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Home My WebLink About188-112MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-31 PRUDHOE BAY UNIT Z-31 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 Z-31 50-029-21871-00-00 188-112-0 G SPT 6648 1881120 1662 2928 2929 2926 2928 203 249 253 254 4YRTST P Bob Noble 6/8/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT Z-31 Inspection Date: Tubing OA Packer Depth 98 1853 1826 1822IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250617141525 BBL Pumped:3.7 BBL Returned:4.3 Thursday, July 24, 2025 Page 1 of 1           Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' MEMORANDUM To: Jim Regge �'//�/Z P.1. Supervisor � � 1 ,t FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT Z-31 Insp Num: mitSAM210612182214 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 8, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, I,I.0 Z-31 PRUDHOE BAY UNIT Z-31 Src: Inspector Reviewed By: P.I. SuprvZ Comm API Well Number 50-029-21871-00-00 Inspector Name: Austin McLeod Permit Number: 188-112-0 Inspection Date: 6/12/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- - --- - . -,. Well Z -3I Type Inj N -TVD --- 6648 Tubin g' 16 4242 _'� 4076 _ 4026 -- -- --- PTD 1881120 - Type Test SPT jest psi 4000 IA 7 160 _ 162 153 BBL Pumped: 2.71BBL Returned: 2.6 OA 23 24 21 21 Interval OTHER QIP/F P Notes: MITT post RWO to 4000psi. Sundry 321-161. Tubing plug at 9531' MD. Thursday, July 8, 2021 Page I of I MEMORANDUM TO:gg Jim Re I e z�r%�IG j Z�7Z P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 8, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC Z-31 PRUDHOE BAY UNIT Z-31 Sre: Inspector Reviewed By: P.I. Suprv. jTp-- Comm Well Name PRUDHOE BAY UNIT Z-31 API Well Number 50-029-21871-00-00 Inspector Name: Austin McLeod Permit Number: 188-112-0 Inspection Date: 6/12/2021 ' Insp Num: mitSAM210612183426 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-31 Type Inj N "I VD 6648 Tubing 1979 2592 - 2593 - 2577 ' - PTD 1881120 Type Test SPT Test psi 3000 IA 58 4264 I 4197 4170 - ---- - --- -- -- BBL Pumped- 9.6 , BBL Returned: 9.6 - - OA — 20 - — 8z - - 82 80 Interval] OTHER - P/F P Notes: MITIA post RWO to 3000psi . Sundry 321-161. Thursday, July 8, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 8, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC Z-31 PRUDHOE BAY UNIT Z-31 Src: Inspector Reviewed By: P.I. Supry 1763 - Comm Well Name PRUDHOE BAY UNIT Z-31 API Well Number 50-029-21871-00-00 Inspector Name: Adam Earl Permit Number: 188-112-0 Inspection Date: 6/25/2021 InSp Num: mitAGE210627183913 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-31 Type Inj G - TVD 6648 Tubing — 2614 1 2618 ---� -1 2616 - 2616 1881120 PTDSPT Type Test SPT' Test psi 1662 - IA 142 1 3250 3206- — 3191, — -- —1---- BBL Pumped:- 6.9 BBL Returned: 6.1 OA 14 1 291 285 276 Interval INtTAL P/F P 1 Notes: MIT IA post initial injection Thursday, July 8, 2021 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor �\(f ��l -711 FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 8, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC Z-31 PRUDHOE BAY UNIT Z-31 Src: Inspector Reviewed By: P.I.10 F Supry J Comm Well Name PRUDHOE BAY UNIT Z-31 API Well Number 50-029-21871-00-00 Inspector Name: Adam Earl Permit Number: 188-112-0 Inspection Date: 6/25/2021 .� Insp Num: mitAGE210627183913 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well z i Type Inj G 'TVD 66as Tubing 2614 2618 - 2616 . 2616 -- PTD lssuzo Type Test SPT Test psi 1662 Ip 142 3250 - 3206 - 3191 - BBL Pumped: 6 Q " BBL Returned: 6.1 OA 14 291 285 276 - Interval INITAL - P/F P Notes: MIT IA post initial injection — S(n,vl(ri, 3-Z1 — 101 dwc, 1�0_ I_Z-013 J' shwa -In 51 tAQ l L zt i Thursday, July 8, 2021 Page I of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:188-112 6.50-029-21871-00-00 PRUDHOE BAY, BOREALIS 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 13251 12136 8349 9504, 12103 None 6649, 8326 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 37 - 117 37 - 117 1490 470 Surface 2910 13-3/8" 36 - 2946 36 - 2693 5020 2260 Intermediate Production 12606 9-5/8" 35 - 12641 35 - 8707 6870 4760 Perforation Depth: Measured depth: 9620 - 13084 feet True vertical depth:6725 - 9039 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 33 - 6759, 8308 - 8525 9504 6649Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Packer Liner 870 7" 12381 - 13251 8521 - 9161 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 848603894 5067 600 2667 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: Brodie Wages David.Wages@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5006 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing 5 GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service 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 measured9161 Sundry Number or N/A if C.O. Exempt: 321-161 4-1/2" Baker S3 Packer 12103 8326 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A 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 5Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0047450 PBU Z-31 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 12136, 12200, 12999, 13094 33 - 9672, 12077 - 12388 By Samantha Carlisle at 7:46 am, Jul 02, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.01 15:32:26 -08'00' Stan Golis (880) DSR-7/6/21 , ADL0028262 MGR26JUL2021 SFD 7/2/2021RBDMS HEW 7/2/2021 SFD 7/2/2021 ACTIVITY DATE SUMMARY 3/15/2021 T/I/O = SSV/80/0. Temp = SI. PPPOT T (PASS), PPPOT IC (PASS) (pre RWO). PPPOT-T: Stung into test port (1500 psi), bled void to 0 psi. Single port, unable to pump through void. Pressured test void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely. Torqued all LDS and gland nuts to 450 ft/lbs. 1 LDS blank is installed. PPPOT-IC: Stung into test port (0+ psi), bled void to 0 psi. Single port, unable to pump through void. Pressured test void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. We did not function PO LDS. 4/12/2021 **WELL S/I ON ARRIVAL** 3500PSI MIT-IA(PASSED) PULLED P-PRONG & 3.81" PXN @ 12379'MD TAGGED TD w/ 2.44" CENT & 2" BLR @ 12946'SLM. ***WELL S/I ON DEPARTURE*** 4/19/2021 ...Well shut in on arrival... (AK EL - chem cut tbg) LRS LOAD TBG WITH 220BBL SKL, 40BBL DIESEL. SET LEGACY OIL TOOLS 4-1/2" CIBP AT 12,200'. LRS PERFORM PASSING MIT-T TO 3,500 PSI. PUNCH TBG FROM 12,053' - 12,056' WITH 3' x 1-9/16", ZERO PHASE, 6 SPF, CIR- 1603-3T381. ...Continued on 20-APR-2021... 4/19/2021 Assist E-Line w/ Load and Test (RWO CAPITAL) MIT-T to 3500 psi ***PASS*** Pumped 1 bbl 60/40 meth, 219 bbls 110* 2% SKL, 3 bbls 60/40 meth and 37 bbls DSL down Tbg for load and FP. Pumped 3.4 bbls DSL down Tbg to take Tbg to 3500 psi. Tbg lost 65 psi in 1st 15 mins and 15 psi in 2nd 15 mins for a total loss of 80 psi in 30 min test. PASS bled back ~ 3 bbls. 4/21/2021 ***CONTINUED FROM 4/19/2021*** STRING SHOT TBG from 12087' - 12096'. TO CLEAN WALLS PRIOR TO CHEM CUT. CHEM CUT TBG @ 12095' WITH 3-5/8" CHEM CUTTER. POOH. RIG DOWN POLLARD ELINE. ***JOB COMPLETE*** 4/24/2021 T/I/O= 1545/1325/6 Temp=S/I (Pre RWO Capital) CMIT-TxIA Inconclusive. Pumped 6 bbls diesel down IA into TBG. At 2996 psi on TBG and 2811 psi on IA Pressures fell off rapidly to T/IA 2097/1886 psi.Pumped 7 bbls diesel down IA to establish LLR of .52 bpm @ T/IA 1042/788 psi.Tags hung. DSO notified. SV WV SSV= closed MV IA OA= open. Final Whp's= 225/300/7 4/30/2021 ***WELL S/I ON ARRIVAL*** TAGGED CIBP W/ BARBELLED 3.70 CENT, 3.45" DE-CENT, 3.70 LIB @ 12,200' MD(impression of cibp) RAN 4 1/2" BRUSH TO X NIPPLE @ 12,073' MD FOR CORRECTION. ***WSR CONTINUED ON 5-1-21*** 5/1/2021 ***CONTINUE FROM 04/30/2021 WSR*** RIG DOWN DUE TO PUMP TRUCK AVAILABILITY ***JOB INCOMPLETE, PAD OP NOTIFIED OF STATUS*** Daily Report of Well Operations PBU Z-31 Daily Report of Well Operations PBU Z-31 5/4/2021 ***WELL S/I UPON ARRIVAL*** (rwo capital) DRIFTED TBG W/ 10' x 2-1/2" DUMMY GUNS(2.63" rings), TAGGED CIBP @ 12,200' MD. RAN READ CASED HOLE STP LDL LOG FROM CIBP TO SURFACE (good data) LRS PUMPED 177 BBLS OF DIESEL DOWN IA FOR LOG.(see log) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 5/4/2021 T/I/O= 350/vac/5 Temp= S/I Assist Slickline with LDL (RWO Capital) Pumped 177 bbls of 26* diesel down IA while Slickline logged. Slickline in control of well upon departure. IA OA= OTG. Final Whp's=500/488/10 5/9/2021 T/I/O = 260/70/0. Temp = SI. TBG & IA FL (E-Line request). No flowline or wellhouse. Rig scaffold installed around well. TBG FL @ 610' (9.3 bbls). IA FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:45 5/10/2021 Assist Eline (RWO CAPITAL) Pumped 19 bbls DSL down Tbg to attempt to pump ELine past tubing cut. Eline in control of well per LRS departure. IA,OA=OTG 5/10/2021 ***WELL S/I ON ARRIVAL*** ATTEMPTED TO SET NORTHERN SOLUTIONS 3.5" CIBP AT 12200'. TAGGED UP AT APPROXIMATELY 12094' WHICH IS THE CHEMICAL CUT DEPTH. SEVERAL ATTEMPTS WERE MADE AND SIT DOWN AND PICK UP WERE THE SAME EVERY TIME WITH NO OVERPULL ON TENSION. RIG LRS UP TO TRY AND PUMP THE TOOLS THROUGH THE CUT AT 1 BPM AND 1.6 BPM. STILL TAGGING AT 12094' WITH NO OVERPULL ON TENSION. ***JOB TO BE CONTINUED ON 5-11-2021, WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 5/11/2021 ***JOB CONTINUED FROM 5-10-2021*** ATTEMPT TO DUMP BAIL SAND ON EXISTING PLUG AT 12200'. SIT DOWN AND TAG AT APPROXIMATELY 12095' WHICH IS THE CHEM CUT DEPTH. OVER PULL 300# ON SECOND ATTEMPT. RUN LIB TO 12095' FOR IMPRESSION OF CUT TUBING. GOOD IMPRESSION ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 5/18/2021 T/I/O= 80/40/0. LRS unit 72 Ciculate Wellbore Pumped 750 bbls of 9 ppg brine into the TBG with IA returns to OTT. Freeze protect tbg & IA w/20 bbls DSl SV,WV,SSV=closed MV,IA,OA=open DSO notified on departure. ***job continued to 05-19-21*** 5/19/2021 ***Job continued from 05-18-21*** Finish U-Tube, FP surface lines $ bbls 60/40 rig down, Travel 5/19/2021 T/I/O=VAC/VAC/0. Pre Thunderbird Rig. T bared in CTS 4" H plug. Pulled 4" Cameron tree with THA. Installed BOP stack. Torqued to spec. Final WHP's CTS 4" H plug/VAC/0. 6/4/2021 Job Scope: Recomplete Start RD @ Z-11 and move to Z-31 Daily Report of Well Operations PBU Z-31 6/5/2021 Thunderbird Rig 1: R/U on Z-31. Fill 13-5/8" BOPE Stack with Fresh Water. Perform BOPE Shell test to 250 psi low and 3,000 psi high. Notify AOGCC for witness. Perform BOPE test to 250 psi low and 3,000 psi high. Test Annular to 250 psi low and 2,500 psi high 2-7/8" x 5.5" VBRs tested with 4-1/2" test joint. Fail/Pass on one CMV. AOGCC requested tripping drill, PVT alarm and flo-show test. Gas alarm test. Unable to hear audible alarms in cellar. AOGCC requested not starting the well until secondary monitor installed. Waiting for bridge to reopen to receive secondary monitor from Deahorse. 6/6/2021 Thunderbird Rig 1: Wait for bridge to reopen to receive secondary monitor from Deadhorse. Conoco transported monitor across bridges w/ loader. Install and test secondary monitor. Send pics to AOGCC as requested. Dry rod out test dart Tbg on a vac. Add 15 bbls 9.1 ppg NaCl to IA and fish rubber off top of H plug. Pull H plug. CIrc 9.1 brine IA @ 2 bpm to get returns from tbg. SD and U-tube until balanced. Move all brine from UR to pits. MU landing Jt to hanger. BOLDS. Pull Hanger free at 95k-lbs. Full P/U weight 117k-lbs.POH L/D 4-1/2" completion. 6/7/2021 ***RIG ASSIST*** CURRENTLY LOG OOH W/ HES CBL ***CONT ON 06/09/21*** 6/7/2021 Thunderbird Rig 1: Reverse Circulate 60 bbls of 9.1 ppg brine to displace diesel in Tubing while taking returns out to the Tiger Tank. Continue to POH w/ 4-1/2" completion. R/U Pollard Wireline. RIH w/ HES memory CBL. Tag at 12,067'. POH while logging at 40 fpm to surface. 6/7/2021 ***RIG ASSIST*** CURRENTLY LOG OOH W/ HES CBL ***CONT ON 06/09/21*** 6/8/2021 Cont. POH while logging with memory CBL at 40 fpm to surface. Filling hole every hour. Consistent 4 bbl/hr loss rate. Good data.TOC @ 2,942' slmd. RIH annd set Scoop Guide at 12,067' slmd. RIH and set 4-1/2" Plug Body at 12,113' SLM. POH. RIH and set Prong at 12,109' SLM. POH. 30 min charted test on 9-5/8. 3600 psi. Lost 15 psi and 0 psi. Final pressure 3585 psi. RD Slickline. RU GBR. RIH w/ 4-1/2" VAM TOP completion. Well wants to U-Tube out Tubing. Stop RIH. Line up to reverse circulate diesel/crude cap out of Tubing. 6/8/2021 ***RIG ASSIST / CONT FROM 06/08/21*** SET NORTHERN SOLUTION SCOOP GUIDE @ 12,077' SLM SET 4-1/2" PX PLUG W/ FILL EXT IN X NIPPLE @ 12,136' MD RIG PERFORMED PASSING PRESSURE TEST TO 3500psi ***JOB COMPLETE*** 6/8/2021 ***RIG ASSIST / CONT FROM 06/08/21*** SET NORTHERN SOLUTION SCOOP GUIDE @ 12,077' SLM SET 4-1/2" PX PLUG W/ FILL EXT IN X NIPPLE @ 12,136' MD RIG PERFORMED PASSING PRESSURE TEST TO 3500psi ***JOB COMPLETE*** Daily Report of Well Operations PBU Z-31 6/9/2021 Thunderbird Rig 1: Troubleshoot Pump. Found pump packed off with chunks of rubber. Clear blockage. Reverse circulate 40 bbls of 120 degree fresh water at 3 BPM and 30 psi. Diesel returns seen for the first 12 bbls of those returns. Monitor well. No U-Tubing. Continue to RIH w/ 4-1/2" L-80 Vam Top Completion. Final PU and S/O Wt 90/72K. Land Hanger and RILDS. CBU to get warm brine to upper wellbore. Set BPV.Sustained ~4 bbl losses / hr until tbg plug was set. Fluid in well is 9.0 brine and 127 bbls SW (brine unavailable during road outage). Closed blinds. KWF and test plug in tail. ***Tubing swap completed*** Operational Standdown started @ 1900 hrs. Will carry costs and AWGRS on Z-31 until RD begins then charges transfer to18-08 . 6/10/2021 ...Continue WSR form 6/09/2021... Rig Stand Down Scope: Evaluate daily hand over between crews. Review procedures and processes. Crew Change to Days (pusher Tim Parker/Driller Apti Satuev: Day crew review WC Procedure. Decision to continue StandDown on next well (18-08). Resume operations. Develop procedures for each operation. Written plan and role assignment for each task as work progresses. Reverse from Pit 2 until warm returns to surface. Set & test TW C. Vac out pits & BOP stack. Begin transporting equipment to DS 18. 6/11/2021 T/I/O=0/0/0. Torqued 4" Cameron THA by MV to API spec. PT to 5000psi. Passed. Pulled 4" H TWC. Job Complete. Final WHP's 0/0/0. 6/12/2021 ***WELL S/I ON ARRIVAL***(post rig) LRS CIRC KCL & FREEZE PROTECT DROP BALL & ROD, LRS SET PACKER LRS PERFORMED PASSING MIT-T & MIT-IA PULLED B&R & RHC FROM 9,573' SLM (9,531' MD). ***note: depth irregularity*** DRIFTED TO 9,900' SLM w/ 30' x 2-7/8" DUMMY GUNS.(3.16" swell) ***JOB COMPLETE, WELL LEFT S/I*** 6/12/2021 Assist Slickline (RWO CAPITAL) AOGCC MIT-T to 4026 psi ***PASS*** AOGCC MIT-IA to 4170 psi ***PASS*** Pumped 375 bbls Inhibited 1% KCL and 185 bbls DSL down IA and up Tbg taking returns to open top tanks. U-Tube DSL into Tbg for 1 hour. SL dropped ball and rod. Pressured Tbg to 3500 psi w/ 2.5 bbls DSL to set packer. Pumped 2.7 bbls DSL down Tbg to take pressure to 4242 psi for AOGCC MIT-T. Tbg lost 166 psi in 1st 15 mins and 50 psi in 2nd 15 mins for a total loss of 216 psi in 30 min test. Bled Tbg to 20 psi and got back ~2.6 bbls. Pumped 9.6 bbls DSL down IA to take pressure to 4264 psi for AOGCC MIT-IA. IA lost 77 psi in 1st 15 mins and 27 psi in 2nd 15 mins for a total loss of 104 psi in 30 min test. Bled IA to 0 psi and got back ~ 9.5 bbls. Test Witnessed by WSS Conrad and State Rep Austin **Tags hung on MV and IA 6/15/2021 ***WELL S/I ON ARRIVAL*** LOG CORRELATION PASS FROM 9900' - 9000' CORRELATE TO GAMMA RAY. ***DEPTH IRREGULARITY ON TUBING DEPTHS, DISCUSSED WITH OE*** PERFORATE 9668.5' - 9701' W/32.5' x 2.875" HSC MAXFORCE (17.5 gram), 6 SPF, 60 DEG PHASING ***JOB TO BE CONTINUED ON 6-16-2021, WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** Daily Report of Well Operations PBU Z-31 6/16/2021 ***JOB CONTINUED FROM 6-15-2021, WELL S/I ON ARRIVAL*** PERFORM JEWELRY LOG W/GAMMA RAY AND CCL FROM 9900' - SURFACE PERFORATE 9636' - 9668.5' W/ 32.5' x 2.875" HSC MAXFORCE (17.5 gram), 6 SPF, 60 DEG PHASING PERFORATE 9620' - 9636' W/ 16' x 2.875" HSC MAXFORCE (17.5 gram), 6 SPF, 60 DEG PHASING ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 6/25/2021 T/I/O=2614/142/15 AOGCC MIT-IA to 3250 psi **PASS** Pumped 6.9 bbls DSL down IA to take pressure to 3250 psi Max applied for AOGCC MIT-IA. IA lost 44 psi in 1st 15 min. and 15 psi in 2nd 15 min for a total loss of 59 psi in 30 min test. Bled back ~ 6 bbls DSL . AOGCC test witnessed by state rep Adam Earl and WSS Ryan Holt. Tag hung on IA CV, pad op notified of well status up departure, FWHP's = 2619/120/13 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 06/16/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API PTD # Log Date Log Type Log Vendor 13-20 500292070500 182009 05/08/2021 RCBL HALLIBURTON E-34A 500292243701 214096 06/06/2021 RCBL READ CH G-18B 500292062002 214071 05/23/2021 RCBL HALLIBURTON S-201A 500292298701 219092 05/29/2021 IPROF-WFL and ANALYSIS HALLIBURTON S-210 500292363000 219057 04/27/2021 IPROF-WFL and ANALYSIS HALLIBURTON V-117 500292315600 203090 05/02/2021 PPROF and ANALYSIS HALLIBURTON V-117 500292315600 203090 05/02/2021 RCBL HALLIBURTON Z-11A 500292205301 205031 05/18/2021 RCBL HALLIBURTON Z-31 500292187100 188112 06/07/2021 RCBL HALLIBURTON Please include current contact information if different from above. Received By: 06/16/2021 37' (6HW By Abby Bell at 10:04 am, Jun 16, 2021 STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry Z-ZI ROPE Test Report for: PRUDHOE 13AY UNIT Z-31 — Comm Contractor/Rig No.: Hilcorp Thunderbird 1 PTD#: 1881120 - DATE: 6/52021 Inspector Guy Cook " Operator: Hilcorp North Slope, LLC Operator Rep: Arvell Bass Rig Rep: Tim Parker Type Operation: WRKOV Sundry No: Type Test: INIT 1 321-161 ' Rams: 250/3000 Test Pressures: Annular: Valves: 2502500 - 250/3000 TEST DATA Insp Source Inspector MASP. lospection No: bopGDC210604185959 2340 - Related Insp No: MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P - Trip Tank P P - System Pressure NT Housekeeping: P Pit Level Indicators P " P - Pressure After Closure NT " PTD On Location P Flow Indicator P - P ' 200 PSI Attained NT - Standing Order Posted P Meth Gas Detector P P Full Pressure Attained NT Well Sign P H2S Gas Detector P P Blind Switch Covers: NT Dirt. Rig P MS Misc NA NA Nitgn. Bottles (avg): _. NT Hazard Sec. P ACC Mise 0 NA Mise NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 0 - NA- Stripper 0 NA No. Valves 11 - F, Lower Kelly 0 " NA' Annular Preventer 1 - 13 5/8 5000 ' NT : Manual Chokes 2 NT Ball Type 1 NT- #1 Rams 1 - 2 7/8"x5" VB - P Hydraulic Chokes 0 NA Inside BOP 1 P " 42 Rams 1 Blinds P CH Mise 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves I - 31/8" 5000 - NT Quantity P/F HCR Valves 1 - 3 1/8" 5000 NT ' Inside Reel Valves 0 NA Kill Line Valves 3 - 31/8" 5000 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 1 ✓ Test Results Test Time 5.5 Remarks: 4.5 test joint used for testing. Tour Pusher was the only person who knew how to run ihePYT system. Instructed him to show the drillers and anyone who could possibly stand in for them how to operatethe m. Had to have them call CANRIG and calibrate their pits as the pits were showing incorrect bbl counts. Had a second audible alarm installed closer to the "cellar" so the gas alarms could be has due to the trailered heaters used to keep the rig from freezing. On test #3 cho a manifold valve #4 failed. Before we could test any further I left location to try and make it back over the Kuparuk bridge before the Kuparuk Rrver over -flowed and the bridge was closed. I did not witness any more tests. ;/ v Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:188-112 6.API Number:50-029-21871-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 047450 Property Designation (Lease Number):10. 341H 8. PBU Z-31 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 5 Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13251 Effective Depth MD: L-80 11. 4/20/2021 Commission Representative: 15. Suspended Contact Name: Brodie Wages Contact Email: David.Wages@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9161 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate 5Perforate New Pool No Packer No SSSV Installed Date: Liner 870 7" 12381 - 13251 8521 - 9161 7240 5410 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 36 - 2946 36 - 2693 14. Estimated Date for Commencing Operations: BOP Sketch 37 - 117 Structural Proposal Summary 13. Well Class after proposed work: No Packer 12857 - 13084 8867 - 9039 4-1/2" 12.6#33 - 12388 Production 12376 8517 None 37 - 117 470 13-3/8" Contact Phone:907.564.5006 Date: 80 149020"Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2910 5020 Intermediate 12606 9-5/8" 35 - 12641 35 - 8707 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2340 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 12376, 12999, 13094 By Samantha Carlisle at 1:29 pm, Apr 01, 2021 321-161 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.01 13:05:21 -08'00' Stan Golis (880) 12,103' MD, 9,457' MD (new pool) DLBDLB BOPE test to 3000 psi. Annular to 2500 psi. AOGCC to witness MIT-T to 4000 psi to assure isolation of PB oil pool. AOGCC to witness MIT-IA to 3000 psi to assure IC and packer integrity. CBL to AOGCC prior to perforating Borealis oil pool. * Waiver to 20 AAC 25.112. Well plugging requirements (c)(1)(E) - temporary bridge plug to isolate PB oil pool from Borealis oil pool. 2340 10-404 / Borealis Oil Pool 0 X DSR-4/1/21MGR01APR21DLB 04/01/2021 Yeson Required? Comm Yeson Required? 