36 7 65 INCH 8 73 60 9 65 . ! IN !1 66 2 12 68 13 66 1 14 65 . liN 15 66 73 16 66 1 0 66 0 ** SET TYPE - CH~N ** NAME SERV ~WIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI~ASS MOD NUMB SAMP ELEM CODE (HEX) TOD TCH S 42 000 O0 0 2 1 1 4 73 8200000000 TIME TCH MS 42 636 21 0 2 1 1 4 68 8000000000 ETIM TCH S 42 636 21 0 2 1 1 4 68 8000000000 CS TCH F/HR 42 636 21 0 2 1 1 2 49 8200000000 DIFF TCH F 42 636 21 0 2 1 1 4 68 8000020000 TENS TCH LBF 42 635 21 0 2 1 1 4 68 8000000000 MARK TCH F 42 i50 O1 0 2 1 1 2 49 8000000000 DEVI TCH DEG 42 620 !! 0 2 1 1 2 49 8000000000 RB TCH DEG 42 631 !1 0 2 1 1 2 49 8000000000 W1T1 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T1 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W3T1 TCH 42 OgO O0 0 2 3 1 6 49 8000000000 AGT1 TCH DB 42 000 O0 0 2 3 1 6 49 8000000000 DTT1 TCH US 42 000 O0 0 2 3 1 6 49 8000000000 W1T2 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T2 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W3T2 TCH 42 000 O0 0 2 3 1 6 49 8000000000 AGT2 TCH DB 42 000 O0 0 2 3 1 6 49 8000000000 DTT2 TCH US 42 000 O0 0 2 3 1 6 49 8000000000 W1T3 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T3 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W3T3 TCH 42 000 O0 0 2 3 1 6 49 8000000000 AGT3 TCH DB 42 000 O0 0 2 3 1 6 49 8000000000 DTT3 TCH US 42 000 O0 0 2 3 1 6 49 8000000000 W1T4 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T4 TCH 42 000 O0 0 2 3 1 6 49 8000000000 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 23-MAR-1996 12:51 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE ~FUMB NUMB SIZE REPR PROCESS i~ ORDER # LOG TYPE CLASS .'.,:OD NUMBSAMP EL~.I CODE (HEX) W3T4 TCH 42 000 O0 3 2 3 1 6 49 8000000000 AGT4 TCH DB 42 000 O0 ~ 2 3 1 6 49 8000000000 DTT4 TCH US 42 000 O0 3 2 3 1 6 49 8000000000 WlT5 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T5 TCH 42 000 O0 O 2 3 1 6 49 8000000000 W3T5 TCH 42 000 O0 O 2 3 1 6 49 8000000000 AGT5 TCH DB 42 000 O0 ~ 2 3 1 6 49 8000000000 DTT5 TCH US 42 000 O0 O 2 3 1 6 49 8000000000 W1T6 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T6 TCH 42 000 O0 O 2 3 1 6 49 8000000000 W3T6 TCH 42 000 O0 0 2 3 1 6 49 8000000000 AGT6 TCH DB 42 000 O0 0 2 3 1 6 49 8000000000 DTT6 TCH US 42 000 O0 0 2 3 1 6 49 8000000000 W1T7 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T7 TCH, 42 000 O0 0 2 3 1 6 49 8000000000 W3T7 TCH 42 000 O0 ~ 2 3 1 6 49 8000000000 AGT7 TCH DB 42 000 O0 0 2 3 1 6 49 8000000000 DTT7 TCH US 42 000 O0 0 2 3 1 6 49 8000000000 W1T8 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T8 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W3T8 TCH 42 000 O0 0 2 3 1 6 49 