The URL can be used to link to this page

Home My WebLink About193-1287. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU Z-08A Renew Well Suspension Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-128 50-029-21787-01-00 N/A ADL 0028245 11475 Conductor Surface Intermediate Production Liner 9171 80 2640 10046 1532 10880 20" 13-3/8" 9-5/8" 7" 8657 34 - 114 35 - 2675 34 - 10080 9943 - 11475 34 - 114 35 - 2675 34 - 7990 7894 - 9171 10832 2260 4760 7020 None 5020 6870 8160 10608 - 10612 3-1/2" 9.2# x 3-1/2" 8.18#, 4-1/2" 12.6# 13cr80, L80 32 - 10726, 10394 -107178420 - 8423 Structural 3-1/2" Baker S-3 Packer 4-1/2" Baker S3 Packers 10298, 8151 10422, 8257 / 10668, 8473 Date: Torin Roschinger Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY 8/2/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:21 am, Jul 21, 2023 323-418 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.21 09:04:21 -08'00' Torin Roschinger (4662) MGR26JULY23 July 24, 2028 SFD 7/26/2023 DSR-7/24/23GCW 07/28/2023JLC 7/28/2023 07/28/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.28 16:34:36 -06'00' RBDMS JSB 080123 Hilcorp North Slope, LLC Torin Roschinger, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 07/20/2023 Chairman Brett Huber, Sr. Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Well Z-08A (PTD #193128) Application for Renewal of Existing Suspension (10-403) Dear Chairman Huber, An AOGCC witnessed suspended well inspection of Prudhoe well Z-08A was conducted on 08/06/2022 (20 AAC 25.110 (h)). The submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: x Suspended Well Site Inspection form documenting the pressures and site condition. x Wellbore diagram illustrating the current configuration of the well. Prudhoe well Z-08A was suspended on 10/02/2013 and has future utility as a rig sidetrack candidate. The strata through which the well was drilled is neither abnormally geopressured nor depleted. The well is mechanically sound, passing a MIT-T to 3007 psi on 9/2/2013 post 7” liner cement plug. After CTD drilled into the cement and the bottomhole assembly became stuck the rig obtained a passing pressure test of the tubing and cement to 1930 psi on 10/3/2014. Based on these conditions and the inspection on 08/06/2022, Prudhoe well Z-08A meets the provisions required in 20 AAC 25.110 (a)(1). Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). In summary, Hilcorp believes Prudhoe well Z-08A is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 406-570-9630 or Oliver Sternicki at 907-564-4891. Sincerely, Torin Roschinger PBW Operations Manager Attachments Technical Justification 2022 Suspended Well Site Inspection Form Wellbore Schematic Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.21 08:32:00 -08'00' Torin Roschinger (4662) Prudhoe Well Z-08A (PTD #193128) Technical Justification for Renewal of Suspended Status 07/20/2023 Well History and Status Prudhoe well Z-08 was originally completed as a producer in 1988 and was sidetracked as Z- 08A in 1993. In 2007 after developing a tubing leak a RWO repaired the well. Z-08B was planned as a CTD sidetrack in late 2013 under sundry 313-422. Pre rig pressure testing of the well passed an MIT-IA to 3000 psi and a MIT-OA to 2000 psi on 8/21/2013. On 8/29/2013 service coil set a cement plug in the 7” liner to abandon the Z-08A perfs. Slickline tagged TOC at 10632’ SLM on 8/30/2013 and the cement plug passed a MIT-T to 3000 psi on 9/2/2013. CTD milled a pilot hole in the cement from 10676-10883’ MD in preparation for setting a whipstock. While pulling out of hole the bottom hole assembly became stuck at 10839’ MD and the lower 11.5’ of the tool were left in hole on 9/27/2013. Multiple attempts to were made to retrieve the fish, but none were successful. An MIT-T passed at 1930 psi on 10/3/2014 prior to the rig freeze protecting the tubing and moving off the well. The well future utility is as a sidetrack candidate. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe well Z-08A is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O = 73/ 375/ 3 psi. Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for Z- 08A. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. By Anne Prysunka at 4:21 pm, Aug 09, 2022 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 InspectNo:susLOL220806123257 Well Pressures (psi): Date Inspected:8/6/2022 Inspector:Lou Laubenstein If Verified, How?Other (specify in comments) Suspension Date:10/2/2013 #313-422 Tubing:73 IA:375 OA:27 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:8/5/2022 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT Z-08A Permit Number:1931280 Wellhead Condition Wellhead clean and in good condition, no leaks or visual issues Surrounding Surface Condition Area is clean and free of debris Condition of Cellar Water is in cellar box, clean without and sheen Comments Supervisor Comments Photos (2) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, September 2, 2022 9 99 9 9 9 9 9 9 2022-0806_Suspend_PBU_Z-08A_photos_llPage 1 of 1Suspended Well Inspection – PBU Z-08APTD 1931280AOGCC Inspection # susLOL220806123257Photos by AOGCC Inspector L. Laubenstein8/6/2022 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:193-128 6.50-029-21787-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11475 10880 8656 10298 10832 8151 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34 - 114 34 - 114 Surface 2640 13-3/8" 35 - 2675 35 - 2675 5020 2260 Intermediate 10046 9-5/8" 34 - 10080 34 - 7990 6870 4760 Production Perforation Depth: Measured depth: 10608 - 10612 feet True vertical depth:8420 - 8423 feet Tubing (size, grade, measured and true vertical depth)36 - 10726 36 - 8523 10298 8151Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker S-3 Packer Liner 1532 7" 9943 - 11475 7894 - 9171 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Andy Ogg PBFieldWellIntegrity@hilcorp.co Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907-659-5102 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9171 Sundry Number or N/A if C.O. Exempt: No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Inspect Suspended Well Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028245 PBU Z-08A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" 9.2# 13cr80 x 3-1/2" 8.18# 13cr80 By Samantha Carlisle at 12:03 pm, Aug 17, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.17 09:30:36 - 08'00' Stan Golis RBDMS HEW 8/19/2020MGR02SEP2020 SFD 8/17/2020DSR-8/17/2020 ACTIVITY DATE SUMMARY 8/2/2020 T/I/O = 140/350/50. Suspended well inspection by AOGCC rep Matt Herrera. Daily Report of Well Operations PBU Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:Z-08 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD):1931280 API Number: Operator:Hilcorp North Slope LLC Date Suspended: 10/2/2013 Surface Location:Section: 19 Twsp: 11N Range: 12E Nearest active pad or road:Z Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good. Pad or location surface: Good. Location cleanup needed: No. Pits condition: N/A. Surrounding area condition: Good. Water/fluids on pad: No. Discoloration, Sheens on pad, pits or water: None. Samples taken: None. Access road condition: Access road and pad in good condition. Photographs taken (# and description):No. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Tree - Actuated Swab, Upper Master, Lower Master. Wellhead - TBG spool with 2 casing valves, Starting head with 1 casing valve. Cellar description, condition, fluids: Snow/Ice melt. Clean water. Fluid in cellar below lowermost casing valve. Rat Hole: N/A. Wellhouse or protective barriers: Yes, wellhouse. Well identification sign: Yes. Tubing Pressure (or casing if no tubing):140 psi. Annulus pressures: IA / OA = 350 psi / 50 psi. Wellhead Photos taken (# and description): Yes, (1) wellhouse and sign, (1) wellhead/tree. Work Required: None Operator Rep (name and signature):Eric Dickerman AOGCC Inspector:Matt Herrera Other Observers: Inspection Date: 8/2/2020 AOGCC Notice Date: 7/31/2020 Time of arrival: 10:00am Time of Departure: 10:15am Site access method: Truck/Walk. 500292178701 Re-Inspection SUSPENDED Suspended Well Inspection Re'ew Report |nspectNo: susK8FH2008040819I9 Date Inspected: 8/2/20I0 Inspector: Matt Herrera Type of Inspection: Subsequent —|' VVe!|Name� PRUDH0EBAY UNIT Z4)8A ' DateADG[CNotiHe6: 7/3I/2020 -1 Permit Number: 1931280 | Operator: Hi|co/pNorth Slope, LLC Suspension Approval: Completion Report Operator Rep: EhcDickennan Suspension Date: 10/2/2013 Wellbore Diagram Avail? Location Verified? W Photos Taken? � | |fVerified, How? Other (specify incomments) ' | Offshore? El WellWellPnPressures (psi): Tubing: 140 ' Fluid in Cellar?Ll |A: 350' 8PV|nstmUed? OA: 50 VRP|ug(s)Installed? VVeUhea6[ondition Wellhead in good condition; no leaks. All valves and gauges functional, SSV still installed in closed position. Condition ofCellar Cellar looked good no water or stains and no subsidence. Surrounding SutfaceCondition � VVeUhousestill onwell. Surrounding area and gravel was clean with no stains or subsidence. Laterals disconnected and - blinded atthe header. � Ozmmetits Location Verified with Aeha|Photo��ap ' Supervisor Comments Photos (3)attached -7 -Z Thursday, August 2lZ0ZO Suspended Well Inspection — PBU Z -08A PTD 1931280 AOGCC Inspection # susMFH2O0804081919 Photos by AOGCC Inspector M. Herrera 8/2/2020 2020-0802_Suspend_PBU_Z-08 A_mh.docx Page 1 of 2 STATE OF ALASKA ALASI~~IL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS ~ Other ^ 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q RB I Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Qperator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 193-1280 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-21787-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~ ADLO-028245 BU Z-08A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11475 feet Plugs (measured) None feet true vertical 9180.02 feet Junk (measured) None feet Effective Depth measured 11426 feet Packer (measured) 10298 10422 10640 true vertical 9137.89 feet (true vertical) 8161 8266 8457 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2678 13-3/8" 68# L-80 SURFACE - 2678 SURFACE - 2678 4930 2270 Intermediate 10080 9-5/8" 47# L-80 SURFACE - 10080 SURFACE - 7990 6870 4760 Production Liner 1531 7" 29# L-80 9944 - 11475 7894 - 9180 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# 13CR80 SURFACE - 10726 SURFACE - 8533 4-1/2" 12.6# L-80 10394 - 10717 8242 - 8525 Packers and SSSV (type, measured and true vertical depth) 7X3-1/2" BAKER S-3 10298 8161 7"X4-1 /2" BAKER S-3 10422 8266 7"X4-1/2" BAKER S-3 10640 8457 12. Stimulation or cement squeeze summary: Intervals treated (measured): 0SS10[1 ~ ~,pC'(1m Treatment descriptions including volumes used and final pressure: ~ ~ 13. Representative Daily Average Production or Inje n ata t1G~ ~' "` Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 44 2356 423 207 Subsequent to operation: 48 2699 372 260 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/7/2010 VI111 IV-YVY yCGVWG4 l/GVV~ RBDMS ~1L a 8 ~r r ~f~ ~ ^L. /~v~v~~~~~ v~~y~~~u~ v~~~~ Z-08A 193-128 PFRF ATTOrHMFNT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z-08A 10/1/93 PER 10,608. 10,612. 8,429.09 8,432.61 2-08A 10/10/93 STO 10,608. 10,612. 8,429.09 8,432.61 Z-08A 10/15/93 PER 11,144. 11,174. 8,894.98 8,920.87 Z-08A 10/15/93 PER 11,188. 11,200. 8,932.96 8,943.31 Z-08A 10/15/93 PER 11,202. 11,216. 8,945.03 8,957.11 Z-08A 10/15/93 PER 11,222. 11,232. 8,962.29 8,970.91 Z-08A 11/11/93 APF 11,140. 11,145. 8,891.52 8,895.84 Z-08A 11/11/93 APF 11,230. 11,235. 8,969.18 8,973.5 Z-08A 12/4/93 SQZ 11,140. 11,235. 8,891.52 8,973.5 Z-08A 12/11/93 RPF 11,150. 11,174. 8,900.16 8,920.87 Z-08A 12/11/93 RPF 11,188. 11,200. 8,932.96 8,943.31 Z-08A 12/11/93 RPF 11,202. 11,216. 8,945.03 8,957.11 Z-08A 12/11/93 RPF 11,222. 11,227. 8,962.29 8,966.6 Z-08A 10/23/94 RPF 11,150. 11,174. 8,900.16 8,920.87 Z-08A 7/29/07 APF 11,125. 11,150. 8,878.57 8,900.16 Z-08A 12/18/07 APF 11,095. 11,115. 8,852.64 8,869.93 Z-08A 3/17/08 APF 11,060. 11,085. 8,822.33 8,843.99 Z-08A 3/23/08 APF 11,041. 11,056. 8,805.84 8,818.86 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE + • • Z-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/2/2014,ASRC Test Unit #3, Transport equipment to location, MIRU, Stand by for Pump Crew, ***Job in Progress*** ~ Inlet Z-08, Outlet Z-05 6/3/2010~ASRC Test Unit #3, Stand by for Pump Crew, Stand by due to high winds, i***Job in Progress*** Inlet Z-08. Outlet Z-05 6/3/2010~Assist ASRC test unit (Acid) Road to location, SB for WS to respot flowback tanks. i **Cont. on next WSR** 6/4/2010ASRC Test Unit #3, End stand by, Proceed with Acid Stim Operations. Inlet Z-08, Outlet Z-05 ~ 6/4/2010 _ _ .~.....-~...~., -.~~ __m_~___ _._. ~ ~ _____. __ **Cont. from prev. WSR** T/I/0=1800/1760/120 Temp=S1 Assist ASRC test unit (Acid) Pumped down TBG: 2 bbls meth spear, 12 bbsl 12% HCL, 5 bbls meth flush/spacer, and 46 bbls crude to start overflush. Job in progress. **Cont. on next WSR** 6/5/2010 **Cont. from prev. WSR** ~ Pumped 49 bbls crude down TBG (95 total) to complete overflush. Well testers flowed well. RU to IA and pumped 5 bbls 60/40 spear and 594 bbls crude to Toad. and cap with 5 bbls 60/40 meth water. ASRC on well at departure wing °shut, swab open, SSV open, master open, casing valves open A/I line closed. °Final Whp's= 375, 120, 150. 010 **Job continued on 6/6/10** Pump Mud Acid Treatment:. Pump: Preflush- 20 bbls of 3% NH4CL + 0.2% F103, Acid- 50 bbls of 12% HCI acid, Mud Acid- 50 bbls of 9:1 Mud acid + 5% U067 mutual solvent, Overflush- 75 bbls of 3% NH4CL + 0.2% F103, Diversion- 14 bbls of 450# DS wax beads in 30# HEC gel, Spacer- 10 bbls of 3% NH4CL + 0.2% F103, Acid- 50 bbls of 9:1 Mud acid + 5% U067 mutual solvent, Overflush- 75 bbls of 3% NH4CL + 0.2% F103, Diversion- 14 bbls of 450# DS wax beads in 30#HEC gel, Spacer- 10 bbls of3% NH4CL + 0.2% F103, Acid- 50 bbls of 12% HCI acid, Mud acid- 50 bbls of 9:1 Mud acid + 5% U067 mutual solvent, Overflush- 100 bbls of 3% NH4CL + 0.2% F103. 6/5/2010=':ASRC Test Unit #3,Proceed with Acid Stim Operations, ***Job in Progress*** s Inlet Z-08, Outlet Z-05 j~. 6/6/2010~Job continued from 6/5/10: ~ Pump Mud Acid Treatment: Pump: Preflush- 20 bbls of 3% NH4CL + 0.2% IF103, Acid- 50 bbls of 12% HCI acid, Mud Acid- 50 bbls of 9:1 Mud acid + 5% U067 mutual solvent, Overflush- 75 bbls of 3% NH4CL + 0.2% F103, Diversion- 14 bbls of 450# DS wax beads in 30#HEC gel, Spacer- 10 bbls of 3% NH4CL + 0.2% F103, Acid- 50 bbls of 9:1 Mud acid + 5% U067 mutual solvent, Overflush- 75 bbls of 3% NH4CL + 0.2% F103, Diversion- 14 bbls of 450# DS wax beads in 30# HEC gel, Spacer- 10 bbls of3% NH4CL + 0.2% F103, Acid- 50 bbls of 12% HCI acid, Mud acid- 50 bbls of 9:1 Mud acid + 5% U067 mutual solvent, Overflush- 100 bbls of 3% NH4CL + 0.2% F103. 