4/12/21 dts 4/12/2021 JLC 4/12/2021 RBDMS HEW 4/12/2021 Re-complete Ivishak Injector to Kuparuk Injector Well: Z-31 PTD: 188-112 API: 50-029-21871-00 Well Name:Z-31 API Number:50-029-21871-00 Current Status:Operable Injector Rig:Workover Estimated Start Date:April 2021 Estimated Duration:4days Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Abbie Barker Permit to Drill Number:188-112 First Call Engineer:David “Brodie” Wages 713.380.9836 (M) Second Call Engineer:Brian Glasheen 907.545.1144 (M) Current Bottom Hole Pressure:3877 psi @ 8800’ TVD BHP Survey 4/2000 Maximum Expected BHP:3000 psi @ 6700’ TVD Max. Anticipated Surface Pressure:2340 psi Gas Column Gradient (0.1 psi/ft) Equivalent Brine Weight:6.8 ppg Expected Stabilized Injection Rates Post RWO 1500 BWPD 2 MMSCFD Brief Well Summary Drilled in 1988, Z-31 has had several workovers to maintain and boost Ivishak injection but at this point, there is no current remaining value in continuing Ivishak injection. The proposed workover will convert the well from an Ivishak injector to a Kuparuk injector. Z-31 crosses the Kuparuk interval in a perfect location to support Z-112 to the south, V-117 to the west and V-115 to the north. The only issue with Z-31 is going to be the siderite concentration. Happily, siderite is somewhat soluble in acid so we should be able to stimulate the well to achieve target injection rates. Notes Regarding Wellbore Condition 9-5/8” Production Casing cemented with 2765 cf Class G cement Shoe @ 12641’ MD in a 12.25” hole, TOC Est @ 3813’ MD Top of Kuparuk @ -6625’ TVDss (9607’ MD) Pre-2000: several acid jobs to improve injectivity. Add perfs and bridge plugs to control where injection was going. 2005: RWO for gas tight threads After RWO several PPROFs, a camera run to verify tubing position, ivishak value has dropped. 3/15/2021: PPPOT-T 5000 psi pass 3/15/2021: PPPOT-IC 3500 psi pass 10/22/2019: MIT-T 2669 psi pass 4/25/2019: MIT-IA 2739 psi pass Scope of Work The primary objective of the RWO is to temporarily abandon the Ivishak and recomplete this well as a Kuparuk injector. Pre Rig Prep Work: 1) SL: D&T, pull X plug in XN nipple 2) MIRU E-Line, Set bridge plug @ ~12,200’ in tubing tail, cut tubing above packer Proposed RWO Procedure: 1) MIRU workover rig Rig. 2) ND tree. Test BOPE to 250psi Low/ 3000psi High, annular to 250psi Low/ 2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3) Pull 4-1/2” tubing 4) Run CBL from tubing stub to surface DLB -00 CBL results to AOGCC for review prior to perforating Borealis. Re-complete Ivishak Injector to Kuparuk Injector Well: Z-31 PTD: 188-112 API: 50-029-21871-00 5) Install scoop guide 6) Run 4-1/2” L-80 completion, space out, freeze protect, set packer 7) Perform MIT-T to 4000psi and MIT-IA to 3000psi. AOGCC to witness passing MIT-IA to 3000 psi. 24 hour notice. 8) Set a TWC and RDMO. Post rig Work 1) Spot Slickline unit and RU. 2) Pressure test lubricator to 300psi low and 3000psi high. 3) Pull B&R and RHC 4) Eline perforate Kuparuk Interval a. ~9607’-9701’ b. Depths to be confirmed by recent CBL 5) Handover to ops 6) Schedule SVS testing with AOGCC as per regulations Area of Review – PBU Z-31 (PTD # 188-112) Prior to the conversion of well Z-31 from Ivishak Injector to Kuparuk Injector, an Area of Review (AOR) has been conducted. This AOR found six wells and former wells within ¼ mile of Z-31’s entry point into the Kuparuk Formation. See attached table Area of Review Z-31 for annulus integrity and zonal isolation of all wells within the AOR. AOR Table State to witness MIT-T to assure isolation from Ivishak oil pool. Re-complete Ivishak Injector to Kuparuk Injector Well: Z-31 PTD: 188-112 API: 50-029-21871-00 AOR Map Re-complete Ivishak Injector to Kuparuk Injector Well: Z-31 PTD: 188-112 API: 50-029-21871-00 Current WBD: Re-complete Ivishak Injector to Kuparuk Injector Well: Z-31 PTD: 188-112 API: 50-029-21871-00 Proposed WBD: Re-complete Ivishak Injector to Kuparuk Injector Well: Z-31 PTD: 188-112 API: 50-029-21871-00 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: April 1, 2021Subject: Changes to Approved Sundry Procedure for Well Z-31Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 STATE OF ALASKA RECEIVED A CA OIL AND GAS CONSERVATION COMMON SEP 18 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair WellU Plug Perforations u, Perforate LJ OtherLAOGCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdowr9 Stimulate - Other ❑ Re -enter Suspended WeI❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ r 188 -112 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ell 6. API Number; Anchorage, AK 99519 -6612 50- 029 - 21871 -00 -00 7. Property Designation (Lease Number): . 8. Well Name and Number. ADL0047450 PBU Z -31 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): ( 9 P P ) (: - ) To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 13251 feet Plugs measured See Attachment feet true vertical 9161.36 feet Junk measured None feet Effective Depth measured 12990 feet Packer measured 12103 feet true vertical 8968.22 feet true vertical 8326.17 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 37 - 117 37 - 117 1490 470 Surface 2910 13 -3/8" 68# L -80 36 - 2946 36 - 2693.07 5020 2260 Intermediate None None None None None None Production 12606 9 -5/8" 47# L -80 35 - 12641 35 - 8706.76 6870 4760 Liner 870 7" 26# L -80 12381 -13251 8520.73 - 9161.36 7240 5410 Perforation depth Measured depth 12857 - 12897 feet 12914 - 12942 feet 12952 - 12967 feet 12967 - 12990 feet 12990 - 12992 feet 13002 - 13022 feet 13032 - 13046 feet 13058 - 13082 feet 13058 - 13082 feet True Vertical depth 8866.92 - 8897.56 feet 8910.55 - 8931.86 feet 8939.45 - 8950.82 feet 8950.82 - 8968.22 feet 8968.22 - 8969.72 feet 8977.26 - 8992.3 feet 8999.8 - 9010.27 feet 9019.22 - 9037.08 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 33 - 12388 33 - 8525.68 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm P< 12103 8326.17 Packer None None None SSSV 12. Stimulation or cement squeeze summary: 0 Intervals treated (measured): H BAR L Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2119 0 652 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service Q -' Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: - Oil ❑ Gas LJ WDSPLU GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUC❑ 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 Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature JJ ( Phone 564 -4424 Date 9/14/2012 VL r ABrCIS SEP 2 0 20iZ 2 --.... t o 13 ) )1 ' , Form 10-404 Revised 11/2011 Submit Original Only • • Z -31 188 -112 -0 Plugs Attachement SW Name Date MD Description Z -31 8/20/2012 12999 7" Posiset Plug Z -31 11/2/2010 13094 7" Posiset Plug Daily Report of Well Operations ADL0047450 ACTIVITYDATE I SUMMARY INITIAL T /I /O = 0/0/0 SSV CLOSED " ., ,, RAN 2.13" POSI -SET PLUG TO ISOLATE LOWER PERFS. SET PLUG AT 13000.5' TOP OF ELEMENT DEPTH CORRECTED TO SLB CBL LOG DATED 15- NOV -88. SET LENGTH OF PLUG IS 3.3'. TQP-OF PLUG lS 12999'. TAGGED PLUG AFTER SETTING TO CONFIRM SET. SECURED WELL FOR NIGHT, INFORMED DSO WE WILL RETURN IN MORNING TO 4. COMPLETE CEMENT DUMP BAILER RUNS. 8/19/2012 ***CONTINUE JOB NEXT DAY * ** • ** *CONTINUED FROM PREVIOUS DAY * ** MADE ONE UNSUCCESSFUL CEMENT DUMP BAILER RUN TO TOP OF PLUG AT 12999'. (BAILER ACTUATED NORMALLY, BUT SOLIDS IN CEMENT FELL OUT OF SOLUTION AND CLOGGED THE DRAIN AT THE BOTTOM OF BAILER. RECOVERED ALL CEMENT FROM BAILER AT SURFACE) MADE TWO SUCCESSFUL CEMENT BAILER RUNS AND PLACED 7 FEET OF CEMENT ON TOP OF PLUG. LAID DOWN EQUIPMENT FOR NIGHT AND WILL RETURN IN MORNING TO MAKE ONE MORE CEMENT BAILER RUN SECURE WELL, INFORM DSO WE WILL RETURN IN MORNING TO COMPLETE FINAL RUN. 8/20/2012 ** *JOB CONTINUED ON 08/21/12 WSR * ** ** *JOB CONTINUED FROM PREVIOUS DAY * ** RAN FINAL CEMENT DUMP BAILER TO PLUG AT 13000'. DID NOT TAG PREVIOUS CEMENT P,44 TO AVOID CLOGGING DUMP PORTS ON BAILER. CALCULATIONS LEAVE TOP OF CEMENT . 12990'. INSTRUCTIONS LEFT FOR DSO TO NOT FLOW WELL FOR 5 DAYS TO ALLOW • CEMENT TO CURE AS PER PACKAGE. LEFT WELL SHUT -IN AND SECURE, HANDOVER WITH DSO PRIOR TO DEPARTURE. N.7 FINAL T /I /O = 0 /0 /0. 8/21/2012 ' ** *JOB COMPLETE * ** ** *WELL SHUT IN ON ARRIVAL * ** LOCATE TBG TAIL © 12,370' SLM / 12,388' MD S TAG CEMENT © 12,965' SLM / 12,983' MD 8/30/2012 ** *WELL LEFT SHUT IN PAD OP NOTIFIED ON DEPARTURE * ** TREE= 3" MCEVOY Y NOTES: H2S READINGS AVERAGE 125 ppm AD =' • MCEVOY • ON MI. WELL REQUIRES A SSSV WHEN ON AC1UA ACTUATOR = OTIS = M/ KB. E..EV = 91.46' BF. ELEV = 55.46' KOP = 1500' ' MO Angle = 57° @ 5500 ' ' ' I 2105' — I4 - 1/2" HES X NP, D = 3.813" Datum MD = 12889' DatumTVD= 8800'SS 113 -3/8" CSG, 68#, L-80,10 = 12.415" H 2946' — _41 I I 12073' H4 -1/2" HES X NP, D = 3.813" I Minimum ID = 3.76" @ 12376' 4 -112 •' HES XN NIPPLE ESI ® 12103' — 9-5/8" X 4-1/2" BKR S-3 PKR D = 3.875' I I 12136' (- 14 -1/2" HES X NP, ID = 3.813" I 12376' - (4 -1/2" HES XN NIP, D = 3.75" I (TOP OF 7" LNR H 12381' ( , 14- 112" TBG, 12.6#, L -80, .0152 bpf, D = 3.958" -1-1-113' \ , 12388' 4 - 1/2" VULEG, ID= 3.958" F 9-5/8° CSG, 47 #, L -80, D = 8.681" -[ 12641' —4 I HELM) TT NOT LOGGED [ 12764' 1 MARK JOINT PERFORATION SUMMARY ' REF LOG: Bt-CS ON 11/11/88 - CST ON 11/15/88 ANGLE AT TOP PERT 40° @ 12857' Note: Refer to Production DB for historical perf data 1 SIZE SFF INTSNAL Opn/Sqz DATE • T 6 12857 - 12897 0 09/06/01 2" 6 12914 - 12942 0 09/06/01 ' ^ 12990' TOP OF CalENT (08/21/12) 2" 6 12952 - 12967 0 09/06/01 12999 ' — I 2.13" FOSISEr PLUG (08/19/12) 2 -1/8" 4 12952 - 12992 S 08/06/01 �= - -....-- 2-7/8" 6 12967 - 12992 0 10/21/05 4 5" 4 13002 - 13022 S 08/06/011 2 -7/8" 6 13002 - 13022 C 10/21/05 5" 4 13032 - 13046 S 08/06/01 2 -718" 6 13032 - 13046 C 10/21/05 2 -1/8" 4 13058 - 13084 S 08/06/01 ' 13082' ( — ( TOP OF CEMENT (11 /02/10) 2 -7/8" 6 13058 - 13084 C 10/21/05 13094' -- 12 -1/8" FOSISET PLUG (11 /02/10) I 4 :7 :7 :7 13102' —1 FILL (10/2/05) I PBTD 1 13210' 4•4y 17 " LNR, 6#, L -80, .0383 bpf, D = 6.276'—[ 13261' , k • � • � • � • � • � • � • � • 1 R DATE REV BY CONSENT'S DATE REV BY COMuEJTS PRUDHOE BAY UNIT 11/16/88 ORIGINAL COMPLETION 10/21/05 RWUPJC ADFERFS WELL Z -31 12/20/04 SRB/TLH RWO 11/08405 TLH/TLH DEPTH CORRECTION PERMIT No: '1881120 10/03/05 MIA RWO 11/16/10 SRD/PJC SET POSISET/ CMT (11/02/10) API No: 50- 029 - 21871 -00 08/13/01 SRBITP SQZ PB FS 02/16/11 MB/JMD ADDED SSSV SAFE!Y NOTE SEC 19, T11N, R12E, 714' FNL & 3644' FE_ 09/06/01 CWS/TLH ADD FERFS 08/24/12 JCMJM) SET FOSISET/ CMT (08/19- 21/12) 10/15/05 SGS/PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • • s ifor [E IF junslA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Todd Sidoti Well Intervention Engineer ` f , BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 a � 317./3 1 \ - Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, -31 Sundry Number: 311 -330 Dear Mr. Sidoti: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i7 Daniel T. Seamount, Jr. Chair Y DATED this 4 - day of November, 2011. Encl. c TE OF ALASKA p�,l E CE1 \�ED` ALASKA OIL AN CONSERVATION COMMISSION A -��,��. APPLICATION FOR SUNDRY APPROVALS W V • C 12 7 20 /` � " 20 AAC 25.280 01611414[4114€1 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ balifilligah Suspend ❑ Plug Perforations 0 - Perforate ❑ Pull Tubing ❑ A ItinfilpExtension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 188 -1120 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 _ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21871- 00 -00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU Z -31 Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 047450 - PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13251' 9161.36. 13210 9131.3 13082 (TOC) NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 37 117 37 117 1490 470 Surface 2910' 13 -3/8" 68# L -80 36 2946 36 2693 4930 2270 Production 12606' 9 -5/8" 47# L -80 35 12641 35 8707 6870 4760 Liner 870' 7" 26# L -80 12381 13251 8521 9161 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 33 12388 Packers and SSSV Tvpe: 4 -1/2" Baker S -3 Perm Packer Packers and SSSV MD and ND (ft): 12103 8326 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch p Exploratory ❑ Development p Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/9/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Todd Sidoti Printed Name Todd Sidoti Title Well Intervention Engineer Signature done Date �, A 632 -4113 10/26/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5 ` ' 5.0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /6 — 7 b - 1 APPROVED BY 1 Approved by: A COMMISSIONER THE COMMISSION t Date: / ( / � Z. ' / 'B II nnS / IV 1/2010 zoi ORIGINAL /e4 Form 10 -403 Revised 1/2010 Submit in Duplicate Z -31 188 -112 P ERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z -31 11/16/88 PER 13,002. 13,022. 8,977.26 8,992.3 Z -31 11/16/88 PER 13,032. 13,046. 8,999.8 9,010.27 Z -31 11/18/91 APF 12,914. 12,942. 8,910.55 8,931.86 Z -31 11/18/91 APF 12,952. 12,992. 8,939.45 8,969.72 Z -31 11/18/91 APF 13,058. 13,084. 9,019.22 9,038.56 Z -31 8/6/01 SQZ 12,914. 13,084. 8,910.55 9,038.56 Z -31 9/5/01 APF 12,857. 12,897. 8,866.92 8,897.56 Z -31 9/5/01 RPF 12,952. 12,967. 8,939.45 8,950.82 Z -31 9/6/01 RPF 12,914. 12,942. 8,910.55 8,931.86 Z -31 12/3/04 BPS 12,335. 12,857. 8,488.18 8,866.92 Z -31 12/6/04 SPS 12,300. 12,315. 8,463.53 8,474.09 Z -31 3/22/05 SPR 12,300. 12,315. 8,463.53 8,474.09 Z -31 3/24/05 BPP 12,335. 12,857. 8,488.18 8,866.92 Z -31 10/2/05 FIL 13,102. 13,210. 9,051.9 9,131.3 Z -31 10/18/05 APF 13,058. 13,084. 9,019.22 9,038.56 • Z -31 10/19/05 APF 13,002. 13,022. 8,977.26 8,992.3 Z -31 10/19/05 APF 13,032. 13,046. 8,999.8 9,010.27 Z -31 10/20/05 APF 12,967. 12,992. 8,950.82 8,969.72 Z -31 11/1/10 BPS 13,094. 13,095. 9,045.98 9,046.72 Z -31 11/2/10 SQZ 13,082. 13,094. 9,037.08 9,045.98 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 • • • by otoo 04 To: J. Bixby / Rob Liddelow Date: October 10, 2011 AK D &C Wireline Ops TLs From: Carolyn Kirchner, PE PECT: APBZPDWL31 Todd Sidoti, Well Interventions IOR: 100 Subject: Z -31 Posiset Plug for Injection Profile Est. Cost: $500k Modification This procedure includes the following steps: 1 S Drift for posiset plug with —2.25" OD bailer and TEL. Plug setting toolstring is 36', eline bailer is 36', both 2.125" OD MCX pulled 4/13/10 2 E Install Posiset plug, dump bail cement 3 S Bailer and TEL drift to TOC (WOC 5 days). 4 EP IPROF following stable injection. Current Status: WAG injector- currently on water Last Test: 09/09/11 500 WHIP, 2.1 MBWPD Max Deviation: 57° at 5,500' MD Top Perf Deviation: 40° @ 12,857' MD Minimum ID: 3.725" ID 4.5" XN nipple at 12,376' MD Last Downhole Op: 07/10/11 IPROF Last Drift: 07/10/11 Eline SCMT — tagged TD at 13078' ELMD Last Tag: 11/07/10 Tag TOC at 13082' ELM Latest H Value: N/A 20 PPM average for Z pad Reference Log: 11/15/88 SWS CBT Objective: The objective is to set a posiset plug in the well to redirect infection into the upper zones. This is the second attempt and this plug will be set up shallower in the well. Well History: Well Z -31 i is a WAG injector. The well was pre - produced until 1996 and was then converted to injection in 2002. The original CBL shows a high -side channel that was squeezed in 2001 with LARC cement. Injectivity tests show this was successful. Only the upper two sets of perfs were reperfed at this time. In 2002 an acid stim was performed that returned injectivity to pre- squeeze rates. Either the acid stim worked or it damaged the squeeze. However a 2006 IPROF on MI shows injection distribution to be pretty good. A 2010 (PROF on water shows 100% of the water exiting the wellbore below the bottom perforations. Following this data, it was decided to set a posiset plug at the base of the bottom perfs in an effort to redirect injection into the perforations. A follow -up IPROF showed that this did not really work and it is likely that the channel or thermal fracture is back in play. One possible explanation for this is that cement • • shrinks over time, especially when in a dry environment like that of MI injection or the cold water that has been injected has thermally fractured the formation making a preferential fluid flow path. At this point, an analysis of reserves in the 41 and 42P was done and it appears that these lower zones are more depleted than the upper zones based on allocated production and perforation history. Calculations show that only 20% of the OOIP in the area has not been recovered to date and with minimal offtake in the offset wells in these zones, it is unlikely that it would be recovered anyways. An SCMT was run and shows decent cement quality with only a few definite sections of isolation. It has been decided that a second posiset plug will be run shallower to shut off the 42P and 41 P in the hopes of redirecting injection into the upper zones for MI sweep. The offset wells in the pattern are Z -27, Z -29, Z- ✓ 30 Z -22b. The Z -31 Hall Plot shows a slight decrease in injectivity following the setting of the posiset plug, but the injectivity returened to the original slope after a short time. This may be due to a thermal fracture being re- initiated from a shallower depth and contacting the existing fracture down to the 31 P. So you might be asking why are we doing this again if we've done it once and didn't get the results we wanted the first time around? Well, there will be more stand off from the original fracture, and although this may not work forever, it may buy some time so that a rig sidetrack can be planned and scheduled. Wtr Inj Hall Plot WI Time WI WHP WI Trend 0 Picks — °° Inj Index Posiset set 12/30/12 1.6 1 2/31 /11 - _ – 1.4 12/30/10 - ■ I _ __ • 12/30/09 �• - 1.2 12/30/08 I 11.7111 1 2/31 /07 • i ,I9 d' — 1 E E 12/30/06 • l d1 0.8 = 12/30/05 I WAR-' 12/30/04 #nn 1 _.,m1 1 11111 0.6 12/31/03 - I 11111111111 0.4 0 12/30/02 1.1117.1 �I l 1 I Il1�11 !U r�.r .ir�lr " – 0.2 12/30/01 . 12/30/00 - 0 0 1 2 3 4 5 6 7 8 CumWI(mmb) 0.20psi /b Schlumberger posiset plug will be set with the element at 13000.5' MD with a cement cap to shut off water injection This should allow for improved pattern support and FOR responses. Contacts for questions or comments regarding this procedure are listed below: Carolyn Kirchner Todd Sidoti 980 -2926 632 -4113 564 -4109 cc: w /a: Well File 2 • • Risk and Discussion • The target for setting the posiset plug is for the top of the plug to be placed at 12999' MDBKB (blank pipe interval 12992 -13002 MD — no tubing tally available and CCLs are not clear). The top of the sealing element is 19" below this after the plug is set. This should place the top of the sealing element at —13000.5' BKB. • 10' of cement will be dump bailed above the plug with a positive displacement type eline bailer. f Calculations indicate that 6' of competent cement plug should give the minimum required 2500 psi differential pressure rating. It is planned to dump bail 9' of cement. 16 gallons of cement will be required for a 10' plug in the 7" 26# liner; this should result in 3500 -4000 psi differential pressure rating plus the 1500 psi rating of the posiset for a total rating of 5000 — 5500 psi. Bailer capacity is 0.134 gal /ft, or 4 gallons per 30' bailer. Four (4) 30' bailer trip i e needed for 16 • gallons total cement. Required plug height: H(ft) = differential PRESSURE x CSG I.D. /48 x CEMENT SHEAR BOND (IbAn2) where cement shear bond is 57 lb /sq inch. • The positive displacement type eline bailer is 36' x 2 1/8" OD. A piston inside the bailer is electronically released at the desired depth to displace the cement out of the bailer. • Cement is supplied in 5 gallon bucket type kits by SWS to be mixed onsite, and then pumped into the bailer. Cement type is Schlumberger Dump Bailer Cement Kit T6016548. Cement thickening time is 4 -6 hours. Ultimate cement compressive strength of this cement is 3000 psi. PREPARATION AND SPECIAL TOOLS • Matt Dresel (alt. Brian Sunderland) with SWS can be contacted regarding plug and bailer details, 659 -2487. 2 -3 weeks lead time will be required to moblize personnel and equipment to the North Slope for the job. • Review attached posiset plug setting and bailing best practices. • Set up some form of spill containment area for mixing cement and for loading the bailer with cement. On a prior job some years ago absorbent was laid on the ground for spill prevention; this turned out to be marginally adequate containment on a somewhat breezy winter day. • SI well at least 24 hours prior to Posiset run to ensure well is stabilized. Pre Job 1. RU slickline. Drift and tag TD with a —2.25" x —36' toolstring with TEL to simulate posiset plug and eline bailer toolstrings. Eline Posiset Plug Installation and Dump Bailing Cement 1. MIRU eline. 