8000000000 AGT8 TCH DB 42 000 O0 0 2 3 1 6 49 8000000000 DTT8 TCH US 42 000 O0 0 2 3 1 6 49 8000000000 W1T9 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W2T9 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W3T9 TCH 42 000 O0 0 2 3 1 6 49 8000000000 AGT9 TCH DB 42 000 O0 0 2 3 1 6 49 8000000000 DTT9 TCH US 42 000 O0 0 2 3 1 6 49 8000000000 ~WM TCH 42 000 O0 0 2 3 1 6 49 8200000000 ECCE TCH IN 42 000 O0 0 2 3 1 6 49 8200000000 CALU TCH iN 42 280 50 0 2 3 1 6 49 8200000000 W2F9 TCH 42 000 O0 0 2 3 1 6 49 8000000000 W3F9 TCH 42 000 O0 O 2 3 1 6 49 8000000000 CSP~N TCH 42 000 O0 O 2 1 ! 2 49 8200000000 CSI42fTCH 42 000 O0 0 2 1 1 2 49 8200000000 AW2 TCH 42 000 O0 O 2 1 1 2 49 8000000000 AW3 TCH 42 000 O0 0 2 1 1 2 49 8000000000 AAG1 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AWll TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW21 TCH 42 000 O0 O 2 1 1 2 49 9000000000 AAG2 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW12 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW22 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AAG3 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW13 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW23 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AAG4 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW14 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW24 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AAG5 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW15 TCH 42 000 O0 0 2 1 1 2 49 9000000000 LIS Tape Verificauion Lis~ing Schlumberger Alaska Computing Center 25-~fAR-1996 12:51 PAGE: NA~E SERV t~IT SERVICE API API API API FILE ~FJMB NUMB SIZE REPR PROCESS iD ORDER # LOG TYPE CLASS M~D NUMB SAMP ELE~ CODE (HEX) AW25 TCH 42 000 O0 £ 2 I 1 2 49 9000000000 ~G6 TCH 42 000 O0 3 2 ! 1 2 49 9000000000 AW16 TCH 42 000 O0 3 2 ! 1 2 49 9000000000 AW26 TCH 42 000 O0 £ 2 ! 1 2 49 9000000000 AAG7 TCH 42 000 O0 3 2 I 1 2 49 9000000000 AW17 TCH 42 000 O0 3 2 1 1 2 49 9000000000 AW27 TCH 42 000 O0 3 2 i 1 2 49 9000000000 AAG8 TCH 42 000 O0 3 2 2 1 2 49 9000000000 AW18 TCH 42 000 O0 .3 2 ! 1 2 49 9000000000 AW28 TCH 42 000 O0 3 2 1 1 2 49 9000000000 AAG9 TCH 42 000 O0 D 2 I 1 2 49 9000000000 AW19 TCH 42 000 O0 3 2 i 1 2 49 9000000000 AW29 TCH 42 000 O0 O 2 1 1 2 49 9000000000 AW31 TCH 42 000 O0 9 2 1 1 2 49 9000000000 AW32 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW33 TCH 42 000 O0 3 2 I ! 2 49 9000000000 AW34 TCH 42 000 O0 3 2 1 1 2 49 9000000000 AW35 TCH 42 000 O0 ~ 2 ! 