6/6/2010~ASRC Test Unit #3, Proceed with Acid Flwback, ***Job in Progress'""` ~ Inlet Z-08, Outlet Z-05 6/7/2010'ASRC Test Unit #3, Continue Acid Flowback, ***Job in Progress*"* Inlet Z-08, Outlet Z-05 6/8/2010~ASRC Test Unit #3, Continue Acid Flowback, ***Job in Progress**" ~ Inlet Z-08, Outlet Z-05 6/9/2010~ASRC Test unit #3, start 12 hour test "*job in progress** ""inlet well Z-08, outlet Z-05** 6/10/2010 ASRC Test unit #3, complete 12 hour test, RDMO **job complete** ~**inlet well Z-08, outlet well Z-06** FLUIDS PUMPED BBLS 112 12% HCL ACID 28 450# DS WAX BEADS IN 30# HEC GEL =WATER 100 9:1 MUD ACID +5% U067 MUTUAL SOLVENT 165 3% NH4CL + 0.2% F103 10 60/40 METH 415 Total TREE = 6-3/8" CMJ WELLHEAD ~ ' MCEVOY ACTUATOR = AXELSON KB. ELEV = 91.66' BF, ELEV = 55.31' KOP = 2650' Max Angle = 51 @ 5646' Datum MD = 11137 Datum TV D = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" n Minimum ID = 2.813" @ 2100' 3-1/2" HES X NIPPLE 9-5/8 " X 7" BKR LTP w / 6' TIEBACK, ID = 6.375" 9-518 " X 7" BKR LNR HGR, ID = 6.187" 3-112" TBG, 9.2#, 13CR-80, VAM TOP, .0087 bpf, ID = 2.992" I 9957' I I 10375' I 17" LNR, 29#, L-80, NSCC, .0371 bpf, ID = 6.184" I~ 10555' 4-1/2" TBG, 12.6#, L-80, ~ 10717• .0152 bpf, ID = 3.958" 3-1/2" TBG, 8.18#, 13CR-80, 10726' STL, .0087 bpf, ID = 2.990" 9-5/8" CSG, 47#, L-80, ID = 8.681" 10080' PERFORATION SUMMARY REF LOG: BRCS 09129193 ANGLE AT TOP PERF: 30° @ 11041' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11041 - 11056 O 03/23/08 2" 6 11060 - 11085 O 03/17/08 2" 6 11095 - 11115 O 12/18/07 2" 6 11125 - 11150 O 07/29/07 3-3/8" 6 11140 - 11150 S 12/04/93 3-3/8" 4 11150 - 11174 O 10/23/94 3-3/8" 4 11188 - 11200 O 12112/93 3-318" 4 11202 - 11216 O 12/12/93 3-3/8" 4 11222 - 11227 O 12/12/93 3-318" 6 11230 - 11235 S 12!04!93 SAF TES: PAREM WELLBORE NOT SHOWN Z-OSA "*CHROMETBG&(LNR*** WINDOW@10080' 7" LNR, 29#, 13CR, .0371 bpf, ID = 6.184" I-{ 11475' 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 2307 2307 1 MMG DMY RK 0 03/21/07 7 3148 3133 23 MMG DOME RK 16 03!21/07 6 4242 4002 43 MMG DMY RK 0 02/05/07 5 6344 5388 49 MMG DOME RK 16 03121107 4 7689 6299 45 MMG INKY RK 0 02/05/07 3 8693 6998 46 MMG DOME RK 16 03/21107 2 9382 7487 43 MMG DMY RK 0 02/05/07 1 10258 8217 35 MMG SO RK 20 03(21107 9861' -~ 3-112" HES X NIP, ID = 2.813" I 9891' HES SYMPHONY GUAGE CARRIER w /CABLE TO SURFACE IN IA, ID = 2.992" 10298' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10333' 1 3-1/2" HES X NIP, ID = 2.813" 03~-~ 3-1/2" HES X NIP, ID = 2.813" I 0394' -(4-1/2" TBG sTUB 04~ 7" X 4-112" BKR S-3 PKR, ID = 3.875" 10640' --17" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10668' 4-112" PKR SWS NIP, ID = 3.813" 10705' 4-112" PKR SWN NIP, ID = 3.725" 10717' ~4-1/2" WLEG, ID=3.958" 10693' ELMD 10726' 3-1 /2" W LEG, ID = 2.992" (BEHIND PIPE 19-518" MILLOUT WINDOW (Z-08A) 10080' - 10130' ~ ~ 11026' 20' MARKER JOINT 11426' I-IPBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 05/01/88 ORIGINAL COMPLETION 08/07/07 GJB/SV PERF/REPEF2F 10!04/93 CINDER SIDETRACK (Z-08A} 12/18/07 GJF/PJC PERFORATE 02/06/07 D16 RWO 04/02/08 RRD/ PJC PERFORATE (03/17/08) 03/05/07 MSW/PJ DRLG DRAFT CORRECTIONS 04102/08 TELlPJC PERFORATE (03/23/08) 03/06!07 GJF/TLH GLV GO (03!03!07) 03/21/07 DRF/TLH GLV GO PRUDHOE BAY UNff WELL: Z-08A PERMIT No: 1931280 API No: 50-029-21787-01 SEC 19, 711 N, R12E, 9735' SWL & 1252' EWL BP Exploration (Alaska) Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD Z-08A B58M00015 PRODUCTION PROFILE 3-27/M-33 88K5-00012 - / PRODUCTION PROFILE 10/25/09 1 1 2-34/P-14 S-213A V-227 AWJI-00061 68K5-00007 669K-00036 / MEM INJECTION PROFILE (~ - GAS LIFT SURVEY - ~ $ USIT U ZL° ~{ - 11/18/09 12/01/09 10/26/09 1 1 1 1 1 1 06-18i 62NJ-00033 O MCNL .11/19/09 1 1 L3-11 AP3Q-00065 RST 10/12/09 1 1 O-D4B H-OSB B2NJ-00036 B2WY-00033 - MCNL - MCNL _ v 10/31/09 11/04/09 10/20/09 1 1 1 1 1 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETt1RMtur: Wort rnnv ceru rn. nr txploratlOn (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ~;,{;~y~~rga~: ~~~ ~ ~,rJ 900 E. Benson Blvd. ~~~ ",~ ~;,rr ~ ~ ~. v Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i u BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 sa+~,: ~"~~"~~~.~'... ;`!~' ` `` '°F(':. f.~ ~ a,. ; Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, -__J bp ~~~~~~~~ OCT 0 5 2009 ~Ias~C~ 4if & Gas Cans. Co~+R~~~~! Anchora~a 3- C~ ~~ ~-' a~/~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ! BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date fi bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-06 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-OSA 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 5002921967ot00 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 NA 12 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-146 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-is 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 02 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50029218790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220~30100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-326L1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 S/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-10t 2001620 50029229780000 NA 1 NA t0.20 7/23/2009 Z-i02 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-t03 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-108 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-112 2071720 50029233800000 NA surface NA ~~ STATE OF ALASKA ALAS A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS i~ECEi V~~. MAR 2 4 2008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ ~aS~(a ~Qther C t V 1 l P rf d t'.Of1S. C,Otf~~S5i~+, orme e : Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ ime Ext n e n si o Change Approved Program ~ Operat. Shutdown ~ Perforate ^~ Re-enter Suspended Wel 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~ 193-1280 3. Address: P.O. Box 196612 Stratigraphic Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-21787-01-00 7. KB Elevation (ft): 9. Well Name and Number: 88.56 KB ' ~ PBU Z-08A - 8. Property Designation: 10. Field/Pool(s): _ ' ADLO-028245 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11475 ~ feet Plugs (measured) None true vertical 9180.02 feet Junk (measured) None Effective Depth measured 11426 feet true vertical 9137.89 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2678' 13-3/8" 68# L-80 Surface - 2678' Surface - 2678' 4930 2270 Intermediate 10080' 9-5/8" 47# L-80 Surface - 10080' Surface - 7990' 6870 4760 Liner 1531' 7" 29# L-80 9944' - 11475' 7894' - 9180' 8160 7020 ~~~N~~ APR 0 4 2008 Perforation depth: Measured depth: SEE ATTACHMENT True Vertical depth: Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 13CR80 Surface - 10726' 4-1/2" 12.6# I-80 10394' - 10717' Packers and SSSV (type and measured depth) 7"X3-1/2" BAKER S-3 10298' 7"X4-1/2" BAKER S-3 10422' 7"X4-1/2" BAKER S-3 10640' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 37 230 732 255 Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~, Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil I~' Gas WAG (~!! GINJ ' WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer n Signature r,, Phone 564-4944 Date 3/24/2008 a Form 10-404 Revis d 04/2006 ~ _ _ i.~/ Submit Original Only ~.. s Z-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE f SUMMARY 3/17/2008 ""*WELL SHUT IN UPON ARRIVAL**" :;INITIAL T/I/O = 2000/1700/0 PSI ;PERFORATED FROM 11060'-11085' WITH 2" 2006 POWERJET OMEGA, 6SPF, 60 DEG PHASE, 21.8" PEN, 0.22" HOLE ENTRANCE. '';SECOND GUN RUN FRO . '- 'POSTPONED DUE TO RIG JOB. ::.WILL RETURN AT LATER DATE TO COMPLETE RUN 2. `FINAL T/I/O = 2000/1700/0 PSI. WELL LEFT SI. `,*** JOB INCOMPLETE '"`* 3/22/2008{""'WELL SHUT IN UN ARRIVAL. T/I/0= 1950/2025/0"""" 'RU 2" POWER JET OMEGA, HMX, RUN IN HOLE TO PERFORATE 11,041'- f 11056'. MISRUN ON RUN 1 DUE TO FAULTY DETONATOR. `RIH WITH NEW GUN TO PERFORATE 11 41 TO 11.056 FT. """JOB CONTINUED ON 23 MARCH 2008."*" 3/23/2008:;"'*JOB CONTINUED FROM 22 MARCH 2008"*"' ;WELL SHUT IN ON ARRIVAL. INITIAL T/I/0= 1950/2025/0 2" POWER JET OMEGA, HMX, 6SPF,. RUN IN HOLE TO PERFORATE 11,041 to 11,056 FT. ''.WELL LEFT SHUT IN ON DEPARTURE: FINAL T/I/0= 1450/2000/0 ""'`JOB COMPLETED*** FLUIDS PUMPED BBLS 2 diesel 2 Total i ~ Z-08A 193-1280 PERF ATTACHMENT MD TVD 11041 11056 O 8806 8819 11060 11085 O 8822 8844 11095 11115 O 8853 8870 11125 11150 O 8879 8900 11140 11150 S 8892 8900 11150 11174 O 8900 8921 11188 11200 O 8933 8943 11202 11216 O 8945 8957 11222 11227 O 8962 8967 11230 11235 S 8969 8974 0~. j.JL T Si 9.~; STATE OF ALASKA ~~ DES ~ $ ~~~j] ALASKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATI~~~ '~ ~ ~~ '~ ~' 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ O her Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~] Change Approved Program ~ Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Dri{I Number: Name: Development .~' Exploratory 193-1280 3. Address: P.O. Box 196612 Stratigraphic ~'' Service I"~ 6. API Number. Anchorage, AK 99519-6612 50-029-21787-01-00 7. KB Elevation (ft): 9. Well Name and Number: 88.56 KB PBU Z-08A 8. Property Designation: 10. Field/Pool(s): ADLO-028245 PRUDHOE BAY Fields PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11475 feet Plugs (measured) None true vertical 9180.02 feet Junk (measured) None Effective Depth measured 11426 feet true vertical 9137.89 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2678' 13-3/8" 68# L-80 Surface - 2678' Surface - 2678' 4930 2270 Intermediate 10080' 9-5/8" 47# L-80 Surface - 10080' Surface - 7990' 6870 4760 Liner 1531' 7" 29# L-80 9944' - 11475' 7894' - 9180' 8160 7020 ~~Ll~r`f~~~ JAN ~ ~ 2008 Perforation depth: Measured depth: SEE ATTACHMENT True Vertical depth: Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 13CR80 Surface - 10726' 4-1/2" 12.6# I-80 10394' - 10717' Packers and SSSV (type and measured depth) 7"X3-1/2" BAKER S-3 10298' 7"X4-1/2" BAKER S-3 10422' 7"X4-1/2" BAKER S-3 10640' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 25 268 416 235 Subsequent to operation: 32 274 382 264 14. Attachments: 15. Well Class after Droposed work' Copies of Logs and Surveys Run Exploratory Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil I+~i Gas WAG ~~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 12!27/2007 ~. c Form 10-404 Revised 04/2006 '~ `" `~~~~~ h ~J~~ (~ „~ Submit Original Only • Z-08A 193-1280 PERF ATTACHMENT MD TVD 11095 11115 O 8853 8870 11125 11150 O 8879 8900 11140 11150 S 8892 8900 11150 11174 O 8900 8921 11188 11200 O 8933 8943 11202 11216 O 8945 8957 11222 11227 O 8962 8967 11230 11235 S 8969 8974 • • z-osA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/12/2007 '`'*WELL SHUT IN ON ARRIVAL*** (pre-adperf) RAN 2.5" DMY GUN, TEL, & S-BAILER TO 886' SLM. BAILER CAME BACK W/HYDRATES. PUMPED -8 BBLS OF METHANOL, TBGP INCREASED FROM 1850 TO 12500 PSI. **'`CONTINUE ON 12/13/07 WSR'`*" 12/13/2007 '`"*CONTINUE WSR FROM 12/12/07*** (pre adperf) -:RAN 2.5" CENT & S-BAILER TO TD @ 11,236' SLM. 'RAN 10' x 2.5" DUMMY GUN TO TD @ 11,236' SLM bEPTH=11,115') '***NOTIFY PAD OPERATOR- LEFT WELL S/L"'`'` (SAND IN BAILER) (TARGET 12/18/2007 WELL SHUT-IN ON ARRIVAL. INTITAL T/I/O: 1800/1750/0. PERFORATE WELL FROM 11095'-11115' WITH 2" POWERJET OMEGA 6 SPF 60 DEG PHASE. API PENETRATION = 21.8", API ENTRANCE HOLE DIAMETER = 0.22". RIH WITH 2" GUN AND GR/CCL. LENGTH = 29.3. MAX OD = 2". TROUBLE ON RIH UNTIL 900' DUE TO POSSIBLE HYDRATES. FINAL TJUO: 2100/1700/0. ""'`JOB COMPLETE*"" FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL 09/24/07 /~ Sc6lumberger Alaska Data & Consulting Services 2525 Gambeil Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~:m;;=,~~~~ NaV ~ ~ 200"t Well Job # Loo Description NO. 4414 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Date BL Color CD 09-25 11695072 LDL U -1.. 4 _ 08i17i07 L-04 11661166 SCMT 08/25/07 1 15-266 11661165 MEM PROD PROFILE 08123107 1 02-126 11628789 MEM PROD PROFILE (~ 08/20/07 1 02-11A 11428266 MCNL ~ / 1 10/03/O6 1 1 18-24AL2 11209591 MCNL _ C / 03/23/06 1 1 14-07 11637334 RST t - / L 05/08107 1 1 B-14 11637349 RST '~~- / ~~ 07/04/07 1 1 Z-08A 11630483 RST - t 06/21/07 1 1 Z-46 40012671 OH EDIT MWD/LWD - ~ ! Y < 12/12/05 2 1 Z-46A 40012671 OH EDIT MWD/LWD ~ / - 01/03/08 2 1 E-37A 10928640 MCNL c`~ 05 -OCR ~ / 06114!05 1 1 B-34 11594510 RST u ~ ~ ~ ` ~- 06/14/07 1 1 MPH-17 11813063 CBUUSIT (PDC) CH EDIT ~p~ -(~ ~ S ~ 07/21/07 1 r'LCAi7C AGr\IYVYVLCUOC RCVCiI' 1 6i .7WIVIrVO An1U RCI URIVIIYV VIVO GVY1 tAGI'7 1 V: BP Exploration (Alaska) Inc. pp .l Petrotechnical Data Center LR2-1 ~~ ~~/ ti F~~, '' 900 E. Benson Blvd. -. ; ~~,,. i~ ~ ~ ~ - ~ "~~ Anchorage, Alaska 99508 Date Delivered: ~-u ° ~' (3 ~~~ . ~~~ ~ _'~. ., ~.i'll!i: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth Received by: ~ -- ~~ Sç~lulDblrgep Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R,ECEIVED JUL 0 3 Z007 í\læka Oil & Gas Coos. Commission Anchorage 06/29/07 NO. 4324 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # loa DescriDtion Date Bl Color CD H-13 11676950 GAS ENTRY SURVEY 06/20/07 -" C-41 11801077 lDl 06/19/07 1 A-30A 11661159 MEM PROD PROFilE 06/23/07 1 W-21A 11661140 MEM PROD PROFilE 04/21/07 1 E-21B 11661157 MEM PROD PROFilE 06/19/07 1 M-23 11626107 PRODUCTION PROFilE 06/23/07 1 01-21 11824330 PRODUCTION PROFilE 06/22/07 1 J-25A 11767130 MEM PROD PROFilE 06/18/07 1 Z-08A 11630483 GlS/PROD lOG 06/22107 1 M-34 11824330 PRODUCTION PROFilE 06/22/07 1 02-30B 11594512 lDl 06/23/07 1 Z-29 11686758 PRODUCTION PROFilE 06/15/07 1 S-38 11801078 lDl 06/20/07 1 H-37 A 11594506 PPROFIIPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFilE (REVISED) 06/13/07 1 Z-13A 11649962 MEM PROD PROF (REVISED) 04/21/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 USIT (CEMENT) 06/24/07 1 12-05 11676951 USIT (CORROSION) 06/24/07 1 B-15 11626097 USIT 06/14/07 1 G-24A 11628750 SCMT 02/05/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNI~e~51t.jr: 0 5 2007 BP Exploration (Alaska) Inc. '" Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: {03 - IÐ7r . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 03/20/2007 Schlumbel'ger NO, 4188 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth sCANNED APR 1 0 2007 I C)3 - /()i) Company: State of Alaska Alaska Oil & Gas Cons C:omm AUn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 Field: Prudhoe Bay WI! BL CD CI J b# L D 'f D t e 0 og eSCrlptlon ae o or 15-18 10861914 CH EDIT OF MCNL (JEWELRY) 06/07/04 1 P2-43PB1 40011721 OH EDIT MWD/LWD 03/29/05 2 1 P2-43PB2 40011721 OH EDIT MWD/LWD 04/07/05 2 1 Z-08A 11626372 USIT 02/01/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, r"'~ Petrotechnical Data Center LR2-1 il.__-:' 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 'I ATTN". (ì ) e Received by: ....-/: ~ I' /1........----' tJiAr~ 2 2 ZOO!' Date Delivered: if"~ ('~n¡'nJ\~~3?t~Ün /-1 . . A STATE OF ALASKA ~~f'. REC~E'VED R:~J':TO~~~~SDC~~S:~~~O~~~~~~~/'3¡\ FŒ 2 8 2007 Alaska 0;1 & Gas Cons. Anchotsge o Re-Enter Suspended Well o Other 1. Operations Performed: o Abandon o Repair Well ~ Pull Tubing o Operation Shutdown o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 88.56' , 8. Property Designation: ADL 028245 < 11. Present well condition summary Total depth: measured 11475 ' feet true vertical 9180 . feet Effective depth: measured 11426 feet true vertical 9138 feet Casing Length Size Structural Conductor 110' 20" Surface 2678' 13-3/8" Intermediate 10080' 9-5/8" Production Liner 1531' 7" Perforation Depth MD (ft): Perforation Depth TVD (ft): 11150' - 11227' 8900' - 8967' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): ion o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate o Time Extension 4. Well Class Before Work: !81 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 193-128 / 6. API Number: 50-029-21787 -01-00 / 9. Well Name and Number: PBU Z-08A ./ 10. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool /' Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 110' 110' 2678' 2678' 4930 2270 10080' 7990' 6870 4760 9944' - 11475' 7894' - 9180' 8160 7020 SCANNED MAR {} 1 2007 3-1/2",9.2#; & 4-1/?" 1? R# 7" x 3-1/2" Baker 'S-3' packer; & two (2) 7" x 4-1/2" Baker 'S-3' packers 13Cr80; I -RO 10726'; 10298'; 10422' & 10640' Treatment description including volumes used and final pressure: Cut and pull 5-1/2" x 4-1/2" tubing from -10394'. Log and cleanout. Run new chrome tubing. 13. Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory !81 Development 0 Service ~ Daily Report of Well Operations 16. Well Status after proposed work: ~ Well Schematic Diagram ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 NJA Printed Name Terrie Hubble Signature Form 10-404 Revised 04/2006 Cj \ ~"C,,~,: . i¡\'AL \ 1\1, ' Title Technical Assistant Date 0 z:¡ zE.'O MAR 0 1 Z007 Terrie Hubble, 564-4628 Submit Original Only Prepared By Name/Number: Phone 564-4628 · Page 1 of 1 Digital Wellfile A Well Events for SurfaceWell - z-'ð'~ Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> Z -> Z-08 Date Range: 13/0ct/2006 to 27/Jan/2007 Data Source(s): DIMS, AWGRS Events Source DIMS AWGRS AWf~KS Well Z-08 Z -08A Z-08A Date 01/27/2007 12/15/2006 11/15/2006 AWGRS Z-08A 11/12/2006 AWGRS Z-08A 11/12/2006 AWGRS Z -08A 11/10/2006 AWGRS Z-08A 11/09/2006 Description Rigged Down, Moved off R-15, Moving to Z-08 SET BPV THRU TREE PRE RIG WORK API VALVE SHOP Z-08 LDS follow up. [3] LDS on tubing spool from previous well work, [1] was left out [2] they were unable to move. Installed heater on well head and heated up tubing spool. Rigged up torque eliminator and freed up the [2] bad LDS that were flagged. Worked the LDS that was left out. It should be re-places during rig work over operations. Cycled all remaining LDS. backed all the way out and back in. Same was done on casing spool. All LDS now move freely. T/I/O = 0/0/50. Temp = S/ I . ALP = 1200 psi. AL S/I at casing and lateral valve. Bleed WHPs to 0 psi (pre PPPOT, T & IC). Bled AL line to 0 psi. Bled OAP to tank from 50 psi to 0 in 5 min. OAP builds when S/1. Pressure bleeds off in seconds. FWHP = 0/0/10. T/IA/OA = 0/0/0 (Pre Rig Workover Inspection) PPPOT-IC = Passed PPPOT-T = Passed Bled inner casing packoff void to 0 psi. Unable to remove internal check, installed external test fitting. Torqued lockdown pins to 450 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up viod to 3,800 psi for 30 mins. = Passed. Bled tubing hanger void to 0 psi. Unable to remove internal check, installed external test fitting. Torqued lockdown pins to 450 ft/lbs. (Need to address "3" of the pins prior to workover). Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 5,000 psi. for 30 mins. = Passed. T/I/0=500/1100/0 ( Circ-out / CMIT Tx IA / MIT OA ) Pump 5 bbls Neet Meth followed by 1065 bbls 1 % KCL Water then 150 bbls 90 degree diesel. U- Tube Tx IA for 1 HR. CMIT Tx IA. Initial Press. =3520/3400/460. 15 min press.=3470/3350/460. 30 min. pressure=3450/3325/460. Passed. Bleed tbg & IA pressure down to 400 psi. RD off tbg. RU to OA. MIT OA to 2000 psi. 15 minute reading=400/400/1900. 30 minute reading=400/400/1850. Passed. Bleed OA pressure down to 400 psi. Freeze protect FL w/ 10 bbls neat meth. FWHP=400/400/400. ****Note**** Tree bolts not up to spec. ***** T/I/O= 500/1100/0 Circ-out / CMIT Tx IA / MIT x OA ) Pump 5 bbl neet spear down TBG followed by 20 bbls 1% kcl water Cont. on next days WSR ---__n_-------JOB IN PROGRESS---- ------------ AWGRS Z-08A 11/06/2006 WELL SHUT IN UPON ARRIVAL. CUT 4 1/2" TUBING AT 10395' WITH 3.65" POWER CUTTER IN THE FIRST JOINT ABOVE THE TOP PACKER. INITIAL T/I/O = 450/600/0. POST CUT T/I/O = 500/600/0 TOTAL TOOL STRING LENGTH = 20.6' *****JOB COMPLETE***** AWGRS Z-08A 10/30/2006 T/I/O = 470/770/70. Temp = S1. WHPs, TBG & IA FLs (pre eline). TBG FL near surface. IA FL @ 450' (28 bbls). AWGRS Z-08A 10/13/2006 TIO = 420/700/80. Temp = S1. AL casing and lateral valve's S1. ALP = 900 psi. Bleed WHP's to 0 psi (pre PPPOT). TBG FL near surface. IA FL @ 440'. OA FL near surface. - http://digitalwellfile.bpweb. bp.comIW ellEvents/Home/Default.aspx 2/28/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-08 ~ Z-08 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 1/27/2007 Rig Release: 2/5/2007 Rig Number: 16 Spud Date: 3/15/1988 End: 2/5/2007 1/27/2007 16:30 - 17:30 1.00 MOB P PRE Move Slop tank, Unhook Top Drive and Bridle up to lay derrick over. 17:30 - 19:30 2.00 MOB P PRE Prep moving system and move off of well R-15. Spot rig on location to layover derrick. 19:30 - 21 :00 1.50 MOB P PRE RID floor and pipe chute, Lower and secure derrick. 21 :00 - 22:30 1.50 MOB P PRE Remove BOP stack from cellar pedestal, install onto moving stand. Install rear booster wheels. 22:30 - 00:00 1.50 MOB P PRE Move rig from R pad, down R- pad access road. 1/28/2007 00:00 - 09:00 9.00 MOB P PRE Continue to move rig from R -pad to Z-pad, Move off R-pad access road, west on the Spine road to Z-pad access road. Spot rig on Z-pad. 09:00 - 10:00 1.00 MOB P PRE Remove rear booster wheel assembly and install BOP stack on pedastal. 10:00 - 11 :00 1.00 MOB P PRE Raise and pin derrick. Raise pipe chute. 11 :00 - 13:00 2.00 MOB P PRE Lay herculite and mats around Z-08. Place wellhead equipment in cellar. RlU rig floor. Rig Accepted at 12:00 hrs. 13:00 - 15:00 2.00 MOB P PRE Spot rig over well Z-08. Level and shim rig. Bridal down blocks hook up Top Drive 15:00 - 17:00 2.00 MOB P PRE Spot cuttings tank, Install secondary annulus valve. RlU to circulate out well. 17:00 - 18:00 1.00 KILL P DECaMP RlU DSM lubricator and pull BPV. 0 psi on tubing and annulus. 18:00 - 21 :00 3.00 KILL P DECOMP Pressure test lines to 3,500 psi, pump 20 bbl of safe surf pill and 20 bbl high-vis sweep. Displace well with 825 bbls of 120 degree seawater. 8 bpm at 820 psi. Pressure up against plug. Plug gave way at 1,900 psi. 21 :00 - 22:00 1.00 KILL P DECOMP Establish loss rate of 6 bph. Discuss options with well engineer. 22:00 - 23:00 1.00 KILL P DECOMP Blow down lines and install TWC with Cameron. 23:00 - 00:00 1.00 KILL P DECOMP Test TWC to 3,500 psi for 10 minutes on chart. Blow down and RID lines. 1/29/2007 00:00 - 01 :30 1.50 WHSUR P DECOMP N/D tree and adaptor flange and remove from cellar. 01 :30 - 02:00 0.50 WHSUR P DECOMP Function lock down screws and inspect hanger threads. TC4S threads were in good condition. Screwed in TC4S crossover sub in, took 8.5 turns. 02:00 - 05:00 3.00 BOPSU DECOMP Nipple up BOP stack. Install riser and turnbuckles. 05:00 - 10:00 5.00 BOPSU DECOMP RlU test assembly and test BOPE to 250 psi low and 3,500 psi high. Each test was held for 5 minutes. AOGCC witness of test was waived by Lou Grimaldi. Test was witnessed by the Doyon Toolpusher and the BP WSL. Good test, No failures. 10:00 - 11 :00 1.00 BOPSU P DECaMP RID BOP Test Equipment. Wait on DSM to arrive wI lubricator to pull TWC. 11 :00 - 12:00 1.00 PULL P DECOMP P/U Lubricator Ext and Lubricator. Pull TWC, no pressure below, well seem static. UD Lubricator and Extension. 12:00 - 13:00 1.00 PULL P DECOMP PIU Landing Joint and M/U 7" TC4S XO to Landing Joint. RIH and MIU to Hanger wI 8-1/2 RH Turns. 13:00 - 14:00 1.00 PULL P DECOMP POOH wI Hanger. Hanger came off seat at 130,000 Ibs. Tubing came free at 180,000 Ibs. Pull to Rig Fir wI 130,000 Ibs. 14:00 - 15:30 1.50 PULL P DECaMP UD Hanger and Rig to Circ Head. Circ Btms Up at 8 bpm and 800 psi. Seen some gas at bottoms up. 15:30 - 16:30 1.00 PULL N DPRB DECOMP Shut Down pumps and monitor well. Fluid level falling in annulus. UD Circ Head. Find Well flowing up tbg. M/U Circ Head again. Continue to circ well. Consult Town. 16:30 - 17:30 1.00 PULL N DPRB DECOMP Continue to circ well and wait on 50 bbl 9.8 ppg brine pill. 17:30 - 18:30 1.00 PULL N DPRB DECOMP Pump 50 bbl 9.8 brine pill and spot on bottom. Let set for 30 Printed: 2/12/2007 10:10:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-08 Z-08 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 1/27/2007 Rig Release: 2/5/2007 Rig Number: 16 Spud Date: 3/15/1988 End: 2/5/2007 1/29/2007 17:30 - 18:30 1.00 PULL N DPRB DECOMP minutes. 18:30 - 20:30 2.00 PULL N DECOMP Pump 20 bbl high-vis sweep around at 8.5 bpm with 810 psi. Observe well, well static. 20:30 - 00:00 3.50 PULL P DECOMP UD 5 1/2" tubing, dual 1/4" control lines, ball valve assembly and 5 1/2" x 4 1/2" XO. Recovered 56 Stainless Steel Bands. 5 1/2" tubing was in good condition. 1/30/2007 00:00 - 07:30 7.50 PULL P DECOMP UD 4 1/2" tubing. Recovered 257 Joints of Tbg, 1 X Nipple, 5 GLM's and 1 Cut Joint. Length on Cut Joint = 19.29'. Flare was small measured 4-5/8" x 4-9/16". A good amount of scale was seen on the inside and outside of the Tbg. 07:30 - 08:00 0.50 CLEAN P DECOMP P/U Wear Ring and Set in Well. ID on Wear Ring = 9.0" 08:00 - 09:00 1.00 CLEAN P DECOMP Clean and Clear Rig Floor. Pull all Tbg Handling Equipment Off Floor. 09:00 - 09:30 0.50 CLEAN P DECOMP Gather and P/U Clean Out BHA Subs and Equipment. 09:30 - 11 :00 1.50 CLEAN P DECOMP M/U BHA #1; 6" Tri-Cone Bit, 7" Casing Scraper, But Sub, Bumper Sub, Oil Jars, XO, 12 - 4.75" DC's, 1 Jt HT-38 DP, XO Sub, Double Pin Sub, 9-5/8" Casing Scraper, Bit Sub, XO. Total Length = 440.54 ft. With 9-5/8" Scraper Landing Out on 7" TOL the 7" Csg Scraper will cover to -10375'. 11 :00 - 21 :30 10.50 CLEAN P DECOMP RIH wI BHA #1 on 4" HT-38 DP. P/U DP 1x1 from Pipe Shed. 21 :30 - 22:00 0.50 CLEAN P DECOMP M/U T/D and Wash Down at 7 bpm and 1130 psi, No-Go 95/8" Scraper at 9,932' with Bit at 10,374', Up Weight=177,000' and Down Weight 147,000'. 22:00 - 00:00 2.00 CLEAN P DECOMP Pump 20 bbl Hi-Vis Sweep at 8.5 bpm and 1650 psi. 1/31/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP Displace Well w/8.4 ppg Sea Water 120 deg, at 8 bpm wI 1500 psi. 01 :30 - 02:00 0.50 CLEAN P DECOMP UD 2 jts BID Top Drive, POOH with 5 stds. 02:00 - 03:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line and Service Draworks. 03:00 - 06:30 3.50 CLEAN P DECOMP Continue to POOH. 06:30 - 07:30 1.00 CLEAN P DECOMP Stand Back Drill Collars, UD Clean Out BHA. , 07:30 - 08:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 08:00 - 13:30 5.50 CLEAN P DECOMP M/U 7" RBP and RIH t/9,916'. 13:30 - 14:30 1.00 CLEAN P DECOMP M/U TID and Work Through Liner Top, Continue to RIH and Set 7" RBP at 10,001' 14:30 - 15:30 1.00 CLEAN P DECOMP R/U and Test RBP to 3,500 psi for 30 minutes. Charted OK. 15:30 - 00:00 8.50 CLEAN P DECOMP Stand Down Due to Level 3 Conditions on Access Roads and Pads. Install TIW Valve and Circulate BIU Monitoring Well. Perform Work Orders and Light Maintenance 2/1/2007 00:00 - 03:30 3.50 CLEAN P DECOMP POOH UD RBP Running Tool 03:30 - 04:30 1.00 CLEAN P DECOMP R/U SWS to Run USIT and Corrosion Logs. 04:30 - 08:30 4.00 EVAL P DECOMP RIH w/USIT. Log at 50' I min up from 7" TOL at 9944' to surface in corrosion and cement mode 08:30 - 11 :00 2.50 EVAL N DFAL DECOMP Tool problems above 3000 ft. POOH, replace sub, cartridge, and gamma ray. RIH back down to 3700' to log up again to surface. 11 :00 - 17:00 6.00 EV AL P DECOMP Continue with primary pass from 3700' to surface logging at 50' 1 min. Make secondary passes over areas of corrosion greater than 20%. 17:00 - 17:30 0.50 EVAL P DECOMP Rig Down E-Line Equipment and Tools. 17:30 - 18:00 0.50 EVAL P DECOMP Perform Derrick inspection. 18:00 - 19:00 1.00 CLEAN P DECOMP M/U RBP Retrieval Tool on jt of Drill Pipe. RIH w/21 stds Drill Pipe, M/U Storm Packer, RIH 1 std Drill Pipe. 19:00 - 19:30 0.50 CLEAN P DECOMP Obtain Parameters, Set Storm Packer at 101'. Release Printed: 2/12/2007 10:10:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-08 Z-08 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 1/27/2007 Rig Release: 2/5/2007 Rig Number: 16 Spud Date: 3/15/1988 End: 2/5/2007 2/112007 19:00 - 19:30 0.50 CLEAN P DECOMP f/Packer. 19:30 - 20:00 0.50 CLEAN P DECOMP RlU and Test Packer t/2,500 psi and Chart for 15 mins. 20:00 - 20:30 0.50 CLEAN P DECOMP BID Lines, Drain BOP Stack and Pull Wear Ring. 20:30 - 22:00 1.50 CLEAN P DECOMP NID BOPs and Tubing Spool. 22:00 - 23:00 1.00 WHSUR P DECOMP BOLDs Pull Pack Off Install New Pack Off. 23:00 - 00:00 1.00 WHSUR P DECOMP Nipple Up and Install New Tubing Spool. 2/2/2007 00:00 - 00:30 0.50 WHSUR P DECOMP Test Packoff to 5,000 psi for 30 minutes. 00:30 - 02:00 1.50 WHSUR P DECOMP NIU BOPs 02:00 - 03:00 1.00 WHSUR P DECOMP Set Test Plug, Fill Stack w/Water, Test Tubing Spool Connection to 250 psi Low and 3,500 psi High Test for 5 Minutes On Chart. RID Test Equipment. Install Wear Ring. 03:00 - 04:00 1.00 CLEAN P DECOMP M/U Storm Packer Retrieval Tool, RIH to Release Storm Packer, POOH w/Same. 04:00 - 06:00 2.00 CLEAN P DECOMP Continue to RIH f/2,167' to Retrieve RBP at 10,001'. 06:00 - 07:00 1.00 CLEAN P DECOMP Engage RBP @ 10001' and Release. Stand One Stand Back. 07:00 - 08:30 1.50 CLEAN P DECOMP Circulate Bottoms Up at 7 bpm and 1060 psi. Flow Check , Well. Break Off and Blow Down Top Drive. 08:30 - 12:00 3.50 CLEAN P DECOMP POOH and Stand Back DP. 12:00 - 13:00 1.00 CLEAN P DECOMP UD 7" RBP and Running Tool. 13:00 - 15:00 2.00 CLEAN P DECOMP RlU 2-7/8" Handling Equipment. M/U BHA wi 3-5/8" Mill, Bit Sub, 12 Joints of 2-7/8" PAC DP, XO, Pump Out Sub, Bumper Sub, Oil Jars, XO Sub, 12 - 4.75" DC's. Total Length = 767.52 ft 15:00 - 18:30 3.50 CLEAN P DECOMP RIH wI Mill BHA to the Fas Dril Plug at 10428', Break Circ every 30 stands. 18:30 - 19:30 1.00 CLEAN P DECOMP Slip and Cut Drilling Line. 19:30 - 20:00 0.50 CLEAN P DECOMP Continue to RIH, Tag at 10,367' 20:00 - 20:30 0.50 CLEAN P DECOMP Attempt to Circulate, Packed off, POOH to 10,063', Gained Circulation. 20:30 - 22:30 2.00 CLEAN P DECOMP Washed and Reamed f/10,063'- t/10,750', Tagged top of Tubing Stub with NO-GO at 10,374'. Fluid Loss Rate at 15 bph. 22:30 - 23:00 0.50 CLEAN P DECOMP Pumped 40 bbl Hi-Vis Sweep at 7 bpm and 2,450 psi. 23:00 - 00:00 1.00 CLEAN P DECOMP Check Valves and Seats on Mud Pump. 2/3/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue to Pump Sweep at 7 bpm 2,600 psi. Monitor Well BID T/D. 01 :30 - 10:00 8.50 CLEAN P DECOMP POOH UD Drill Pipe. 10:00 - 12:30 2.50 CLEAN P DECOMP LID 12 jts of 4-3/4" DC's, Bumper Sub, Jars, 2-7/8" Pac DP and 3-5/8" Mill. 12:30 - 13:30 1.00 CLEAN P DECOMP Clean and Clear Rig Floor. Remove extra subs and tools. 13:30 - 14:30 1.00 RUNCO RUNCMP Rig Torque Turn, Compensator, and tubing handling equipment. Organize Jewelry and tbg in pipe shed. 14:30 - 15:00 0.50 RUNCO RUNCMP Pre Job Safety Meeting with Baker, Halliburton, and Rig Crew on running tbg competion. 15:00 - 00:00 9.00 RUNCO RUNCMP Run 3-1/2", 9.3#, 13Cr80 Tbg Completion. 1,600 ftllbs Torque for STL and 2,900 ftllbs Torque for Vam top. Torque Turning All Connections Using Compensator and Jet Lube Seal Guard Pipe Dope. 2/4/2007 00:00 - 15:30 15.50 RUNCO RUNCMP Continue to Run 3-1/2",9.2#, 13Cr80 SL T and Vam Top Tbg Completion. 3-1/2" WLEG Jt, 10 Jts 3-1/2" SL T Tbg, 1 Jt of 3-1/2" Tbg wI 4-1/2" NO GO Collar, 2 X-Nipples, 7"x4-1/2" Baker S-3 Packer, 1 GLM, HES Gauge Carrier, X Nipple, 7 GLM's, X Nipple. 316 Jts of 9.2# 13 Cr80 Vam Top Tbg, 12 Joints of 8.81 # SL T Tbg Printed: 2/12/2007 10:10:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-08 Z-08 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 1/27/2007 Rig Release: 2/5/2007 Rig Number: 16 Spud Date: 3/15/1988 End: 2/5/2007 M/U Jt #327 and #328. Up Wt = 120,000 Ibs, Down Wt = 105,000Ibs. No-Go Tag Up on 4-1/2" Tbg Stub 14' in on #328, -10377'. Stack up to 7,0001bs down to confirm. UD Joints #328,327,326 16:00 - 17:00 RUNCMP M/U two space out pups, 11.666 ft total length. M/U Joint 326. M/U McEvoy 4-1/2" by 12" Tbg Hanger wI 4-1/2" TCII Lift Thread. Clamp I-Wire to 3.5" pup -3 ft below Hanger. M/U 4-.5" TCII Landing Joint. 17:00 - 17:30 RUNCMP Terminate end of I-Wire. Strip Through Tbg Hanger. Pressure Test Packing to 5000 psi for 15 mins. - Good Test. Function Test I-Wire. Final Test on I-Wire reading 3468 psi bottom hole pressure, 13.5 volts at 5 milliamps. 17:30 - 18:00 0.50 RUNCMP Wrap I Wire around neck of tubing hanger. S/O and Land Tbg Hanger. RILDS. 18:00 - 18:30 0.50 RUNCMP Rig Up to Circ, RILDs. 18:30 - 23:00 4.50 RUNCMP Test Lines t/3,500 psi, Pump 630 bbls of 140 deg Sea Water wlCorrosion Inhibitor at 3 bpm w/450 psi. 23:00 - 23:30 0.50 RUNCMP Drop Ball and Rod, RID Lines and Lay Down Landing Jt. 23:30 - 00:00 0.50 RUNCMP Set Packer and Test Tubing to 3,500 psi for 30 Charted Minutes good test. 2/5/2007 00:00 - 01 :00 1.00 RUNCMP Bleed off Tubing Pressure to 1,750 psi, Pressured up on IA to 3,500 psi and Charted test for 30 minutes, Bled Off Tubing Pressure and Sheared DCR Valve. Confirmed Shear By Pumping at 3 bpm at 160 psi in Both Directions Tubing to IA and IA to Tubing. 01 :00 - 01 :30 0.50 RUNCMP Set TWC and Pressure Tested to 1,000 psi flBelow and 3,500 flAbove, for 5 Minutes Each on Chart. 01 :30 - 07:00 RUNCMP Nipple Down BOPE. 07:00 - 10:00 RUNCMP Clean Hanger Neck, Prepare I-Wire for Adapter, N/U Adapter 13 5/8"x 13518", Torqued all Bolts, Two Threads Exposed on Studs Minimum. Pressure Tested Adapter to 5,000 psi for 30 minutes On Chart, Good Test. 10:00 - 10:30 0.50 RUNCMP Set Production Tree and Installed External Connection on I-Wire, Tested I-Wire 14 volts, 5 milliamps, 3504 BHP. 10:30 - 11 :30 1.00 RUNCMP N/U Production Tree, Fill wlDiesel, RlU Lines to PT. 11 :30 - 12:30 1.00 RUNCMP Pressure Test Production Tree to 5,000 psi for 30 minutes on Chart. Good Test 12:30 - 13:00 0.50 RUNCMP Bled Down and Drained Tree, P/U BPV Lubricator, Pull BPV. 13:00 - 15:00 2.00 RUNCMP PJSM with Rig Crew and Little Red Operators, Pressure Test Lines to 3,000 psi, Pump 175 bbls down IA. Returns Taken up Tubing. Pumped at 2 bpm with 200 psi. 15:00 - 16:00 1.00 RUNCMP U-Tube Well. 16:00 - 16:30 0.50 RUNCMP Check for Pressure, Blow Down Lines, Attempt to Bleed Down Pressure. 