2. Carefully measure and record the distance from the CCL to the bottom of the MPSU. 3. PU 2.125" MPBT Posiset plug (plug H405501) MPSU setting unit and CCL. After pressure testing lubricator, bleed pressure off slowly, at no faster than 100 psi/ minute as the plug may release if pressure is bled off too rapidly. RIH at a maximum of 150 FPM. Tie in with 11/15/88 SWS CBT. Log up from —13,040' MD below planned plug set depth. Set plug so that top of plug is at 12999' MDBKB (This should place the top of the sealing element at —13000.5' MDBKB). The plug will take about an hour to set. If feasible without getting stuck, tag plug after setting and releasing from it. The length of the 9/16" OD extension rod looking up from the top of the plug after 3 • • setting is 19" and the length of the sealing element after setting is 4.4 ". The max OD of the toolstring is 2 -1/8" after release. POOH. 4. PU 30' x 2.125" OD SWS positive displacement bailer and CCL. Mix 4 gallons of cement and pump into bailer. Place samples of each batch of cement mixed in hot water bath at —200 F. Monitor these samples to confirm cement thickening time. 5. RIH with bailer at a maximum speed of 150 fpm. Correlate depth and tag posiset plug. Dump cement from bailer with bottom of bailer right on top of plug so that cement displaces lighter wellbore fluids upward. Pull uphole slowly for a few feet until the bailer is out of the dumped cement in the wellbore. POOH. 6. Repeat steps 3 and 4 three (3) more times for a total of 16 gallons of cement bailed, 10' cement above plug height. The positive displacement technique requires positioning the bailer directly in contact with the previous cement slurry. The cement slurry exits the bailer and displaces lighter well fluid away from the prior cement top. 7. After cement is in place, tag wing valve to leave well shut in a minimum of 5 days. 8. After at least 5 days. RU slickline with a —2.5" bailer and TEL. Tag cement cap to confirm the plug and cement are in place. Note description of any recovery in the bailer on the job report. POH and RD. Cement cap expected at —12990' MD. 9. POI at a rate of 4300 bwpd. Eline Post -Job IPROF 1. Ensure well has been on stable injection for at least 2 weeks following successful cement top tag. 2. RU /RIH with SL. Pull MCX SSSV at 2105' if necessary. 3. RU SL or EL. RIH with fullbore spinner /continuous spinner /temp /pressure /GR /CCL/XY caliper. Tie -In Log: SWS BHCS /GR 11/11/88. 4. Log 40, 80, 120 FPM up and down dynamic passes from 12,800' - 12,985' MD (new cement top). 5. The primary objective of the log is to confirm that injection is being distributed across all open perforation intervals and not entering the formation below the posiset plug. Obtain the following stop counts: Stop Count Depth (MD) 12800' 12900' 12947' —12985' in bottom perfs 6. Record on log remarks - injection rate, choke, WH injection T &P, manifold T &P, IBHP, and IBHT. 7. Reinstall MCX with SL if desired, not required for water injection. The well is planned to remain on water injection for the next year or so. 8. POOH and RD. Return well to injection. Log Presentation: Depth Shift final log to 11/11/88 BHCS 4 • The following information should be presented on the field print. 1. Job Comments - operating steps in sequence, logging passes made, injection splits, basic field interpretation. 2. Present all up pass data in overlays. 3. Present up /down overlay from speed with best data. 4. Stop counts. 5. Present warm back passes. The chart below is after 24 hours CEMENT PLUG LENGTH vs PRESSURE FOR CEMENT KIT T6016548 REV AC (2004) CASING SIZE 25 — 9 5/8" C E 20 7 5/8" E ' • , 0 17 t T F 5 1/2" T 5 „ • 10- 41/2" T 5 — H 0 0 1000 2000 3000 4000 5000 6000 7000 PRESSURE DIFFERENTIAL - PSI 5 - ... 1 , • • flei °IN" LE COPfit EOSCIENCE DEPI. CEMENT BOND LOG (CBT) Schlumberger g COMPANY STANDARD ALASKA PRODUCTION CO F. v § WELL Z - 31 I i 4 . 11 4 FIELD PRUDHOE BAY zi .b 1■4 , — 4 E 0 * . 4 . - • BOROUGH NORTH SLOPE STATE ALASKA .. 3 714' FML & 3944' FEL Other Services 2 i , 7 , .. CET/CST u GCT z g ii , o AT SURFACE: z ' PFRf 3 API ISERial NO BEOT. TWP. t RANGE • 1'.' 50 029 21871 00 A 0 19 11N 17F "5 Permanent Dettim MSL Bev. 00 F Elev.: K.B.91.5 F t . Log Measured From Of 916 F above Perm Datum D.F.91 5 F 9 Drilling Measured From GC G1 53 9 F C. Dete 15-NOV-88 Run No ONE ; peps Diller 132100 F IS Depth Logger (60111 1 '3218 0 F o Rim Log Interver 13189 0 F Top I4.4ii Int/Argil 12350 0 F Tyr Fluid In HOW L 81111r111y kid • (fertility 040 LB/C 8 _ pluki Leval ;I 0 Q Wm. Ric Terry. Dewill11011 43 DEC tr. Loge's an Swum 1115 11 4 - EileiP. I 1-00ation 8361 IFT uDI RAY 1 1 , 9 Recorded By 0. WARNCR 2 Witnessed By KA l IS11-4/M1 LE R i- BOIREHOLE RECORD 1311 Site 12 1/4 B 1/2' Depth CASING I TUBING RECORD Size 9 5/8' 7' . - - Weight 47 0000 IBA 25 0000 LBO Casino- TOP 0.0 F 123810F Casing- BOTTOM 12541 0 F 13741 0 F 6 - .- �}.. »., � ...._ 1 rn' ..... - i t 4_.�_ . . T .y Y a. , .. _ _ i ' V� f LJ J Q , it .. - . � , 4 . — b r- �» .1 I' ti N c CD ' z t . l l 1 r i © v / , o e t 1 1 -- riNtAi \ i N r , . ._... _.__ . _ �, J i x . .. ° ear�I'IR J� E ,t�� ,, t ? � 1r& . *� + ±++ .y''E-3,,,,,00441r".. err.. ----I III.alli""MeAilla"rng.illMllsllmIIMIOPglIllallmwmmoOgallusilIllPM"0.1ItlillQel""dell""i"i"IllaAmmsdsi1IuillIll%ismleei"IIP"LoiOXMIIkw 0. • • TREE = 3" MCE/OY WELLHEAD= MCEVOY ACT .___ UATO __ _.. . _ - ___O O.__. Z _ 3 1 SAFETY NOTES: WELL REQUIRES A SSSV WHEN _.___._...d. -..._ _. _._..._ ._.� ON Al /. KB. ErEV = 91.46' BF. t..61;"- _.__... -. 55746' KOP = 1500' Max Angle = 57 @ 5500' 1 1 I 2105' H4-101-ES X NP, tD = 3.813" Datum MD = 12889' LatumTVD= 8800'SS 113 -38' CSG. Mk L -80. ID = 12.415" H 2946' I I I 12073' H4- 1/2" HES XNP, D =3.813' I Minimum ID = 3.75" c` 12376' 4 -1/2" HES XN NIPPLE X ® I 12103' H9- 5/8 " X4- 1/2'IKRS- 3PKR 3.875' 1 1 I 12136' H4- 1/2" FESX NIP, ID= 3.813' I I I I 12376' I—I4 -1/2" IES XN NAP, ID= 3.75" I ITOP OF r LNR H 12381' I 14 -1/2" TBG, 12.6#, L- 80..0152 bpf, D= 3958" H 12388• I f 12388' I I4 -1/2' WLEC, D= 3 958" I 1 9-58' CSG. 47 #. L -80, ID = 8.681' F 12641' I A I H ELM) TT NOT LOGGED I I 12754' HMAFt<E'tJONT I PERFORATION SUMMARY RE= LOG: BHCS ON 11/11/88 - CBTON 11/15/88 I ANGLE AT TOP PEiF: 4042 12857' Note: Refer to Production DB for historical perf data SIZE SPF INTE21/AL Opn/Sgz DATE I 2' 6 12857 - 12897 0 09/06101 2' 6 12914 - 12942 0 09/06 2' 6 12952 - 12967 0 09/06/01 I 2-1/8" 4 12952 - 12992 S 08/06/01 2 -7/8" 6 12967 - 12992 0 10/21/05 : . ,, 5' 4 13002 - 13022 S 08/0610 �� ■ `�� 2 -7/8" 6 13002 - 13022 0 10/21/05 /II 5' 4 13032 - 13046 S 08 /06/01 2 -718' 6 13032 - 13046 0 10/21/05 2 -1/8' 4 13058 - 13084 S 08/06 2 -7/8' 6 13058 - 13084 0 10/21/05 13082' HTOPOFCt3r€NfT (11 /02/10) I +...... 13094' I— I2- 1/8 °POSISET PLUG (11 /02/10) I 13102' I-1 FLL (10/2105)] PBTD 13210' '4 Y4'4 1 I r LN R 2611. L -80, -0383 bpf. ID= 6276" H 13251' 0.44110,144 DATE REV BY COft 4TS DATE REV BY COWMEVTS PRUDHOE BAY UNIT 11/1688 ORIGINAL COMPLETION 10/15/05 SGS/PJC DRLG DRAFT CORRECTIONS WE-L: Z -31 12/20/04 SRBITLH RWO 10/21/05 RWLtPJC AD ERFS PERMIT No:9881120 10/03/05 MIA RWO 11/08/05 TLHrTLH DEPTH CORRECTION API No: 50-029-21871-00 08/13A1 SRB/TP S0Z PEWS 11/16/10 SRUPJC SET POSISET/CMT(11 /02/10) SEC 19. T11N, R12E, 714' FNL& 3644' Fa 09/06/01 CWSTLH ADD PERFS 02/16/11 M3/i tD ADDED SSSV SAFETY NOTE 03/06105 VIITLH PERE CORRECTIONS (12/08/04) BP Exploration (Alaska) 8 11 % -tt1 13-JUL -2011 7--12. t 5 Schhwaherger No. 5764 Company: State of Alaska Alaska Data & Consulting Services Alaska Oil & Gas Cons Comm Anc Game Street, Suite 400 Attn: Christine Shartzer A ep, AK 99503-2838 333 West 7th Ave, Suite 100 ATTN: N: Stephanie Sttephanie Pacillo Anchorage, AK 99501 Well Job # Log Description Date BL Color CD W -223 BCRJ -00086 ISOLATION SCANNER 18- May -11 1 1 W -221 BJGT -00040 USIT 16-Jun-11 1 1 C -11A BLPO -00111 PPROF W GHOST 14-Jun-11 1 1 12-Jun-11 1 1 H -19B BLPO -00109 MEMORY PPROF W GHOST 19-Jun-11 1 1 V-227 BCRJ -00090 SCMT 18-Jun-11 1 1 X -22A AWJI -00143 USIT 18-Jun-11 1 1 ill MPI -09 BCRC -00067 MEMORY LEAK DETECTION LOG 18 18J Jun -11 1 1 14 -36 BCRJ -00091 (PROF 20-Jun-11 1 1 J -27A BAUJ -00090 PPROF W GHOST 24-Jun-11 1 1 D -06A BL65 -00041 PPROF W DEFT GHOST 27-Jun-11 1 1 16 -05A BSM4-00008 LEAK DETECTION LOG 2-Jul-11 1 1 Z_27 BSM4 -00009 GAS LIFT SURVEY 4-Jul-11 1 1 09 -22 BJGT -00048 IPROF W -08A BBSK -00076 SCMT 25-Jun-11 1 1 Y -04 AWJI-00147 PPROF W DEFT GHOST 22-Jun-11 1 1 1 1 1 16Ju R -28 BJGT -00047 SBHPS 3-Jul-11 u1 -1-11 1 1 10-Jul-11 -Ju U -116 BG4H -00058 PPROF n -1 1 1 1 Z-31 BCRJ -00093 SCMT 1 1 1 F-48 BG4H -00062 PPROF W DEFT GHOST 4-Jul-11 1 1 06 -11 BSM4 -00012 PPROF W DEFT GHOST 5-Jul-11 1 1 C -32C BLPO -00117 PPROF W GHOST 01 -31 BP5G -00001 RST EDIT 17- Mar -11 1 1 1 N -17 BJOH -00007 PDC-GR EDIT 1 C -12B BAUJ -00064 MCNL EDIT 9- Mar -11 1 C.22A BL65 -00022 MCNL EDIT 7- Mar -11 1 1 6- Apr -11 1 1 14 -33A BL65 -00023 MCNL EDIT 7-Nov-10 1 1 S -129 10AKA0109 OH PDC -GR EDIT 1 S- 129PB1 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 5- 129P82 10AKA0109 OH PDC -GR EDIT 7- Nov -10 1 1 ilk PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: Alaska Data & Consulting Services BP Pe Exploration at a C e) ter LR2 -1 2525 Gambell Street, Suite 400 Pe Data Center Anchorage, AK 99503 -2838 9000 0 E E. B Benssoo n Blvd. QED MAR 2 7 203 03/24/11 Schhimhener NO. 5709 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambe9 Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 0' Log Description Date BL Color CD 01 -20 BBSK -00054 I :41 DAiR.L /9Ye]y18MOI ltan�LMINIIINIM ' ' F±M f ] 1 09 -46 BMSA -00006 PRODUCTION PROFILE f • a I, 03/01/11 1 e 1 14 -05A BBKA -00090 PRODUCTION PROFILE '' " 1 —(M j 03/02/11 1 1 12 -30 BBSK -00055 LOL / 03/06/11 1 ,- Spa 1 , D -22C BCRD -00086 SCMT _ 03/04/11 • 1 _ 1 09-02 BBSK -00052 I d' 3e1e11.41,1,{�:b1tl1A� bell , r. 1 1 !>/� ' 1 fir=. 1 09-41 BBSK-00053 PRODUCTION PROFILE "AL��C� 15 -05A BCRD -00084 MjiL'1Z$.'SGA. TAW: I H -15 BCRD -00083 USIT 7 - [) 02/11/11 6 , ' 1 • F -35 BG4H -00037 PRODUCTION PROFILE ) '* Y `^ Y ♦ i 02122111 1 • 1 Z-31 BJOH -00009 INJECTION PROFILE !J r - j s 02/12/11 1 F4 • 1 K- 06 -16 BCRD -00 PRODUCTION PROFILE � « — b 03/07111 1 V •l, .r 1 X -17 BJOH -00008 RST — 0 . 1 H -20 BBSK -00051 RST LL1l . - 02113111 1 - • 1 06 -20A BNWP -00003 RST :105 -- 02/17/11 1 Oy 9 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 III 51 MAR 2 5 2017 t G r�� i 1 % c :,, Fit "' ' STATE OF ALASKA ALASK*L AND GAS CONSERVATION COMMISS1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other ❑� POSISET PLUG Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ * 188 -1120 3. Address: P.O. Box 196612 Stratigraphic❑ Service Q 6. API Number: Anchorage, AK 99519 -6612 A 50- 029 - 21871 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 047450 PBU Z -31 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 1325 feet Plugs (measured) 13082 (TOC) feet true vertical 9161.36 feet Junk (measured) None feet Effective Depth measured 13210 feet Packer (measured) 12103 feet true vertical 9131.3 feet (true vertical) 8326 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" SURFACE - 110 SURFACE - 110 Surface 2946' 13 -3/8" 68# L -80 SURFACE - 2946 SURFACE - 2693 4930 2270 Intermediate 12641' 9 -5/8" 47# L -80 SURFACE - 12641 SURFACE - 8707 6870 4760 Production Liner 870' 7" 26# L -80 12381 - 13251 8521 - 9161 7240 5410 Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 12388 SURFACE - 8526 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" X 4 -1/2" BKR S -3 PKR 12103 8326 ?EI E 12. Stimulation or cement squeeze summary: NO 1 ! 2010 Intervals treated (measured): 46A, o � Ut � �N�� NOV 1 2010 Treatment descriptions including volumes used and final pressure: A "Ph'orage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 3270 573 Subsequent to operation: 2496 935 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[] Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: �& Oil F1 Gas LJ WDSPL GSTOR ❑ WINJ ❑ WAGE] GINJ p SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -341 Contact Joe Lastufka Printed N e e Lastu a Title Data Manager Signs re Phone 564 -4091 Date 11/12/2010 MS N O V I 5 2010 75 Form 10 -404 Revised 10/2010 l J Submit Original Only Z -31 18 -112 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth ToF Tvd Depth Bas Z -31 11/16/88 PER 13,002. 13,022. 8,977.26 8,992.3 Z -31 11/16/88 PER 13,032. 13,046. 8,999.8 9,010.27 Z -31 11/18/91 APF 12,914. 12,942. 8,910.55 8,931.86 Z -31 11/18/91 APF 12,952. 12,992. 8,939.45 8,969.72 Z -31 11/18/91 APF 13,058. 13,084. 9,019.22 9,038.56 Z -31 8/6/01 SQZ 12,914. 13,084. 8,910.55 9,038.56 Z -31 9/5/01 APF 12,857. 12,897. 8,866.92 8,897.56 Z -31 9/5/01 RPF 12,952. 12,967. 8,939.45 8,950.82 Z -31 9/6/01 RPF 12,914. 12,942. 8,910.55 8,931.86 Z -31 12/3/04 BPS 12,335. 12,857. 8,488.18 8,866.92 Z -31 12/6/04 SPS 12,300. 12,315. 8,463.53 8,474.09 . Z -31 3/22/05 SPR 12,300. 12,315. 8,463.53 8,474.09 Z -31 3/24/05 BPP 12,335. 12,857. 8,488.18 8,866.92 Z -31 10/18/05 APF 13,058. 13,084. 9,019.22 9,038.56 Z -31 10/19/05 APF 13,002. 13,022. 8,977.26 8,992.3 Z -31 10/19/05 APF 13,032. 13,046. 8,999.8 9,010.27 Z -31 10/20/05 APF 12,967. 12,992. 8,950.82 8,969.72 Z -31 11/1/10 BPS 13,094. 13,095. 9,045.98 9,046.72 Z -31 11/2/10 SPS 13,082. 13,094. 9,037.08 9,045.98 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I 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 -31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY fflaffavNINIMEME i ........... W= gwql i 11/1/20101 *****WELL FLOWING UPON ARRIVAL * * ** (ELINE: POSSISET PLUG) ' INITIAL T /I /0= 375/0/250. LRS FREEZE PROTECTS WELL AND FLOW LINE AND SHUTS-IN WELL BEFORE RIG UP. SET POSSISET PLUG W/ TOP PLUG A T 13094': SSV =C, M =O, W =C, CSG =OTG FINAL T /1 /0= 100/0/225 ' ** *JOB INCOMPLETE -- RETURN 2- NOV- 2010 * ** i r i j I 11/1/2010T/I/0= 1520/40/300 E -Line assist (Freeze Protect) Pumped 8 bbis Neat Methanol down flow line and pressured up to 1500 psi. Pumped 7 bbis Neat Methanol, 35 bbis I `Diesel, followed by 1 bbis Neat Methanol down TBG as per E -Line PE procedure. FWHP's T /1 /0= 720/40/300 SV,WV =C SSV,MV =O I /O =OTG E -Line in control of well. 3 1 I s 11/2/2010 *****WELL SHUT IN UPON RETURN * * ** (ELINE: POSSISET PLUG) INITIAL T /1 /0= 100/0/250. CONTINUE DUMPING CEMENT FOR A TOTAL OF —19 GAL 12' ON TOP OF POSSISET PLUG, CEMENT TOP 13082'. SSV =C, M =O, W =C, CSG =OTG FINAL T /1 /0= 100/0/225 [ ** *JOB COMPLETE, WELL SHUT -IN UPON DEPARTURE ** 1 FLUIDS PUMPED BBLS 16 METH 39 DIESEL 55 TOTAL TREE = 3" MCEVOY WELLHEAD= MCEVOY smr ACTUATOR= OTIS Z-31 KB. ELEV = 91.46' BF. ELEV = 55.46' KOP = 1500' Max Angle = 57 @ 5500' Datum MD = 12889' 2105' 4 -1/2" HES X NIP, ID = 3.813" Datum TV D = 8800' SS 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 2946' 12073' 4 -1/2" HES X NIP, ID = 3.813" Minimum ID = 3.75" @ 12376' 4 -1/2" HES XN NIPPLE 12103' 9- 5 /8 "X4- 1 /2 "BKRS- 3PKR,ID= 3.875" 12136' 4 -1/2" HES X NIP, ID = 3.813" 12376' 4 -1/2" HES XN NIP, ID = 3.75" TOP OF 7" LNR 12381' 4 -1/2" TBG, 12.6 #, L-80,.0152 bpf, ID = 3.958" 12388' 12388' 4 -1/2" WLEG, ID = 3.958" 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 12641' EI MD TT NOT LOGGED 12754' MARKER JOINT PERFORATION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLE AT TOP PERF: 40 @ 12857' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 12857 - 12897 O 09/06/01 2" 6 12914 - 12942 O 09/06/01 2" 6 12952 - 12967 O 09/06/01 2 -1/8" 4 12952 - 12992 S 08/06/01 2 -7/8" 6 12967- 12992 O 10/21 /05 5" 4 13002 - 13022 S 08/06/01 2 -7/8" 6 13002 - 13022 O 10/21/05 5" 4 13032 - 13046 S 08/06/01 2 -7/8" 6 13032 - 13046 O 10/21/05 �'� 4- C� 2 -1/8" 4 13058- 13084 S 08/06/01 v µ 2 -7/8" 6 13058 - 13084 O 10/21/05 �38Z 0 1 FILL (10/2/05) PBTD 13210' 7" LNR, 26 #, L-80,.0383 bpf, ID = 6.276" 13251' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/16/88 ORIGINAL COMPLETION 10/15/05 SGS /PJC DRLG DRAFT CORRECTIONS WELL: Z -31 12/20/04 SRB/TLH RWO 10/21/05 RWL/PJC ADPERFS PERMIT No: x 1881120 10/03105 WA RWO 11/08/05 TLH/TLH DEPTH CORRECTION API No: 50- 029 - 21871 -00 08/13/01 SRB/TP SQZ PERFS V SEC 19, T11 N, R12E, 714' FNL & 3644' FEL 09/06/01 CWS/TLHj ADD PERFS 03/06/05 Vl/TLH IPERF CORRECTIONS (12108/04) BP Exploration (Alaska) Schium6erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2830 ATTN: Beth Well Job it NO.5514 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD Z-30A P-i6 03-Ot AWJI-00077 AYS4-00122 89RH-00024 MEMORY GLS - PRODUCTION PROFILE _ C X-FLOW CHECK/IBP/CEMENT D MP - 03/06/10 03/08/10 04/21/10 1 1 1 1 1 1 P2-22 U-03 03-37 8BU0-00007 BBKA-00021 BBKA-00023 USIT X-FLOW CHECK/P UG/C MENT G/ - G STATIC PRESSURE SURVEY '~ _.) 03/08/10 04/22/10 04/24!10 1 1 1 1 1 1 S-111 R-28 R-04 BSJN-00049 BCZ2-00008 BCZ2-00010 INJECTION PROFILE PRODUCTION PROFILE - ~ PRODUCTION PROFILE 04/19/10 04!26/10 04/27/10 1 1 1 1 1 1 13-23A 5-06 Z-31 17-22 BBSK-00016 BBKA•00026 B3S0-00060 AWJI-00085 INJECTION PROFILE - INJECTION PROFILE ~ INJECTION PROFILE MEM PRODUCTION PROFILE ~' - 04/29/10 04/30/10 04/27/10 04/28/10 1 1 1 1 1 1 1 1 14-07 AVYO.00068 PRODUCTION PROFILE - 04/26/10 1 1 04.29AL1 A-06 A-28 BBSK-00017 BBKA-00006 AUTO-00037 USIT RST - RST - 04/30/10 02/09/10 02/16/10 1 1 1 1 1 1 17.09A 17-09AP81 t0AKA0128 10AKA0128 OH MWD/L D EDIT ' OH MWD/LWD EDIT ~ 02/11AD 02/0'7/10 2 2 1 1 at FACE Af:KIJOWI Fflr_c GC! `CIDT cv aC,.ne, 2 •.,., .~~.,,...,,.,.. ....~ ......., ~.-....~-. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 os/o7n o • °.~!'~ '~~~~~"~~ it ~~ sp Y t~'f~¢ ,F"4 ,.-,msl~ ~~,„~~ ~~ ~~~~t ;.#«~ , . . .t~ ! '~ ~ MEMORANDUM TO: Jim Regg N' . a ~ ~~'~ , ~ ~'~~, ~ ~ \.-~~ ~ { P.I. Supervisor FROnt: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, October 15, 2009 SUBJECT: Mechanical Integiry Tests BP EXPLORATION (ALASKA) INC Z-31 PRUDHOE BAY UNIT Z-31 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~~" Comm Well Name: pRUDHOE BAY LJNIT Z-31 API Well Number: 50-029-21871-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS091013090234 Permit Number: 188-112-0 Inspection Date: 10/I 1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. `7~1e~] Z-31 ~~'rype jp~.~W 'r~ 8326 jA 40 4000 3950 3940 '~ _P.'T.D 18811Z~ T)'[ICTeS ~SPT - ~- --- - TCSt pSl i 2081 ~ ~L~~ 340 ~ 760 ---~- --~ 760~ 760 -- Interval 4YRTST P~ ---- - P ,/ Tubing - -- --- ~ 450 450 -~--~ 450 I 450 _- -... __~ --- Notes: ~l~r,~C,r"CGC~~:% t~ls ta .~L ~,~ ~Ut~~J Thursday, October 15, 2009 Page 1 of 1 ~ ~ ~~ BP Exploration (Alaska) Inc. .~ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 °`' f~ ~,"~~ ``'~ ~~ ;. ~:~ `~?~1Ca August 14, 2009 r~'"~~'~' t W ~~~~~~~ Mr. Tom Maunder OCT ~U 5 20Q9 Alaska Oil and Gas Conservation Commission ~1I~Sk~ Oii & Gas Cons. Cor~i~Rian 333 West 7th Avenue Anchoraqe Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad ~~~ -~~d- Dear Mr. Maunder, ~" ~~~ 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 attaehed spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and vo(umes 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 ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 500292t8140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24l2009 Z-04A 2042300 500292t9900100 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-06A 1931280 50029217870100 NA 0.2 IVA 2.55 7/2412009 Z-O9A 2081410 50029219670100 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-i6 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 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380100 NA 02 NA 1.70 7/23/2009 Z-22B 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 500292i9500200 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 7l25/2009 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 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-32811 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2W9 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 8/8/2009 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-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-t08 2052010 50029232920000 NA 1.5 NA ti.90 7/24/2009 Z-112 2071720 50029233800000 NA surface NA R Scblum~epgep OCT 1 0 2006 ~Qil& NO. 3982 Al1cOOr~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth U.:Ic, \~Í) -- \1 d Field: Prudhoe Bay D B CI CD Well Job# LOll Description ate L oor 3-29IJ-32 11414759 SBHP SURVEY 09104106 1 L4-10 11285941 MEM PROD PROFILE 09115106 1 L2-21A 11421023 LDL 09111/06 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 N/A INJECTION PROFILE 09/03/06 1 Z-31 11414379 INJECTION PROFILE 09/04/06 1 S-27B 11285940 MEM PROD PROFILE 09/14/06 1 P-13 11414277 INJECTION PROFILE 09/03/06 1 X-33 11421024 LDL 09/12/06 1 Z-19A N/A MDT 09/08/06 1 A-17 11414381 USIT 09/07/06 1 X-01 11422961 USIT 09/09/06 1 H-04A 11285942 SCMT 09/17/06 1 15-39A 11212888 SCMT 09/16/06 1 C-09A 11209608 MCNL 06/16/06 1 1 C-18A 11285934 MCNL 07/29/06 1 1 Z-14B 40013765 OH EDIT OF MWD/LWD 07/31/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consultmg ServIces 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth ~.:'r ~ ~Nr;:E) GVf-~o' \,'--.....~ ¿p ]~ " 1 0/06/06 . . ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg V P.I. Supervisor )'\~cr tlc¡/o{o DATE: Thursday, January 05, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-31 PRUDHOE BAY UNIT 2-31 \Clß/i\'J- FROM: J eff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..:1ß¿ t(q IQb Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT Z-31 Insp Num: mitJJ060105142601 Rei Insp Num API Well Number 50-029-21871-00-00 Permit Number: 188-112-0 Inspector Name: Jeff Jones Inspection Date: 11/1/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2-31 IType IOj.1 w I TVD I 12'0--'-- I I Well 8326 fA 2400 2370 2370 ---t P.T. 1881120 TypeTest i SPT Test p~l 2081. 