1 2 49 9000000000 AW36 TCH 42 000 O0 0 2 1 1 2 49 9000000000 AW37 TCH 42 000 O0 ~ 2 1 1 2 49 9000000000 AW38 TCH 42 000 O0 0 2 i 1 2 49 9000000000 AW39 TCH 42 000 O0 0 2 1 1 2 49 9000000000 TITRA TCH 42 420 O1 9 2 1 1 4 68 8440000000 RTNR TCH 42 420 O1 9 2 1 1 4 68 8040020000 RCFT TCH CPS 42 420 O1 0 2 1 1 4 68 8000020400 RC~Ff TCH CPS 42 420 O1 ~ 2 1 1 4 68 8000020400 TALP TCH 42 890 O0 ~ 2 1 1 4 68 8200020400 CFTC TCH CPS 42 420 O1 ~ 2 1 1 4 68 8800000400 CIPTC TCH CPS 42 420 O1 ~ 2 1 1 4 68 8800000400 TNPH TCH V/V 42 890 O0 O 2 1 I 4 68 8240002400 NPOR TCH V/V 42 890 O0 3 2 1 1 4 68 8240002400 NPHI TCH V/V 42 890 O0 3 2 ! 1 4 68 8240000000 RGR TCH GAPI 42 310 O1 2 2 ! 1 2 49 8000020000 GR TCH GAPI 42 310 O1 ~ 2 ! 1 2 49 ~400000000 STSG TCH 42 000 O0 O 2 1 1 2 79 8000000000 HTEN TCH LBF 42 000 O0 ~ 2 1 1 2 49 8000000000 RHTE TCH LBF 42 000 O0 3 2 ! 1 2 49 8000000000 MRES TCH OHPffq 42 000 O0 ~ 2 1 1 2 49 8000000000 MT~q TCH DEGF 42 000 O0 0 2 1 1 2 49 8000000000 AMTE TCH DEGC 42 000 O0 O 2 1 1 2 49 8400000000 DTE~ TCH DC/K 42 000 O0 0 2 1 1 2 49 8000000000 RCCL TCH 42 150 O1 0 2 6 1 12 49 8000020000 CCL TCH 42 150 O1 0 2 6 1 12 49 8400000000 ICV TCH F3 42 282 O1 3 2 1 1 2 49 8400000000 IHV TCH F3 42 282 O1 0 2 1 1 2 49 8400000000 ** DATA ** LIS Tape Verificmuion LisCing Schlumberger Alaska Compucing Cenuer 20-LVzAR-1996 12:51 PAGE: 13 TOD. TCH DIFF. TCH RB. TCH AGT1. TCH W3 T2. TCH W2T3. TCH W1 T4 . TCH DTT4. TCH AGT5. TCH W3 T6. TCH W2TT. TCH WI TS. TCH DTT8. TCH AGT~. TCH CALU. TCH CSSE~. TCH AWi 1. TCH AW22. TCH AAG4. TCH AW15. TCH AW26. TCH AAG8. TCH AWl 9. TCH AW33. TCH AW37. TCH RTNR. TCH CFTC. TCH NPHI. TCH HTEN. TCH AMTE. TCH ICV. TCH TOD. TCH DIFF. TCH RB. TCH AGT1. TCH W3 T2. TCH W2T3. TCH Wi T4. TCH DTT4. TCH AGTS. TCH W3 T6. TCH W2T7. TCH Wi TS. TCH DTTS. TCH AGT9. TCH CALU. TCH CS~E<. TCH AW11. TCH AW22. TC~ ** DEPTH = 12552. 000 FEET 553492751 22390.000 269.750 0.000 0.000 O.O00 0.000 0.000 $.000 0.000 0.000 0.000 0.000 0.000 2.291 304 750 4 000 -0 815 0 000 0 000 0 000 -92768 001 0 000 0 000 0 974 2.667 353.412 0.211 -!22.000 78.500 0,000 ** DEPTH = 508493941 0,050 Z87,875 4,000 2170,000 2246.000 1792.000 54.594 7.0OO 2060.000 2458.000 i712.000 54.500 7.000 6.227 241.000 1737.000 1.220 TI?,~. TCH TEi~. TCH Wi Ti . TCH DTTi. TCH AGT2. TCH W3 T3. TCH W2 T4. TCH W1 T5. TCH DTTS. TCH AGT6. TC~ W3 T7. TCH W2 T8. TC~ Wi T~. TCH DTT~. TCH W2F~. TCH AW2. TCH AW21. TCH AAG3. TCH AWl4. TCH AW25. TCH AAG7. TCH AW18. TCH AW29. TCH AW34. TCH AW38. TCH RCFT. TCH CNTC. TCH RGR. TCH RHTE. TCH DTE~. TCH IhW. TCH 12000.000 FEET TIME. TCH TENS. TCH WI Ti. TCH DTT1. TCH AGT2. TCH W3 T3 . TCH W2T4. TCH W1 T5. TCH DTTS. TCH AGT6. TCH W3TT. TC"~ W2 T8. TCH W1 T9. TCH DTT9. TCH W2F~. TC"N AW2. TC"H AW21. TCH AAG3. TCH 55~.000 4535.000 3.000 3.000 2.000 3.000 2.000 ~ 000 3.000 3.000 3.000 