16:30 - 18:00 1.50 RUNCMP Wait on BPV Lubricator. 18:00 - 18:30 0.50 RUNCMP P/U BPV Lubricator Set BPV UD Lubricator, Pressure Test BPV to 1,000 psi flBelow w/Little Red. 18:30 - 19:30 1.00 RUNCMP RID Little Red, BID Lines and Hoses, RID Double Annulus Valve. Install Gauges and Secure Tree. Rig Released at 19:30 on 2/5/2007 Printed: 2/12/2007 10:10:46 AM TREE = WELlH D = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 6-3/8" crw MCEVOY AXELSON 91.66' 55.31' 1800' 51 @ 5646' 11137 8800' SS . 113-3/8" CSG, 68#, L-80, ID = 12.415" I Minimum ID = 2.813" @ 2100' 3-1/2" HES X NIPPLE 19-5/8 " X 7" BKR L TP w I 6' TIEBACK, ID = 6.375" I 19-5/8 " X 7" BKR LNR HGR. ID = 6.187" I 3-1/2" TBG, 9,2#, 13CR-80, V AM TOP, ,0087 bpf, ID = 2.992" 10375' I 7" LNR. 29#, L-80, NSCC, .0371 bpf, ID = 6.184" I 10555' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 3-1/2"TBG, 8.18#, 13CR-80. STL, ,0087 bpf, ID = 2.990" I 9-5/8" CSG, 47#, L-80, ID = 8,681" I ÆRFORA TION SUMMARY REF LOG: BHCS 09/29/93 ANGLEATTOPÆRF: 30@ 11140' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 11140 - 11150 S 12/04/93 3-3/8" 4 11150 - 11174 0 10/23/94 3-318" 4 11188 - 11200 0 12/12/93 3-3/8" 4 11202 - 11216 0 12/12/93 3-3/8" 4 11222 - 11227 0 12/12/93 3-3/8" 6 11230 - 11235 S 12/04/93 Z-08A ary NOTES: PARENT WELLBORE NOT SHOWN ~ TOP OF MILLOlJT WINDOW @ 10080' ***CHROMETBG & LNR*** 2100' -13-1/2"HESXNIP,ID=2,813" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 8 2307 2307 1 MMG OCR RKP 0 02/05/07 7 3148 3133 23 MMG DMY RK 0 02/05/07 6 4242 4002 43 MMG DMY RK 0 02/05/07 5 6344 5388 49 MMG DMY RK 0 02/05/07 4 7689 6299 45 MMG DMY RK 0 02/05/07 3 8693 6998 46 MMG DMY RK 0 02/05/07 2 9382 7487 43 MMG DMY RK 0 02/05/07 1 10258 8217 35 MMG DMY RK 0 02/05/07 9861' -13-1/2"HESXNIP,ID=2.813" I HES SYMPHONY GUAGE CARRIER w I CABLE TO SURFACE IN lA, ID = 2.992" 10298' -1T'X3-1/2" BKRS-3 PKR, ID = 3.875" I 10333' -13-1/2"HESXNIP,ID=2.813" I 10364' -13-1/2" HES X NIP, ID = 2,813" I 10394' 10422' -1T' X 4-1/2" BKR S-3 PKR, ID = 3.875" I -17" X 4-1/2" BKR S-3 PKR, ID = 3.875" I -14-1/2" PKR SWS NIP, ID = 3.813" BEHIND PIPE -14-1/2" PKR SWN NIP, ID = 3,725" ~4-1/2" WLEG, ID - 3.958" I H ELMD I -13-1/2" WLEG, ID = 2.992" 9-5/8" MILLOUT WINDOW (Z-08A) 10080' - 10130' 11026' H20' MARKER JOINT I I 7" LNR, 29#, 13CR, .0371 bpf, ID = 6.184" DATE 05/01/88 1 0/04/93 02/06/07 02/12/07 REV BY COMMENTS ORIGINAL COM PLETION LINDER SIDETRACK (Z-08A) D16 RWO ?/ PJC DRLG DRAFT CORRECTIONS DATE REV BY PRUDHOE BA Y UNIT WELL: Z-08A ÆRMIT No: "1931280 API No: 50-029-21787-01 SEe 19, T11N. R12E, 9735' SWL & 1252' EWL COMMENTS BP Exploration (Alaska) Well Z-08A (PTD 1931280) Reclassified from Waiver to Trouble e e ~r BIDIÐ~ Sub.iect: WeIl Z-08A (PTD 1931280) Reclassified from Waiver to Trouble From: "NSU, ADW Wclllntegrity Engineer" <NSLJADWWelllntegrityEnginccr@BP.com> Date: Thu, 02 Mar 2006 14:42: 12 -0900 To: jimJcgg@admin.state.ak.us, winton_aubcrt@admin.statc.ak.us, "NSU, ADW Well Operations Supervisor" <NSUADWWcIlOperationsSupcrvisor@BP.com>, "GPB, Wells Opt Eng" <GPB\Vells0ptEng@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, "Kurz, John" <john.kurz@BP.com>, "GPB, GC2 Area Mgr" <GPBGC2TL@BP.com>, "Robertson, Daniel B (Alaska)" <DanicI.B.Robertson@BP.com>, G ANC Wcllwork Program <gpbuwcllworkprogram@BP.com>, "GPB, GC2 Wellpad Lead" <GPBGC2Wc)]padLead@BP.com>, "GPB, GC2 OTL" <gpbgc2otl@BP.com>, "GPB, Well Pads LVZ (GPBWeIlPadsLVZ@BP.com)" <IMCEAEX- _ O=BP.....'OU=USAPBLJ _ CN=R ECIPlENTS.._CN=GPB WELLP ADSL VZ@BP.com> CC: "NSlJ, ADW Well Integrity Engincer" <NSUADWWe1HntcgrityEngincer@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "NSU, ADW WI Tech" <NSUADWWITech@BP.com>, "Luckctt, Ely Z. (VECO)" <luckez@BP.com> Hello all. Well Z-08A (PTD 1931280) has been reclassified from Waiver to Trouble. A tubing restriction is preventing the setting of a TTP to allow pressure testing of the production casing. Lead Operator: would you please ask the Pad Operator to remove any waiver related signage? Wells Tech Aide: would you please delete the 4 steps on the WBL? Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.eom l' ¡\ tJ;: (ì .) 1 of 1 3/8/2006 1 :44 PM RECEIVED . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2, 8 Z001 REPORT OF SUNDRY WELL OPERATIONS , , 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ ~ Pre Acid - TI FL & TD Tag Pu, tubing _ Alter casing _ Repair well _ Other_X Anchorage 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 89 feet 3. Address Exploratow.__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 973' FNL, 1251' FWL, Sec. 19, T11 N, R12E, UM (asp's 598976, 5959100) Z-08A At top of productive interval 9. Permit number / approval number 1982' FSL, 3270' FWL, Sec. 13, T11 N, R11 E, UM (asp'sn/a) 193-128 At effective depth 10. APl number 2069' FSL, 1998' FWL, Sec. 13, T11 N, R11 E, UM (asp's 594404, 5962085) 50-029-21787-01 At total depth 11. Field / Pool 2200' FSL, 1982' FWL, Sec. 13, T11 N, R11 E, UM (asp's 594386, 5962215) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11475 feet Plugs (measured) true vertical 9180 feet Effective depth: measured 11217 feet Junk (measured) TD Tag @ 11217 (05/17/2001 ) true vertical 8958 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 72 c.f. concrete 146' 146' Surface 2642' 13-3/8" 41 85 c.f. Permafrost 2678' 2678' Intermediate 10044' 9-5/8" 2485 c.f. Class 'G' 10080' 8748' Liner 1531' 7" 354 c.f. Class 'G' 9944' - 11475' 7894' - 9180' Liner Perforation depth: measured Open Peris 11150' - 11174', 11188' - 11200', 11202' - 11216', 11222' - 11227', Straddle Pack- Open 10608' - 10612', Sqzd Peris 11140'- 11150', 11227'- 11235'. true vertical Open Peris 8900' - 8921', 8933'- 8943', 8945' - 8957', 8962' - 8967', Straddle Pack- Open 8429' - 8433', Sqzd Peris 8892' - 8900', 8967' - 8974' Tubing (size, grade, and measured depth) 5-1/2" x 4-1/2" @ 2172', 4-1/2", 12.6#, L-80 TBG @ 10640' MD. Tubing Tail @ 10693'. Packers & SSSV (type & measured depth) 7" X 4-1/2" Baker SABL-3 Packers (ID 3.875") @ 10422' & 10640' MD. 5-1/2" Otis SSSVLN @ 2037' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. .R. epresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~...,~~ .~~)~ Title: Technical Assistant Date June 22 2001 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN ~)UPLICATE Z-08A Description of Work Completed NRWO OPERATIONS 09/29/2000 01/10/2001 05/17/2001 05/18/2001 ACID: TAG'D TD @ 11,216', TIGHT @ 10,629 & 10,650' (PRE- CT ACID STIM, IN-PROGRESS) ACID: TIFL. PASSED (PRE-ACID STIM) ACID: DRIFT AND TAG FOR FB ACID STIM ACID: TIFL. PREP FOR TBG WASH. SUMMARY 09/29/00 RAN 2.25 LIB TO TD @ 11216' WLM. FOUND MINOR RESTRICTION BETWEEN 10629' WLM AND 10650' WLM. LIB SHOWS INCONCLUSIVE RESULTS. 01/10/01 PERFORMED TIFL ON WELL, 1ST SHOT @ 9889' LAST SHOT @ 9842'. PASSED TIFL. 05/17/01 DRIFT AND TAG TD W/3.50" CENT, TEL AND SAMPLE BAILER & SET DOWN @ 10,629, COULDN'T GET THRU, POOH. RIH W/2.25 SWAGE & TAG TD @ 11,217' SLM. 05/18/01 TIFL PASSED. T/I/O =1760/1760/340. TIFL PASSED.( PREP FOR TBG WASH). INITIAL IA FL @ 9649'. BLED IA FROM 1760 PSI TO 500 PSI IN 4 HOURS AND 30 MINUTES. MONITOR FOR 30 MINUTES. POST IA BLEED FL @ 9617'. NO CHANGE IN IA PRESSURE. FINAL WHP"S: 1680/500/340. WELL BACK ON WITH GAS LIFT. Fluids Pumped BBLS. Description NO FLUIDS PUMPED 0 TOTAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: April 21, 2001 THRU: FROM: Tom Maunder, P. I. Supervisor % tf ~ %- C~ \ Lou Gdmaldi, SUBJECT: Petroleum Inspector SVS Tests BPX Z-pad Prudhoe Bay Field Saturday, April 21, 2001; I witneSsed the three-month SVS retests on BPX Z pad in the Western Operating Area of the Prudhoe Bay Field. Merv Liddelow performed the SVS tests today. The test results (one SSV Failure) are noted on the accompanied SVS test spreadsheet. All well houses were in "OK" condition. This was the first experience ! have had with the new SV control system on Z pad and found it':to operate quite well. The temperatures today were somewhat mild (+15) and it remainsto be :seen how~:they will hold up dudng next winter's cold season: Wells Z'5 and Z, Shad slow clOsing SSV's (+ 2 minutes), Merv called the Automation crew and these were being worked on before I left the pad. The pad is being used as a staging area for some pipeline fabrication and has some equipment and material stored on it. This was kept for the most part neat and orderly. SUMMARY: I witnessed the three-month SVS retests on Z pad in the Prudhoe Bay Field. 20 wells, 40 components, Onefailure, 34 Wellhouse inspections, no problems. Attachments: SVS PBU Z pad 4-21-01 LG.XLS NON-CONFIDENTIAL SVS PBU Z pad 4-21-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX OPerator Rep: Merv Liddelow AOGCC Rep: Lou Grimaldi Submitted By: Lou G. Date: Field/Unit/Pad: ,Prudhoe Bay Field, Z pad Separator psi: LPS 159 HPS 2.,,I-A.. pr , i i .. . t I i ~i i i i We~ Permit Separ Set L/P Test Test Test Date oi~ WAG, GIN J, Number Number PSI PSI Tdp Code Code Code Pa~ed GAS or CYCL~ z_O 880660 P z-02A 1960430 Z-03 ·1971310 159 125 115 P "~ ...... ,,, Z-04 1891230 Z-05 1900780 " 159 '125 1~5 P P '" ,, , ~ , , Z-06 1880320 159 125 125 P P Z~07A 1931100 ..... Z-08A 1931280 159 125 120 P e ~209' 1890850 ' z-10 1891160 , Z-11 1900720 159 125 125! P P , , ,, Z-12 1891020 ,, Z-13 1900940 159 125 1251 P P iZ-14A 1980510 ' Z-15 1880880 Z'16' 1920120 159 " 125 t25 e "P ,, . , , , Z-17 1891390 159 125 125 P P , ,, ,, Z-18 1890960 Z-19 1920230 Z_20 "'1881000 ,,, Z-21 1890420 159 " 12'5 125 P P ......... Z225B ' i960350 '159 125 115 "e e Z-23A ' i950430 159 ' ' 125 125 P P Z'24 1890180 159 125 i'25 P 4 ' , , , . i, ~ ,, , , , Z-25 1881590 159 125 125 P P Z-26 1890520 159 125 125 P P '' z-2~' 190'0310 '159 125 125 P P ,, Z_28 1881270 · , , , ,, Z-29 18~0656 159! i55 120 P P , , , Z-30 1900230 159 125, 120 , P .P ..... Z-31 1881120 Z'35B ' "1'970340 1'59 125" 125' P e " ' , , ,, , Z-33A 1890050 , , , , Z-35 1980930 Z-38 1980600 "159 125 1'20 P P , , RJF 1/16/01 Page 1 of 2 SVS PBU Z pad 4-21-~ ~_G . i i i i i . _ !iL ':':~ :~¢: '~--~ ~ ~ ~ -, ~:~:~ ~:~:..'z~7' ~ -'-~ ~-~ Well ! Permit Number Number Wells: 20 Remarks: ?i lsss: ti l: eil Type:.:'~ ; I SePar I Set I L/P ! Test [ Test ! Test ! Date I Oa, WAG, GiNJ, I PSI [ PSI [ Trip I Code I Code ! Code I Passed [ GAS or CYCLE I Components: 40 Failures: 1 Failure Rate: 2.50% [] g0 Day Z-5 & 8 Long closure times on SSV. RJF 1/16/01 Page 2 of 2 SVS PBU Z pad 4-21-01 LG MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie HeUsser {}~"'~, ~'~ Commissioner DATE: January 23, 2001 THRU: FROM: T°m Maunder, P. !. Supervisor Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Z Pad Friday, JanUa.ry..19j 2001: I traVeled to BPX's Z Pad in the Prudhoe Bay Field and witnessed surface safety valve system testing. Merv Liddelow was the BPX representative in charge of testing. As the attached AOGCC Safety_ Valve System Test Report indicates I witnessed the testing of 21 wells and 43 components with 6 failures: The pilot on well Z-03 failed to trip and the pilot on well Z-08 was frozen and once thawed it passed a retest but the SSV on this well had an unacceptable closure time (12-min.). The SSV on well Z-18 also had an unacceptable closure time (15-min.) and the SSV's on wells Z-22B and Z-24 failed to pressure test. The high failure rate on Z Pad requires it be placed on a 90- day test interval. Mr. LiddloTM indicated to me today that all failures have been repaired except the slow SSV closure of wells Z-O8A and Z-18. The hydraulic lines on these wells need to be flushed and he has arranged for the maintenance crew to perform the work. Wetlhouse inspections were conducted on the 21 wells tested with no exceptions noted. Summary: i witnessed SVS testing at BPX's PBU Z Pad. 21 wells, 43 CompOnents, 6 failures, 13.9% failure rate. 2t wellhouse inspections conducted. Attachment: SVS PBU Z Pad 1-19-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv L!dde, low. AOC~C Rep: Jeff Jones Submitted By: Jeff Jorles Field/Unit~ad: PBF/PBU/Z Pad Separator psi: "LPS i5'~ Date: 1/19/01 HPS ........ , .... . s. ',' .... , ' .i. ,. :- ' , .iii : ' .'.:i ' "i ':' i' !' '- ~;":;i;7'~::'_ i .... '":i~'~ '!':" .... ~ ........ ' .... ':~ ":='" ......... : Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PS1 PSI Trip Code Code Code Passed GAS or C¥CI~ i i i~ i i i Z-01 1880660 15~ 125 125 P OIL Z-02A 1960430 ' " : ....... Z-03 ' 1971310 15~ 125 ' 0' 1 ' "P ..... OIL Z-04 18912301 , ~-05 '" 1900:/80' ' '159 125 ' '120 'P '~ ...... OIL z-06 '88032'0 z_07^ 95 i oo .. 1 ................ Z-08A 1931280 1~9 125 '0' 2 ' 43 1/22/01 OIL, Z-09 1890it50[ , ' ......... Z-10 1891'160 .............. Z-11 1'900720 159';' i25 125 P ~ ....... OILI Z-12 1891020 Z-13 1900~j40 ' '159 .... 1'25 ' 125 'p "p ....... OIL Z-14A 1980510 z-15 1880880 ......................... Z-16 1920120 '159 125 -125 P 'P " ' OIL Z-17 1891390 159 125 125 P P OIL Z'18 1890960 "159: 125 1~0 P ''~3 ' oI'L z-19 .1920230 z-20 1881000 Z-21 1890420 Z-22B 1960350 159 125 : 125 P 4 OIL Z-23A 1950430 Z'-24' 1896180 159 125 130 ' P 4 ' OIL Z-25 1881590 1591 125 125 P P OIL Z-26 1890520 159!125 125 P P OIL Z-27 1900310 1591 125 125 P P OIL Z_,,~8 ,, 1881270 ............. Z-~9 1890650" 159! 125 120 P ,,pt ........... OIL Z-30 1900230 '159 125 ' ' 1"15 'P 'P OIL Z-31 1881120 Z-32B 19{0340 159 125 i3_5 P ..... P ' OIL Z-33A 1890050 2750 2600 2500 P P P GINJ Z-35 ' 1~J8'0950 159 125 120=' P' "P .... OiL 1/24/01 Page 1 of 2 SVS PBU Z Pad 1-19-01 JJ. xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Code Code Code Passed GASor CYCLE I I I I I I IIIII I I I I I I III Z-38 1980600 159 125 120 -P P OIL Wells: 21 Components: 43 Failures: 6 Failure Rate: 13.9°/d~i9o var Remarks: Z-08A SSV failed: 12 minme close. Z-18 SSV failed: 15 minute close, frozen pilot thawed & passed retest. 1/24/01 Page 2 of 2 SVS PBU Z Pad 1-19-01 JJ.xls ON OR BEFO iANUARY 03 2001 ,5 I A I I: UI- ALA,SF, A At~'*-KA OIL AND GAS CONSERVATION COMMI ~-~- REPOR'I. ": SUNDRY WELL OP,-,,ATIONS 1. Operations performed: Operation shutdown__ Stimulate x Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate__ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 973' SNL, 1252' EWL, SEC. 19, T11N, R12E At top of productive interval 1982' NSL. 3270' EWL, SEC. 13, T11N, R12E At effective depth 3104' NSL, 3293' EWL, SEC. 13, T11N, R11E At total depth 2200' NSL, 3296' EWL, SEC. 13, T11N, R11E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB£ = 8~.56 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number Z-O8A (23-13-11-11) PBU 9. Permit number/approval number 93-128 / 10. APl number 50-029-21787-01 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural __ Conductor 110 Surface 2641 Intermediate 10043 Production _. Liner 1531 Perforation depth: measured 11475 BKB 9182 11426 BKB 9139 Size feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth True vertical depth BKB 8 c.v. Concrete 147 147 4185 c.f. Permafrost 2678 2678 2485 c.f. Class "G" 10080 8748 20 13 3/8 9 5/8 7 354 c.f. 9944-11475 7894-9180 10608~10612~11144~11174~11188'-11200~11202~11216~11222'-11232' true ve rtica~ubsea 8427'-8431 ', 8440'-8922', 8934'-8944 ', 8946'-8958', 8963'-8972' Tubing (size, grade, and measured depth~ 1/2"x 4 1/2" L-80 @ 10717' Packersand~Ss~(typeandmeasureddepth~5/8~T~Wpackerat1~639~;5~/2~sSs~a~2~73~6~ED 13. Stimulation or cement squeeze summan~ee Attachment Intervals treated (measured) Treatment description including volumes used and final pressure Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 448 595 162 1540 798 918 0 1450 Tubing Pressure 282 253 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of W~)II Operations_/~ I ! Oilx Gas Suspended 17' I ~b~ce/~/at t.~reg°~/s,~tx rue.,~/rect ft° the best °f mY kn°wledge' Signed/,/ / .