5 OA 380 450 460 460 _____.-1 Interval INIT AL P/F p Tubing 1600 1600 1600 1600 ¡ Notes 6.1 BBLS 60/40 methanol pumped. 1 well house inspected; no exceptions noted. 8{;ANNEJ) ".~~:~N ~j; 02.D05 Thursday, January 05, 2006 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 2005 REPORT OF SUNDRY WELL OPERATIONS;,' GommissiDi1 1. Operations Performed: Vb /I-tU '-J~ o Abandon o Suspend 151 Operation Shutdown !HI Perforate o Other o Alter Casing !HI Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program !HI Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. ~ermit To Drill Number: BP Exploration (Alaska) Inc. o Development o Exploratory , 1"'112 3. Address: o Stratigraphic !HI Service 6. API Numbér: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21871-00-00 7. KB Elevation (ft): KBE = 91.5' 9. Well Name and Number: PBU Z-31 i 8. Property Designation: 10. Field / Pool(s): ADL 047450 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 13251 feet true vertical 9161 feet Plugs (measured) None Effective depth: measured 13102 feet Junk (measured) None true vertical 9052 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2946' 13-3/8" 2946' 2693' 4930 2270 Intermediate 12641 ' 9-5/8" 12641 ' 8707' 6870 4760 Production Liner 870' 7" 12381' - 13251' 8521' - 9161' 7240 5410 , ' :ft" DEC 1 c 2.0D~~ $ANN.. ,i.J ." }1 ,.. (\) Perforation Depth MD (ft): 12857' - 13084' Perforation Depth TVD (ft): 8867' - 9039' 4-1/2", 12.6# L-80 12388' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer 12103' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: !HI Daily Report of Well Operations o Exploratory o Development !HI Service !HI Well Schematic Diagram 16. Well Status after proposed work: o Oil o Gas !HI WAG OGINJ OWINJ o WDSPL 17. I hereby certify that tne toregolng IS true and correct to tne best ot my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 305-237/305-257 Printed Name Terrie Hubble Title Technical Assistant '1Ój . tl ð. (J ()" Phone Date II (oelos Prepared By Name/Number: Signature 1 Afu 0 '1 X1\ \~ 564-4628 Terrie Hubble, 564-4628 ...- Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only ~ Well: Field: API: Permit: Z-31 Rig Workover Prudhoe Bay Unit 50-029-21871-00-00 188-112 I 305-237 I 305-257 PRE-RIG WORK 08/13/05 CUT TUBING AT 12195', 2' ABOVE PACKER WITH 3.65" SCP JET CUTTER. Accept: Spud: Release: Rig: 08/21/05 N/A 09/01/05 Doyon 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Exploration Operations Summary Report Z-31 Z-31 WORKOVER DOYON DRILLING INC. DOYON 16 From - To I Hours Task Code NPT ¡ Phase .-----.. ---- --.. n___ 05:00 - 07:00 2.00 MOB P 07:00 - 08:30 1.50 MOB P 08:30 - 09:00 0.50 MOB P 09:00 - 11 :00 2.00 MOB P 11 :00 - 00:00 13.00 MOB P 00:00 - 18:00 18.00 MOB P 18:00 - 22:30 4.50 MOB P 22:30 - 00:00 1.50 MOB P Date ....- 8/19/2005 8/20/2005 ----....---...- 8/21/2005 00:00 - 01 :00 1.00 MOB P 01 :00 - 12:00 11.00 MOB P 12:00 - 16:00 4.00 MOB P 16:00 - 18:00 18:00 - 19:30 19:30 - 20:30 20:30 - 00:00 2.00 MOB P 1.50 WHSUR P 1.00 WHSUR P 3.50 WHSUR P PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP 8/22/2005 00:00 - 00:30 0.50 WHSUR P DECOMP 00:30 - 01 :00 0.50 WHSUR P DECOMP 01 :00 - 02:00 1.00 WHSUR P DECOMP 02:00 - 05:00 3.00 BOPSUF P DECOMP 05:00 - 06:00 1.00 BOPSUF P DECOMP 06:00 - 15:30 9.50 BOPSUF P DECOMP Page 1 of 14 Start: 8/19/2005 Rig Release: 10/4/2005 Rig Number: I I Spud Date: 10/17/1988 End: 10/4/2005 Description of Operations _u. __...__...__.._..__..__ .-- -------- ..-.. -..-..-.. RID Rig Floor, Bridle Up Blocks, Lower Pipe Skate Chute. Prepared to Move Off of Q-03A. Held PJSM. Pulled Off of Q-03A. Moved to Middle of Pad. Held PJSM. Unpinned and LID Derrick. Removed BOP Stack from Cellar and Placed on Moving Pedestal. Installed Front and Rear Booster Wheels. Moved Rig Down Q Pad Access Road on Double and Triple Matting. Shuffling Rig Mats from Behind Rig to Front of Rig. Moved Rig Down Q Pad Access Road on Double and Triple Matting. Shuffling Rig Mats from Behind Rig to Front of Rig. Rig at J-Pad and Spline Road Intersection. P/U and Separate Rental Mats From BP Mats, Moving Bp Mats Ahead of Rig to Kaparuk Bridges and to Z- Pad Access Road. Move Rig From Q-Pad Access Road to Spline Road, Position Rig at J-Pad. Remove all Mats From Q-pad Access Road and Stage in Front of Rig. P/U All Mats on Q-Pad Access Rd. Separate Rental Mats from BP Mats. Transport BP Mats and Stage in Front of Rig Move Rig from J-Pad to Z-Pad, Position Rig on Pad to Raise Derrick Remove Front and Rear Booster Wheels, Remove BOPE from Transport Carrier and Position on Cellar Pedestal. Inspect and Raise Derrick. Move Camp from J-Pad to Z-Pad Move Rig Over Z-31. Center Up and Level Rig Checked IA and Tubing Pressures = 0 psi. Installed Secondary Annulus Valve on IA. R/U Circulating Lines to Cellar Circulating Manifold and Tree to Displace Freeze Protection. Take On 140 deg. 2% KCL in Pits 3 & 4. Set Slop Tank ACCEPTED RIG AT 1800 hrs. R/U DSM Lubricator and Pull BPV. RID and UD Lubricator PJSM-Test Circulating Lines t/2,000 psi. Pump 100 bbls 140 deg. 2% KCL Water Down IA Displacing Freeze Protection from Tubing at 5 bpm, 360 psi, Taking Returns Up Tubing to Slop Tank. Pump 40 bbls Safe-Clean Pill Down Tubing Displacing Freeze Protection from IA at 6-1/2 bpm, 500 psi, Followed by 950 bbls 140 deg. 2% KCL Water, Taking Returns Up IA to Slop Tank. Monitor Well -Static Install TWC and Test from Below t/1 ,000 psi. OK Blew Down Circulating Lines and RID Same N/D Tree and Adapter Flange, Install TCII XO in Tubing Hanger to Check Threads, Threads in Good Condition. Split Tree and Adapter Flange and Remove from Cellar Area. Install 3' Spacer Spool and N/U BOPE. Modify Drilling Riser to Fit and Install. M/U Flow Line, Kill line and Choke Line. P/U Test Joint and M/U to Tubing Hanger. M/U Floor Safety Valve and Dart Valve to Test Joint. R/U Pressure Test Manifold and Fill BOPE Stack With Water. PJSM; Test BOPE's Test #1- Annular t/ 250 psi low I 3,500 psi high Door Seal on Pipe Rams Leaked, Replace and Retested, Ok Test #2- Dart Valve t/ 250 psi low I 4,000 psi high Printed: 10/10/2005 11 :34:43 AM BP Exploration Operations Summary Report Page 2 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Z-31 Z-31 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 8/19/2005 Rig Release: 10/4/2005 Rig Number: ì Phase ! Spud Date: 10/17/1988 End: 10/4/2005 n...,__n 8/22/2005 06:00 - 15:30 From - To Hours, Task I Code NPT L....._ Description of Operations 9.50 BOPSUF P n'___I-_..,_'n .. n, n .....u .u___,__. un .._.,___ DECOMP Test #3- Floor Safety Valve t/250 psi low /4,000 psi high Test #4- Pipe Rams, Upper IBOP, V 250 psi low /4,000 psi high Isolation Vlave on Test Pump Leaked, Replaced and Retested Test #5- Blind Rams, Kill Line HCR, Choke Manifold Valves 12,13,14 V 250 psi low / 4,000 psi high TWC Leaked, DSM Replaced and Tested Test #6- Manual Kill Line, Choke Manifold Valves 9,11 V 250 psi low / 4, 000 psi high Test #7- Choke Manifold Valves 5, 8, 10 V 250 psi low /4,000 psi high Test #8- Choke Manifold Valves 4,6,7 V 250 psi 10 w/4,000 psi high Test #9- Choke Maniflod Valve 2 V 250 psi low /4,000 psi high Test #10-Choke Manifold Valve 3, V 250 psi low /4,000 psi high Test #11-Choke Manifold Valve 1, V 250 psi low/4,000 psi high Test #12-Choke Line HCR Valve V 250 psi low /4,000 psi high Test #13-Manual Choke Line Valve V 250 psi low /4,000 psi high All Tests held for 5 min. Each. AOGCC Rep. John Crisp Waived Witness of Test. Tests Witnessed by BP Drilling Supervisor and Doyon Tool Pusher. DECOMP R/D Test Equipment DECOMP R/U Dsm Lubricator and Pulled TWC, R/D and LlDLubricator DECOMP M/U Spear Assy. to 4" DP. RIH and Spear Tubing Hanger. Spear Stacked Out in top of Hanger. Released Spear, B/O and LID Same. M/U 4-1/2" TCII XO to 4" DP. RIH and M/U to Tubing Hanger. BOLDS. Pull Tubing Hanger Off Seat w 142,000#. Pulled Hanger to Rig Floor with 155,000# Up Weight. Circulate Bottoms Up at 10 bpm, 560 psi. Monitor Well-Static PJSM-B/O and LID Landing Joint. B/O and LID Tubing Hanger C/O Bails and Elevators. R/U Compensator, Single Joint Elevators and Tubing Tongs PJSM-POH w/4-1/2" 12.6# TCII Tubing. Utilizing Single Joint Elevators to Pick Joint Out of Box and LID on Sakte PJSM-POH w/4-1/2" 12.6# TCII Tubing. Utilizing Single Joint Elevators to Pick Joint Out of Box and LID on Skate. Recovered 289 jts. tubing, 1 pup, 2 x X Nipple Assy's, and 7.29' Cut Joint. RID Tubing Handling Equipment, Clean and Clear Floor Install Wear Ring Load Collars and HWDP in Pipeshed and Strap Same. Stock rig floor and strap Milling BHA P/U and M/U PKR Milling BHA. 3-5/16" X 3-1/8" PRT Bull Nose Mill, 8 1/2" Metal Muncher PKR Mill, Triple Connection Bushing, 3 x Boot Baskets, Bit Sub,-Bumper Sub, Oil Jar, XO, 12 x 6-1/4" Drill Collars, XO, Jar Intensifier, XO, 21 x 4" HWDP. Total BHA Length = 1076.79' DECOMP RIH with Milling BHA, Picking up 4" Drillpipe from pipeshed DECOMP RIH w/ Milling BHA, P/U 4" Drillpipe from pipeshed 1 x 1 V "- ----- . 15:30 - 16:00 16:00 - 16:30 16:30 - 17:00 0.50 BOPSUF P 0.50 BOPSUF P 0.50 PULL P 17:00 - 18:30 1.50 PULL P DECOMP 18:30 - 19:00 0.50 PULL P DECOMP 19:00 - 20:00 1.00 PULL P DECOMP 20:00 - 00:00 4.00 PULL P DECOMP 8/23/2005 00:00 - 09:30 9.50 CLEAN P DECOMP 09:30 - 10:30 1.00 CLEAN P DECOMP 10:30 - 11 :00 0.50 CLEAN P DECOMP 11 :00 - 12:00 1.00 CLEAN P DECOMP 12:00 - 15:30 3.50 CLEAN P DECOMP 8/24/2005 15:30 - 00:00 00:00 - 02:00 8.50 CLEAN P 2.00 CLEAN P Printed: 10/10/2005 11:34:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Exploration Operations Summary Report Page 3 of 14 Z-31 Z-31 WORKOVER DOYON DRILLING INC. DOYON 16 From - To . Hours I Task : Code I NPT Date f--.._m ______._n._... 8/24/2005 00:00 - 02:00 02:00 - 07:30 07:30 - 09:00 09:00 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 20:00 20:00 - 20:30 Start: 8/19/2005 Rig Release: 10/4/2005 Rig Number: Spud Date: 10/17/1988 End: 10/4/2005 Phase Description of Operations 0___._ .. -...--'----.-.-- -.---- ,. n__ -.---....-...- .--------- -.-...--..- 2.00 CLEAN P 5.50 CLEAN P DECOMP 12,175' DECOMP M/U Top Drive, Established Parameters, St. Wt. Up 225K, St. Wt. Dn. 148K, Rt. St. Wt. 181K, Pump 6 bpm, 1300 psi, Rotary 80 rpm, 9,500 ftllbs Torque. Wash Dn. f/12,175'. Tag Tubing Stub at 12,195'. Mill f/12,195', WOM 5/12K. Mill to 12,201' and packer falls free. Work BHA up 20' and back down to ensure BHA is free. DECOMP Circulate 40Bbls Hi-Vis sweep @ 9-10 BPM. DECOMP POH and SIB DP in Derrick. DECOMP BIO and UD Milling BHA #1. Empty Junk Baskets and recovered 4-5 gallons of metal cuttings and metal bands from packer. DECOMP M/U Packer plucking BHA #2: Itco Spear wI 3.885" Grapple, XO, Bumper Sub, Super Jars, XO, 12 x 6-1/4" DCs, XO, Jar Intensifier, Pump Out Sub, XO, 21-joints of 4" HWDP. Total BHA Length = 1060.16" DECOMP Slip and Cut Drilling Line. DECOMP RIH wI BHA #2 on 4" Drillpipe DECOMP M/U Top Drive. Established Parameters, P/U Wt. 230K, SIO Wt. 145K, Pump 3 bpm, 330 psi,. Tagged at 12,201', bottomed out at 12,209' wI 25K down Wt. Observed 200 psi increase in pump pressure. P/U and repeat process tI verify suspected latch. No excess up weight or drag. POH w/9 5/8" x 41/2" PKR and 41/2" tail assembly. Dropped ball and attempted to open pump out sub. No indication of pump out sub opening. POOH wet. POH w/9 5/8" x 4 1/2" Pkr and 41/2" tail assembly. Wet Trip POH wI BHA #2, Stand back 12 x 61/4" DC,s. BIO and UD Spear, CIO Elevators. POH w/4 1/2" Tbg. Tail Assy. R/U Wach and cut 4 1/2" Tbg., Made 2 cuts. Recovered partial Pkr., 6 pup jts. X nipple, XN nipple, XO and overshot. DECOMP P/U and M/U SBR Retrieving BHA (BHA #3): 83/8" x 81/8" Overshot Guide, 8 1/8" Bowl w/3 1/2" Grapple/MCP, 8 1/8" Overshot Extension, 8 1/8" Overshot Top Sub, XO, Bowen Lubricated Bumper Sub, Bowen Super Sub, XO, 12x 61/4" DC's, XO, Bowen Jar Intensifier, Pump Out Sub, XO, 21x 4" HWDP. Total BHA Length = 1062.04' DECOMP RIH wI BHA on DCs and DP from Derrick. DECOMP P/U DP jt #351; get parameters: P/U wt 235K, SIO wt 145K. Start pump, 4-BPM @ 350 psi. Rotate 40 RPM wI Rot wt 180K. Slowly RIH and see pressure increase to 1290 psi @ 15' in on Jt #351. Continue on to 22' in wI Jt #351. P/U to 250K to check for engagement--got it. Set down to 125K then P/U to 275K to set and release jars for "soft jar". Repeat one time wI same good results. P/U to 275K and check for torque to 15K--okay. SIO to neutral point, then P/U to 150K , begin to slowly rotate, then P/U to 180K for 20 turns. See pressure drop off to -380 psi. P/U to check weight and see 245K . SIO to check for Latch-up, but don't see pressure increase, although lose wt to neutral. P/U to verify and still see 245-250K. SIO to verify one more time, and P/U -250K. Decide to POOH. DECOMP POH and SIB DP and DCs. DECOMP BIO and UD BHA #3. Recover 16.69' cut joint from the lower 1 .50 CLEAN P 5.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 1.00 CLEAN P 3.50 CLEAN P 0.50 CLEAN P 20:30 - 00:00 3.50 CLEAN P DECOMP 8/25/2005 00:00 - 02:00 2.00 CLEAN P DECOMP 02:00 - 04:30 2.50 CLEAN P DECOMP 04:30 - 06:00 06:00 - 09:30 09:30 - 10:30 10:30 - 15:30 15:30 - 16:30 1.50 CLEAN P 3.50 CLEAN P 1.00 CLEAN P 5.00 CLEAN P 1.00 CLEAN P Printed: 10/10/2005 11 :34:43 AM BP Exploration Page 4 of 14 Operations Summary Report Legal Well Name: Z-31 Common Well Name: Z-31 Spud Date: 10/17/1988 Event Name: WORKOVER Start: 8/19/2005 End: 10/4/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 10/4/2005 Rig Name: DOYON 16 Rig Number: Date l!rom - To . Hours Task I COder NPT : _P_~_~ Description of Operations ---- -.- ..._-~._... ____o ____00. ..---.... -----..- _. n__ 8/25/2005 15:30 - 16:30 1.00 CLEAN P DECOMP SBR and Packer Assembly. The pin end had a one inch-wide by one foot-long wear pattern that started in the middle of the threads. The wear marks are circumferential, not axial, with no corresponding markings on the opposite side of the tube. 16:30 - 17:00 0.50 CLEAN P DECOMP Clear and clean Rig Floor and confer with Town. Will RIH wI similar BHA equipped with a 4-1/2" Grapple. 17:00 - 18:30 1.50 CLEAN P DECOMP M/U BHA #4: 83/8" x 81/8" Overshot Guide, 8 1/8" Bowl wI 4.5" Grapple/MCP, 8 1/8" Overshot Top Sub, XO, Bowen Lubricated Bumper Sub, Bowen Super Jars, XO, 12 x 6-1/4" DCs, XO, Bowen Jar Intensifier, Pump Out Sub, XO, 21-joints of 4" HWDP. Total BHA Length = 1060.42'. 18:30 - 21 :00 2.50 CLEAN P DECOMP RIH wI 4" DP tl12,287' 21 :00 - 21 :30 0.50 CLEAN P DECOMP M/U Top Drive, Establish Parameters Up Wt. 248K, On Wt. I 142K, Rot Wt. 185K , 40 RPM, Tq. 7500 ftllbs. 4 bpm @ 350 psi. Tagged Top of Fish @ 12,290'. Observed pressure I increase of 30 psi. P/U to 260K , SIO to 125K, P/U to 270K, set off jars, P/U to 300K, Reset jars wI 125K , P/U to 300K, set off jars, pull to 325K, Reset jars wI 125K, P/U to 325K and set off jars, pull to 350K, Reset jars wI 125K, P/U 360k, set off jars, pull to 360k. Repeat process at 360K. Pulled loose wI 360K Straight pull. P/U tl12,280' no overpull or drag. Blow down Top Drive, Monitor well,- Static 21 :30 - 00:00 2.50 CLEAN P DECOMP POH wI 4" Drillpipe 8/26/2005 00:00 . 02:00 2.00 CLEAN P DECOMP POH wI 8-1/8" Overshot with 4-1/2" Grapple on 4" DP 02:00 - 03:30 1.50 CLEAN P DECOMP POH wI BHA #4; Stand Back 21 HWDP and 12 x 6-1/4" DC's in Derrick. Break down overshot bowl eX1ension to inspect grapple. Recovered 3 1/2" Tbg. Collar. Collar milled appx. 2" wide by the full length. It was cut through to the threads. Confirmed coil tbg. milled outside stub on 3/17/2005. (From Annulus Pressure Report printout of the Well Servicing Reports contained in the Rig Handover folder received from Wells Group.) 03:30 - 04:00 0.50 CLEAN P DECOMP Clear and clean Rig Floor. Contacted Anchorage, Discussed options, Decision was made to run 4 1/8" grapple to catch 3 1/2" Tbg. upset. 04:00 - 05:00 1.00 CLEAN P DECOMP Service Top Drive and Drawworks. 05:00 - 06:30 1.50 CLEAN P DECOMP M/U BHA #5: Overshot w/4-1/8" Grapple, 83/8" x 8 1/8" Overshot Guide, 8 1/8" Bowl wI 4-1/8'''' Grapple/MCP, 8 1/8" Overshot Top Sub, XO, Bowen Lubricated Bumper Sub, Bowen Super Jars, XO, 12 x 6-1/4" DCs, XO, Bowen Jar Intensifier, Pump Out Sub, XO, 21-joints of 4" HWDP. Total BHA Length = 1060.42'. 06:30 - 11 :30 5.00 CLEAN P DECOMP RIH BHA #5 on DP from Derrick. 11 :30 - 12:00 0.50 CLEAN P DECOMP P/U jt #352, M/U to Top Drive, establish parameters: P/U wt 250K, SIO wt 142K. Start pump and engage Rotary Table: 40 SPM, 350 psi, Rot wt 185K, free torque 7-8K Ib-ft. Stop rotation and slowly RIH and see pressure increase to 450-460 psi and stack out to 125K. Stop and P/U slowly to check for grab. P/U to 260K and grapple releases--no joy. RBIH wI slow rotation, stack out to 125K, stop rotation and P/U to check grab. Grapples release w/265K. Repeat P/U and SIO 3-more times; do not see pressure increase of first engagement. RBIH wI slow rotation to stop at 145K, but continue slow rotation. Get 7 Printed: 10/10/2005 11 :34:43 AM Legal Well Name: Z-31 Common Well Name: Z-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To Hours Task ---.- ,-, ----... 8/26/2005 11 :30 - 12:00 12:00 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 19:30 19:30 - 11 :00 11 :00 - 00:00 BP Exploration Operations Summary Report Page 5 of 14 Start: Rig Release: Rig Number: Spud Date: 10/17/1988 End: 10/4/2005 8119/2005 10/4/2005 0.50 CLEAN Ii , , I ~_~de~:T : P ....-..... .--- , Phase ; Description of Operations ---- ._____. _n... 4.50 CLEAN P 1.00 CLEAN P DECOMP turns and grapples release. Try 3-more times to engage, but have same results as first 5-6 attempts. Decide to POH. DECOMP POH w/4" DP DECOMP POH wI BHA; SIB 21 HWDP and 12 x 6-1/4" DC's, UD 8 3/8" x 8 1/8" Overshot Guide, 8 1/8" Bowl with 41/8" Grapple/MCP, 8118" Overshot Top Sub and XO. DECOMP Clear and Clean Rig Floor. DECOMP M/U Milling BHA, 8 1/2" x 8 1/8" x 6 7/8" Mill Shoe, 8 1/8" Wash pipe Extension, Wash pipe Boot Basket TC Conn, Sub, Double Pin Sub, 3 x Boot Basket, Bit Sub, Bowen Lubricated Bumper Sub, Bowen Super Sub, XO, 12 x 61/4" DC's, XO, Bowen Jar Intensifier, Pump Out Sub, XO, 21 x 4" HWDP = 1086.72' DECOMP RIH with BHA #6, Milling BHA on DP from Derrick DECOMP M/U Top Drive, Establish parameters: P/U 250K, SIO 140K, Rt Wt. 188K, Tq. 8500 ft/lbs at 60 RPM, 5 bpm @ 560 psi. Tag top of fish @ 12290'. Mill on fish 60 rpm, Tq, 12/15K Weight on Mill 5/7K, 5 bpm @ 550 psi Mill on fish f/12,293' t/12,294' 60 rpm, Tq, 12/15K Weight on Mill 5/15K, 5 bpm @ 550 psi. Circulate 20-Bbl Hi-Vis sweeps every 30 minutes. P/U one joint of DP and circulate 40-Bbl Hi-Vis sweep. Bleed down Top Drive. POH and SIB DP, HWDP, and DCs. Break-out BHA, inspect Mill and see that the inside buttons show even wear patterns, with spiral marks inside the barrel to +1- 1.5'. The bottoms of the milling segments are worn with one segment missing a section -1" square. Junk Baskets contained -5 gallons or 50-60 Ibs of metal cuttings and some oily debris. DECOMP M/U 6-7/8" Grapple BHA: 8-1/8" Overshot Guide, 8-1/8" Bowl wI 6-7/8" Grapple, 2 x Overshot Extensions, 8-1/8" Overshot Top Sub, XO, Bumper Sub, Super Jars, XO, 12 x 61/4" DCs, XO, Jar Intensifier, Pump-Out Sub, XO, and 21 x joints of 4" HWDP. Total BHA Length = 1,064.31'. DECOMP RIH wI SBR Retrieving BHA on 4" DP from derrick DECOMP M/U Top Drive, Establish parameters, P/U 243K, SIO 148K, Rt Wt 185K, 40 RPM @ 7K Tq., 4 bpm @ 280 psi. Tag fish at 12,294' SIO to 125K, P/U to 248K, no bite, SIO to 125K while rotating at 20 RPM, Observed 30 PSI increase in pressure P/U to 255K, SIO to 125K P/U to 275K, Jar, P/U to 285K, SIO to 115K, P/U to 300K, Jar, P/U to 325K, SIO to 125K, P/U to 325K, Jar, P/U to 350K, SIO to 125K, P/U to 350K, Jar, P/U to 375K, SIO to 125K, P/U to 375K, Jar, Came loose. SIO to 125K got 30 PSI increase, would not engage. No Overpull or Drag. Blow down Top Drive, monitor well, Static. DECOMP POH and SIB DP DECOMP POH wI SBR Retrieving O/S. SIB Drillpipe DECOMP POH and SIB HWDP and 61/4" DC's. Break off OIS and inspect Grapple. Grapple was broken, 4" x 1" x 1/8" section of grapple was left in hole. Call Anchorage and discuss options. Baker to re-dress 8-1/2" x 8-1/8" x 6.875" Mill in their shop. Will RIH wlOIS with 4.00" Grapple to grab the upset of the 3-1/2" 0.50 CLEAN P 1.50 CLEAN P 15.50 CLEAN P 13.00 CLEAN P 8/27/2005 00:00 - 06:00 6.00 CLEAN P DECOMP 06:00 - 08:00 2.00 CLEAN P DECOMP 08:00 - 15:00 7.00 CLEAN P DECOMP 15:00 - 16:00 1.00 CLEAN P DECOMP 16:00 - 17:30 17:30 - 21 :00 21 :00 - 22:00 8/28/2005 22:00 - 00:00 00:00 - 03:00 03:00 - 04:30 1.50 CLEAN P 3.50 CLEAN P 1.00 CLEAN P 2.00 CLEAN P 3.00 CLEAN P 1.50 CLEAN P Printed: 10/10/2005 11:34:43 AM 8/29/2005 06:00 - 11 :30 11 :30 - 12:00 12:00 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 21 :00 21 :00 - 00:00 00:00 - 00:30 00:30 - 06:30 Page 6 of 14 BP Exploration Operations Summary Report S.SO CLEAN P O.SO CLEAN P DECOMP DECOMP Legal Well Name: Z-31 Common Well Name: Z-31 Event Name: WORKOVER Start: 8/19/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 10/4/2005 Rig Name: DOYON 16 Rig Number: Date _ _~rom - To Hours· Task . ?o~e I_~~T I Phase 8/28/200S 03:00 - 04:30 1.50 CLEAN P DECOMP 04:30 - OS:OO O.SO CLEAN P DECOMP OS:OO - 06:00 1.00 CLEAN P DECOMP S.OO CLEAN P 1.00 CLEAN P O.SO CLEAN P 1.S0 CLEAN P DECOMP DECOMP DECOMP DECOMP 1.00 CLEAN P 3.00 CLEAN P O.SO CLEAN P 6.00 CLEAN P DECOMP DECOMP DECOMP DECOMP 06:30 - 14:00 7.S0 CLEAN P DECOMP 14:00 - 14:30 0.50 CLEAN P DECOMP 14:30 - 1S:00 O.SO CLEAN P DECOMP 1S:00 - 20:00 5.00 BOPSU P DECOMP 20:00 - 22:00 2.00 CLEAN P DECOMP Spud Date: 10/17/1988 End: 10/4/2005 Description of Operations --.