3.000 3.000 3.000 Z.O00 ~.403 4.000 0.000 0.000 9.000 0.974 -32768.001 0.000 3.000 -32768.001 329.431 ~2.563 44.719 -1072.000 9.000 0.000 1339.000 9220.000 !755.000 53.594 4.000 2084.000 2666,000 !866.000 55.875 7.OOO 2378.000 2072,000 1546.000 47.375 l. O00 1.308 1.416 4.000 ETIM. TCH 5~ARK. TCH W2T1. TCH W1 T2 . TCH DTT2.TCH AGT3.TCH W3T4.TCH W2T5.TCH W1T6.TCH DTT6.TCH AGT7.TCH W3T8.TCH W2T9.TCH WWM. TCH W3F9 TCH AW3 TCH AAG2 TCH AW13 TCH AW24 TCH AAG6 TCH AWl 7 TCH AW28 TCH AW31.TCH AW35.TCH AW39.TCH RCNT. TCH TNPH. TCH GR.TCH MRES.TCH RCCL.TCH ETIM. TCH MARK. TCH W2T1 TCH W1T2 TCH DTT2 TCH AGT3 TCH W3T4 TCH W2T5 TCH W1T6 TCH DTT6.TCH AGT7.TCH W3TS.TCH W2T9.TCH WWM. TCM W3F9.TCH AW3.TCH AAG2.TCH AWl3.TCH 23.301 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0 000 1 000 1 163 -0 815 0 000 0 000 0 000 0 974 -32768 001 4.000 0.000 0,000 882. 358 0.230 51 . 625 O. 012 -0. 019 1214.059 0.000 2496.000 1716.000 53.188 4.000 2392.000 2416.000 1850.000 56.188 4.000 2025.000 319.000 0.906 1.000 1.260 4.000 1558.000 CS.TCH DEVI. TCH W3 TI. TCH W2T2. TCH W1 T3. TCH DTT3. TCH AGT4.TCH W3 TS. TCH W2 T6, TCH Wi T7 . TCH DTT7.TCH AGTS.TCH W3T~.TCH ECCE. TCH CS~N. TCH AAG2 TCH AW12 TCH AW23 TCH AAG5 TCH AW16 TCH AW27 TCH AAG9 TCH AW32 TCH AW36 TCH TNRA TCH TALP. TCH NPOR.TCH STSG. TCH MTEM. TCH CCL.TCH CS. TCH DEVI.TCH W3 TI. TCH W2 T2. TCH W1 T3. TCH DTT3. TCH AGT4. TCH W3TS.TCH W2T6.TCH W1T7.TCH DTT7.TCH AGT8.TCH W3T9.TCH ECCE. TCH CSt4N. TCH AAG1.TCH AW12.TCH AW23.TCH 1810.000 35.969 ~ 000 3.000 0.000 O.O00 0.$00 0.000 9.000 0.000 0.000 0.000 0.000 0.000 0.000 4 000 -0 815 0 000 0 000 0 000 0 974 0 000 -0 815 0 000 2 551 0.283 0.230 I76 173.375 -0.038 1727.000 35.938 2254.000 2126.000 1582.000 53 500 4 000 2108 000 2070 000 1855 000 56 281 4 000 378000 0.061 0.000 4.000 1740.000 1.389 LiS Tape Verification Lis~ing Schlumkerger Alaska Computing Cen~er 20-MAR-1996 12:52 PAGE: 14 AAG4. TEH AW15. iEH AW26. TCH AAGS. TSH AW19. TSH AW33. TSH AW3 7. TEH R T2~. TCH CFTC. -_EH NPHI. TCH HT~L TCH AMTE. TCH I C~-/. TCH TOD. TCH DIFF. TCH RB. TCH AGTI. TCH W3 T2. TCH W2T3. TCH WI T4. TCH DTT4. TCH AGTS. TC7¥ W3T6. TCH W2TT. TCH W1 TS. TCH DTT8. TCH AGTg. TC"H CALU. TCH CSNE~. TCH AW11 TCH AW22 TCH AAG4 AW15 TCH AW26 TCH AAG8 TCH AW19. TCH AW33. TCH AW37. TCH RTNR. TCH CFTC. TCH NPHI. TCT~ HTEN. TCH AMTE. TC"H I C"~. TCH 4. 000 1852. 000 1. 151 4. 000 i545. 000 ! . 