~~~ ~,/~u~_/_//~//C_,f_~~ Title Technical Assistant IV Form 10-404 Ro(~ 06/15~8- / Service Date 7~c:~ SUBMIT IN DUPLICATE Z-08A DESCRIPTION OF WORK COMPLETED Stimulation Operation 03/08/98 A Mud Acid Stimulation Treatment was performed using the following fluids: SUMMARY PT lubricator and lines to Trico to 4000 psig. Begin Bullhead kill down backside line from surface. Injectivity not good after 75 bbls SW pumped: 1200 psi @ lbpm. Rig in hole and circulating out gas of tbg. Tag bottom @ 11248'. BH --100 bbls SW into formation and circulate another 200 bbls SW while recip across perfs. Injectivity 1.1 bpm @ 968 psig and slowly getting worse. Pump 1st stage of 60 bbls of 12/10 HCL/Xylene acid. Slow rate to 1.5 bpm & recip across perfs seeing no break. Follow w/57.6 bbls of 9/1 Mud Acid. No break-slow increase in pressure. Follow w/58 bbls 5% HCL stage. Follow w/100 bbls 2% NH4CL. Injectivity getting worse (Whp= 1700 psig @ 1.5 bpm). Decision was made to pump 300# of wax beads, instead of full 600#'s since injectivity didn't improve at all on first acid stages. Pump 300# wax beads. Follow with 63 bbls 12/10 HCL/Xylene. See no diversion & no break to speak of. Switch to MA. After 4 bbls Mud Acid pumped decide to mix up another 300#'s of wax beads. Pump 14 bbls 2% NH4CL at min while getting other diverter pill made up. Pump 2® 300# slug of wax beads with nozzle above perforations. Follow with the remaining 53 bbls of 9/1 Mud Acid. See a slight diversion (several 10 psi bumps @ 1.5 bpm, but no success). Switch to 5% HCL. Up rate to 2 bpm (Whp= 1950 psig @ 2 bpm). Pump 55 bbls of 5% HCL & switch to 80 bbls of NH4CL. Finish w/33.6 bbls SW to displace treatment to perfs. Shoot fluid level on IA at 2450'. lAP- 1800 psig. WHP= 1600 psig. Injectivity and acid action masked by fluid loss into IA.. It is likely that IA was topping up during cool down phase. Assuming that fluid level was at the orifice valve (station #1 9860') at the beginning of the job, the IA could have inflowed 396 bbls throughout the course of the job. Therefore: worst case is approx. 100 - 150 bbls of treatment into the IA. Well left flowing to TRICO for Acid Flow back and later piggy back well test. Fluids Pumped BBLS. Description 49 Methanol 347 Sea Water 189 2% NH4CL 121 12/10 HCL/Xylene 115 9/1 Mud Acid 118 5% HCL 24.5 300 # wax breads 963.5 Total Pumped STATE OF ALASKA ~,~ASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ StimuJate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Developrnent_X 68' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchora~]e, AK 99510-0360 Service_ Prudhoe Bay Unit 14. Location of well at surface: 8. Well number: 1145' SNL, 1252' WEL, Sec 9, T10N, R14E, UM. 14-01A At top of productive interval: 9. Permit number/approval number: 3381' NSL, 4466' WEL, Sec 4, T10N, R14E, UM. 93-185 At effective depth: 10. APl number: 50-029-20317-01 At total depth: 11. FieldJPool: 3642' NSL, 4627' WEL, Sec 4, T10N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11541 feet Plugs (measured) true vedical 9241 feet Effective Depth: measured 11418 feet Junk (measured) true vertical 9138 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 122' 20" 425 Sx Arcticset II 122' 122' Surface 2405' 13-3/8" 5647 Sx Permafrost 2473' 2470' Production 9397' 9-5/8" 1125 Sx Class G 9465' 7676' Liner 1638' 7" 420 Sx Class G 10905' 8710' Liner 822' 5" 89 Sx Class G 11530' 9237' Perforation Depth measured 10874 - 10888'; 11191 - 11206' P~ECEIVED ]'1 ]998 true vertical 8684 - 8695'; 8949 - 8962' p, ij ~j - ~ " Gas Cons. Comrnt,~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 CR-80, Tbg @ 10673' MD. A~a.s['~a, 0i~ & /,,nebo rage Packers and SSSV (type and measured depth) Baker SABL Packer @ 10614' MD; 4-1/2" Camco TRDP SSSV @ 2206' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1014 16801 4758 1024 Subsequent to operation 1184 21863 5525 1179 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Repo,rt of Well Operet~ons _X Oil _X Gas _ Suspended _ Service _ 17. I hereby, Z' .ff~fy that ti'~i~'oing is true and correct to the best of my knowledge. Signed v' CL'-/,"~'~ ~)~ ~ Title: Engineering Supervisor Date 0 ~ o° Form 10-, l Rev 06/15/88 SUBMIT IN DUPLICATE 14-01A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 5/21/98: MIRU & PT equipment. RIH w/perforating guns & shot 14' of perforations as follows: Added perforations: 10874 - 10888' MD (Sag) Ref. Log: BHCS 12/27/93. Used a 3-3/8" carrier & shot the perfs at 6 spf at 60 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production & obtained a valid welltest. PERMIT -- 93-128 93-128 93-128 93-128 93 -128 93-128 93-128 93-128 93-128 ACGCc Individual Well Geological Materials Inventory DATA T DATA_PLUS 5799 ~/OH-CN, 10133-11444 407 ~MP DATE: 10-16-93 DAILY WELL OP ,~~/20/93 TO 10/06/93 SURVEY ~~10970-11428 BHC/AL/GR ~'2&5", 10200-11444 CNL/GR -~'/-~&5",10800-11410 ? DLL/GR/SP ~/2&5", 10200-11412 GR/CCL (JWL) ,10600-11348 GR/CCL(PFC) (JWL)~~5",9800-11012 93-128 PFC/CCL (PERF) 93-128 PFC/CCL (PERF) 93-128 PFC/CCL(PERF) 93-128 PFC/GR/CCL 93-128 '/L ~" 10570-10900 ~R1,10941-11236 g]~-5'', 11030-11300 ~ !1000-11215 93-128 PFC/GR/~L(PERF) 0-11212 1 _, SBT/GR/CCL "~E~'', 10690-11388 Page: 1 Date- 09/29/95 RUN DATE_RECVD 10/12/1993 11/09/1993 11/09/1993 11/09/1993 10/13/1993 10/13/1993 10/13/1993 10/19/1993 10/21/1993 10/13/1993 11/16/1993 10/21/1993 11/03/1994 01/05/1994 ].0/19/1993 Are dry ditch samples required? yes~___~d received% yes--~tlo ~ Was the well cored? yes ~...~_~A~nalysis~ received? Are well tests required*~fes _~__~-ived~=~_ _- Well is in compliance In~,tial yes no COMMENTS ,-- STATE OF ALASKA · I .,A OIL AND GAS CONSERVATION COMMIS, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging Pull tubing __ Alter casing __ Repair well __ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 973'SNL, 1252'EWL, SEC. 19, T11N, R12E At top of productive interval 1982'NSL, 3270'EWL, SEC. 13, T11N, R12E At effective depth 3104'NSL, 3293'EWL, SEC. 13, T11N, R11E At total depth 2200'NSL, 3296'EWL, SEC. 13, T11N, R11E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 88.56 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-O8A (23-13-11-11) PBU 9. Permit number/approval number 93-128 / 10. APl number 50- 029-21787-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2641 Intermediate 10043 Production -- Liner 1531 Perforation depth: measured 11475 feet BKB 9182 feet 11426 feet BKB 9139 feet Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth BKB 20 8 c.y. Concrete 147 147 13 3/8 4185 c.f. Permafrost 2678 2678 9 5/8 2485 c.f. Class "G" 10080 8748 7 354 c.f. 9944-11475 10608'-10612', 11144'-11174', 11188'-11200', 11202'-11216', 11222'-11232' 7894-9180 true vertical subsea 8427'-8431',8440'-8922',8934'-8944',8946'-8958',8963'-8972'~ Tubing (size, grade, and measured depth) 5 1/2"x4 1/2"L-80 @ 10717' AUG 30 ]995 Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 10639~ 5 1/2" SSSV at 2073' Aias~ 0it & Gas Cons. Commission 13. Stimulation or cement squeeze summary See Attachment Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 448 595 162 1540 798 918 0 1450 Tubing Pressure 282 253 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17.1 hereby~__ - ~/'~c~rtify that the foreg~p~tru~ corre.ct to the best of my knowledge. Signed (.._~.- ~ ~ ,/-//~ Title Senior TechnicalAss/stent II Form 10-404 Rev 06/15/88 SUBMIT IN DL:fPLI(:::ATE 10/23/94 WELL Z-08A (23-13-11-11) Reperf Operation The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 11150'-ll174'MD LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 27 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: jELL DESCRIPTION 1 CCL/TUBCUTR FINAL BL 1 CCL/TUBCUTR RF SEPIA (13-24-12-13) Z-22A (32-12-11-11) 1 PFC/P~RF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 CCL/PERF FINAL BL 1 CCL/PERF RF SEPIA Run # 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run # 1 ECC No. 4027.02 5191.02 6050.06 6065.05 Please sign and return to: Atlas Wireline Services 56?0 B Street STATE OF ALASKA ALA~:~.OIL AND GAS CONSERVATION COMMISS REPORT SUNDRY WELL OPE, ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 973' SNL, 1252' EWL, SEC. 19, T11N, R12E At top of productive interval 1982'NSL, 3270' EWL, SEC. 13, T11N, R12E At effective depth 3104'NSL, 3293'EWL, SEC. 13, T11N, R11E At total depth 2200'NSL, 3296'EWL, SEC. 13, T11N, R11E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 88.56 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-O8A (23-13-11-11) PBU 9. Permit number/approval number 93-128 / 10. APl number 50- 029-21787-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2641 Intermediate 10043 Production -- Liner 1531 Perforation depth: measured 11475 feet BKB 9182 feet 11426 feet BKB 9139 feet Plugs (measured) Junk (measured) Size Cemented Measured depth 20 8 c.y. Concrete 147 13 3/8 4185 c.f. Permafrost 2678 9 5/8 2485 c.f. Class "G" 10080 7 354 c.f. 9944-11475 10608'-10612', 11144'-11174', 11188'-11200', 11202'-11216', 11222'-11232' True vertical depth BKB 147 2678 8748 7894-9180 true vertical subsea 8427~8431~8440~8922~8934~8944~8946~8958~8963~8972' Tubing (size, grade, and measured depth) 5 1/2"x 4 1/2"L-80 @ 10717' Packers and SSSV (type and measured depth) 9 5/8" TlWpacker at 10639'; 5 1/2" SSSV at 2073' JUL 1 ~ 1994 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 0il & Gas Cons. Commis'~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 982 1425 Tubing Pressure 480 778 257 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c, ertify that the foregoing is true and correct to the best of my knowledge. Signed ('~v't.~,,.~ Title Senior Technical Assistant I Form 10-40~ Rev 06/15/88 / Date SUBMIT IN DU'PLI(~ATE 10/14/93 11/11/93 12/04/94 WELL Z-08A(23-13-11-11) AddperffReper~RWO The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12766'-12805MD The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 11230'-11235MD A NRWO GSO was performed using the following fluids below: SUMMARY WELL SI ON ARRIVAL. LIQUID PACK WITH 400 BBLS 100 DEG SW. COOL WELLBORE AND SUMP W/131 BBLS SW. INJECTIVITY WAS 1.0 BPM @ 150 PSI AND 5.0 BPM @ 890 PSI. TAGGED PBD @ 11274' WHICH WAS HIGHER THAN PREVIOUS TAG OF 11393' (AM GUESTIMATING THAT FILL WAS FROM BARITE THAT FELL OUT OF THE DRILLING MUD AFTER THE WELL WAS POP). BULLHEAD CEMENT WHILE POOH AND OPEN CHOKES @ 1000 PSI. DECREASED WHP AFTER IT WAS OBVIOUS SQUEEZE WOULD NOT LOCK UP. PLAYED WITH CEMENT FOR 3 HRS 8 MIN WHILE INCREASING PRESSURE TO 2800 PSI MAXIMUM AND LOSING SLIGHT RETURNS THE WHOLE TIME. LRO'D TO PREVIOUS FLAG @ 11264'. REVERSED CLEAN. JETTED "X" NIPPLES TO 10364' AND REVERSED CLEAN. JETTED FROM PBD TO EOT AND BACK AND REVERSED CLEAN WITH 0.1 BPM LOSS @ 2000 PSI CONSTANT. JETTED TO 11300', BUT WERE UNABLE TO PASS 11270' WHILE REV OUT. POOH. DID NOT FP WELL. INJ TEST @ SURFACE 0.1 BPM @ 1500 PSI. NOTE: DID NOT UNDERBALANCE OR RESQUEEZE SINCE INJECTIVITY WAS TOO LOW TO RESQUEEZE AND OBJECTIVE OF PLACING CEMENT BEHIND PIPE WAS PROBABLY MET. WL WILL RUN GLV'S TO UNDERBALANCE FOR PERFORATING. FLUIDS 400 131 10 30 6 26 20 47 290 35 57 38 170 34 BBLS BBLS BBLS BBLS BBLS BBLS BBLS BBLS BBLS BBLS BBLS BBLS SW (LIQUID PACK) SW (COOL WELLB ORE) EW (PREFLUSH) CEMENT EW (SPACER) SW (SPACER) DUO POLYMER (CONTAMINANT) SW (DISPLACEMENT) SW (REVERSE OUT) sw (JET PASS) SW (REVERSE OUT) sw (JET PASS) BBLS SW (FINAL REVERSE OUT) BBLS MEOH (FREEZE PROTECTION CT) RECEIVED JOL 1 3 1994 ,,.l~ska ul~ & Gas Cons. Commission Anchorage PAGE 2 12/11/93 WELL Z-08A(23-13-11-11) WELL CLEANED OUT TO 11270' 300 BBLS LOAD FLUID BEHIND PIPE TODAY 10 BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) CEMENT (B..I. SERVICES) 15.8 PPG CLASS "G" CMT CONTAINING 0.7% FL-33 0.1% CD-32 0.5% R-11 1.0 GAL PER SK FP-6L The following interval were reperforated using 3 3/8" guns, 4 SPF, random orientation and 120° phasing. 11150'-ll174'MD 11188'-ll200'MD 11202'-l1216'MD 11222'-11227'MD fjh 7/11/94 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 27 December 1993 RE: Transmittal of Data ECC #: 6050.05 Data: PL Dear Sir/Madam, Reference: BP Z-08A NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Sent by U.S. MAIL PFC/GR/CCL FINAL BL PFC/GR/CCL FINAL RF Run # 1 Run # 1 Received by: Date: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson '~.l,~s/~,~ 0il ¢ Sos co~s. This is to acknowledga .eceipt of the following p. Its and negatives. COMPANY: STATE OF ALASKA-ALASKA OIL & GAS CONSERVATION COMMISSION ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY & ENDICOTT WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA BHC/AC-GR 1 R-34 S~ SEA ~ ~L" [%7~5 ~ ~Lq~ 1 2-50/U-08 SBT; (E~ICOTT ~,, 1 S I GNED a/ DATE .'~'~l'm~m~ :~;i-/~l] Please retu/rn o~n~e copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT~RTN~i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONF~I~I/% SERVICE [] 2. Name of Operator~ *' ..4.~/~ ~/~ 7. Permit Number BP Exploration ' / ( 77/ .~ 93-128 3. Address /j/ ,// ~. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o-029-21787-01 4. Location of well at surface . .p..._..~.,_. 9. Unit or Lease Name 973'SNL, 1252' EWL, SEC. 19, T11N, R12E i~'~i~,,i~,i;~.i?T?':~ rtoc,~Iloe~.~ Prudhoe Bay Unit ,i i[ 0. Well Number At Top Producing Interval 1982' NSL, 3270' WEL, SEC. 13, T11N, R12E!! ~J'?~-[~ ~ ~ ~' ~. -~~ 11. Field and Pool At Total Depth ~. -.~./~C....!. i~ii Prudhoe Bay Field/Prudhoe Bay Pool 2200' NSL, 3296' WEL, SEC. 13, T11N, R11E .' .............. -~: 5. Elevation in feet (indicate KB, DF, etc.} ]6. Lease Designation and Sedal No. KBE = 88.56' ] ADL 28245 12. Date Spuddedg/25/93 13. Date T.D. Reached9/28/93 14' Date C°mp" Susp' °r Aband' I15' Water Depth' il °tfsh° re 116' N°' °f C°mploti°nsl 0/16/93 N/A leet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey ~0. Depth where SSSV set Fl. Thickness of Permafrost 11475' MD/9182' TVD 11426' MD/9139' TVD YES [] ND []I 2073'feet MD ! 1890'(Approx.) 22. Type Electric or Other Logs Run GR/DL UCNL/BHCS 23. CASING, LINER AND CEMENTING SE3-r#qG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 8 cu yds Concrete 13-3/8" 68# L-80 Surface 2678' 17-1/2" 4185 cu fl Permafrost 9-5/8" 47# L-80 Surface 10080' 12-1/4" 2485 cu ft Class "G" 7" 29# L-80/13CR80 9944' 11475' 8-1/2" 191 CU fl Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MD) Gun Diameter3-3~8" 6 spf 5-1/2"x 4-1/2" 10717' 10639' MD TVD 10608'-10612' 8427'-8431' L-80 11144'- 11174' 8440'-8922' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11188'-11200' 8934'-8944' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 11202'-11216' 8946'-8958' 11222'-11232' 8963'-8972' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 10/19/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR :OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. REC£1V D ~10V -9 1995 Al~s~ 0il & Gas Cons. Commission Anchorage ... Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS I-,.,,{MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top Sag River 10828' 8530' Shublik 10864' 8562' Sadlerochit 11042' 8718' RECEIVED NOV - 9 1993 Alaska Oil & Gas Cons. Commission Arm. hnr~n,, 31. LIST OF ATTACHMENTS 32. I hereby certify tha.~.L.t~e foregoing is true and correct to th? best of my knowledge Si ned~ Engineer Su_o,rvisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: Z-8A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-21787 PERMIT: APPROVAL: ACCEPT: 09/21/93 03:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 14 WO/C RIG: DOYON 14 09/20/93 ( 1) TD: 0 PB: 0 DISP OUT DIESEL. MW: 8.5 Seawater MOVE RIG. RIG ACCEPTED @ 03:00 HRS, 9/20/93. TAKE ON SEAWATER. DISP OUT DIESEL. 