--"-... ----.-.-.. Stub on top of the SBR assembly. Clear and Clean rig floor. M/U BHA for 3 1/2" Tubing Stub: 8-3/8" x 8-1/8" OIS wI 4.00" Grapple, Bumper Sub, Super Jar, 12-ea 6-1/4" DCs, Jar Intensifier, Pump-Out Sub, 21-ea 4" HWDP. RIH BHA on HWDP and DP from Derrick. P/U single DP joint, RIH, P/U remaining Stand in Derrick and RIH. Get parameters: P/U wt 2S0K, SIO wt 143K (with and without pump), Free Torque @ 40 RPM 10K Ib-ft, 38 SPM @260 psi. SIO and decrease rotation to 10 RPM, SK Ib-ft. Pressure increases to 460 psi as 3-1/2" stub is swallowed. Stop rotating. Set down to 125K, P/U to 2S0K + to check grab, SIO to 11 OK then P/U to 2S0K to verify, but lose grab. Repeat SIO to 11 OK and P/U to 26SK and grapples hold. SIO to 11 OK to energize jars, P/U to 27SK to set off jars. Repeat P/U to 275K then SIO to 190K and rotate for 13-1/2 rotations, 10K Ib-ft and torque drops off to SK Ib-ft. P/U to 2S0K and SIO to 11 OK, 3-times to check grab, then P/U to 275K to set off jars. Pressure bled off to 260 psi. SIO and pressure increases to 460 psi, P/U to 2S0K and POH -10' and pressure drops to 260 psi; repeat process 2-times wI same results. Do not know if SBR has been pulled free. Prepare to POH. POH and SB DP, HWDP, and DCs. B/O Overshot--No fish in Grapple. Clear Rig, Service Top Drive and Drawworks. M/U Milling BHA, 8 1/2"x 8 1/8"x 6 7/8" Mill Shoe, 8 1/8" Washpipe Extension, Washpipe Boot Basket TC Conn. Sub, Double Pin Sub, 3 x Boot Baskets, Bit Sub, Bowen Super Jar, XO, 12 x 6 1/4" DC's, XO, Bowen Jar Intensifier, Pump Out Sub, XO, 21 x HWDP = 1077.82'. Slip and Cut Drilling Line. RIH wI Milling BHA on DP from Derrick. RIH wI Milling BHA on Drillpipe from Derrick M/U Top Drive and Establish Parameters. P/U 24SK, SIO 144K, Rt Wt 181 K, 60 RPM at 10/11 K Tq., 60 SPM at 640 PSI. Tag Top of Fish at 12,293'. Mill Fishing Neck on SBR Overshot Top Connection and Spaceout Nipple. 10/1SK WOM, 60 RPM at 13/1SK Tq. 60 SPM at 700 PSI. Make only 1-2" additional and decide to POH. POH and SIB DP, HWDP, and DCs in Derrick. BIO and empty Junk Baskets, find a 1 "-long piece of 1" Brass Bolt in the cuttings and debris from the baskets. Clear and clean Rig Floor. Pull Wear ring and set Test Plug. Prepare for BOPE Test. Test BOPE to 2S0 psi low and 4,000 psi high. Test Annular to 2S0 psi low and 3,SOO psi high. All tests held S minutes each. All tests witnessed by BP Drilling Supervisor and Doyon Toolpusher. AOGCC's Jeff Jones waived witnessing the BOPE tests. RID Test tools, UD test plug, Install wear ring. M/U Close Catch OIS BHA, 8 1/2" Short Catch OIS Bowl wI 6 3/4" Grapple, 8 1/2" BOS Pin x 8 1/8" TSWP Box, 8 118" Washpipe Extension, 8 1/2" TSWP Pin x 4 1/2" IF Drive Sub, Bowen Lubricated Bumper Sub, Bowen Super Jar, XO, 12 x 6 Printed: 10/10/2005 11 :34:43 AM Page 7 of 14 BP Exploration Operations Summary Report Legal Well Name: Z-31 Common Well Name: Z-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To ! Hours I Task µ.=. '" ---..-----1- _ n..---L..--___ 8/29/2005 20:00 - 22:00 2.00 CLEAN 8/30/2005 22:00 - 00:00 00:00 - 02:00 02:00 - 12:00 '~ode LNPT I Phas~ n ; P DECOMP 2.00 CLEAN P 2.00 CLEAN P 10.00 CLEAN P DECOMP DECOMP DECOMP 12:00 - 19:00 7.00 CLEAN P DECOMP 19:00 - 20:00 1.00 CLEAN P DECOMP 20:00 - 00:00 4.00 CLEAN P DECOMP 8/31/2005 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 03:30 3.00 CLEAN P 03:30 - 05:00 1.50 CLEAN P 05:00 - 10:00 5.00 CLEAN P 10:00 - 10:30 0.50 CLEAN P 10:30 - 11 :00 0.50 CLEAN P 11 :00 - 17:00 6.00 CLEAN P 17:00 - 18:00 1.00 CLEAN P 9/1/2005 18:00 - 00:00 00:00 - 04:30 04:30 - 05:00 05:00 - 07:00 07:00 - 11 :00 11:00 -12:00 12:00 - 14:00 14:00 - 15:30 15:30 - 18:30 DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 6.00 CLEAN P 4.50 CLEAN P 0.50 CLEAN P 2.00 RUNCOr p 4.00 RUNCOI P 1.00 RUNCOr P 2.00 BOPSUF P DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP RUNCMP 1.50 WHSUR P Start: 8/19/2005 Rig Release: 10/4/2005 Rig Number: Spud Date: 10/17/1988 End: 10/4/2005 Description of Operations -- .....----.. .-.-- _.._____n_____.._.. 1/4" DC's, XO, Bowen Jar Intensifier, Pump Out Sub, XO, 21 Jts HWDP = 1064.93 RIH wI BHA on DP from Derrick RIH wlOIS BHA on DP from Derrick t/12,230' M/U Top Drive, Established Parameters; Up Wt. 240K Dn Wt.146K, Rt. Wt. 183K Tq 9K @ 60 RPM, Pump 40 SPM @ 300 PSI. RIH and Rotate Over 6-3/4" Fishing Neck at 12,294'. Stop Rotation and Apply 125K Set Down Wt. Observed 40 PSI Pump Pressure Increase P/U to 250K, Trip Jars, Straight Pull to 275K, Recock Jars wI 125K Dn. Repeat Jarring Process with 25K Increments in P/U Wt and Straight Pull Weight. Maximum Jar Trip and Straight Pull is 375K. Repeating Jarring Process at 375K every 5-8 minutes. Make 4-5' of progress during 10-hours of jarring. Decide to rotate to either release the Latch Receptacle Anchor or the 6-3/4" Grapple. SIO to 200K and begin to rotate @ 6K Ib-ft, torque slowly climbs to -11 K Ib-ft during 17 revolutions and quickly releases to -6K Ib-ft. P/U 15' and weight increases, continue P/U to 350K and pull quickly through tight spot. POH and SIB DP and HWDP, LID DCs, Short Catch Overshot Grapple BHA, SBR and Latch Assembly. M I U and RIH with BHA #11; Bit, Casing Scraper, Bumper Sub, Oil Jar, 21 Jts HWDP. Total length = 674.49'. RIH with 4" DP from Derrick to 11,900'. PI U 10 single joints from pipe shed to and RIH to 12200'. Establish parameters: Up Weight = 210,000 Ibs, Down Weight = 145,000 Ibs. Rotating Weight = 167,000 Ibs. Rotating 20 rpm's at 6,000 ft-Ibs. Wash down at 5.0 bpm at 650 psi while rotating at 20 rpm's from 12120' - 12200'. Circulate well bore to clean seawater with 830 bbls at 6.5 bpm at 900 psi. PJSM. Slip and Cut Drilling Line. POOH and stand back 4" DP in Derrick. BIO and UD BHA #11 P/U Halliburton 9-5/8" RBP and prepare to RIH. RIH RBP on HWDP and DP from Derrick. Set RBP @ 12,150'. R/U to circulate 20 Bbls down tubing, then Pressure Test Casing to 4,000 psi, hold and record for 30 minutes. Good, rock-solid test. POH and UD DP and HWDP, 212 of 360 jts. POOH and LID 4" DP and HWDP. BIO and UD RBP Running Tool. Clean and clear rig floor. Rig up to run 4-1/2" tubing, compensator, bails, torque turn equipment. Pull wear bushing. Run Kill String completion for temporary cessation of Rig Workover. 4-1/2" WLEG set @ 2,198', Doyon 16 RKB. M I U tubing hanger and landing joint. Land tubing hanger and RILDS. Set TWC and test to 1000 psi. BID lines and N I D BOPE. RUNCMP Attempt to change lockdown screw - plug off instead. Install packoff . RUNCMP N I U adapter flange and tree. Pressure test each to 5000 psi 3.00 WHSUR P Printed: 10/10/2005 11 :34:43 AM Page 8 of 14 BP Exploration Operations Summary Report Start: Rig Release: Rig Number: Phase Legal Well Name: Z-31 Common Well Name: Z-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 ~~__Lr0m -T_~l Hours :__Task Jcode '~PT . 9/1/2005 15:30 - 18:30 3.00 WHSUR P 18:30 - 21 :30 3.00 WHSUR P RUNCMP RUNCMP 21 :30 - 22:30 22:30 - 00:00 1.00 WHSUR P 1.50 WHSUR P WHDTRE WHDTRE 9/21/2005 06:00 - 08:00 2.00 MOB N PRE 08:00 - 09:30 09:30 - 10:30 1.50 MOB 1.00 MOB N N PRE PRE 10:30 - 15:00 4.50 MOB N PRE 9/22/2005 15:00 - 18:30 3.50 MOB N PRE 18:30 - 19:00 0.50 MOB N PRE 19:00 - 20:00 1.00 MOB N PRE 20:00 - 00:00 4.00 MOB N PRE 00:00 - 03:00 3.00 MOB P PRE 03:00 - 04:00 1.00 MOB P PRE 04:00 - 05:00 1.00 MOB P PRE 05:00 - 10:30 5.50 MOB P PRE 10:30 - 14:00 3.50 MOB P PRE 14:00 - 15:30 1.50 MOB P PRE 15:30 - 16:30 1.00 MOB P PRE 16:30 - 19:00 2.50 MOB P PRE 19:00 - 21 :00 2.00 MOB P PRE 21 :00 - 00:00 3.00 MOB P PRE 00:00 - 01 :00 1.00 MOB P PRE 01 :00 - 03:00 2.00 MOB P PRE 03:00 - 05:00 2.00 MOB P PRE 05:00 - 08:30 3.50 MOB P PRE 08:30 - 12:00 3.50 MOB P PRE 12:00 - 15:30 3.50 RIGU P PRE 9/23/2005 8/19/2005 10/4/2005 Spud Date: 10/17/1988 End: 10/4/2005 Description of Operations ..----------.--.--.----... -- ..-- for 30 minutes. Rig up circulating hoses and Little Red. Pressure Test to 3000 psi. Pump 155 bbls of diesel freeze protect at 2.0 bpm @ 250 psi. U-tube to equilize. Install BPV and pressure test to 1000 psi from below. BID hoses. Rig down Little Red. Install gauges, rig down second annulus valve, and secure well. Rig released at 24:00 hrs. Rig was moved off Well S-14 and positioned on S-pad to Remove and Replace two Off-Driller-side Front-Drive tires and to R&R the Driller-side Front-Drive Jacking Cylinder. Remove Rig Mats and Berm-up under Rig for R&R-ing the Jacking Cylinder and Tires. PJSM. Remove Booster Wheels Goose-neck from Rig. Remove Substructure Spreader Cross-frame in front of the Front-Drive Wheels. PJSM for Deflating Tires, Removing Split Ring and Back Up Wheel Rings, and removing two Front-Drive Tires. Remove and Reinstall Tires. Dismantle Hydraulic System for Driller-side Front-Drive Wheels. Remove Hydraulic Jacking Cylinder from Rig and Take to Welding Shop for Modification to Steering Arm Remove BOPE Stack from Cellar Pedistal and Place on Traveling Stand for Rig Move Install rear Booster Wheels Remove Elevators and Bails, Stand Top Drive in Rotary Table and Remove from Traveling Blocks. Bridle Up Blocks, Lay Over Skate Chute Install New Hydraulic Jacking Cylinder in Rig and Secure to Frame Move Wheels Into Position below Jacking Cylinder for Install Connect Hydraulic System to Jacking Cylinder Connect Axle Trunnions to Jacking Cylinder. Reinstall Spreader Frame. Complete welding on the Jacking cylinder. Hookup all hydraulic control lines to Jacking Cylinder. Wait on new Trunnion Bolts. Install Trunnion Bolts, test hydraulic lines and system, and prepare to UD Derrick. UD Derrick and secure Rig for move to Z-31. Wait on Security personnel for Rig Move. Move rig from S-Pad to intersection of spine road, Inspect tires and moving system. Continue moving rig from S-pad road intersection to Z-pad road. Move Rig to Spline Rd.l Z-Pad Intersection Turn Off Spline Rd. onto Z-Pad Access Rd. Move Rig from Spline Rd. to Z-PAd Remove Booster Wheels, Install BOPE Stack on Cellar Pedestal, Inspect and raise Derrick. Spot rig over Well. Set Slop Tank, Install Secondary Annulus Valve on IA. Accept Rig @ 1200 Hours. Remove Bridle Lines and RIU Top Drive, take on Seawater to pits #3 and #4. Printed: 10/10/2005 11 :34:43 AM Page 9 of 14 BP Exploration Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Z-31 Z-31 WORKOVER DOYON DRILLING INC. DOYON 16 From - To I Hours I Task __m ._:_n ,""'__ 15:30 - 16:30 1.00 RIGU Start: 8/19/2005 Rig Release: 10/4/2005 Rig Number: I Phase I -...-.---. I Code i NPT i , I , .' __f--_m u ,-----.-.. P PRE 9/23/2005 16:30 - 17:00 0.50 RIGU P PRE 17:00 - 18:00 1.00 KILL P DECOMP 18:00 - 20:30 2.50 WHSUR P DECOMP 20:30 - 23:00 2.50 BOPSUF P DECOMP 23:00 - 00:00 1.00 BOPSUF P DECOMP 9/24/2005 00:00 - 06:00 6.00 BOPSUF DECOMP 06:00 - 09:30 3.50 BOPSUF DECOMP 09:30 - 11 :00 1.50 PULL DECOMP 11 :00 - 12:00 1.00 PULL DECOMP 12:00 - 12:30 0.50 PULL DECOMP 12:30 - 15:00 2.50 PULL DECOMP 15:00 - 15:30 0.50 PULL DECOMP 15:30 - 16:00 0.50 PULL DECOMP 16:00 - 00:00 8.00 FISH DECOMP 9/25/2005 00:00 - 02:00 2.00 FISH P DECOMP 02:00 - 05:30 3.50 FISH P DECOMP 05:30 - 06:00 0.50 FISH P DECOMP 06:00 - 07:00 1.00 FISH P DECOMP 07:00 - 07:30 07:30 - 00:00 0.50 FISH 16.50 FISH P P DECOMP DECOMP Spud Date: 10/17/1988 End: 10/4/2005 Description of Operations -- ....-.---.- .,- ._ on P/U ands install DSM Lubricator, pull BPV, remove and UD Lubricator. R/U Circulating Lines to Cellar Manifold, Tree, and IA. Test Lines to 1,000 psi. Circulate out 155 Bbls of Diesel Freeze Protect fluid. Blow down Circulating Lines. Install TWC and test to 1,000 psi. PJSM. N/D Tree and Adapter Flange. Hanger Threads found to be in good condition. Check all LDS, good. PJSM--N/U BOPE. Connect Kill and Choke Lines. Install Drilling Riser. Install Test Joint, R/U Test Equipment. Test BOPE. Test annular to 250 psi Low 13,500 psi High; Annular leaked on High test. Test following to 250 psi Low, 4,000 psi High: Choke Maniflod Valves 1 - 14, Kill Line and choke Line Valves, Blind Rams, Pipe Rams, Floor Safety Valves, Upper and Lower IBOP---Successful tests, each held and recorded for 5 minutes. Tests witnessed by Jeff Jones, AOGCC, BP Drilling supervisors, and Doyon Tool Pusher. Rig Down Test Eqpt. Suck out Stack. BID and remove Drilling Riser and inspect Hydril. Found no indication of damage or wear. Reassemble Drilling riser and test Hydril---250 psi Low, 3,500 psi High, hold and record for 5-minutesugood test. Rig up casing tools to pull 4 1/2" kill string. Rig up ludricator extension and DSM lubricator. Pull TWC, rig down lubricator. Make up landing joint, BOLDS, pull tubing hanger to floor, up wt 60k, lay down hanger and landing joint. Lay down 51 joints 41/2" 12.6# L-80 TC-II tubing and XN nipple assembly. Rig down casing tongs and tubing handling equipment. Install wear ring. PJSM, Make up Halliburton RBP, overshot retrieving tool. RIH with HES retrieving tool, picking up 4" DP to 9,130' RIH with RBP overshot retrieving tool from 9,130' to 12,137' Makeup topdrive, and break circulation, 3 bpm @ 270 psi, up wt = 210k, dn wt = 130k, slack off and engage overshot, P/U to 215k to confirm latched, work torque down to release upper slips, 1/2 turn increments working string between 100k and 220k, no progress. Torque string to 7K ftIlbs (4 turns), continue working torque down, work string between 90k - 250k, broke free with 250k RBP unset. pulled up to 12,130' slips hung up, worked down to below RBP setting depth to insure free. Pulled up to 12,130' slips hanging up. Continue working string until free, pulled up full stand with no problem. Circulate bottoms up. Pumped 740 bbls. 9 BPM @ 2300 psi. No losses. Monitor well. Blow down Top Drive. POOH wI RBP. from 12,150' to 9,033', BP dragging, Slips won't fully release. Having to rotate string 30 RPM , torque 6k, while POH slowty to keep from setting slips. Mixed 20 bbl EP Mud Lube pill & spot down around DP. Continue to POOH, metal to metal drag decreased with lube pill in the hole. Printed: 10/10/2005 11 :34:43 AM BP Exploration Operations Summary Report Page 10 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-31 Z-31 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 8/19/2005 10/4/2005 Spud Date: 10/17/1988 End: 10/4/2005 Date From - To Hours, Task 'Code NPT I Phase I .--. ---" ..--- ..-----. --..-. -..- 9/26/2005 00:00 - 10:00 10.00 FISH P DECOMP Continue to POH with Halliburton RBP from 9,130' to 4,668' POH slowly, rotating 30 rpm, torque 5k, slips on BP hanging up on 95/8" casing collars. At 7,000' pump out several stands to clear any debris that has accumulated and spot 20 bbl EP mud lube pill. 10:00 - 12:00 2.00 FISH P DECOMP Con't to POOH from 4668 to surface. Now able to pull stands wlo rotation. Still have occasional drag. 12:00 - 12:30 0.50 FISH P DECOMP Pull retreiving tool to surface -NO RBP. Inspect tool. No damage. Prep to RIH & find RBP. 12:30 - 14:30 2.00 FISH P DECOMP RIH & fish RBP. Found plug @ 4480'. SIO w/30K & engauge RBP. P/U & pull plug. Will not come wlo rotation. 14:30 - 00:00 9.50 FISH P DECOMP POOH wI RBP. Continue to rotate while pulling pipe. Check every 5 stands wI straight pull to insure fish still engauged. No indication of BP hanging up after 1,370', continue POH to surface, no Fish. Inspect overshot, no visible signs of wear or I damage. 9/27/2005 00:00 - 00:45 0.751 FISH P DECOMP RIH with Halliburton overshot retrieving tool, tag BP @ 1,340', set down 10k, saw visual indication of latch up, picked up 50' with no rotation, no excess drag. Slack off to 1,340' set down 10k. Rotate string at 10 rpm while picking up slowly, positive indication of latch up. 10-15k intermitent drag. 00:45 - 05:00 4.25 FISH P DECOMP POH with BP slowly, rotating string at 10 rpm, torque 1.5k, BP hanging up on casing collars. 05:00 - 07:00 2.00 FISH P DECOMP RBP hanging up in wear bushing, BOLDS and attempt to pull wear ring with RBP, No go. RIH one single and make up wear ring running tool, pull and lay down wear ring, attempt to pull RBP thru wellhead. Rotating string 5 rpm pulled up 15k over and stalling out top drive. Drag blocks or upper hold down slips appear to be hanging up in wellhead below tubing spool. Unable to pull RBP to floor. 07:00 - 08:00 1.00 FISH P DECOMP R/U to test IBP. Test & chart IBP to 1000 psi for 30 min. Tested good. RID test equip. 08:00 - 16:30 8.50 FISH P DECOMP Discuss options wI office engineers. Submit a revised plan forward for approval. Clean & service rig. Perform rig maintenance. 16:30 - 17:00 0.50 FISH P DECOMP PJSM wI Rig Hands, HES, and Cameron 17:00 - 18:00 1.00 FISH P DECOMP M I U Test Plug and XO to Joint of DP. Land Test Plug and B I o Joint of DP. 18:00 - 19:30 1.50 FISH P DECOMP N I D BOPE and Standback Stack 19:30 - 21 :30 2.00 FISH P DECOMP M I U Single of 4" DP to Test Plug. Work RBP thru Packoff. Pull RBP to Rig Floor. Complete RBP Was Recovered. After inspection of BP it was determined that the inner mandrel had twisted off, not allowing the upper hold down slips to fully retract. Slips hung up in the void in the upper portion of the packoff. 21 :30 - 22:00 0.50 FISH P DECOMP Clean and LID RBP From Rig Floor. 22:00 - 23:00 1.00 FISH P DECOMP Nipple Up BOPE and drilling nipple. 23:00 - 00:00 1.00 BOPSU P DECOMP Rig up BOP test equipment, Test BOP body to 250 psi low, 4,000 psi high. Test witnessed by WSL Bill Burson, Doyon Toolpusher Glen Herman.. 9/28/2005 00:00 - 01 :00 1.00 BOPSU P DECOMP RID Test Equipment, Pull Test Plug, Drain Stack, and Install Wear Bushing. Clear Test Equipment From Floor. 01 :00 - 04:00 3.00 FISH P DECOMP PI U IBP Retrieval BHA. 8 1/4" x 5 3/4" Oversized Guide, 5 Printed: 10/10/2005 11 :34:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L.~ate _ 9/28/2005 9/29/2005 9/30/2005 Page 11 of 14 BP Exploration Operations Summary Report Z-31 Z-31 WORKOVER DOYON DRILLING INC. DOYON 16 I I I ' From - To : Hours Task' Code! NPT I Phase ___ ,_.. ._ 1._. _ _, ._'. _. __'.. :__, ,_, 01 :00 - 04:00 3.00 FISH P DECOMP 04:00 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 17:00 17:00 - 18:30 18:30 - 19:00 19:00 - 21 :00 21 :00 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 10:00 10:00 - 11 :00 11 :00 - 13:00 13:00 - 14:00 14:00 - 15:30 15:30 - 19:30 19:30 - 00:00 00:00 - 04:00 4.50 FISH 1.00 FISH 1.00 FISH 1.00 FISH 5.50 1.50 0.50 2.00 3.00 FISH 1.00 FISH 2.00 FISH 7.00 FISH 1.00 FISH 2.00 FISH 1.00 FISH 1.50 FISH 4.00 FISH 4.50 FISH 4.00 FISH P P DECOMP DECOMP P DECOMP P DECOMP FISH FISH FISH FISH P P P P DECOMP DECOMP DECOMP DECOMP P P P DECOMP DECOMP DECOMP P DECOMP P DECOMP P DECOMP P P P DECOMP DECOMP DECOMP P DECOMP P DECOMP Start: 8/19/2005 Rig Release: 10/4/2005 Rig Number: Spud Date: 10117/1988 End: 10/4/2005 Description of Operations . _ ____ ,__, __ __. ______ _ ,__ _n__ __. ._ 3/4" Overshot Bowl w/1 3/4" Grapple, 53/4" Overshot Top Sub, Pump Out Sub, Double Pin XO, 3 x Boot Baskets, Bit Sub, Bowen Lubricated Bumper Sub, Bowen Super Jar, XO, 12 x 6 1/4" Drill Collars, XO, Bowen Jar Intensifier, XO. Total BHA Length 432.42' RIH w IIBP Retrieval BHA on 4" DP Establish Parameters; Pick Up Wt = 205,000 Ibs, Down Wt = 155,OOOlbs. Rotating Wt = 180,000 Ibs with 30 rpm's @ 6500 ft-Ibs torque. Establish Circulation 4.0 bpm at 540 psi. RIH and tag up at 67' in on stand #124 = 12305'. No increase in pump pressure. P I U with no increase in Up Wt. Rotate Pipe and RIH, tag up at same spot. Cut pump rate to 2.0 bpm and attempt to latch IBP again. No increase in Pick Up Wt observed. Shut-in pumps and try again. No increase in Pick Up Wt observed. Establish Reverse Circulation at 12305' with 4.0 bpm at 750 psi. Attempt to clean off top of IBP and Latch Fish Neck. No increase in Pick Up Wt. Reverse Circulate at 12305' wI 4.0 bpm at 750 psi. Consult wI Town, decide to POOH and use different BHA. POOH wI 4" DP and Stand Back in Derrick. LID IBP Retrieval BHA. ( No Fish ). Clean and Clear Rig Floor M I U New IBP Retrieval BHA. Oversized Guide, 2 1/8" IBP Overshot, XO, XO, Bit Sub, Double Pin XO, Shear Pin Sub, 2 7/8" PAC Pony Drill Collar, XO, Pump Out Sub, Double Pin XO, 3 x Junk Baskets, Bit Sub, Bumper Sub, Jars, XO, 12 x 61/4" Drill Collars, XO, Bowen Jar Intensifier, XO. BHA Length = 449.07' RIH w/lBP Retrieval BHA on 4" DP RIH with IBP Retrieval BHA on 4" DP t/12,254' Establish Parameters, 205,000# Up Wt. 157,000# Down Wt. 182,000# Rotating Wt. 20 RPM with 6,000 ftllbs torque. 