403 ! .212 2 656 529 756 0 2i5 851 000 76 750 41 156 ** DEPTH = 508494289 0.050 188.000 5.000 2452.000 2244.000 1774.000 54.688 6.000 2162.000 i734.000 1743.000 53.281 7.0OO 6.223 956.500 1896.000 1 408 3 000 1654 000 0 765 6 000 i559 000 1 190 1.247 2.842 550.435 0.225 832.000 76.125 53.813 AW14. TCH AW25. TCH AAG7. TCH AW18. TCH AW29. TCH AW34. TCH AW38. TCH RCFT. TCH CNTC. TCH RGR. TCH RHTE. TCH DTEM. TCH IHV. TCH 11833.000 FEET TItlE. TCH TENS. TCH WI TI. TCH DTT1. TCH AGT2. TCH W3 T3. TCH W2 T4. TCH WI T5. TCH DTTS. TCH AGT6. TCH W3 T7. TCH W2TS. TCH Wi Tg. TCH DTTg. TCH W2F9. TCH AW2. TCH AW21. TCH AAG3 TCH AW14 TCH AW25 TCH AAG7 TCH AW18 TCH AW29 TCH AW34 TCH AW38 TCH RCFT. TCH CNTC. TCH RGR. TCH RHTE. TCH DTE~. TCH IHV. TCH 1779. 000 AW24. 1 . 389 AAG6. 4. 000 AW17. 1754. 000 AW28. _ O. 207 AW31 . 1. 328 AW35.7_---4 1 . 207 AW39. 478. 020 RCNT. 1371 . 393 TNPH. 65. 063 GR. -99. 000 MRES. T~~. O. 000 RCCL. 115. 938 1047.000 9045 000 1990 000 52 781 5 000 1948 000 1864 000 1645 000 57.188 7.OOO 2074.000 2806.000 1559.000 47.375 1.000 1.146 1.137 5.000 1800.000 1.100 3.000 1839.000 0.215 1.149 1.298 490.738 1510.024 81.500 -118.000 0.000 151.250 ETIM. MARK. W2T1. Wi T2 . DTT2 . AGT3 . W3 T4. W2TS . Wi T6. DTT6 . AGT7 . W3 T8. W2 Tg . WWM . W3F9. AW3. AAG2 . AW13. AW24. AAG6 . AW17. AW28. AW31. AW35. AW39. R CNT . TNPH. GR. ~iRES . R CCL. 1 . 526 7. 000 1837. 000 i. 153 ! .299 1.217 0.235 1313. 686 0.243 71. 875 O. 012 0.018 1561.634 0.000 2194.000 1914.000 52 875 5 000 2072 000 1785 000 1876 000 57 094 3 000 2194 000 330 000 0.830 1.000 1.206 5.000 1814.000 1.025 7.000 1671.000 1. 475 1.194 1. 094 0.236 1422.928 0.266 85.813 0.012 0.010 AAGS.TCH AW16.TCH AW27.TCH AAG9.TCH AW32.TCH AW36. TCH TNRA. TCH TALP. TCH NPOR.TCH STSG.TCH MTElVi. TCH CCL.TCH CS TCH DEVI TCH W3 T1 TCH W2T2 TCH W1 T3 TCH DTT3 TCH AGT4 TCH W3T5 TCH W2T6 TCH W1T7, TCH DTT7 TCH AGT8.TCH W3Tg. TCH ECCE. TCH CS~N. TCH AAG1.TCH AW12.TCH AW23.TCH AAG5.TCH AW16.TCH AW27.TCH AAGg. TCH AW32.TCH AW36.TCH TNRA.TCH TALP. TCH NPOR.TCH STSG. TCH MTEM. TCH CCL.TCH 7.000 1833.000 1.286 7.O00 1.274 1.085 2.579 0.458 0.258 176 170.250 0.036 1730.000 34.625 2408.000 2480.000 1644.000 53.688 3.000 1827 000 2048 000 1687 000 55 781 6 000 367 750 0.081 23.297 4.332 1913.000 1.290 6.000 1894.000 1. 027 7. 000 1.294 1. 039 2. 638 0.540 0.288 176 169.125 0.021 ** ---~'~ OF DATA ** LIS Tape Verification Lis[ing Schlumberger Alaska Co?..pu[ing Cen~er 20-MAR-1996 12:51 PAGE: 15 **** FILE TRAILER **** FILE NAME : TCH .002 SERVICE · PLAY VERSION : 44.2 DATE : 96/32/11 ~4AXREC SIZE : i024 FILE TYPE : CR LAST FILE : * * * * TAPE TRAIL~ * * * * SERVICE NAME : CPLAYA DATE : 96/02/16 ORIGIN · CSU TAPE NAME : CONTINUATION # : O0 PREVIOUS TAPE : COMPLENT : SCHLUMBERGER WELL SERVICES CSU TAPE **** REEL TRAILER **** SERVICE NAME : CPLAYA DATE : 96/02/16 ORIGIN : CSU REEL NAME : CONTINUATION # : O0 PREVIOUS REEL : COf4FIE2VT : SCHLUF~ERGER WELL SERVICES CSU TAPE