09/21/93 (2) TD:11710 PB:10908 L/D TBG. MW: 8.4 Seawater CIRC OUT DIESEL. N/D TREE. N/U BOPE. TEST BOPE. R/U LUB. PULL TBG FREE. CIRC. POOH, L/D 5-1/2" & 4-1/2" TBG. 09/22/93 (3) TD:llT10 PB:10350 09/23/93 (4) TD:10080 PB:10350 09/24/93 ( 5) TD:10130 PB:10350 POOH. MW: 8.4 WBM POOH, L/D TBG. TEST BOPE. RIH W/ BAKER N-1 BP. CIRC. SET @ 10350' TEST CSG. OK. DISP WELL TO MILLING FLUID. POOH. POOH. MW:10.6 WBM POOH. L/D BAKER RUNNING TOOL. RIH W/ MILL. CIRC @ 10080' MILL CSG F/ 10080'-10082' MILL FELL THRU. POOH TO CHECK MILL. POOH. MW:10.7 POOH. RIH W/ NEW SECTION MILL. MILL WINDOW F/ 10082'-10130' CIRC. POOH. WBM 09/25/93 ( 6) TD:10130 PB: 9900 RIH W/KO ASSY MW:10.8 WBM RIH W/SHOE, REV CIRC. RIH, CIRC COND HOLE. PUMP CMT SLURRY. CIRC. SQZ CMT. POH. C/O BOP. TEST. ORIENT MWD & RIH. 09/26/93 (7) TD: 10357' (10357) 09/27/93 (8) TD:10940' ( 583) DRLG & SURV MW:10.1 VIS: 54 RIH, TAG CMT. DRIL CMT. ORIENT MWD & K/O CMT PLUG. DRLD TO 10357. DRLG DRLG & SURV TO 10940. MW:10.2 VIS: 63 09/28/93 ( 9) TD:ll080' ( 140) DRLG. DRLG F/ 10940'-10970' DRLG F/ 10970'-11080' MW:10.2 VIS: 63 CBU. POOH. CHANGE BIT, BHA. RIH. RECEIVED NOV - 9 199~ Alaska Oil & Gas Cons. Commission Anchorage WELL : Z-8A OPERATION: RIG : DOYON 14 PAGE: 2 09/29/93 (10) TD:11475' ( 395) 09/30/93 (11) TD:11475 PB: 0 10/01/93 (12) TD:11475 PB:11434 10/02/93 (13) TD:11475 PB:11426 POH FOR E-LOGS MW:10.2 VIS: 61 DRLD TO 11475. CIRC. SHORT TRIP. SURV. POH, CBU. POH FOR E-LOGS. POOH. MW:10.3 WBM R/U ATLAS. LOG RUN: GR/DLL/CNL/BHC. R/D ATLAS. L/D BHA. RIH W/ 7" 13 CR, NT-80S LNR ON DP. CIRC. RIH W/ LNR. CIRC @ SHOE. RIH & WASH LNR TO BTM. PUMP 25 BBLS ARCO SPACER. CIRC SPACER AROUND. RELEASE F/ HGR. CBU. POOH. POOH. MW:10.3 WBM POOH. L/D BAKER RUNNING TOOL. RIH W/ BIT. CIRC. NO GO. POOH. PLUGGED. RIH TO TOL @ 9944' REV CIRC. RIH TO PLUG CATCHER. REV CIRC. POOH. BREAK CIRC THRU SHOE MW:10.4 WBM CONT POH. RU & RUN WIRE LINE W/PERF. POH. RIH W/CMT RET & SET. POH. RIH TO TOP OF LINER, BREAK CIRC THROUGH SHOE. 10/03/93 (14) TD:11475 PB:11426 10/04/93 (15) TD:11475 PB:11426 POH MW:10.4 WBM CONT CIRC. MIX CMT. TEST LINES. PUMP CMT. CIRC. POH, LD TOOLS & DP. PU BIT & SCRAPER, RIH, BREAK CIRC. CIRC & COND MUD. POH FOR POLISH MILL. RIH MW:10.4 WBM RIH W/POLISH MILL. CBU. POH, LD MILL. PU PKR & RIH.TEST PERFS. POH. RIH W/DC. CHG OVER TO SALT WATER. 10/05/93 (16) TD:11475 PB:11426 RUN TBG. MW: 9.2 NaC1 RIH W/ BAKER RET. CIRC. DISP WELL W/ BRINE. POOH. LD/ DP. RIH W. 5-1/2" X 4-1/2" TBG. 10/06/93 (17) TD:11475 PB:11426 RIG RELEASED. MW: 9.2 NaC1 RIH W/ TBG. LAND TBG. N/D BOPE. N/U TREE. TEST TBG, ANNULUS, SET PKR. R/U LUB. RIH W/ SLICKLINE, PULL DUMMY VALVE, PKR SETTING BALL. TEST TBG, LOWER PKR. OK. SHEAR RP VALVE. R/D LUB, SLICKLINE. DISP TOP 2300' W/ DIESEL. SET BPV. SECURE TREE. RIG RELEASED @ 04:00 HRS, 10/6/93. SIGNATURE: (drilling superintendent) DATE: RECEIVED NOV - 9 1993 Alaska Oil & ~as Cons. Commission Anchorage ANCHORAGE ALASKA PRUDHOE BAY DRILLING /~/~ DATE OF SURVEY: 092993 PBU/Z-08A k~//~//.%. MAGNETIC MULTI-SHOT SURVEY 500292178701 ~/~///~% JOB NUMBER: AK-EI-30073 NORTH SLOPE 9 KELLY BUSHING ELEV. = 89.96 FT. COMPUTATION DATE: 10/ 5/ 3 OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10970 8744.69 8654.73 28 47 N 5.40 W .00 2919.57N 4518.45W 5376.81 11024 8792.02 8702.06 29 36 N 5.92 W 1.55 2945.89N 4521.06W 5393.95 11117 8872.94 8782.98 30 15 N 6.55 W .78 2992.20N 4526.12W 5424.49 11211 8953.61 8863.65 30 23 N 6.61 W .14 3039.08N 4531.53W 5455.63 11305 9035.20 8945.24 30 34 N 6.85 W .24 3086.78N 4537.16W 5487.42 11399 9116.22 9026.26 30 42 N 7.21 W 11428 9141.15 9051.19 30 42 N 7.07 W .24_ 3134.42N 4543.03W 5519.39 .26 3149.11N 4544.88W 5529.27 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5529.27 FEET AT NORTH 55 DEG. 16 MIN. WEST AT MD = 11428 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 304.72 DEG. ECEIVED NOV -'9 ;9 5 a~aska Oit & Gas Cons. Cor/irnission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/Z-08A 500292178701 NORTH SLOPE COMPUTATION DATE: 10/ 5/93 DATE OF SURVEY: 092993 JOB NUMBER: AK-EI-30073 KELLY BUSHING ELEV. = 89.96 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10970 8744.69 8654.73 11428 9141.15 9051.19 2919.57 N 4518.45 W 2225.31 3149.11 N 4544.88 W 2287.75 62.44 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/Z-08A 500292178701 NORTH SLOPE COMPUTATION DATE: 10/ 5/93 DATE OF SURVEY: 092993 JOB NUMBER: AK-EI-30073 KELLY BUSHING ELEV. = 89.96 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10970 8744.69 8654.73 11021 8789.96 8700.00 11137 8889.96 8800.00 11253 8989.96 8900.00 2919.57 N 4518.45 W 2225.31 2944.73 N 4520.94 W 2231.89 6.58 3002.07 N 4527.26 W 2247.34 15.45 3060.26 N 4533.99 W 2263.24 15.90 11369 9089.96 9000.00 11428 9141.15 9051.19 3118.95 N 4541.08 W 2279.40 16.16 3149.11 N 4544.88 W 2287.75 8.35 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS This is to acknowledge receipt of the following prints and negatives. COMPANY: STATE OF ALASKA-ALASKA OIL & GAS COMMISSION ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA ,t~ z-os A PFC~ERF~ eau ~,, %~0~o 3 ~300 0 1 q~' U-04 AI GR/CCL (~ ~" ~0! '~0 0 1 U-04 AI PLS ~~ ~ ~% [0~~ [~[~ 0 1 ., 10/17/93 (rkl) Please return one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 This is to acknowledge receipt of the following prints and negatives. COMPANY: STATE OF ALASKA - ALASKA 0IL & GAS COMMISSION ATTENTION: LARRY GR3kNT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA IX-22 DILF/GR 2~" X-22 WATER SA~TION ~,, 1 l~O~- i[~%0 1 S-36 I PFC/CCL(PERF) S,t 1 ~_ a%tO0 1 OCr l ' SIGNED DATE - / Please return one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT/RTNCARD1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 10/4/93 T# 85084 BPX/PBU O~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 09/29/93 #1 09/29/93 31 09/29/93 31 10200.00-11444.00 ATLAS 2/5" 10200.00-11412.00 ATLAS 2/5" 10800.00-11410.00 ATLAS 2/5" info~aation Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BPX/PBU ~LOGS DATE: 10/4/93 T# 85085 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 10/01/93 #1 09/29/93 #1 09/30/93 #1 09/29/93 #1 10/01/93 ~1 10/01/93 #1 9300.00- 9700.00 ATLAS 5 " 10930.00-11360.00 ATLAS 5 " 11130.00-11300.00 ATLAS 5 " 10740.00-11000.00 ATLAS 5 " 10300.00-10500.00 ATLAS 5 " 10570.00-10900.00 ATLAS 5 " Information Control Well Records ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 11 October 1993 RE: Transmittal of Data ECC #: 6050.00 Data: OH-LDWG Dear Sir/Madam, Reference: BP Z-08A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: ~apes/Diskettes: Prints/Films: Sent by U.S. MAIL CN/AC/DLL LDWG TAPE Run # 1 DLL/AC/CN LDWG LIST Run ~ 1 Received by: Date: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 3, 1993 Michael Zanghi Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit Z-08A BP Exploration Permit No. 93-128 Sur. Loc. 973'SNL, 1252'EWL, Sec. 19, TllN, R12E, UM Btmnhole Loc. 2123'NSL, 1989'EWL, Sec. 13, TllN, RilE, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector, on the North Slope pager at 659-3607. Sincerely, Russsell A. Douglass Commissioner BY-ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~,~ printed on recycled paper b y C,t'J. STATE OF ALASKA " ALASK,. OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25,OO5 la. Type of work Drill [] Redrill E'lllb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl"]I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 91.66 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28245 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(me 2o ^^(~ 25.o~5) 973' SNI_, 1252' EWL, SEC. 19, T11N, R12E Prudhoe Bay Unit At top of productive interval i8. Well number Number 2055' NS/., 1994' EWL, SEC. 13, T11N, R11E Z-O8A (11-19-11-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 2123' NS/_, 1989' EWL, SEC. 13, T11N, R11E 9/7/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and 'rVD) ~ property line ADL 28240-3155' feet No close approach feet 2560 11358' MD/9082' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s,,e 2o ,~c 25.035 (e){2)) Kickoff depth ~o~oo feet Maximum hole angle~ro.,~ 0 Maximum surface 3330 psig At total depth (TVD) ~00'/4390 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29~ NT-80 NSCC 1408' 9950' 7898' 11358' 9082' 120 sx Class "G" 19. To be completed for R~drill, Re-entry, and Deepen Operations: Present well condition summary AUG ~ ~ Total depth: measured 11710 feet Plugs (measured) Alaska 0ii & Gas Cons. Corr~rnissior'. true vertical BKB9111 feet Anchorage Effective depth: measured 11668 feet Junk (measured) true vertical BKB9084 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" 8 c. y. concrete 147' 147' S u rface 2641' 13-3/8" 4185 cuft PF 2678' 2678' I ntermed late 10937' 9-5/8" 2285 cu ft "G" 10974' 8630' Production Liner -995' 7" 354 cuft "G" 10715'- 11710' 8448'-9111' Perforation depth: measured 11384'-11412', 11418'-11436', 11442'-11506', 11520'-11540', 11540'-11552' true vertical 8898'-9007' (5 Intervals) !20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program IT1 'Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements I-'] Signed {v, ~-- 1~,~. ~. Title Drilling Engineer Supervisor Date ~"-'-Z~---~ Commission Use Only Permit Number IAPI number IApproval date ISee cover letter 2~-/2-~ 150-o.z.?--, ~./7 ~"7-o 1 J ~2~ .:;~.. ~':;~ Ifor other requirements Conditions of approval Samples required [] Yes ,l~ No Mud Io~ req'~ed'l~'~'es J~ No Hydrogen sulfide measures [] Yes [] No Directional survey requ~rea ~ Yes I-] No Required working pressure for BOPE 1-12M; 1-13M; /~5M; 1-110M; []15M; Other: Ol~t~!:~J~[. ,.e,l~/fFD by order of Approved by BY' Commissioner [ne comm,ssion Date Form 10-401 Rev. 12-'1"-~ Submit in triplicate SUMMARY PROCEDURE: Z. . . . 6b. . , . 10. 11. 12. 13. 14. Z-08A Sidetrack Plan Summary Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 4-1/2" tubing at _+10,~74' MD. Freeze protect if necessary. MIRU workover rig. Test intermediate packoff to 5000 psi. Pull BPV. Circulate out freeze protection fluid if necessary. Set BPV. ND tree. NU 11" 5M x 13-5/8" 5M DSA if reo_uired and BOP's. Install tree test plug. Test BOP's to 5000 psi. Pull tree test plug and BPV. Pull and lay down 4-1/2". 12.6#. L-80. AB-MOD X 5-1/2". 17#. IJ4S, tubing. Record the total number of full joints laid down on morning report as well as description of cut on cut joint. NOTE: Check with COOPER in PBU for running thread on landing joint. No record in Anchorage. Check with single point contact (564-5510) on whether or not to send tubing for Class "B" inspection. RIH w/9-5/8" bridge plug and set at 10.350' MD. Replace intermediate packoff if necessary. RIH with a ~9-5/8" section mill and cut a 50' section in the 9-5/8" casing starting at +/- 1 O, 100' MD. Prior to starting section cut, spot an 18 ppg pill from PBTD to the base of the proposed section. RIH with open-ended DP. Mix and pump a minimum of 1 t57 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. Drill with an 8-1/2" packed hole assembly to total depth of 11.472' MD/9.184 TVD which is _+150' MD below OOWC. RU Atlas wireline and log with the GR/SP/DIL/BHCS/CNL. Make wiper trip depending on hole conditions and logging time. Run 7". 29#: L80, NSCC standard liner assembly to TD with liner top packer and +/- 1 50' lap. Cement liner with a minimum of 227 sacks. Clean out liner to PBTD and test to :3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. Change over to clean inhibited seawater. A U G 3 1 1993 Page 3 ,Alaska 0il & Gas Cons. Oomrnissior~ Anchora~o [Well Name: I Z-08A Redrill Plan Summary ~Type of Redrill (producer or injector): I PRODUCER Surface Location' Target Location: Bottom Hole l.~ocation: 973 FNL 1252 FWL S 19 T11N R12E UM 2055 FSL 1994 FWL S13 TllN RllE UM 2123 FSL 1989 FWL S13 TllN RllE UM [AFE Number: [4P8009 I ~.Estimated Start Date: ] 07SEP93 IMD: !11,358' I I Rig: ] DOYON RIG #14 I I Operating clays to complete: I 12 ITVD: 19,082' I [KBE: Well Design (conventional, slimhole, etc.): 91.66' I CONVENTIONAL [Objective: ] SADLEROCHIT Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. Special design considerations I NONE Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 15 5 10 10 0 5 tO tO tO tO tO tO tO tO tO TD' 10.0 18 30 15 30 5 0 8 Directional: [ KOP: [ 10,100' MD/8,005' TVD ] m~ximum I-Io,e Angle: [ ~0.48° Close Approach Well: NONE The above listed wells will be secured during the close approach. RECEIVED Z-08A Sidetrack Plan Summary AUG LPG ~995 Alaska Oil & ~as Gons. bul~H'niSs~t/:' Anchorage Page 1 Casin ~/Tubin~ Program: we~i Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8-1/2" 7" 29#/1~T NT-80 NSCC 1408' 995077898' 11,358'/9,082' Cement Calculations: I Liner Size: 1 7" I Basis:! 50~o open hole ex~ess, 40' shoe joint, 150' liner lap and 150' excess above line~' with DP. Total Cement Volume: 120 sxs of Class G Blend w/silica flour @ 1.545. ft3/sx -. _ ILiner-Size: I Basis:[ 50qo open hole ex~ess, 40' shoe joint, 150' liner lap and 150' excess above line~' with DP. Total Cement Volume: sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. RECEIVED A U G ~ 6 199J~ Alaska Oil & Gas Cons. (;ommissio~ Anchorago Z-08A Sidetrack Plan Summary Page 2 P?. ~sdhoe Bey Dr i~ti n g Pi~udhoe Bey Z-P~D Z-08 ZO8STwp HALLIBURTEIN 08/17/1 gg3 I I CJ~ om 7900~ 8100~ 8303-- 8400-- 87C0--~ 88g0~ TRUE J~.~ deg. [OS't [k~clinol:ion VERTICAL VIEW SCALE 100 f'¢. / D]V]S]EN TVD REF: WELLHEAD VERTICAL SECTIDN REF: WELLHEAD HORIZONTAL VIEW SCALE ]00 Ct. / DIVISION SURVEY REF: WELLHEAD 4800 4go0 ,5000 5] O0 ,5~00 53CX] .5400 VERTICAL SECTION PLANE: ~34.~8° --?7' I 4003 3900 RECEIVED AU G 2 G 1993 Alaska 0ii & Gas Cons, Commisslo" Anchorage CR]I']CAC Pr'JlNi DAIA MD ]r,c AZ, lVD NO''''~ Eost IJD ICc?6" l_C 1b'~33 30.6: '233.6l 8ilo B7E~ -z.:~3 END ~ CL~VE 10755 EILEEN 1 lO~ TDz' I ]076 ~.g4 ~5.~ ~31 ~g -4534 S~;C?~7 .-' ~/~. T~ ~/T & 11315 ~.94 ~5.~ ~44 ~77 -4~2 THIn. SS l~ l]~ ~.g4 ~5.~ ~ ~:'-4~4 BHL DAIA ~vg ~2.42 ND 1 ! _.--~J~.l 0 I VS 5498.73 t,~ th 3096.86 Eo$-t -4~3.73J ! ~', STATE OF ALASKA ~),/~ ALA' 'OIL AND GAS CONSERVATION COMMISS,,.,,'~ APPLICATION FOR SUNDRY APPROVALS" A~ter ~si~ Rep~r ~ Plugging~ ~ime extension S~mulate~ I/ J Ch~ge ~proved pr~r~ ~ Pull ~bing ~ VaH~ ~rate ~her x Plugback for redr~ 1. Type of Request: 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 973' SNL, 1252' EWL, SEC. 19, T11N, R12E At top of productive interval 2122'NSL, 1630'EWL, SEC. 13, T11N, R11E At effective depth 2358'NSL, 1408'EWL, SEC. 13, T11N, R11E At total depth 2382'NSL, 1385'EWL, SEC. 13, T11N, R11E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development x Exploratory __ Stratigraphic__ Service ' RECEIVED AU G 2 0 199 .(lit .& Gas.C0ns. 11710 feet Plugs (measured) BKB 9111 feet 6. Datum elevation (DF or KB) KBE = 91.66' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-08 (23-13-11-11) 9. Permit number 88-20 10. APl number 50- 029-21787 11. Field/Pool Prudhoe Bay Field/Oil Pool Effective depth: measured true vertical 11668 feet Junk (measured) BKB 9084 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 110' 20" 8 cu yds Concrete 14 7' 2641' 13-3/8" 4185 cu ft PF 2678' 10937' 9-5/8" 2285 cu fl Class "G" 10974' 995' 7" 354cu ft Class "G" 10715'-11710' measured 11384°-11412', 11418'-11436', 11442'-11506', 11520'-11540', 11540'-11552' True vertical depth 147' 2678' 8630' 8448~9111' true vertical 8898'-9007' (5 intervals) Tubing (size, grade, and measured depth) 5-1/2" L-80 surface to 2195~4-1/2" L-80 2195'-10654' w/4-1/2" tailpipe to 10788' Packers and SSSV (type and measured depth) 9-5/8" TlWpacker @ 10654~5-1/2" SSSV @ 2019' 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 8/25/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. I h,ereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance ~ Mechanical Irftegrity Test Subsequent form required 10- ~tO7 Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By I Approval No..~,,~._,~ ~ Approved Copy Returned ... Commissioner Date ~?/7.. ~/,¢ '~ SUBMIT IN TRIPLICATE · 0 L °""~ Well History File APPENDIX Information of detailed nature that is not particulady 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. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: Z - 08A 500292178701 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 06-OCT-93 RUN1 6050.00 R. ECK D. BOYER RUN2 RUN3 19 liN 12E 973 1252 89.90 88.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 10080.0 8.500 11475.0 DLL/AC/CN/GR CIRCULATION STOPPED @ 00:30 29-SEP-93. NEUTRON LOG PARAMETERS: 8.5" BOREHOLE CORRECTION CHISM FILTERING ACTIVE SANDSTONE MATRIX. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DLL 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 10133.0 11380.0 10196.0 11444.0 10165.0 11412.0 10796.0 11387.0 GR (MEASURED DEPTH) BASELINE DEPTH LL3 10107.0 10107.0 10211.5 10241.5 10245.0 10265.5 10268.0 10270.0 10293.5 10293.5 10296.0 10298.5 10298.0 10300.5 10303.0 10303.0 10329.0 10342.0 10342.0 10342.5 10344.5 10348.5 10352.0 10365.0 10374.0 10374.5 10374.5 10378.0 10382.5 10401.5 10404.0 10407.5 10431.5 10431.5 10432.0 10435.0 10438.0 10440.5 10445.5 10458.5 10469.0 10475.5 10500.0 10508.5 10523.5 10536.5 10541.0 all runs merged; EQUIVALENT UNSHIFTED DEPTH DT NPHI 10107.0 10107.0 10211.0 10241.0 10245.0 10265.5 10268.0 10269.5 10294.5 10297.0 10299.5 10301.0 10329.0 10343.0 10345.0 10349.5 10352.0 10365.0 10374.5 10378.5 10383.0 10401.5 10404.5 10408.0 10432.0 10435.5 10438.5 10441.0 10446.0 10459.5 10469.5 10476.0 10501.0 10509.0 10524.5 10537.5 10542.0 no case 10574.5 10597.0 10637.5 10662.5 10677.0 10702.5 10711.0 10718.0 10809.5 10830.0 10830.5 10858.5 10866.5 10870.5 10876.0 10886.5 10887.0 10888.0 10888.5 10889.5 10900.5 10902.0 10902.5 10907.0 10910.0 10911.0 10916.5 10917.0 10921.0 10922.5 10923.0 10924.5 10928.5 10935.0 10948.5 10949.0 10956.0 10972.0 10974.0 10976.0 10980.5 10981.0 10987.0 10990.5 10997.0 10997.5 11011.0 11025.5 11026.0 11041.0 11052.5 11059.5 11060.0 11086.5 11153.0 11163.0 11176.5 11177.0 11182.5 11195.0 10637.5 10661.0 10677.0 10702.5 10830.0 10866.5 10870.5 10888.5 10902.5 10911.5 10918.0 10921.0 10949.0 10971.5 10974.0 10976.5 10980.5 10997.0 11011.0 11026.0 11052.5 11086.0 11176.5 10574.5 10598.0 10662.5 10702.5 10712.0 10719.0 10809.5 10831.0 10859.0 10866.5 10887.5 10888.5 10890.5 10900.5 10902.0 10918.0 10923.5 10925.5 10929.5 10974.0 10981.0 10997.5 11012.0 11026.5 11052.0 11059.5 11087.0 11153.0 11162.5 11178.0 11182.5 10809.0 10830.5 10859.0 10866.5 10876.5 10886.0 10888.0 10890.0 10900.5 10902.0 10907.0 10910.5 10917.0 10922.0 10924.5 10928.5 10936.0 10948.5 10956.0 10976.0 10981.0 10987.0 10990.5 10997.0 11011.0 11025.5 11042.0 11059.5 11086.0 11182.5 11195.5 11218.0 11227.5 11248.5 11254.5 11256.5 11257.0 11265.5 11269.5 11270.0 11295.0 11301.5 11315.5 11327.0 11332.5 11364.0 11475.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DLL 2435 $ REMARKS: 11227.5 11249.0 11255.0 11257.0 11258.0 11266.5 11271.0 11301.5 11327.0 11332.5 11333.0 11475.0 11475.0 11218.0 11269.5 11296.0 11316.0 11365.0 11475.0 RUN NO. PASS NO. MERGE TOP 1 4 10133.0 1 4 10196.0 1 4 10165.0 1 4 10796.0 MAIN PASS. LLD, SP, TEND, & TENS WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. $ CN : BP EXPLORATION WN : Z - 08A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA MERGE BASE 11380.0 11444.0 11412.0 11387.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code 1 GR BCS 68 2 DT BCS 68 3 TEND BCS 68 4 TENS BCS 68 5 LL3 DLL 68 6 LLD DLL 68 7 SP DLL 68 8 NPHI 2435 68 9 FUCT 2435 68 10 NUCT 2435 68 Samples Units 1 GAPI 1 US/F 1 LB 1 LB 1 OHMM 1 OHMM 1 MV 1 PU-S 1 CPS 1 CPS Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 * DATA RECORD (TYPE# 0) Total Data Records: 119 1018 BYTES * 40 Tape File Start Depth = 11475.000000 Tape File End Depth = 10107.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 30108 datums Tape Subfile: 2 316 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 4 0.2500 VENDOR TOOL CODE START DEPTH GR 10133.0 AC 10196.0 DLL 10165.0 2435 10796.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 11404.0 11468.0 11436.0 11406.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : 29-SEP-93 FSYS REV. J001 VER. 1.1 30 29-SEP-93 913 29-SEP-93 11475.0 11452.0 10200.0 11444.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XB/XA 1229EL/MA 3967XB/XA 1609EA/1603MA 8.500 10080.0 10072.0 KCL / BIOPOLYMER 10.20 61.0 MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. NEUTRON IS CHISM FILTERED. $ CN : BP EXPLORATION WN : Z - 08A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 9.8 5.0 198.0 0.145 0.044 0.100 0.000 0. 185 0.000 THERMAL SANDSTONE 0.00 8.500 0.0 60.0 198.0 57.0 0.0 53.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 68 * DATA RECORD (TYPE# 0) Total Data Records: 391 1014 BYTES * Tape File Start Depth = 11475.000000 Tape File End Depth = 10107.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 98515 datums Tape Subfile: 3 475 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH GR 10736.0 AC 10799.0 DLL 10768.0 2435 10742.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 11407.0 11470.0 11439.0 11414.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): 29-SEP-93 FSYS REV. J001 VER. 1.1 30 29-SEP-93 840 29-SEP-93 11475.0 11452.0 10200.0 11444.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XB/XA 1229EA/MA 3967XB/XA 1609EA/1603MA 8.500 10080.0 10072.0 KCL / BIOPOLYMER 10.20 61.0 9.8 5.0 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. NEUTRON IS CHISM FILTERED. $ CN : BP EXPLORATION WN : Z - 08A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 198.0 0.145 0.044 0.100 0.000 0. 185 0.000 THERMAL SANDSTONE 0.00 8.500 0.0 60.0 198.0 57.0 0.0 53.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 CHT AC 68 1 LB 4 4 TTEN AC 68 1 LB 4 5 SPD AC 68 1 F/MN 4 6 RS DLL 68 1 OHMM 4 7 RD DLL 68 1 OHMM 4 8 SP DLL 68 1 MV 4 9 ED DLL 68 1 MV 4 10 ES DLL 68 1 MV 4 11 ID DLL 68 1 A 4 12 IS DLL 68 1 A 4 13 CNC 2435 68 1 PU-S 4 14 CNCF 2435 68 1 PU-S 4 15 CN 2435 68 1 PU-L 4 16 LSN 2435 68 1 CPS 4 17 SSN 2435 68 1 CPS 4 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 220 Tape File Start Depth = 11478.000000 Tape File End Depth = 10710.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 85423 datums Tape Subfile: 4 302 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS 93/10/ 5 01 **** REEL TRAILER **** 93/10/ 5 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 5 OCT 93 11:23a Elapsed execution time = 30.21 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER . ****************************** . ............................ ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : BP EXPLORATION WELL NAFiE.' : Z-O8A FIELD NAlViE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292178701 REFERENCE NO : 98528 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: **** REEL HEADER **** SERVICE NAFiE : EDIT DATE : 98/10/20 ORIGIN : FLIC REEL NAM~ : 98528 CONTINUATION # : PREVIOUS REEL : COM~-~Ff : BP EXPLORATION, Z-OSA, PRUDHOE BAY, API# 50-029-21787-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/20 ORIGIN : FLIC TAPE NAME : 98528 CONTINUATION # : 1 PREVIOUS TAPE : COMM~J~T : BP EXPLORATION, Z-OSA, PRUDHOE BAY, API# 50-029-21787-01 TAPE PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: Z-O8A API NUFi~ER: 500292178701 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 20-0CT-98 JOB NUM~ER: 98528 LOGGING ENGINEER: C. CYCA OPERATOR WITNESS: J. RATHERT SURFACE LOCATION SECTION: 19 TOWNSHIP: lin RANGE: 12E FiFL: 973 FSL: FEL: FWL : 1252 ELEVATION (FT FROM MSL O) KELLY BUSHING: 89.90 DERRICK FLOOR: 88.40 GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 11475.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUFIBER: PASS NUFI~ER: DATE LOGGED: 29-SEP-93 LOGGING COMPANY: ATLAS BASELINE DEPTH 88888.0 11199.0 11187.0 11186.0 11177.5 11176.0 11171.5 11128.5 11128.0 11117.0 11116.0 11108.0 11106.5 11101.0 11090.5 11089.5 11086.5 11067.5 11066.5 11060.5 11059.5 11054.0 11053.0 11041.5 11040.5 11026.5 11025.0 11007.0 10995.0 10983.5 10980.5 10976.0 10973.0 10951.5 10950.0 10947.5 10944.0 10937.0 10926.5 10919.5 10917.0 10915.5 10901.0 10886.0 10872.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.0 88889.5 11200.5 11186.0 11186.0 11177.0 11177.0 11171.0 11128.0 11128.0 11117.0 11117.0 11107.5 11107.5 11102.0 11102.0 11089.5 11089.5 11087.0 11087.0 11067.5 11067.5 11060.0 11060.0 11053.5 11053.5 11041.5 11041.5 11026.0 11026.0 11007.5 11007.5 10997.0 10984.0 10984.0 10981.0 10981.0 10976.0 10976.0 10974.0 10974.0 10952.0 10952.0 10948.5 10944.5 10944.5 10938.0 10938.0 10927.0 10927.0 10920.0 10920.0 10917.0 10917.0 10902.0 10902.0 10887.0 10887.0 10873.0 10873.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 10863.0 10864.0 10861.5 10864.0 10836.0 10836.5 10836.5 10830.0 10830.5 10828.0 10830.5 10822.0 10823.5 10823.5 10814.5 10815.0 10815.0 10783.5 10783.0 10783.0 10714.0 10714.5 10714.5 100.0 100.5 100.5 $ CONTAIArEDHEREIN IS THE RST SIGMA-MODE DATA ACQUIRED ON BP EXPLRATIONWELL Z-O8A ON 19-SEP-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #1 GRCH TO THE BASELINE GAM~ARAY PROVIDED BYTHE CLIENT (GR.BCS); AND RST SIGMA-MODE PASS #1 SIGM TO GR.BCS. ALL OTHER RST SIGM-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1FUBIBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11192.0 10708.0 RST 11210.0 10708.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 CIRlVFIL 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 5 NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFNC RST CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1210846 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11211.500 NBAC. RST 2357.126 FBAC.RST 3243.698 SBNA.FIL SFNA.FIL 22.387 SBFA.FIL 37.865 SFFA.FIL 18.301 TRAT. FIL IRAT. FIL 0.478 CIRN. FIL 0.976 CIRF. FIL 2.157 BSAL.RST SIBF.RST 58.136 TPHI.RST 36.438 SFFC.RST 16.082 SFNC.RST SIGM. RST 16.134 DSIG.RST 3.505 FBEF.RST 59.643 CRRA.RST GRCH. RST -999.250 TENS.RST 1499.000 CCL.RST -0.005 DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST GRCH.RST 10708.500 NBAC. RST 2288.583 FBAC. RST 3072.245 SBNA.FIL 41.318 SBFA.FIL 48.597 SFFA.FIL 43.819 TRAT. FIL 0.481 CIRN. FIL 0.491 CIRF. FIL 0.709 BSAL.RST 53.812 TPHI.RST 57.040 SFFC.RST 41.671 SFNC.RST 41.916 DSIG.RST 0.132 FBEF. RST 60.560 CRRA.RST 49.323 TENS.RST 1386.000 CCL.RST -0.004 49.082 0.954 99.145 19.947 2.037 59.851 1.427 87.826 41.107 2.033 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: FILE HEADER FILE NIIM~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~ER : 2 DEPTH INCREMENT: 0.5000 FILE SUMSfARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11194.0 10708.0 RST 11212.0 10708.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88887.5 88889.5 11205.0 11206.5 11202.5 11202.5 11199.0 11200.5 11195.0 11196.0 11188.0 11187.5 11186.0 11186.0 11177.0 11177.0 11176.0 11177.0 11152.0 11152.5 11150.0 11150.5 11146.5 11147.0 11143.0 11144.0 11139.5 11139.0 11132.5 11133.5 11127.5 11127.5 11116.5 11117.5 11116.0 11117.0 11103.5 11104.5 11102.0 11102.0 11094.0 11094.5 11089.5 11090.0 11086.0 11086.5 11067.0 11067.5 11066.5 11067.5 11059.5 11060.0 11053.5 11053.5 11043.0 11043.5 11041.0 11041.5 11036.5 11037.5 11030.0 11029.5 11025.5 11026.0 11024.5 11025.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 11010.5 11011.5 11006.0 11007.0 10995.0 10997.0 10986.5 10987.0 10983.0 10984.0 10982.0 10983.0 10980.0 10981.0 10977.5 10977.5 10974.5 10975.0 10971.5 10973.0 10966.5 10968.0 10954.5 10956.5 10951.0 10952.0 10949.5 10951.5 10942.5 10943.5 10936.0 10938.0 10934.0 10935.0 10926.5 10927.5 10925.5 10926.5 10923.0 10923.5 10916.5 10917.0 10915.5 10917.0 10903.0 10904.5 10900.0 10902.0 10895.0 10896.5 10887.5 10889.0 10885.0 10887.0 10883.0 10884.0 10874.5 10876.0 10872.0 10873.5 10867.5 10868.5 10862.0 10864.0 10861.5 10864.0 10856.5 10857.0 10838.0 10839.0 10835.5 10837.0 10830.5 10832.5 10828.0 10830.5 10827.0 10828.5 10821.5 10823.5 10818.0 10817.5 10811.5 10815.0 10808.0 10810.0 10793.0 10794.0 10773.0 10774.5 10770.0 10770.5 10744.0 10746.0 10726.0 10728.0 10723.5 10725.0 10721.0 10722.0 100.0 101 . 0 101.5 $ THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #2. THE DEPTH SHIFTS SHOWN LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 SIGM TO PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAi~ SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 9 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIGM RST CU 1210846 O0 000 O0 0 2 I 1 4 68 0000000000 DSIG RST CU 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1210846 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11213.500 NBAC.RST 2364.462 FBAC.RST 3056.712 SBNA.FIL SFNA.FIL 21.471 SBFA.FIL 44.613 SFFA.FIL 18.032 TRAT. FIL IRAT. FIL 0.485 CIRN. FIL 0.985 CIRF. FIL 2.187 BSAL.RST SIBF.RST 60.533 TPHI.RST 35.162 SFFC.RST 15.769 SFNC.RST SIGM. RST 15.781 DSIG.RST 3.119 FBEF. RST 58.347 CRRA.RST GRCH. RST -999.250 TENS.RST 1462.000 CCL.RST 0.000 55.280 0.933 105.358 18.878 2.049 DEPT. 10709.000 NBAC. RST -999.250 FBAC. RST -999.250 SBNA.FIL -999.250 SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL -999.250 IRAT.FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST -999.250 SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST -999.250 SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST -999.250 GRCH.RST 42.549 TENS.RST -999.250 CCL.RST -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~ : EDIT .003 SERVICE : FLIC VERSION : O01COi DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 10 FILE HEADER FILE ~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~ER : 3 DEPTH INCREMENT: 0.5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11200.0 10706.0 RST 11218.0 10706.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88887.5 88889.0 11205.5 11206.5 11195.0 11196.0 11191.0 11190.5 11186.5 11186.5 11182.0 11182.0 11177.5 11177.0 11176.0 11177.0 11142.0 11140.0 11128.0 11128.0 11117.5 11117.0 11116.0 11117.0 11108.0 11107.5 11098.5 11098.5 11091.5 11091.5 11089.0 11089.0 11088.0 11087.0 11066.0 11067.5 11061.0 11060.0 11060.0 11060.0 11054.0 11053.5 11043.5 11043.5 11041.5 11041.5 11040.5 11041.5 11033.0 11034.0 11026.5 11026.0 11025.0 11025.5 11011.5 11012.0 11006.0 11007.0 10995.0 10997.0 10986.5 10987.0 10984.0 10984.5 10974.5 10975.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 11 10969.5 10971.0 10961.5 10963.0 10956.0 10956.0 10954.5 10956.5 10951.5 10952.0 10949.5 10951.5 10943.5 10943.5 10937.5 10938.0 10934.0 10935.0 10928.0 10928.5 10925.0 10925.5 10920.0 10921.0 10916.5 10917.0 10915.5 10917.0 10909.0 10910.5 10899.0 10900.5 10896.5 10897.0 10888.0 10889.0 10883.0 10884.5 10875.5 10875.5 10872.0 10873.5 10863.0 10864.0 10862.0 10864 . 0 10838.0 10839.0 10836.0 10837.0 10831.0 10832.5 10830.0 10830.5 10828.0 10830.5 10822.0 10823.5 10807.0 10809.5 10800.5 10801.5 10787.5 10789.0 10766.5 10769.0 10765.5 10766.0 10737.0 10737.5 100.0 100.5 102.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 SIGM TO PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE APIAPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 1210846 NBAC RST CPS 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RST PPK 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1210846 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 13 ** DATA ** DEPT. 11219.000 NBAC.RST SFNA.FIL 22.861 SBFA.FIL IRAT. FIL 0.509 CIRN. FIL SIBF. RST 59.925 TPHI.RST SIGM. RST 17.188 DSIG.RST GRCH.RST -999.250 TENS.RST DEPT. 10706.500 NBAC. RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST 50.401 TENS.RST 2333.333 FBAC. RST 47.833 SFFA.FIL 0.901 CIRF.FIL 27.560 SFFC. RST 2.566 FBEF.RST 1504.000 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF. RST -999.250 CCL.RST 3819.061 19.441 2.071 17.202 53.051 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SBNA. FIL TRAT. FIL BSAL. RST SFNC. RST CRRA . R S T SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST CRRA.RST 52.063 0.854 103.787 19.787 1.959 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS ND?4~ERS RST 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 14 REMARKS: THE ARITHFIETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT RSAV 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNRSAV 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF RSAV 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRSAV PPK 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RSAV PU-S 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 15 NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DSIG RSAV CU 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA RSAV 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1210846 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11211.500 NBAC.RST 2357.126 FBAC.RST 3243.698 SBNA.RSAV 49.536 SFNA.RSAV 21 . 958 SBFA.RSAV 40. 720 SFFA.RSAV 18. 441 TRAT. RSAV O. 956 IRAT.RSAV O. 484 CIRN. RSAV O. 992 CIRF. RSAV 2.159 BSAL.RSAV 103. 977 SIBF.RSAV 60. 000 TPHI.RSAV 37. 319 SFFC.RSAV 16.135 SFNC.RSAV 19. 476 SIGM. RSAV 16.190 DSIG.RSAV 3. 157 FBEF.RSAV 58. 517 CRRA.RSAV 2. 023 GRCH. RST -999. 250 DEPT. 10708.500 NBAC.RST 2288.583 FBAC.RST 3072.245 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC. RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST 49. 323 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 16 FILE NUI4BER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS--ER: 1 DEPTH INCREMiENT: 0.5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH RST $ LOG HEADER DATA DATE LOGGED: 11237.0 SOFTWARE VERSION: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 10678.