3 BPM @ 370 PSI. Tagged @ 12,305', Sheared at 12,306' with 13,000# Down Wt. SIO to 12,310' and latch onto IBP. P/U to 215,000# let IBP Relax, SIO to 150,000#, P/U to 220,000# Sheared IBP with 15,000# overpull. Observed 210 psi increase in pump pressure. Monitor well. Static Blow down Top Drive POOH with 4" DP and IBP Retrieval BHA. Have IBP, the plug is in very bad condition but all major pieces are recovered. Clean Rig Floor, very slick from Schmoo coming off DP and BHA. LID Fish and B I 0 IBP Retrieval BHA. Clean Out Junk Baskets. M I U 8-1/2" Packer Milling BHA RIH with 8-1/2" Packer Milling BHA, DC's, and 1 Stand of DP. Slip and Cut Drill Line. RIH with 8-1/2" Packer Milling BHA on 4" DP from Derrick. t/ 12244' Establish Parameters, Up Weight 205,000 Ibs, Down Weight 155,000 Ibs, Rotating Weight 182,000 Ibs. Torque 6000 Ibs at 60 RPM, 4BPM at 750 psi. Tag Packer and Mill from 12,302' t/ 12,309' Mill Packer from 12,309' t012,314', up wt = 205k, dn wt = 150k, Printed: 10/10/2005 11 :34:43 AM Page 12 of 14 BP Exploration Operations Summary Report Z-31 Z-31 WORKOVER Start: 8/19/2005 DOYON DRILLING INC. Rig Release: 10/4/2005 DOYON 16 Rig Number: From - To ! Hours I Task ! Code i NPT I Phase I Description of Operations u_, u~.. ,_H .._.... u_.., .____ .__.... _..__'_... ...__..... ..._._.u _.__..._, __.._ .__. 00:00 - 04:00 4.00 FISH P DECOMP rt wt = 182k, 252 gpm, 1,510 psi. Wash down pushing packer to 12,337' dn wt = 165k, picked up to to 12,242' up wt = 215k. to confirm latched onto packer and tail pipe assembly. DECOMP Pump 40 bbl hi vis sweep, around at 320 gpm, 2350 psi. No losses. Monitor well, well static. blow down topdrive. POOH wI 4" DP and DC's and Stand Back in Derrick. POOH wI Packer Mill, Grapple and Fish. Very tight fit through Wear Ring. LID 3 Joints of 3-1/2" Tbg, 2 X-Nipples, 1 WLEG, Packer Assembly wI Mill Out Extension and XO. Found Fas-Drill Plug -8' in on first full Tbg Joint below Packer. LID 3 Boot Baskets and recovered -2 gallons of metal shavings and -1 gallon of schmoo. Clean and Clear Rig Floor. Rig Up to Test BOPE. Test BOPE. Lou Grimaldi wI AOGCC waived witness of test. Pressure test to 250 psi low and 4000 psi high. Per Doyon testing procedure. Hydril failed test. Test was witnessed by WSL Bill Burson, Doyon Toolpusher Glen Hermann. DECOMP Rig Down BOPE Test Equipment. Blow Down Lines DECOMP Hold PJSM, Work on Changing Hydril Element. Remove drilling nipple and flange on top of Hydrill, break and back out cap. DECOMP Change Out Hydrill Element and Seals. Elements torn up severly on the backside, inside in good shape. Re-install cap, flange and drilling nipple. DECOMP Rig up BOP test equipment and re-test Hydrill to 250 psi low, 3,500 psi high. ok. DECOMP Pull Test Plug and Install Wear Bushing DECOMP M I U Clean Out BHA; 6" Junk Mill, Bit Sub, 6 jts 4-3/4" DC's, 17 jts 4" DP, Dbl Pin XO, 9-5/8" Scraper, 3- Boot Baskets, Bit Sub, Bumper Sub, Super Jar, Pump Out Sub, 12 jts 6" DC's, Bowen Intensifier Jar. Total BHA Length 1168.66' DECOMP RIH with Clean Out BHA on 4" DP from Derrick to 12302' DECOMP Screw in top drive and attempt to circulate. Found pipe plugged. Pressured up to 2500 psi within 3 bbls. Pressure up on pipe a second time to 2500 psi and bleed off quickly still not able to circulate. Pick Up and then RIH, try to shake loose. Able to circulate. Circulate drill pipe volume to confirm clean of obstructions. Circulate at 7 bpm and 1480 psi. DECOMP M I U Stand 117 and RIH, tag top of liner at 12364'. M I U to top drive, P I U full stand length, wash and ream to top of liner at 12364'. Pump rate 7.0 bpm at 1400 psi. Circulate 100 bbls to ensure liner top is clean. DECOMP M I U next stand of DP and enter liner. Wash and Ream entire liner from 12364' to 13102' at 6.7 bpm and 1300 psi, 20 rpm's and 6000 ft-Ibs torque with 0-3000 Ib weight on mill. No significant obstructions or fill seen. Experienced no significant fluid losses while cleaning out liner section. Pumped one 40 bbl Hi-Visc Sweep at top of liner and one 20 bbl Hi-Visc Sweep at end of clean out run. With mill at 13102',9-5/8" Casing Scaper at 12364'. DECOMP Circulate surface to surface 20 bbl Hi-Visc Sweep at 8.4 bpm and 2000 psi. First Hi-Vise Sweep came back very dirty, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ---...-" 9/30/2005 04:00 - 05:30 1.50 FISH P 05:30 - 06:30 1.00 FISH P 06:30 - 14:00 7.50 FISH P 14:00 - 16:00 2.00 FISH P DECOMP DECOMP DECOMP 16:00 - 16:30 0.50 FISH P 16:30 - 17:30 1.00 CLEAN P 17:30 - 22:30 5.00 BOPSUF P 22:30 .. 23:00 0.50 BOPSUFP 23:00 - 00:00 1.00 BOPSUF P 10/1/2005 00:00 - 03:30 3.50 BOPSUF P 03:30 - 04:30 1.00 BOPSUF P 04:30 - 05:00 0.50 BOPSUF P 05:00 - 08:00 3.00 CLEAN P DECOMP DECOMP DECOMP 08:00 - 12:30 12:30 - 13:00 4.50 CLEAN P 0.50 CLEAN P 13:00 - 14:00 1.00 CLEAN P 14:00 - 15:30 1.50 CLEAN P 15:30 - 17:30 2.00 CLEAN P Spud Date: 10/17/1988 End: 10/4/2005 Printed: 10/10/2005 11 :34:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Exploration Operations Summary Report Page 13 of 14 Z-31 Z-31 WORKOVER DOYON DRILLING INC. DOYON 16 8/19/2005 10/4/2005 Spud Date: 10/17/1988 End: 10/4/2005 Start: Rig Release: Rig Number: , I Phase j Date ! From - To : Hours _... ....._.._______.____. ..__u___.._.. 10/1/2005 15:30 - 17:30 17:30 - 00:00 10/2/2005 00:00 - 04:00 04:00 - 08:00 08:00 - 09:00 09:00 - 10:30 10:30 - 15:30 15:30 - 16:30 16:30 - 17:30 17:30 - 00:00 Task: Code i NPT Description of Operations ___n___.._n .1.__ ......_n____ .--- ._u_ n_.._..____... 2.00 CLEAN P DECOMP mostly just schmoo I mung from the well, little solids. Second Sweep came back clean. Circulate a total of 870 bbls. DECOMP Monitor Well. B I 0 and BID Top Drive. POOH, Laying Down DP t/6321' DECOMP Lay Down Drill Pipe fl 6321' t/1168' DECOMP C I 0 Handling Equipment, Lay Down BHA DECOMP Clean and Clear Rig Floor. R I U Tubing Handling Equipment. DECOMP E-Line on Location. PJSM on E-Line Procedures and Operations. R I U E-Line Sheaves, line wiper I pack-off, and USIT Tool. DECOMP RIH with USIT Logging Tool. Log from Top of Liner to 5000' MD, in both cement and corrosion mode. Very liitle Corrosion seen in log interval, max corrosion found 8%. Very good quality cement found from TOL to -9600', above this cement quailty begins to decrease. No Top of Cement found in log interval. DECOMP POOH with E-Line and RID. RUNCMP Clear Rig Floor. Pull Wear Ring. Rig Up of Tubing Handling Equipment. RUNCMP Make up and run WLEG, XN nipple assembly with RHC plug installed, ran 5 joints of 4.5" 12.6# L-80 tc-II tubing, X nipple assembly, Baker S-3 Packer, X nipple assembly. Baker Lok all connections below Packer, make Up to 3850 ft-lbs Optimal Torque. Run 4.5" 12.6# L-80 TC-II completion per running detail, Torque turn all connections, use Jet-Lube pipe dope. Backed out and Re-torque several joints due to improper makeup. Inspect pin ends on pipe in shed, all appeared to have surface rust on the first two or three threads and seal area. Clean pin ends in pipe shed as pipe is being picked up. Replaced joint # 18 due to damaged lip seal on pin. Continue running 4.5" completion to 2,520' Run 4.5" TC II, 12.6#, L-80 Tubing f/2,520' t/12,362'. Cleaning surface rust off of pins in the pipeshed. Had to backout, clean and re-torque several connections due to improper make-up. M / U Tubing Hanger and Landing Joint to Completion String. Up Weight 155,000 Ibs. Down Weight 115,000 Ibs. Land Hanger and RILDS. Total Depth Run = 12388.5' Rig Hoses and Circulating Head to Landing Joint. Pressure Test to 2500 psi. Reverse Circulate 190 bbls 140 deg F 8.7 ppg KCL brine and 660 bbls 140 deg F 8.7 ppg KCL Brine wI Corrosion Inhibitor. Pump at 3 bpm and 190 psi. PJSM, Spot Little Red, rig up circulating lines to annulus and tubing, test to 4,250 psi. Reverse circulate 155 bbls heated diesel down 9 5/8" x 4.5" annulus @ 2.5 bpm, 225 psi. To freeze protect tubing and annulus to 2,200' Allow diesel to U-tube. Bleed off pressure, blow down circulating lines. Drop 1 7/8" rod and ball. Back out and lay down landing joint. Rig up to pump down tubing with Little Red. Pressure up on tubing to 2,500 psi, to set packer hold for 5 min. Continue pressure up to 4,000 psi for tubing test, hold for 30 min, record on chart. Bleed tubing pressure to 2,000 psi. Switch valves and 6.50 CLEAN P 4.00 CLEAN P 4.00 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 5.00 EVAL P 1.00 EVAL P 1.00 RUNcmfP 6.50 RUNcmfp 1 0/3/2005 00:00 - 13:30 13.50 RUNCorfP RUNCMP 13:30 - 14:30 1.00 RUNCm 1P RUNCMP 14:30 - 19:30 5.00 CLEAN P SURE 19:30 - 20:00 0.50 WHSUR P WHDTRE 20:00 - 21 :30 1.50 WHSUR P WHDTRE 21 :30 - 22:00 0.50 WHSUR P WHDTRE 22:00 - 22:30 0.50 ZONISO P OTHCMP 22:30 - 00:00 1.50 ZONISO P OTHCMP Printed: 10/10/2005 11 :34:43 AM BP Exploration Operations Summary Report Page 14 of 14 Legal Well Name: Z-31 Common Well Name: Z-31 Event Name: WORKOVER Start: 8/19/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 10/4/2005 Rig Name: DOYON 16 Rig Number: _Date __ [ F~om ~_TO J HOU~=J T~Sk I COd~. i NPTJ Phas:" -.-__ Descrip~i.o_n of_?per~~ions '" .____ 10/3/2005 22:30 - 00:00 1.50 ZONISO P OTHCMP pressure up on annulus to 4,000 psi to test packer, hold for 30 min record on chart. John Crisp with AOGCC waived witness of Tubing and IA test. Complete IA test, bleed annulus and tubing pressure to zero. Install TWC and test from the top to 1,000 psi wI Little Red ok. Rig down Little Red, Suck diesel from BOP stack, blow down circulating lines. Nipple down BOP, drilling nipple. Nipple Up Tree and adapter flange. Test Tubing hanger void, body seals, ring gasket, and LDS to 5000 psi for 30 minutes. Pressure Test Tree to 5000 psi for 30 minutes. Rig Up DSM Lubricator and Pull TWC. Set BPV. RD DSM Lubricator, secure well, and install gauges. Rig Released at 09:00 hrs. 10/4/2005 00:00 - 00:30 0.50 ZONISO P OTHCMP 00:30 - 01 :30 1.00 ZONISO P OTHCMP 01 :30 - 02:00 0.50 BOPSUF P WHDTRE 02:00 - 03:30 1.50 BOPSUF P WHDTRE 03:30 - 06:00 2.50 WHSUR P WHDTRE 06:00 - 06:45 0.75 WHSUR P WHDTRE 06:45 - 08:00 1.25 WHSUR P WHDTRE 08:00 - 08:30 0.50 WHSUR P WHDTRE 08:30 - 09:00 0.50 WHSUR P WHDTRE Spud Date: 10/17/1988 End: 10/412005 Printed: 10/10/2005 11 :34:43 AM Well: Field: API: Permit: Z-31 Rig Workover Prudhoe Bay Unit 50-029-21871-00-00 188-112 I 305-237 I 305-257 Accept: Spud: Release: Rig: 09/23/05 NIA 1 0104105 Doyon 16 POST RIG WORK 1 0/14/05 PULLED BALL AND ROD FROM 12350' SLM. PULLED RHC FROM 12353' SLM. DRIFT WI 2-7/8" DUMMY GUN, TEL, SB-LOC TTL AT 12369' SLM +18' TO 12387' MD. TAGGED BOTTOM AT 13149' MD, 65' RAT HOLE FROM BOTTOM PERF AT 13084' MD. 1 0/18/05 PERFORATE INTERVAL 13058' - 13084', 27/8" PJ 2906, API ENT HOLE: 0.36", API PEN: 27.7" TIE INTO CBT DATED 11/15/88. 1 0/19/05 PERFORATE TWO INTERVALS: 13032' - 13046', 13002' - 13022'. GUN #1: CCL STOP DEPTH = 13022.67' - PERFORATED INTERVAL = 13032' -13046' GUN #2: CCL STOP DEPTH = 12998.6' - PERFORATED INTERVAL = 13002' - 13022' 10/20/05 PERFORATE 2 7/8" POWERJET INTERVAL 12967' - 12992'. TIED INTO SLB - CEMENT BOND LOG 15-NOV- 88. 10/21/05 RAN 4.5 WIRE BRUSH AND 3.81" GAUGE TO NIPPLE AT 2090 SLM. 10/22/05 SET 4112 MCX AT 2088 SLM SERIAL#MN-14 WI 1 3/16 BEAN. MCX HAS X-EQUALIZING DEVICE. RAN 4 1/2" CHECK SET TOOL TO 2088' SLM, TOOL SHOWS GOOD SET. TREE = WELLHEAD = ACTUA OR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum ND = 3" MCEVOY MCEVOY OTIS 91.46' 55.46' 1500' 57 @ 5500' 12889' 8800' SS 113-3/8" CSG, 68#, L-80, ID = 12.415" H 2946' Minimum ID = 3.75" @ 12376' 4-1/2" HES XN NIPPLE TOPOF 7" LNR H 12381' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 12388' 19-5/8" CSG, 47#, L-80. ID = 8.681" H 12641' PERFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CST ON 11/15/88 ANGLEATTOPPERF: 40@ 12857' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12857 - 12897 0 09/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 2-7/8" 6 12967 - 12992 0 10/21/05 5" 4 13002 - 13022 S 08/06/01 2-7/8" 6 13002 - 13022 0 10/21/05 5" 4 13032 - 13046 S 08/06/01 2-7/8" 6 13032 - 13046 0 10/21/05 2-1/8" 4 13058 - 13084 S 08/06/01 2-7/8" 6 13058 - 13084 0 10/21/05 I PBTD H 13210' 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 13251' DATE 11/16/88 12/20/04 10/03/05 08/13/01 09/06/01 03/06/05 REV BY COMMENTS ORIGINAL COM PLETION SRB/TLH RWO MJA RWO SRB/TP SOZ ÆRFS CWS/TLH ADD PERFS VVTLH PERF CORRECTIONS (12/08/04) Z-31 I SAFETY NOTES: 2105' -14-1/2"HESXNIP,ID=3.813" I 12073' -14-1/2" HES X NIP, ID = 3.813" I 12103' -19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 12136' -14-1/2"HESXNIP,ID=3.813" I 12376' -14-1/2"HESXNNIP,ID=3.75" I \'l3æ' ~ -14-1/2" WLEG, ID = 3.958" I H ELMD TT NOT LOGGED I 12754' -1 MARKER JOINT I 13102' -1 FILL (10/2/05) I DA TE REV BY COMMENTS 10/15/05 SGS/PJC DRLG DRAFT CORRECTIONS 10/21/05 RWL/PJC ADÆRFS PRUDHOE BAY UNrr WELL: Z-31 PERMrr No: "1881120 API No: 50-029-21871-00 SEC 19, T11N, R12E, 714' FNL & 3644' FEL BP Exploration (Alaska) '( ;~ ~l7\ ~ f? 'I\-\ ~~ ~>, J l:¡ ;///1 '~" 11:1 :1:s \~It .I iJ) :'; :1:1 l1U LJ LILi U ~ ~n'ì t'~-'I 'r i :\ I ,¡ 'I :1 :\I.¡\ ;::J :IU: ]:1 \;~-;-'") ',~ ¡-1, -:-<)1' \ ï7\'~ n(l"r' l.'~ \ I ,I} 'I ,[ U ':11, ..' ~ 1 ~\ \., ':) ;. ) ~, '\. ':, ~I .,11 '\ .I ! :1 i\ Ii i ! J \ ", '\, :, ¡ \ j' il'l i' J..:J,: i " W: \' J ~\ '-I .' :!...!\ j j"\ \1 L, / l'l \ ru) \1 j\ \ U1 :r-\,'1 :!.:r.J .-.J, ~.J.U ::-J ',____ ;~ .\...J,' w " I / ? ì .ir! ! i / ¡ FRANK H. MURKOWSKI, GOVERNOR Al'tASIiA OIL AND GAS CONSERVATION COMltlISSION 333 W. 7'H AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PaulChan Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 VJ~./\\~ Re: Prudhoe Z-31i Sundry Number: 305-257 .S~·'(~~H;'~~'£"\ (~CD ¡:ìì ..¡ ?rJrJ'I~ J;...J' ~~"Ct' ·~.B·';'f~~i!~,L.lI" 1,:,':ll:~~ II",,,! .jl" toO.' f...,'! Dear Mr. Chan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely i~ it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, John K. Norman Chairman DATED thi~ day of August, 2005 Encl. Cf4 fl, 3/- ()t{. W {)/"r S I ~ 'I ¿(Joe:;; {' STATE OF ALASKA 1::::>'7 { 8/3/ Is' ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ,AUG 3 {) 2005 20 AAC 25.280 I ~ 1 ¡. 1. ' : , ~,,~....: ..: ~. ,.....-.' 1. Type of Request: 0 Abandon 0 Suspend 181 Operation Shutdown 0 Perforate 0 Other ,_::. -' o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic IBI Service / 5. Permit To Drill Number 188-112/305-237 /' 6. API Number: 50-029-21871-00-00 / 99519-6612 KBE = 91.5' 9. Well Name and Number: PBU Z-31i / 8. Property Designation: ADL 047450 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Effective ~3e¿1~MD (~): IEffective~;~~ TVD (It): Plugs \~~;~Ured): Size .' . ·MD.TVD BUrst Junk (measured): None Collapse 11. Total Depth MD (ft): 13251 Cåsing Structural . Conductor Surface Il")termedia\e Production Liner Total Depth TVD (ft): 9161 Length 110' 20" 110' 1101 2946' 13-3/8" 2946' 2693' 4930 2270 12641' 9-5/8" 12641' 8707' 6870 4760 870' 7" 123811 - 13251' 8521' - 9161' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): 12857' - 12967' 8867' - 8951' Packers and SSSV Type: 9-5/8" x 3-1/2" TIW "HBBP' packer Tubing Size: 3-1/2",9.2# Tubing Grade: Tubing MD (ft): L-80 12303' - 124261 Packers and SSSV MD (ft): 12319' 12. Attachments: IBI Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch ,.....\ /" / Au9~005 f\ "J is true and correct to the best of my knowledge. Title Drilling Engineer 13. Well Class after proposed work: r' o Exploratory 0 Development IBI Service 15. Well Status after proposed work: o Oil / o Gas IBI WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Paul Chan, 564-5254 ~.~ Phone 564-5254 êømffil$$IQh.·...I;jS.ij··.·.Q~I.y·.·.··'· Date ~('3 O/I>!" Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness ; '\,':, ':" :'.: ':.';; :\::.:, :':',;::.: .::',:;', ':,,',',:,:;, :;.':'; ,',:; :':(::' ',,:' :<:":':,}':i/::; ;,::'-.';; I~~~~~~~~~~r :..::; .~,~- ;;) S? o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: Tf ~t- K ß Y RBDMS BFL SEP () 1. 2005 Approved By Form 10-403 COMMISSIONER l') P "¡ l \~ APPROVED BY THE COMMISSION ! L_.", Date Øi¿~[ ( (' ^J'·~O.' .'~: Ill:;. ......... ..... .~ GtJJ· ~ 1!tIA.." .<.' ~.."'!' L~ .' " .... ....... . . ' ~~.~ð/l')t "/··/·/(}};",r·./}'~;,,{',i~.'..".'.·..',·'.it >' , .J;Ø¡.¡ lJ.:.lJ - ..'- . ..... ',Oif' '"~J' Z-31 Proposed temporarv suspension of operations 1. Attempt to rotate the K anchor out of the TIW packer. Otherwise release grapple from SBR. 2. POOH and LO excess HWOP and collars. 3. RIH with bit x scraper to -12200' MD. Circulate hole clean. POOH. 4. RIH with HES RBP and set at -121501 MD. Pressure test RBP. POOH LDOP. 5. RIH with -21004-1/2" TC-II. Running order for tubing should be WLEG, joint of tubing, XN nipple, tubing to hanger. 6. Freeze protect well. Set BPV. ROMO. TRff = WELLHEAD = . ACTUATOR = KB. ELEV = BF. B..EV = KOP= '" Max Angle = Datum MD = Datum1VD= 3" MCEVOY MCEVOY OTIS 91.46' 55.46' 1500' 57 @ 5500' 12889' 8800' SS L-31 Current Condit.vn DATE REV BY COMMENTS 03/06/05 VVTLH ÆRF CORRECTIONS (12/08/04) 113-3/8" CSG, 68#, L-80, 10= 12.415" l-i 2946' ~ ( ì ~ ~ TOPOF 7" LNR l-i 12381' 1 I ~ ~ , - J 1 - 19-5/8" CSG, 47#, L-80, 10 = 8.681" l-i 12641' µ ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLEATTOPPERF: 40 @ 12857' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12857 - 12897 0 09/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 ! I I PBTD l-i 13210' 1 17" LNR, 26#, L-80, .0383 bpf, 10 = 6,276" l-i 13251' 1 ..... DATE 11/16/88 12/20/04 08/13/01 09/06/01 03/15/03 12/11/04 REV BY COMMENTS ORIGINAL COM PLETION SRBlTLH RWO SRB/TP SQZ ÆRFS CWS/TLH A DO PERFS JJ/TLH SAFE1Y NOTE (X NIPFt.E) JRA/TLP SLUGGITS/IBP/FASDRILLlCHEMCUT ~ 12303' I-tTW SBRSEAL ASSEMBLY 1 12319' 1-i9-5/8" X 3-1/2" TIW HBBP PKR, 10 = 2.992" 12322' 1-i2..1/2" BAKER 18P, 12/04/04 1 12345~ 1-i:3..1/2" HES FASDRILL PLUG 12/03/04 12361' 1-i3-1/2" OTIS X NIP, 10 = 2,750" 1 12394' 1-i3-1/2" OTIS X NIP, 10 = 2,750" 1 12426' 1-13-1/2" TBG TAIL 1 ~ I 12754' 1-1 MARKER JOINT PRUDHOE BA Y UNIT WELL: Z-31 PERMIT No: 1881120 API No: 50-029-21871-00 SEC 19, T11N, R12E, 714' FNL & 3644' FEL BP Exploration (Alaska) TR~= WELLHEAD = ~. A CTUA TOR = KB. ELEV = BF. ELEV = KOP= ' Max Angle = Datum MD = Datum 1V D = 3" MCEVOY MCEVOY OTIS 91.46' 55.46' 1500' 57 @ 5500' 12889' 8800' SS z-~ Suspension of dJerations ,;' 2946' L: ~/ . 1/ -2060 1-i4-1I2" HES XN NIP .--' 113-3/8" CSG, 68#, L-80, ID = 12.415" l-i ~ I -2100 1-i4-1/2" WLEG 14-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3,958" 1- I TOP OF 7" LNR l-i 12381' 1 -12150 l-i HES 9-5/8" RBP ./ ( ì I 12303' I-iTIVV SBR SEAL ASSEMBLY ~>< I 12319' l-i 9-5/8" x 3-1/2" TIVV HBBP PKR, ID = 2.992" I 12322' 1-i2..1/2" BAKER IBP, 12/04/04 1 ~~ 12345' l-i 3..1/2" HES FASDRILL PLUC 12!O~3¡O4 ! , I 12361' 1-i3-1/2" OTIS X NIP, ID = 2.750" I I 12394' 1-i3-1/2" OTIS X NIP, ID = 2.750" 1 i I I 12426' l-i 3-1/2" TBG TAIL 1 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 12641' µ ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLEATTOPÆRF: 40 @ 12857' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12857 - 12897 0 09/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 ! I 12754' I-iMARKERJOINT I I PBTD l-i 13210' 1 17" LNR, 26#, L-80, .0383 bpf, ID = 6,276" l-i 13251' 1 ~ DA TE REV BY COMMENTS 11/16/88 ORIGINAL COMPLETION 12/20/04 SRB/TLH RWO 08/13/01 SRB/TP SQZ ÆRFS 09/06/01 CWS/TLH ADD ÆRFS 03/15/03 JJ/TLH SAFETY NOTE (X NIPPLE) 12/11/04 JRA/TLP SLUGGrTS/IBP/FASDRILLlCHEMCUT DA TE REV BY COMMENTS 03/06/05 V VTLH ÆRF CORRECTIONS (12/08/04) PRUDHOE BA Y UNIT WELL: Z-31 ÆRMIT No: 1881120 API No: 50-029-21871-00 SEC 19, T11 N, R12E, 714' FNL & 3644' FEL BP Exploration (Alaska) ~ r1\J~.·.:n.J..:.l·~. ....1 , !.r.,:~:"'.'\.,l"1 F.' 1~',.1 ;.' .. ;., ~I' ,p .~ il:I' rù\ " -I I J /J \ ·1 1· . :. :11 1;--1\ ,U'" .1 , ' LJ J=Jw " .L..,. ("('1'. ';¡ .!' l' ,11:: L I ;1 '! II ,:-J t tJ i ii ~ ,\.., iT" n i7\ (~ì. n Or;':\ I :'" \ I 'I' I :., 1\ ~ J, ,,-".1 !I/.,I ..1 .:-1 '. 'r'i" I"~, '" ','! I ¡'\\ ! jj. ,II J ;]:. "", J \ \ J ,¡ .\ / ,~.~ ;1 i l ¡~ -\ r! .'\) : ~!" "'\ /,~ ", LJ U L::.J LI \j ~~¡ UÜ L.J d 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION PaulChan Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 \tt~ ... \ \ 'J- Re: Prudhoe Bay Z-31i Sundry Number: 305-237 SÇ/\NNEì.:) l~UG } 7, 2005 Dear Mr. Chan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on holiday or weekend. A person may not appeal a Commission decisi Superior Court unless rehearing has been requested./ ¡fu' ( Gn JO~1.I?- K/"Norman CH~an DATED this/Þ day of August, 2005 Encl. tJZl 8 ·'¡h~d5 w ()/\ ß /liD{ v'o~ ( STATEOFALAS~ p~ (,,¡,s RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 6 Z005 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Commission Anr.horag.e 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other ________.__ o Alter Casing / II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic !HI Service / 5. Permit To Drill Number 188-112 ./ 6. API Number: ./ 50- 029-21871-00-00 99519-6612 KBE = 91.5' 9. Well Name and Number: PBU Z-31 i ./ 8. Property Designation: 11. Total Depth MD (ft): 13251 Casing Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): 9161 13210 9131 12322 Length Size MD TVD Burst Junk (measured): None Collapse ADL 047450 110' 20" 110' 110' 2946' 13-3/8" 2946' 2693' 4930 2270 12641' 9-5/8" 12641' 8707' 6870 4760 870' 7" 12381' - 13251' 8521' - 9161' 7240 5410 Perforation Depth MD ~): Perforation Depth TVD (ft): Tubing Size: 12857' - 12967' 8867' - 8951' 4-1/2", 12.6# x 3-1/2·, 9.2# Packers and SSSV Type: 9-5/8" x 3-1/2" TIW "HBBP' packer; 9-5/811 x 4-1/2" Baker 'S-3' packer; 4-1/2" HES IX' Nipple Tubing Grade: Tubing MD (ft): L -80 12426' Packers and SSSV MD (ft): 12319',12199'; 2266' 12. Attachments: !HI Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for t'1 15. Well Status after proposed work: Commencing Operations: Augu ~/2005 0 Oil 0 Gas 0 Plugged 16. Verbal Approval: q~, : !HI WAG 0 GINJ 0 WINJ Commission Representative: ~^ ./ 17. I hereby C8(liI..Y tila.l.