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~4ARAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 19-SEP-98 8Cl-205 1924 19-SEP-98 11225.0 11238.0 10750.0 11238.0 3600.0 NO TOOL NUMBER CGRS-A 970 RST-A 8.500 11475.0 PRODUCED FLUIDS THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 17 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: TIED INTO ATLAS BHC ACOUSTILOG DATED 29-SEP-93. RST SIGMA PASSES LOGGED WITH THE WELL SHUT IN. TEST SEPERATOR LEAKING-DATA MAY BE BOGUS. BEST THAT PCC COULD DO. TAGGED TD AT 11238'. NO GROUND LEVEL ELEVATION AVAILABLE. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO?4~ SAMP ELEM CODE (HEX) DEPT FT 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1 F/HR 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) TENS PS1 LB 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 V 1210846 O0 000 O0 0 $ 1 1 4 68 0000000000 CRRA PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 S 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPSl V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 S 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS1 PSIG 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS1 UA 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS1 MA 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS1 UA 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS1 UA 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS1 UA 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PSI 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 XM2V PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PSl MA 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS1 PPK 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS1 CU 1210846 O0 000 O0 0 5 t 1 4 68 0000000000 FBAC PS1 CPS 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 19 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) IRAT FIL 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS1 CPS 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS1 CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS1 CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS1 CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS1 CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1210846 O0 000 O0 0 5 1 i 4 68 0000000000 SIBF PS1 CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS1 CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS1 CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PSl CU 1210846 O0 000 O0 0 5 1 i 4 68 0000000000 SIBF SIG CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS1 K~Z 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS1 KHZ 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS1 DEGC 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS1 DEGC 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS1 KV 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS1 AMP 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PSI AMP 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS1 V 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS1 1210846 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11237.000 CS.PS1 1905.770 TENS.PSi 930.000 NPHV. PS1 NPDE. PS1 1577.073 NSCE. PS1 2.400 CRRA.PS1 2.020 NSCR.PS1 AQTM. PS1 0.661 CHV. PS1 201.339 CP5V. PSl 5.050 CP2V. PS1 CM2V. PS1 -12.231 RCFR.PS1 0.000 RCLC.PS1 0.000 RCRC. PS1 RCAK. PS1 2.000 RI]DF. PSi 0.000 FPHV. PS1 1535.646 FPDE. PS1 FSCE. PS1 1.924 FSCR.PS1 -0.300 AQTF. PS1 0.661 SF6P. PS1 HVPV. PS1 160.889 BMCU. PS1 33.691 GDCU. PS1 60.340 EXCU. PS1 1604. 005 -0. 028 12. 173 O. 000 1508. 371 160. 052 3. 945 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 20 NBEF. PS1 29.469 FBEF.PS1 59.534 NPGF. PS1 BSTR.PS1 49.043 BSPR.PS1 1.137 MARC. PSi XPSV. PS1 5.069 XP2V. PS1 12.100 X~2V. PS1 RXLC. PS1 0.000 RXRC. PS1 0.000 RXAK. PS1 BSAL.PS1 -999.250 BSAL.SIG -999.250 CIRN. PS1 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS1 IRAT. PS1 -999.250 IRAT. FIL -999.250 NBAC. PS1 SFFA. PS1 -999.250 SBNA.PS1 -999.250 SBFA.PS1 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS1 -999.250 SFFC. PS1 -999.250 SIGM. PS1 SIGM. SIG -999.250 TRAT. PS1 -999.250 TRAT. SIG GR.PS1 67.293 RDIX. PS1 76768.000 CRNI.PS1 CTM. PS1 112.793 XTM. PS1 111.816 TAV. PS1 CACU. PS1 2.583 BUST. PSi 3.000 BUSP. PS1 TPHI.PS1 -999.250 TPHI.SIG -999.250 CCLC. PS1 DEPT. 10677.500 CS.PS1 NPDE. PS1 1578.179 NSCE. PS1 AQTM. PS1 0.661 CHV. PS1 CM2V. PS1 -12.231 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 1.899 FSCR.PS1 HVPV. PS1 160.645 BMCU. PS1 NBEF. PS1 29.782 FBEF. PSl BSTR.PS1 90.095 BSPR.PS1 XPSV. PS1 5.064 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL.PS1 74.423 BSAL.SIG CIRN. FIL 0.528 CIRF. FIL IRAT. PS1 0.493 IRAT. FIL SFFA.PS1 46.007 SBNA.PS1 SFFA.SIG 1.673 SBNA.SIG SFFA.FIL 44.626 SBNA.FIL SFNC. PS1 42.109 SFFC. PS1 SIGM. SIG 1.447 TRAT. PS1 GR.PS1 41.560 RDIX. PS1 CTM. PSi 113.281 XTM. PS1 CACU. PS1 2.588 BUST. PSi TPHI. PS1 57.686 TPHI.SIG 3645.856 TENS. PSi 2.383 CRRA.PS1 200.854 CP5V. PSi 0.000 RCLC. PS1 0.000 FPHV. PS1 -0.201 AQTF. PS1 34.026 GDCU. PS1 60.560 NPGF. PS1 1.120 MARC. PSi 12.075 XM2V. PS1 0.000 RXAK. PS1 7.419 CIRN. PS1 0.723 DSIG.PS1 0.489 NBAC. PS1 50.647 SBFA.PS1 4.809 SBFA.SIG 53.487 SBFA.FIL 43.256 SIGM. PS1 1.470 TRAT. SIG 84573.000 CRNI.PS1 112.096 TAV. PS1 3.000 BUSP.PS1 4.070 CCLC. PS1 1.001 0.000 -12.328 0.000 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 448 819 95 031 3.000 0.029 1386.000 2.033 5.069 0.000 1535.646 0.661 59.965 1.001 0.000 -12.362 0.000 0.549 -0.669 2128.852 50.000 4.966 50.219 42.830 0.053 441.309 94.908 3.000 -999.250 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS.PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS. PS1 RSCS.PS1 1. 002 201. 096 O. 000 22. 439 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 222.165 2.480 8878.OO0 8459.000 1606.447 0 296 12 129 0 000 1510 202 163 488 4 171 0 997 201 027 0.000 24.808 0.746 2967.787 39.668 1.443 41.455 48.766 2.771 1.465 217.030 2.446 8878.OO0 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 21 **** FILE HEADER **** FILE NAi~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 2 DEPTH INC~: 0.5000 FILE VENDOR TOOL CODE START DEPTH RST 11235.5 $ LOG HEADER DATA STOP DEPTH 10678.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT)'. BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~fA RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 19-SEP-98 8Cl-205 1924 19-SEP-98 11225.0 11238.0 10750.0 11238.0 1800.0 NO TOOL NUMBER CGRS-A 970 RST-A 8.500 11475.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 22 FLUID RATE AT WELLH3EAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: TIED INTO ATLAS BHC ACOUSTILOG DATED 29-SEP-93. RST SIGMA PASSES LOGGED WITH THE WELL SHUT IN. TEST SEPERATOR LEAKING-DATA MAY BE BOGUS. BEST THAT PCC COULD DO. TAGGED TD AT 11238'. NO GROUND LEVEL ELEVATION AVAILABLE. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #2. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 3 68 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 23 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1210846 O0 000 O0 0 6 1 i 4 68 0000000000 NPHVPS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS2 S 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 C~2V PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS2 S 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS2 PSIG 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS2 UA 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS2 MA 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS2 UA 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS2 UA 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS2 UA 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 XM2V PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 24 NAME SERV UNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RXRC PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RSfAKPS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS2 MA 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS2 PPK 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS2 CPS 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS2 CU 1210846 O0 000 O0 0 6 i 1 4 68 0000000000 SFNC PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS2 KHZ 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS2 KHZ 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS2 DEGC 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS2 DEGC 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS2 KV 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS2 AMP 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS2 AMP 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS2 V 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS2 1210846 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 25 ** DATA ** DEPT. 11235.500 CS.PS2 2214.022 TENS.PS2 NPDE. PS2 1579.324 NSCE.PS2 2.406 CRRA. PS2 AQTM. PS2 0.661 CHV. PS2 200.854 CPSV. PS2 CM2V. PS2 -12.211 RCFR.PS2 0.000 RCLC. PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 FSCE. PS2 1.890 FSCR.PS2 0.299 AQTF. PS2 HVPV. PS2 160.401 BMCU. PS2 32.519 GDCU. PS2 NBEF. PS2 28.182 FBEF. PS2 57.433 NPGF. PS2 BSTR.PS2 56.290 BSPR.PS2 1.077 MARC. PS2 XPSV. PS2 5.069 XP2V. PS2 12.085 X~I2V. PS2 RXLC. PS2 0.000 RXRC.PS2 0.000 RXAK. PS2 BSAL.PS2 -999.250 BSAL.SIG -999.250 CIRN. PS2 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG. PS2 IRAT. PS2 -999.250 IRAT.FIL -999.250 NBAC. PS2 SFFA.PS2 -999.250 SBNA.PS2 -999.250 SBFA.PS2 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC.PS2 -999.250 SFFC.PS2 -999.250 SIGM. PS2 SIGM. SIG -999.250 TRAT.PS2 -999.250 TRAT. SIG GR.PS2 74.023 RDIX. PS2 86958.000 CRNI.PS2 CTM. PS2 113.281 XTM. PS2 112.305 TAV. PS2 CACU. PS2 2.588 BUST. PS2 3.000 BUSP. PS2 TPHI.PS2 -999.250 TPHI.SIG -999.250 CCLC. PS2 1138.000 2.038 5.069 0.000 1535.646 0.661 59.356 1 003 0 000 -12 348 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 452.128 94.888 3.000 0.038 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS. PS2 RSCS. PS2 1606.447 0.061 12.173 0.000 1510.163 164. 401 4. 734 0.997 200.612 0.000 23.739 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 221.853 2.446 8878.000 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 26 FILE~ER FILE IVTJY4~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS--ER: 3 DEPTH INCREMeNT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH RST 11244.5 $ LOG HEADER DATA STOP DEPTH 10659.5 DATE LOGGED: SOFTWARE VERSION: TINGE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION" $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 19~SEP-98 8Cl -205 1924 19-SEP-98 11225.0 11238.0 10750.0 11238.0 3600.0 NO TOOL NUMBER CGRS-A 970 RST-A 8.500 11475.0 PRODUCED FLUIDS THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 27 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: TIED INTO ATLAS BHC ACOUSTILOG DATED 29-SEP-93. RST SIGMA PASSES LOGGED WITH THE WELL SHUT IN. TEST SEPERATOR LEAKING-DATA MAY BE BOGUS. BEST THAT PCC COULD DO. TAGGED TD AT 11238'. NO GROUND LEVEL ELEVATION AVAILABLE. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 28 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3F/HR 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS3 S 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS3 S 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS3 PSIG 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS3 UA 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS3 MA 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS3 UA 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS3 UA 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS3 UA 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 Xhq; PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 XM2V PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS3 MA 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS3 PPK 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 29 NAM~ SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DSIG PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS3 CPS 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS3 I~HZ 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS3 K}tZ 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS3 DEGC 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS3 DEGC 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS3 KV 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS3 AMP 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS3 AMP 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS3 V 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS3 1210846 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11244.500 CS. PS3 3257.918 TENS.PS3 NPDE.PS3 1579.057 NSCE. PS3 2.429 CRRA.PS3 AQTM. PS3 0.441 CHV. PS3 201.581 CPSV. PS3 CM2V. PS3 -12.270 RCFR.PS3 0.000 RCLC. PS3 996. 000 NPHV. PS3 1613. 771 1. 970 NSCR. PS3 -0. 310 5. 079 CP2V. PS3 12.173 O. 000 RCRC. PS3 O. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 30 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 FSCE. PS3 1.875 FSCR.PS3 0.107 AQTF. PS3 HVPV. PS3 161.133 BMCU. PS3 31.347 GDCU. PS3 NBEF. PS3 27.523 FBEF. PS3 54.215 NPGF. PS3 BSTR.PS3 63.011 BSPR.PS3 1.037 MARC. PS3 XPSV. PS3 5.069 XP2V. PS3 12.070 X~2V. PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 BSAL.PS3 -999.250 BSAL.SIG -999.250 CIRN. PS3 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS3 IRAT. PS3 -999.250 IRAT. FIL -999.250 NBAC.PS3 SFFA.PS3 -999.250 SBNA.PS3 -999.250 SBFA.PS3 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS3 -999.250 SFFC. PS3 -999.250 SIGM. PS3 SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG GR.PS3 47.105 RDIX. PS3 104906.000 CRNI.PS3 CTM. PS3 112.793 XTM. PS3 111.816 TAV. PS3 CACU. PS3 2.578 BUST. PS3 3.000 BUSP. PS3 TPHI.PS3 -999.250 TPHI.SIG -999.250 CCLC. PS3 DEPT. 10659.000 CS.PS3 3638.616 TENS. PS3 NPDE.PS3 1580.010 NSCE. PS3 2.390 CRRA.PS3 AQTM. PS3 O. 661 CHV. PS3 201 . 339 CPSV. PS3 CM2V. PS3 -12.231 RCFR.PS3 O. 000 RCLC. PS3 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 FSCE. PS3 1.834 FSCR.PS3 0.338 AQTF. PS3 HVPV. PS3 160.645 BMCU. PS3 31.567 GDCU. PS3 NBEF. PS3 27.651 FBEF. PS3 57.087 NPGF. PS3 BSTR.PS3 67.023 BSPR.PS3 1.165 MARC. PS3 XPSV. PS3 5.072 XP2V. PS3 12.076 X~2V. PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 BSAL. PS3 75.068 BSAL.SIG 18.938 CIRN. PS3 CIRN. FIL 0.502 CIRF. FIL 0.756 DSIG.PS3 IRAT. PS3 0.496 IRAT.FIL 0.496 NBAC. PS3 SFFA.PS3 42.896 SBNA.PS3 51.808 SBFA.PS3 SFFA.SIG 1.711 SBNA. SIG 3.895 SBFA.SIG SFFA.FIL 42.896 SBNA.FIL 51.808 SBFA.FIL SFNC. PS3 44.979 SFFC. PS3 41.996 SIGM. PS3 SIGM. SIG 3.367 TRAT. PS3 1.340 TRAT. SIG GR.PS3 51.643 RDIX. PS3 112757.000 CRNI.PS3 CTM. PS3 113.770 XTM. PS3 112.122 TAV. PS3 CACU. PS3 2.585 BUST. PS3 3.000 BUSP.PS3 TPHI.PS3 54.317 TPHI. SIG 5.937 CCLC. PS3 1535.646 0.441 59.028 1.006 0.000 -12.328 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 443.434 94.888 3.000 0.019 1395.000 2.065 5.040 0.000 1538.087 0.661 60.094 1.000 0.000 -12.350 0.000 0.502 2.984 2078.432 45.759 5.184 45.759 41.996 0.045 450.495 94.978 3.000 -999.250 FPDE. PS3 SF6P.PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 FICU. PS3 RSXS.PS3 RSCS.PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA. SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 FICU. PS3 RSXS.PS3 RSCS. PS3 1511.537 168.495 4.734 1.000 200.854 0.000 25.365 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 225.111 2.422 8878.OOO 8459.000 1604.005 0.437 12.143 0 000 1511 460 169 359 4 142 1 000 201 127 0 000 26 016 0 756 2941.176 43.441 1.382 43.441 49.007 7. O80 1.340 218.207 2.449 8878.000 8463.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 13:05 PAGE: 31 **** FILE TRAILER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/20 ORIGIN : FLIC TAPE NAFiE : 98528 CONTINUATION # : 1 PREVIOUS TAPE : COF~ViENT : BP EXPLORATION, Z-O8A, PRUDHOE BAY, API# 50-029-21787-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/20 ORIGIN : FLIC REEL NAME : 98528 CONTINUATION # : PREVIOUS REEL : COf~4ENT : BP EXPLORATION, Z-O8A, PRUDHOE BAY, API # 50-029-21787-01