\he foregoing .~. true and correct to the best of my knowledge. Printed Nam\ P~Chr"l / Title Drilling Engineer Signature Js;;: ~ ~ Phone 564-5254 Date ~11{PI{)ç , Commission Use Only 13. Well Class after proposed work: / o Exploratory 0 Development !HI Service o Abandoned o WDSPL Contact Paul Chan, 564-5254 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity [!('BOP Test ~echanicallntegrity Test 0 Location Clearance I Sundry Number: ~~- til.37 O M:r..T r-tb~ ~ d , ther: r€~-t J~ \ E SUb~M b- 4 ( ( ~ Approvt;:J Dy ~ /. ._L': / Form 10-403 Revised 11ì~ f f~ . RBDMS BFL AUG 1 7 20U5 COMMISSIONER APPROVED BY THE COMMISSION Date ~~ '- L' ,:7\ 'AL " I : . . I' I~'\: \ .l11\(0't~\J l \ { O;~4'A'¡¡" ' ;j;.'................ .......,'...... J·D·.·., ã:.: ,i' . _ --",,: '..¡ GE~;. t.i. ~t/' .~'·,f 1Il;l', ;,.: . ~4.l!t!li>··f1·/,L::···.l£i~·;i;(JV Z-31 proposed RiQ Workover Procedure ./ 1. MIRU. NO tree. NU and test BOPE to 4000 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-1/2" tubing string to the cut at +/- 12195' MD. 3. Mill and recover the Baker S-3packer. /' 4. Recover TIW PBR seal assembly and latch. 5. Mill and recover the TIW HBBP packer. /' 6. RIH with bit x scraper to TOL at 12381' MD. 7. Run USIT log from TOL at 12381' MD to 11800' MD to confirm cement behind 9-5/8" casing. -- 8. RIH with RTTS to 12150' MD and test casing to 4000 psi for ,30 minutes. Note: If casing does not pressure test, a 7" scab/tieback liner may be run. /' 9. RIH with 6" bit and cleanout to 13100' MD. 10. Run 4-1/2" L-80 TC-II premi,um connection completion with packer and standard tailpipe. Set packer at -12100' MD. / 11. Displace the IA to packer fluid and set the packer. 12. Test tubing to 4000 psi, test annulus to 4000 psi. Freeze protect to 2200' MD. 13. Set BPV. NO BOPE. NU and test tree. RDMO. TREE = WELLHEAD = ACTUATOR = KB. B...EV = BF. B...EV = kop= ,~x Angle = Datum MD = Datum lVD = 3" MCEVOY MCEV OY OTIS . 91.46' 55.46' 1500' 57 @ 5500' 12889' 8800' SS 113-3/8" CSG, 68#, L-80, ID = 12.415" l-i 2946' ~ Minimum ID = 2.750" @ 12361' 3-1/2" OTIS SSSV NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 12265' I TOP OF 3-1/2" TBG STUB l-i 12284' I TOP OF 7" LNR l-i 12381' 13-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" l-i 12426' 19-5/8" CSG, 47#, L-80, 10 = 8.681" l-i 12641' ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLEATTOPÆRF: 40 @ 12857' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12857 - 12897 0 09/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 1 PBTD l-i 13210' I r 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 13251' I DA TE REV BY COMMENTS 11/16/88 ORIGINAL COMPLETION 12/20/04 SRBITLH RWO 08/13/01 SRB/TP SQZ PERFS 09/06/01 CWS/TLH ADD PERFS 03/15/03 JJ/TLH SAFETY NOTE (X NIPPLE) 12/11/04 JRA/TL.P SLUGGITS/IBP/FASDRILL/CHEMCUT Z-31 ~ ~ 51 YNOTES: X NIPPLE@ 12361' WILL NOT HOLLJ PRESSURE (03/15/03). 2266' 1-i4-1/2" HES X NIP, ID = 3.813" I ~ .. I 12178' 1-i4-1/2" HES X NIP, ID = 3.813" I ~ /Z/t¡ç- Wt5A Z :g 1 12199' l-i 9-5/8" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 1 ~ ~ ~ I 12223' 1-i4-1/2" HES X NIP, ID = 3.813" I 1 12244' 1-14-1/2" HES XN NIP, ID = 3.7" I ~ 12265' 1-i4-1/2" X 3-1/2" XO, ID = 2.992" I ì ( 1 12276' 1-i9-5/8" X 3-1/2" UNIQUE OVERSHOT l J I 12303' I-iTIW PBR SEAL ASSEMBLY 1 ~ 1 12319' 1-i9-5/8" X 3-1/2" TIW HBBP PKR, ID = 2.992" 1/ I 12322' l-i 2-1/2" ßAI<ER IBP, 12/04/04 1 1 ~~ 12345' 1-i3..1/2" HES FASDRILL PLUG 12/03/04 ! ~ 1 12361' l-i 3-1/2" OTIS X NIP, 10 = 2.750" I I i 1 12394' 1-i3-1/2" OTIS X NIP, 10 = 2.750" I , . ~ I 12426' l-i 3-1/2" TBG TAIL 1 ---A ~ I 12429' Ii. ELMD TT LOGGED 08/22/91 1 ! 1 12754' l-i MA RKER JOINT I ~ DA TE REV BY COMMENTS 03/06/05 VVTLH PERF CORRECTIONS (12/08/04) PRUDHOE BA Y UNIT WELL: Z-31 ÆRMITNo: 1881120 API No: 50-029-21871-00 SEC19, T11N, R12E, 714'FNL&3644'FEL BP Exploration (Alaska) TREE = W~LHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= 3" MCEVOY MCEVOY OTIS !:11.46' 55.46' 1500' 57 @ 5500' 12889' 8800' 5S Proposed CompLtion ~ ~ Z ~: -~ . \13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 2946' ~ 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1- I TOP OF 7" LNR 1-1 12381' 1 I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 12641' µ ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLEATTOPÆRF: 40 @ 12857' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12857 - 12897 0 09/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 I PBTD 1-1 13210' 1 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 13251' 1 I Z . Z I T I I -2100 1-14-1/2" HESXNIP, ID=3.813" 1 ~ 1-14-1/2" HESX NIP, ID= 3.813" I -12100 1-i9-5/8"X4-1/2"BKRS-3PKR,ID=3.875" 1 /' 1-14-1/2" HES X NIP, ID = 3.813" 1 1-14-1/2" HES XN NIP, ID = 3.7" I 1-14-1/2" TBG TAIL 1 .. I 12754' I-IMARKERJOINT DA TE REV BY COMMENTS 03/06/05 V VTLH ÆRF CORRECTIONS (12/08/04) DA TE REV BY COMMENTS 11/16/88 ORIGINAL COMPLETION 12/20/04 SRBlTLH RWO 08/13/01 SRB/TP SQZ ÆRFS 09/06/01 CWS/TLH ADD ÆRFS 03/15/03 JJ/TLH SA FETY NOTE (X NIPPLE) 12/11/04 JRA/TLP SLUGGrTS/IBP/FASDRILLlCHEMCUT I ~ PRUDHOE BA Y UNrT WELL: Z-31 ÆRMrT No: 1881120 API No: 50-029-21871-00 SEC 19, T11N, R12E, 714' FNL & 3644' FEL BP Exploration (Alaska) , STATE OF ALASKA ..... ALASKA _1 AND GAS CONSERVATION CO~...)ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 91.5' 8. Property Designation: ADL 047450 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): RECEIVED DEC 3 02004 Alaska Oil & Gas Cons. Commis Anchorage 0 Other 0 Time Extension 0 Repair Well 0 Plug Perforations 0 Stimulate iii Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 13251 9161 13210 9131 110' 2946' 12641' 870' 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic iii Service 5. Permit To Drill Number: 188-112 6. API Number: 50-029-21871-00-00 9. Well Name and Number: PBU Z-31i 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 12345' feet Junk (measured) None feet Size MD TVD Burst 20" 110' 110' 13-3/8" 2946' 2693' 4930 9-5/8" 12641' 8707' 6870 7" 12381' - 13251' 8521' - 9161' 7240 Collapse 2270 4760 5410 12857' - 12967' 8867' - 8951' SCANNED JAN 0 5 'Lüü5 4-1/2", 12.6# x 3-1/2", Tubing Size (size, grade, and measured depth): 9.2# Packers and SSSV (type and measured depth): 9-5/8" x 3-1/2" TIW "HBBP' packer; 9-5/8" x 4-1/2" Baker 12319', 12199'; 'S-3' packer; 4-1/2" HES 'X' Nipple 2266' 12. Stimulation or cement squeeze summary: Intervals treated (measured): L-80 12426' Treatment description including volumes used and final pressure: RBDMS BFL JAN 0 ~ 2005 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run iii Daily Report of Well Operations iii Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 0 Development iii Service 16. Well Status after proposed work: 0 Oil 0 Gas iii 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 Rob Tirpack, 564-4166 304-466 Printed Name Terrie Hubble Title Technical Assistant Signature ~lV1.Ì-e ¿d)~- Form 10-404 Revised 04/2004 Phone I ':) I . h Prepared By Name/Number: Date """13'01 D<{ Terrie Hubble, 564-4628 Submit Original Only 564-4628 ORIGINAL ) Well: Field: API: Permit: 2-31 RWO Prudhoe Bay Unit 50-029-21871-00-00 188-112 Accept: Spud: Release: Rig: 12/13/04 N/A 12/18/04 Nabors 7ES PRE-RIG WORK 11/26/04 RAN 2.70 CENT, SB TO 2071' (SLM). PULL 31/2 MCX FROM 2071' (SLM). (SER. MP3-05) RAN 2.700 CENT & SB TAG BOTTOM @ 13,103' SLM TARGET DEPTH WAS 12,400. 12/03/04 SET 3-1/2" HES FASTDRILL PLUG AT 12345'. PRESSURE TEST OF TUBING TO 4000 PSI, DID NOT HOLD. 12/04/04 SET BAKER 2.5" IBP MID-ELEMENT AT 12322.4' INSIDE PACKER. TOP OF IBP AT 12315.28'. JOB COMPLETE. 12/06/04 DUMP BAILED 50# SLUGGITS ON IBP @ 12315' ELM. 12/07/04 PERFORMED STRING SHOT, TUBING PUNCH AND CHEM CUT. CHEM CUT MADE AT 12284 ELMO. 12/11/04 SET A 3" BPV PRIOR TO THE RIG MOVING ON. ) ) BPE*pIQr~tJÒh Operation$~~m(;I'J~rý<Repo rt räge'1<öf3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-31 2-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 12/10/2004 Rig Release: 12/18/2004 Rig Number: Spud Date: 10/17/1988 End: Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2004 06:00 - 07:30 1 .50 MOB P PRE Blow down steam and water lines in pits, disconect service lines, move cuttings tank, prep mits to move. 07:30 - 09:30 2.00 MOB P PRE Prep sub for move, move pits around corner to Z-31, move sub off Z-13, pickup mats and herculite. 09:30 - 12:00 2.50 MOB P PRE Move Camp and shop around corner, spot camp and shop. 12:00 - 14:00 2.00 MOB p, PRE Move and spot sub on Z-31, level rig, spot pits and cuttings tank. 14:00 - 15:00 1.00 RIGU P PRE Connect service lines, R/U DSM lubricator and pull BPV, 0 pressure on tubing and annulus. 15:00 - 16:30 1.50 WHSUR P DECOMP Take on seawater in pits, rig up lines to reverse diesel from tubing and annulus, test lines to 3,500 psi. Accept rig at 15:00 hrs 12/13/2004 16:30 - 21 :30 5.00 WHSUR P DECOMP Reverse circulate diesel from tubing, @ 3 bpm 170 psi, pumped 70 bbls before getting clean seawater back. switched over to pump down tubing, pumped 250 bbls at 3 bpm, 350 psi down tubing before seeing clean seawater, increased rate to 6 bpm, 1,125 psi, pumped a total of 868 bbls. 21 :30 - 22:00 0.50 WHSUR P DECOMP Monitor well, install TWC and test from below to 1,000 psi. 22:00 - 23:30 1.50 WHSUR P DECOMP Nipple down tree and adapter flange, function LDS, replace one LDS, inspect lifting threads on tubing hanger. 23:30 - 00:00 0.50 BOPSUR P DECOMP Nipple up BOP, add 2' section to drilling nipple. 12/14/2004 00:00 - 02:00 2.00 BOPSUPP DECOMP Nipple up BOP, choke and kill line, install drilling nipple. 02:00 - 03:00 1.00 BOPSUP P DECOMP Rig up BOP test equipmnet, make up test joint, fill stack and choke manifold. 03:00 - 06:00 3.00 BOPSUR P DECOMP Test BOP's per Nabors testing procedure, 250 psi low, 3,500 psi high, John Chrisp with AOGCC waived witness of the test. Unable to test lower pipe rams at this time. 06:00 - 07:30 1.50 PULL P DECOMP Rig up DSM lubricator and pull TWC, rig down lubricator. 07:30 - 08:30 1.00 PULL P DECOMP Make up landing joint back out lock down screws, pull hanger to floor, up wt 140k. 08:30 - 10:00 1.50 PULL P DECOMP Circulate bottoms up 10 bpm @ 1800 psi. monitor well, static. 10:00 - 11 :00 1.00 PULL P DECOMP Pump dry job, blow down topdrive, UD tubing hanger and landing joint, 11 :00 - 00:00 13.00 PULL P DECOMP Lay down 65 joints 3.5" 9.2# L-80 tubing, spooling up control line, lay down SSSV, recovered 32 control line clamps and 4 SS bands, UD control line spool. Continue to Lay down 3.5" tubing, 325 joints Losses for past 24 hrs = 28 bbls. 12/15/2004 00:00 - 04:00 4.00 PULL P DECOMP Lay down 3.5" 9.2# L-80 tubing, recovered a total of 381 joints, plus 14.8" cut off joint, 6 GLM's, 1 SSSV, 1 sliding sleave. Clean cut on the tubing stub. 04:00 - 05:00 1.00 PULL P DECOMP Clear floor of all tubing handling equipment, clean floor. 05:00 - 06:30 1.50 BOPSUPP CLEAN Install test plug, rig up BOP test equiment, test upper and lower rams to 250 psi low, 4,000 psi high. Load pipe shed with BHA and 4" DP. 06:30 - 07:30 1.00 CLEAN P CLEAN Pull test plug and install wear ring, blow down choke manifold, choke and kill lines, 07:30 - 09:00 1.50 CLEAN P CLEAN Slip and cut drilling line. Inspect and adjust brakes. 09:00 - 10:00 1.00 CLEAN P CLEAN Service topdrive and rig. 10:00 - 12:00 2.00 CLEAN P SURE Load pipe shed with 4" DP strap & tally DP Losses for last 12 hr = 12 bbls. 12:00 - 14:00 2.00 CLEAN P SURE Strap & Tally 4" DP and BHA, PJSM w/ Baker Rep. Printed: 12/27/2004 8:58:05 AM ) ) fi3PExþl()r~nìÖh Op~ratiØ.n$~~l'11il'11~ry'.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-31 Z-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 12/1 0/2004 Rig Release: 12/18/2004 Rig Number: Spud Date: 10/17/1988 End: Date From - To Hours Task Code NPT Phase Description of Operations 12/15/2004 14:00 - 00:00 10.00 CLEAN P CLEAN Make up clean out milling assembly, 8.5" Shoe, wash pipe extension with dressing mill, XO, 9 5/8" casing srcaper, BS, bumper sub, oil jar, XO, 6 43/4" DC's, XO, RIH picking up 4" DP from pipe shed, picked up 319 joints. Losses for last 12 hrs = 7 bbls. 12/16/2004 00:00 - 03:00 3.00 CLEAN P CLEAN RIH with clean out milling assembly, to 12,270' 03:00 - 04:00 1.00 CLEAN P CLEAN Break circulation and wash down from 12,270', 237 gpm @ 670 psi, set down at 12,272', picked up 10' and rotate down with 40 rpm, torque 5,200 ft/lbs, saw a slight torque and weight increase, at 12,272', set down 3k and fell off, shut down rotary and washed down from 12,272' to 12,278', sat down 10k, Pulled up above tubing stub,and rotate back down to 12,278' set down on stub with polishing mill, polish top of tubing stub. Pump 30 bbl high vis sweep. Up wt = 190k, dn, wt = 145k, rt wt = 165', 04:00 - 05:00 1.00 CLEAN P CLEAN Circulate sweep around, 540 gpm, @ 2740 psi, rotaing string 60 rpm, torque 5,200 ft/lbs, working 9 5/8" scraper from 12,252' to 12,191'. 05:00 - 12:00 7.00 CLEAN P CLEAN Monitor well, pump dry job, blow down topdrive and POH with casing scraper & mill assembly to BHA. Losses for last 12 hrs = 8 bbls. 12:00 - 14:00 2.00 CLEAN P CLEAN Monitor well, Lay down BHA. 14:00 - 20:00 6.00 SIT P CLEAN PJSM, Make up Halliburton 9 5/8" RTTS, RIH to 12,252' 20:00 - 21 :00 1.00 SIT P CLEAN Make up TIW valve on DP, Pull up position and set RTTS @ 12,238', Rig up and pressure test 95/8" casing to 4,000 psi, for 30 min, record on chart, lost 42 psi in 30 min. Release RTTS. 21 :00 - 00:00 3.00 SIT P CLEAN Pump dry job and POH laying down 4" DP. 12/17/2004 00:00 - 10:00 10.00 SIT P CLEAN POH with RTTS laying down 4" DP, setting tool and RTTS. 10:00 - 12:00 2.00 RUNCOMP RUNCMP Pull wear ring, rig up to run 4.5" Completion. PJSM with CO Rep, Toolpusher, Baker Rep and rig crew. Losses for last 12 hrs = 9 bbls 12:00 - 00:00 12.00 RUNCOrvP RUNCMP M/U & run 4.5" 12.6# L-80 TC-II Completion 95/8" X 3.5" Unique Machine Overshot 'XN' Nipple Assy, 'X' Nipple Assy & Baker S-3 Production Packer assembly Run 4.5" 12.6# TC-II Tubing as per running order, to 10,608' (250 jts), Makeup Torque 3,850 ft/lbs. Up wt = 125k, Dn wt = 100k Losses for last 12 hrs = 7 bbls 12/18/2004 00:00 - 02:00 2.00 RUNCOrvP RUNCMP Continue Running 4.5" 12.6# L-80 completion, per running order. 02:00 - 03:30 1.50 RUNCOtvP RUNCMP Make up 10' pup on top of joint # 289, pickup joint # 290 RlU circulating head on joint #290 wash over tubing stub with Unique overshot, 3 bpm, 45 psi, pressure increased to 120 psi, when bottomed out on tubing stub @ 12,281' Shut down pump, RID circulating hose, POH lay down joints 290, 289 & 10' pup, pickup space out pup 7.84' pickup joint # 289, makeup hanger and landing joint, Land tubing. Up wt = 145k, Dn wt = 110k 03:30 - 04:00 0.50 RNTBHG P TUBHGR RILDS, back out landing joint, install TWC. 04:00 - 05:00 1.00 RUNCOfvP RUNCMP Lay down tubing handling equipment, clean floor. 05:00 - 07:30 2.50 BOPSUR P WHDTRE Nipple down BOP & Nipple up adapter flange and tree. 07:30 - 08:30 1.00 WHSUR P WHDTRE Test tree and adapter flange to 5,000 psi. 08:30 - 09:30 1.00 WHSUR P WHDTRE Rig up DSM lubricator and pull TWC, rig down lubricator. 09:30 - 10:30 1.00 WHSUR P WHDTRE Rig up circulating lines and manifold to tree, rig up Little Red, test lines to 4,000 psi. Printed: 12/27/2004 8:58:05 AM ') ') Page 3 of 3 BPExplöratioh Operatiøl1s Sumrt1~rY~E!pørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-31 2-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Date From - To Hours Task Code NPT Phase 12/18/2004 10:30 - 12:00 1.50 WHSUR P WHDTRE 12:00 - 13:00 1.00 WHSUR P WHDTRE 13:00 - 14:30 1.50 RUNCOMP RUNCMP 14:30 - 17:30 3.00 RUNCOMP RUNCMP 17:30 - 18:00 18:00 - 19:00 19:00 - 21 :00 0.50 WHSUR P 1.00 RIGD P 2.00 RIGD P WHDTRE POST POST Start: 12/10/2004 Rig Release: 12/18/2004 Rig Number: Spud Date: 10/17/1988 End: Description of Operations Reverse 535 bbls seawater with rig pumps, treated with 2 drums of corrosion inhibitor down 9 5/8" X 4.5" annulus, 2 bpm @ 780 psi. Reverse 160 bbls diesel with Little Red down 9 5/8" X 4.5" annulus, 3 bpm @ 1,500 psi. U- tube Diesel, Drop ball and rod. Pressure up to 4,000 psi to set and test packer, held for 30 min, record on chart, bled tubing pressure to 1,000 psi, pressure up on annulus to 4,000 psi to test packer, held for 30 min record on chart. Pressure test was done with Little Red. Rig down Little Red. Install SPY. Clean Cellar and secure well. Remove excess fluid from pits and brine tanks. Cut drilling line. Release Rig 21 :00 hrs 12/18/2004 Printed: 12/27/2004 8:58:05 AM ) .) Z-31 i Actual Completion FROM DRLG - DRAFT 13-3/8" CSG, 68#, L-80, ID = 12.415" I, 29461 ~ SAFElY NOTES: X NIPPLE @ 12361' WILL NOT HOLD PRESSURE (03/15/03). Chemical Cut @ 12,272' MD~ IComposite bridge plug @ 12,345' MDI I TOP OF 7" LNR I, 123811 I 3-1/2" TBG, 9.2#, L-80, .0087 bpf. ID = 2.992" I, 124261 I 9-5/8" CSG, 47#, L-80, ID = 8.681" I, 126411 ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLE AT TOP PERF: 40 @ 12914' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2" 6 12857 - 12897 0 09/06/01 2-1/8" 4 12914 - 12942 S 08/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 I PBTD I, 132101 1 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I, 132511 1 DATE REV BY COMMENTS 11/16/88 ORIGINAL COMA..ET1ON 03/14/01 SIS-MD FINAL 05/19/01 RNfTP CORRECTIONS 07/13/01 DACJKAK UPDATEGLV INFO 08/13/01 SRB/TP SOl PERFS 09/06/01 CWS/tlh ADD PERFS I I X Nipple @ 2,266' MD ~ ---- 4-1/2", 12.6#, L-80, TC-II tubing X Nipple @ 12,178' Baker 9-5/8" X 4-1/2" 8-3 Packer @ 12,198' MD X Nipple @ 12,223' XN Nipple @ 12,244' Unique Overshot - 8.23" X 3-1/2" @ 12,276' MD I 123031 1-1 TIW PBRSEAL ASSEMBLY 1 ~ ) r 123191 1,9-5/8" X 3-1/2" TIW HBSP PKR, ID = 2.992" 1 I 123611 1-1 3-1/2" OTIS X NIP, ID = 2.750" 1 I 123941 1-1 3-1/2" OTIS X NIP, ID = 2.750" 1 I I 124261 1-13-1/2" TBG TAIL 1 ~ I 124291 1-1 8.MD TI LOGGED 08/22/91 I T I 127541 1-1 MARKER JOINT 1 I I ~ DATE REV BY COMMENTS 07/13/02 SDF/KK GL V CORRECTIONS 03/15/03 JJ/TlH SAFElY NOTE (X NIPPLE) ffiUDHOE BAY UNIT W8.L: Z-31 ÆRMIT No: 1881120 API No: 50-029-21871-00 SEC 19, T11 N, R12E, 714' FNL & 3644' F8. BP Exploration (Alaska) ) ) ~j~~Œ ~~. ~~~~æ~ I AIfA~KA OILAlO) GAS / CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 tt¿{6/ II: 1,.- Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Z-31i Sundry Number: 304-466 Dear Mr. Isaacson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has. been requested. ~ Daniel T. Seamount, Jr. Commissioner DATED thisZq day of November, 2004 Enc!. SCANNED DEC ü 1 2004 ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 . . W(~ f\- U lz c¡ I Zi,1°t{ 2004 1. Type of Request: 0 Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 10. Field / Pool(s): ADL 047450 Prudhoe Bay Field / Prudhoe Bay Pool . PRgSENT WELL CONDITION $.UMMAR~ Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 9161 13210 9131 None Length. Size MD . . : . TVD BOrst 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 91.5' 8. Property Designation: 11. . Total Depth MD (ft): 13251 Casing Structural Conductor Surface Intermediate Production Liner 0 Other 0 Time Extension 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic 181 Service <' 5. Permit To Drill Number 188-112 / 6. API Number: /' 50- 029-21871-00-00 9. Well Name and Number: PBU Z-31 i ./ Junk (measured): None Collapse 110' 20" 110' 110' 2946' 13-3/8" 2946' 2693' 4930 2270 12641 ' 9-5/8" 12641' 8707' 6870 4760 870' 7" 123811 - 13251' 8521' - 9161' 7240 5410 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Si~nature l 'JL, t \-- Phone 564-5521 Perforation Depth MD (ft): Perforation Depth TVD (ft): 12857' - 12967' 8867' - 8951' Packers and SSSV Type: 9-5/8" x 3-1/2" TIW "HBBP' packer; 3-1/2" Otis SSSV Landing Nipple Nove~2004 Tubing Size: 3-1/2", 9.2# Tubing MD (ft): 12426' Tubing Grade: L-80 Packers and SSSV MD (ft): 12319' 2102' 13. Well Class after proposed work: 0 Exploratory 0 Development 181 Service 15. Well Status after proposed work: 0 Oil /,0 Gas 181 WAG 0 GINJ 0 Plugged DWINJ 0 Abandoned 0 WDSPL Contact Rob Tirpack, 564-4166 Date \'/1.3} o~ Prepared By Name/Number: Terrie Hubble, 564-4628 I Sundry Number: ;SoL( - V&J '" 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test Conditions of approval: Notify Commission so that a representative may witness 0 Location Clearance Other: T€ st.. f?;¡Op E tc .~S"OO r<..,'. Subsequent Form Required: \ 0 .- 4: () 4- ' RBDMS BFL NOV 3 0 2004 APPROVED BY COMMISSIONER THE COMMISSION nOtGi~\~ ~t- Date /l/zc¡l4- Submit In Duplicate . . ') ) To: From: Subject: Charge: Winton Aubert Rob Tirpack Operations Drilling Engineer Z-31 i Pre-Rig Work Request PBD4P2276 - Capitol RWO Date: November 22,2004 Approval is requested to change the tubing out on Z-31. The well is incapable of sustained MI injection due / to slow tubing to inner annulus communication while on MI injection. Z-31 is c,urrently injecting water. The 3- 1/2", L-80, EUE 8rd tubing will be replaced with 4-1/2", L-80, TCII tubing. ,./ Z-31 was drilled and completed in 11/88 and then converted to injection in 7/02. MI injection was started in 1/03. After only 9 days of MI injection, the inner annulus started to increase in pressure. Between 1/03 and 11/03 multiple attempts were made at MI injection, all resulting in communication from the tubing to the inner annulus. The inner annulus currently passes pressure tests with liquid with no problem. / Z-31 will provide pressure support and sweep for offset producers Z-32B, Z-27, Z-19 and the recent sidetrack at Z-30A. Incremental reserves for MI injection over water injection are substantial. Pre-RiQ Work Reauest: NOTE: The composite bridge plug should be installed no sooner than 2 weeks prior to the rig move. Due to the composition of the plug, deterioration and subsequent weakening of the plug could be ("/ experienced. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 0 Shut-in water injection. Allow SI pressures to stabilize, fluid pack and freeze protect T and IA. E RU E-line. Make GR/JB run to WLEG at 12,429' MD. E RIH with 3-1/2" composite bridge plug. Set at - 12,345' MD. 0 Pressure test tubing to 4000 psi to verify that the bridge plug is holding. / E RU E-Line. Chemical cut tubing at -12,284' MD. 0 Freeze protect with diesel to 2200' TVD. 0 Test the 9-5/8" pack-off and tubing hanger seals to 5000 psi. MITOA. / 0 Function all lock-down screws. Repair or replace as needed. 0 Bleed casing and annulus pressures to zero. 0 Set a BPV in tubing hanger. Secure well. 0 Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU Nabors 7ES /' 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. ,./ 4. Pull 3-1/2", 9.2#, L-80 tubing from chemical cut at -12,284' MD. 5. RIH with casing scraper and dress mill. 6. Work casing scraper over new packer setting depth. Dress 00 and 10 of tubing stub. looks flared, dress top of tubing stub. 7. Circulate clean with seawater. POOH. 8. PU and run 4-1/2",12.6#, L-80, TCII completion with Unique Overshot. If chemical cut ) ) 9. Engage tubing stub with overshot and land tubing in hanger. Confirm engagement of overshot with /" pump pressures. 10. Set and test TWC. . 11. ND SOPE and NU Tree. Test tree to 5,000 psi. / 12. Pull TWC. Circulate in corrosion inhibitor. U-tube diesel freeze protect to 2,200' TVD. 13. Pressure up tubing to set packer. Test tubing to 4,000 psi for 30 minutes. Test annulus to 4,000 psi for 30 minutes. / 14. Set SPY. 15. RDMO. Post-RiQ Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the new production packer. 3. MIRU coil tubing. Drill out composite bridge plug. 4. POI. Estimated Pre-rig Start Date: 11/29/04 Estimated RWO Date: 12/13/04 Rob Tirpack Operations Drilling Engineer Office: 564-4166 Cell: 440-8633 TREE = 3" MCEVOY WELLHEÂD = MCEVOY 'Ä'ëiüATÕFf;-"-'-""~."'^^õTìS KB~ ELï~v; m. .9{46i BF~^ELE\T;^' .. '''''''''55':46' kÒÞ .;.......m mm."...15Ööö ~-~!:~,~~~~~.:'.:,:.m~~I.'~~_~~,~: Datum MD = 12889' DatumWD;; .. '.8'800' ss ') Z-31 SAR:, )NOTES: X NIPPLE@ 12361' WILL NOT HOLD PRESSURE (03/15/03). <it 2102' 1-i3-1/2" OTIS SSSV LAND. NIP, ID = 2.75" 1 Minimum ID = 2.750" @ 2102' 3-1/2" OTIS SSSV NIPPLE L GAS LIFT MANDRELS ~ ST MD TVD DEV TYPE VLV LATCH 6 3613 2997 53 OTIS DMY RA 5 7995 5555 51 OTIS DMY RA 4 10140 6968 51 OTIS DMY RA 3 11243 7662 49 OTIS DMY RA 2 12031 8184 46 OTIS DMY RA 1 12156 8271 46 OTIS DMY RA PORT DA TE 0 07/08/01 0 07/08/01 0 07/08/01 0 07/08/01 0 07/08/01 0 07/08/01 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 2946' ~ I I 1 12252' l-i 3-1/2" CAMCO SLIDING SLEEVE, ID = 2.750" ~ ) 1 12303' 1-1 TIW PBR SEAL ASSEMBLY 1 :8: :8: 12319' 1-19-5/8" x 3-1/2" TIW HBBP PKR, ID = 2.992" 1 l' ~I r 12361' l-i 3-1/2" OTIS X NIP, ID = 2.750" 1 1 TOP OF 7" LNR 1-1 12381' 1 I 12394' 1-1 3-1/2" OTIS X NIP, ID = 2.750" 1 I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 1-1 12426' 1 1 12426' 1-i3-1/2" TBG TAIL 1 9-5/8" CSG, 47#, L-80. ID = 8.681" l-i 12641' ~ .. I 12429' 1-1 ELMD TT LOGGED 08/22/91 1 ÆRFORA TION SUMMARY REF LOG: BHes ON 11/11/88 - CBT ON 11/15/88 ANGLEATTOPÆRF: 40 @ 12914' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12857 - 12897 0 09/06/01 2-1/8" 4 12914 - 12942 S 08/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 ! 1 12754' 1-1 MARKER JOINT 1 ì I 1 PBTD 1-1 13210' 1 1 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 13251' 1 ~ DATE 11/16/88 03/14/01 05/19/01 07/13/01 08/13/01 09/06/01 COMMENTS ORIGINAL COMPLETION SIS-MD FINAL RN/TP OORRECTlONS DAClKAK UPDATE GL \ï INFO SRBfTP SQZ ÆRFS CWS/tlh ADD ÆRFS BP Exploration (Alaska) REV BY DA TE REV BY COMMENTS 07/13/02 SDF/KK GLV CORRECTIONS 03/15/03 JJfTLH SAFElY NOTE (X NIPPLE) PRUDHOE BAY UNIT WELL: Z-31 ÆRMIT No: 1881120 API No: 50-029-21871-00 SEC 19, T11N, R12E, 714' FNL & 3644' FEL TREE = 3" MCEV OY WELLHtAD = MCEVOY I ,.,^._,~-~.^'.'..'.."..'^'.^~_..''^.'.'''..'._.'^'...'.M.... ACTUATOR = OTIS Ks~ ..eC8ïu;. ..... U uà1.4Si sï=:.ELêi;'^ U ..55:46' kOp.;'..u,. u,...'u.u .,.u1S0¡)i MaxÃngle,;m."'S7 @.'550õ;' 'oafum'MO^;^^"^.'._.".'..^-12äägÎ '5a"iUnl WD^';u U "880C)"88 ) Z-31 Pre-Rig ) 13-3/8" CSG, 68#, L-80, ID = 12.415" I., 2946' ~ Minimum ID = 2.750" @ 2102' 3.1/2" OTIS SSSV NIPPLE SAFETY NOTES: X NIPPLE @ 12361' WILL NOT HOLD PRESSURE (03/15/03). IComposite bridge plug @ 12,345' MDI I TOP OF 7" LNR I., 12381' I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I., 12426' 9-5/8" CSG, 47#, L-80, ID = 8.681" I., 12641' ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLEATTOPÆRF: 40 @ 12914' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12857 - 12897 0 09/06/01 2-1/8" 4 12914 - 12942 S 08/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 I PBTD I., 13210' 1 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I., 13251' 1 <I> L 1 1 t----4 2102' I., 3-1/2" OTIS SSSV LAND. NIP, ID = 2.75" 1 ~ GAS LIFT MANDRB..S a ST MD TVD DEV TYPE VLV LATCH 6 3613 2997 53 OTIS DMY RA 5 7995 5555 51 OTIS DMY RA 4 10140 6968 51 OTIS DMY RA 3 11243 7662 49 OTIS DMY RA 2 12031 8184 46 OTIS DMY RA 1 12156 8271 46 OTIS DMY RA PORT DA TE 0 07/08/01 0 07/08/01 0 07/08/01 0 07/08/01 0 07/08/01 0 07/08/01 1 12252' I., 3-1/2" CAMeO SLIDING SLEEVE, ID = 2.750" I 12303' I., TIW PBR SEAL ASSEMBLY 1 I 12319' I., 9-5/8" x 3-1/2" TIW HBBP PKR, ID = 2.992" I I 12361' I., 3-1/2" OTIS X NIP, ID = 2.750" 1 1 12394' I., 3-1/2" OTIS X NIP, ID = 2.750" 1 I 12426' 1-[3-1/2" TBG TAIL 1 I 12429' I., B..MD TT LOGGED 08/22/91 1 .. T I 12754' I., MARKER JOINT 1 I I I Chemical Cut @ 12,284' MD~ ) ~ .. ~ ì I DATE 11/16/88 03/14/01 05/19/01 07/13/01 08/13/01 09/06/01 REV BY DA TE REV BY COMMENTS 07/13/02 SDF/KK GLV CORRECTIONS 03/15/03 JJrrLH SA FElY NOTE (X NIPPLE) PRUDHOE BAY UNIT WB..L: 2-31 PERMIT No: 1881120 API No: 50-029-21871-00 SEC19, T1.1N, R12E, li4' FNL & 3644' FB.. COMMENTS ORIGINAL COMPLETION SIS-MD FINAL RNITP CORRECTIONS DAO'KAK UPOA TE GL V INFO SRBfTP SQZ PERFS CWS/tlh ADD PERFS -,j--~- BP Exploration (Alaska) . , Z-31)proposed compl~tion 13-3/8" CSG, 68#, L-80, ID = 12.415" l-i 2946' ~ SAFETY NOTES: X NIPPLE @ 12361' WILL NOT HOLD PRESSURE (03/15/03). IChemical Cut @ 12,284' MD I Composite bridge plug @ 12,345' MD I 1 TOPOF7"LNRI-i 12381' I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" l-i 12426' I 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 12641' ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/11/88 - CBT ON 11/15/88 ANGLEATTOPÆRF: 40 @ 12914' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12857 - 12897 0 09/06/01 2-1/8" 4 12914 - 12942 S 08/06/01 2" 6 12914 - 12942 0 09/06/01 2" 6 12952 - 12967 0 09/06/01 2-1/8" 4 12952 - 12992 S 08/06/01 5" 4 13002 - 13022 S 08/06/01 5" 4 13032 - 13046 S 08/06/01 2-1/8" 4 13058 - 13084 S 08/06/01 1 PBTD l-i 13210' 1 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 13251' 1 I ~ ) ;x:. ::x : 1n. ~ ~ I X Nipple @ 2,100' MD ~ --- 4-1/2", 12.6#, L-80, TCII tubing X Nipple " Baker 9-5/8" X 4-1/2" 8-3 Packer @ 12,230' MD / X Nipple XN Nipple Unique Overshot - 9-5/8" X 3-1/2" @ 12,280' MD I 12303' l-i TWV PBR SEAL ASSEMBLY 1 .. I 12319' 1-19-5/8" x 3-1/2" TWV HBBP PKR. ID = 2.992" 1 1 12361' l-i 3-1/2"OTISXNIP,ID=2.750" 1 I 12394' I.., 3-1/2" OTIS X NIP, ID = 2.750" 1 I 12426' 1-13-1/2" TBG TAIL 1 I 12429' 1-1 ELMD TT LOGGED 08/22/91 1 ! I 12754' 1-1 MARKER JOINT 1 ì I DATE 11/16/88 03/14/01 05/19/01 07/13/01 08/13/01 09/06/01 REV BY DA TE REV BY COMMENTS 07/13/02 SDF/KK GLV CORRECTIONS 03/15/03 JJ/TLH SAFÐY NOTE (X NIPPlE) PRUDHOE BA Y UNIT WELL: Z-31 ÆRMIT No: 1881120 API No: 50-029-21871-00 SEC 19, T11N, R12E, 714: FNL & 3644' FEL COMMENTS ORIGINAL COMA-ErION SIS-MD FINAL RNITP CORRECTIONS OAClKAI<UPOATEGLV INFO SRB/TP SOl PERFS CWS/tlh ADD ÆRFS BP Exploration (Alaska) ) ) ~TANDARD AlASKA PRODUCTION COMPANY "ELlHEAD LOCATION DATA 1) HELL: Z-31 FIELD: Prudhoe Bay Unit 2) Hell Head location 714 'from North line 1288 'from West line Section 19 T 11 N R 12 E. UPM -. . Pad "Mon.-2" £1. 51.95 Ft. AMSL NE Corn. (Plant) El. 53.88 Ft. AMSL 36.00 Ft. AMSL 37.58 Ft. AMSL 55.46 Ft. AMSL 91.46 Ft. AMSL x . 599,008.01 y. 5,959,359.96ASP Zone LAT . 70°17'54.298" N. lONG .149°11'53.482" 3) local 8enchmar~ Elevation 4) Top Edge of Cellar 5) Kelly Bushing to Base Flange. 6) Kelly Bushing to Ground level. 7) Base Flange Elevation 8) Kelly Bushing Elevation .Measured by Drilling Foreman NOTES: 4 w 1) The surveyor should fill in Items 2. 3 and 4. 2) The completed form should be returned to Drilling Dept. for distribution. CIRCULATION: North Slope Production Engineering (North Slope, BOC) - 1 Reservoir Engineering Operations (MB9-2) - 1 . North Slope - to Rig for Posting (North Slope, BOC) - 2 Well Records (LR2-l) - 11 Hell Files (HB12-1) - 1 Drilling, Technical Assistant (MB12-1) - 1 Drilling, Completion Technical Assistant (MB12-1) - 1 Graphic Services. Supv.. Cartography (MB2-4) - 1 ~~ November 18, 1986 Date ~""'\ -..'" OF Ai.. \\, .. ~~ ......... 4~ It ;~~ ...- *.... '+ . , " ..' '.'. ... -y " f--l49!.H ~ \ "'." ~. "~....':::7Z::."~ ~ ~ ~ .. .ft:. II ~ ." ...............".'" I: r. ~ -$- '. Ito-rnor¿ To~u¡ch : l!j ~ .~ ~. ~ 8 - ~. w.. c......, 8. L.S. #3798 - ~ 88 <~"-.t " . A .. /(> ... ... ¿;::.': ." .. ",.. .' ~." .. ., {~ p. :......... ~... - , f:..'F[S!""CNV~ \. ~., ""'"'~'~~ r.. .,.-.""",-,---------,---------,-- r¡--- 1 (\ ~ ~ i - ~ a\ ~ ~ r \ WELL PRODUCER. WELL INJECTOR Â \ , \ \ I \ \ \\/ --------~ /' \ ~ ',j \__/ Enter/Ex~~ l..;;;.~ ~) C) '-ì ~j f( ~---- .J 0 J ~.- r in ,... ,... ,... ~' $3c,)(þ(,)~~ ~,.' ,..,;, .;fi~JS~~~~i i. T Eti~t ..'.500'ii~'T~T!~J. . ','¡r\, .~~~~0?~~âJ~~.~iL. J.~ I~ 0 g~:~;~:.~.~_~;1A~...~.~;~:~P~~L.....i".~.. I C~:~~~~~~)~ ~ILJ.I. 444' --d., ~.. . \- DATE: 11/23/2001 SCALE: 1" = 250' MAP DATE: 2000 OE BAY UNIT - Z PAD PRUDH bs14495.dgn 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 STATE OF ALASKA ~ RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION 0 REPORT OF SUNDRY WELL OPERATION§> 2920 4 ~Iaska OlllSt uas Cons. COl1lllli:¡:¡iu/\ Stimulate 0 O~ft~rtfit~1Vert to WAG Inj WaiverD Time ExtensionO Re-enter Suspended WellO /"'-. Repair Well 0 Pull TubingO Operation Shutdown 0 PluQ PerforationsD Perforate New Pool D Perforate D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development D ExploratoryD 5. Permit to Drill Number: 188-1120 6. API Number 50-029-21871-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 91.50 8. Property Designation: ADL-Q047450 11. Present Well Condition Summary: Total Depth measured 13251 feet true vertical 9161.4 feet Effective Depth measured 13210 feet true vertical 9131.3 feet StratigraphicD ServiceŒ 9. Well Name and Number: Z-31 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 37 117 37.0 - 117.0 1490 470 Liner 870 7" 26# L-80 12381 - 13251 8520.7 - 9161.4 7240 5410 Production 12606 9-5/8" 47# L-80 35 - 12641 35.0 - 8706.8 6870 4760 Surface 2910 13-3/8" 68# L-80 36 - 2946 36.0 - 2693.1 4930 2270 Perforation deDth: Measured depth: 12857 - 12897, 12914 - 12942, 12952 - 12967 True vertical depth: 8866.92 - 8897.56,8910.55 - 8931.86, 8939.45 - 8950.82 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 33 12426 Packers & SSSV (type & measured depth): 3-1/2" TIW HBBP Packer @ 12319 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ReDresentative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 13 Prior to well operation: Subsequent to operation: Oil-Bbl o o Tubing Pressure o -12.6 -400 o 3434 Copies of Logs and Surveys run _ Daily Report of Well Operations_ ! 15. Well Class after proposed work: EXPloratoryD 16. Well Status after proposed work: OilD GasD Development 0 ServiceŒ 14. Attachments: Signature Garry Catron Garry Catron ß ~ ~ WAG ŒI GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 302-212 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 9/23/04 Form 10-404 Revised 4/2004 RBDMSBFl On¡r'I'~f i\ . f\ I r 'l~\. /1 L ~ , ¡.~ r\ . SEP 2 ~ ¡n114 ~ ~ Z-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/03/03 Start WAG Injection FLUIDS PUMPED BBLS :TOTAL No Fluids Pumped 0 Page 1 FYI: Z-3,1 Return to MI Injection. Subject: FYI: Z-31 Return to MI Injection. Date: Sat, 21 Jun 2003 18:13:37 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> To: "AOGCC Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us> CC: "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Rossberg, R Steven" <RossbeRS~BP.com>, "Engel, Harry R" <EngelHR~BP.com>, "Frankenburg, Amy" <FrankenA~BP.com>, "GPB, Fld TL" <GPBFldTL~BP.com> Hi Winton & Jim. Well Z-31 has been on MI injection since 5/18/03 and is not exhibiting signs of TxIA comm. Plans are to continue MI injection and monitor wellhead pressure per routine well monitoring procedures. Below is a TIO plot. Let me know if you have any questions. Joe ..... Original Message ..... From: NSU, ADW Well Integrity Engineer Sent: Friday, May 16, 2003 2:12 PM To: AOGCC Winton Aubert (E-mail) Cc: GPB, Well Pads SW; AOGCC Jim Regg (E-mail); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; Frankenburg, Amy; GPB, Fld TL Subject: FYI: Z-31 Return to MI Injection. Hi Winton. Z-31 is a producer to injector conversion that exhibited slow IA pressurization when on MI injection. The well passed an MITIA to 3500 psi on 12/02. MI injection started 01/02 but the well was shut-in after 2 weeks due to slow IA pressurization. It is currently SI. Recent history: > 12/29/02: AOGCC witnessed MITIA PASSED to 3500 psi. > 01/03/03: MI injection starts. > 01/11/03: DSO bled IA from 2250 psi to 1600 psi. > 01/14/03: Bleed IA 1950 to 500. > Ol/15/o3: ZA/OA=1100/~O0. > 01/18/03: SI well. > 01/22/03: Reviewed with Operator. He thought the IAP was starting to stabilize when the well was SI. > 01/25/03: PPPOT-T & IC both Passed > 05/09/03: MITIA Passed to 4000 psi. Current plans are to return the well to MI injection and continue to monitor and bleed any IA pressure. Discussions with the Pad Operator indicated the IA repressure rate seemed to be slowing as the well came up to operating temperature. The IA has been MIT'ed to 4000 psi, above the max anticipated injection pressure. We'll monitor the IA repressure rate and notify you if IA repressurization continues. Please call if you have any questions. Joe Joe Anders, P.E. /..~p~n Cubbon Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 1 of 2 SCANN£D AUG 0 ~ 2003 7/22/2003 5:31 PM FYI: Z-3,1 Return to MI Injection. Mobil: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com ~ .~ole0.bmpI Type: Bitmap Image (image/bmp)I : Encoding' base64 2 of 2 7/22/2003 5:31 PM ~1 ~2003 8.,'2I .QO03 ~ Tlag ~ OA 2003-0521_z-31_retu rn_to_MI, txt subject: RE: FYI: Z-31 Return to MI Injection. oate: wed, 21 May 2003 12:36:46 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWel I Integri tyEngi neer~BP, corn> To: Jim Regg <jim_regg~admin.state.ak.us>, winton G Aubert <wi nton_aubert~admi n. state, ak. us> cc: "GPB, Fld TL" <GPBFldTL~BP.com>, "Engel, Harry R" <EngelHR@BP.COm>, "Rossberg, R Steven" <RossbeRS~BP.com>, "GPB, well Pads LVZ" <GPBWel 1 PadsLVZ@BP. corn>, "Frankenburg, Amy" <FrankenA~BP.com>, "Dube, Anna T" <Anna. Dube@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWel 1 Ope rati onsSupe rvi sor~BP, corn> Hi Jim and winton. Here are the T/IA trends on z-31 since re-starting the well: T IA 5/14/03 SI 1000 5/17/03 2850 1350 5/18/03 2750 1500 5/20/03 2700 1550 Looks like the IA repressure rate has slowed considerably, we'll keep monitoring and keep you informed of pressure trends. Thanks! Joe 659-5102 original Message- From' Jim Regg [mailto:jim_regg@admin.state.ak.us] Sent' wednesday, May 21, 2003 8'57 AM To: NSU, ADW well Integrity Engineer Cc: Winton G Aubert subject: Re: FYI: Z-31 Return to MI Injection. Joe/John - I'm not sure I can see the IA pressure stabilization (and slowing of repressure rate) that the pad operator is suggesting; at least the data provided is not sufficiently detailed to allow that interpretation. Also, the time frame that statement is based (7 days of MI injection) is too short. There was both significant IA and OA pressure increases once MI injection began. There are other variables such as injection rate and temperature that factor into whether the pressure response is because of communication (TXIA) or something else. Best I see from data presented is uncertainty, winton and I have discussed - here's what we suggest: 1) Put we.ll back on MI for 30 days; monitor and record well pressures (TIO), temperature, and rate at least 2 times per day; we're looking for data duri ny stabl~zed injection conditions to validate statements about IA ~r, e~,~~e Page 1 2003-0521_z- 31_retu rn_to_MI, txt 2) Document any pressure bleeds (when occur, duration, beginning and ending pressures); do not bleed IA unless it exceeds 2000 psi; 3) shut in and notify AOGCC if pressures indicate IAxOA communication; 4) Report to AOGCC results after 30 days injection. Any questions/concerns, give me a call. Jim Regg "NSU, ADW Well Integrity Engineer" wrote: > Hi winton. > Z-31 is a producer to injector conversion that exhibited slow IA > p. ressurization when on MI injection. The well passed an MITIA tO 3500 psi on > 12/02. MI injection started 01/02 but the well was shut-in after 2 weeks due > to slow IA pressurization. It is currently SI. Recent history: > > > 12/29/02: AOGCC witnessed MITIA PASSED to 3500 psi. > > 01/03/03' MI injection starts. > > 01/11/03' DSObled IA from 2250 psi to 1600 psi. > > 01/14/03: Bleed IA 1950 to 500. > > 01/15/03: IA/DA=il00/400. > > 01/18/03: SI well. > > 01/22/03: Reviewed with Operator. He thought the IAP was starting to > stabilize when the well was si. > > 01/25/03: PPPOT-T & IC both Passed > > 05/09/03: MITIA Passed to 4000 psi. > > Current plans are to return the well to MI injection and continue to monitor > and bleed any IA pressure. Discussions with the Pad operator indicated the > IA repressure rate seemed to be slowing as the well came up to operating > temperature. The IA has been MIT'ed to 4000 psi, above the max anti ci pared > in~ection pressure, we'll monitor the IA repressure rate and notify you if > IA repressurization continues. > > Please call if you have any questions. > ]De > Joe Anders, P.E. / John cubbon > well Integrity Engineer, BP Exploration, (Alaska) Inc. > work: (907) 659-5102 > Mobil: (907) 943-1154 > Pager: (907) 659-5100, x1154 > Emai I: NSUADWWel 11ntegri tyEngi neer~bp, com > > Name: ole0.bmp ole0.bmp Type: Bitmap Image (image/bmp) Encoding: base64 ,.' Page 2 JUN 0 9 2003 Re: FYI: Z-31 Return to MI Injection. Subject: Re: FYI: Z-31 Return to MI Injection. Date: Wed, 21 May 2003 08:57:13 -0800 From: Jim Regg <jim_regg~admin.state.ak.us> Organization: AOGCC To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllnteghtyEngineer~BP.com> CC: Winton G Aubert <winton_aubert~admin.state.ak.us> Joe/John - I'm not sure I can see the IA pressure stabilization (and slowing of repressure rate) that the pad operator is suggesting; at least the data provided is not sufficiently detailed to allow that interpretation. Also, the time frame that statement is based (7 days of MI injection) is too short. There was both significant IA and OA pressure increases once MI injection began. There are other variables such as injection rate and temperature that factor into whether the pressure response is because of communication (TxIA) or something else. Best I see from data presented is uncertainty. Winton and I have discussed - here's what we suggest: 1) Put well back on MI for 30 days; monitor and record well pressures (TIO), temperature, and rate at least 2 times per day; we're looking for data during stablized injection conditions to validate statements about IA repressure rate; 2) Document any pressure bleeds (when occur, duration, beginning and ending pressures); do not bleed IA unless it exceeds 2000 psi; 3) Shut in and notify AOGCC if pressures indicate IAxOA communication; 4) Report to AOGCC results after 30 days injection. Any questions/concerns, give me a call. Jim Regg "NSU, ADW Well Integrity Engineer" wrote: > Hi Winton. > Z-31 is a producer to injector conversion that exhibited slow IA > pressurization when on MI injection. The well passed an MITIA to 3500 psi on > 12/02. MI injection started 01/02 but the well was shut-in after 2 weeks due > to slow IA pressurization. It is currently SI. Recent history: > > > 12/29/02: AOGCC witnessed MITIA PASSED to 3500 psi. > > 01/03/03: MI injection starts. > > 01/11/03: DSO bled IA from 2250 psi to 1600 psi. > > 01/14/03: Bleed IA 1950 to 500. > > 01/15/03: IA/OA=llO0/400. > > 01/18/03: SI well. · > > 01/22/03: Reviewed with Operator. He thought the IAP was starting to > stabilize when the well was SI. > > 01/25/03: PPPOT-T & IC both Passed > > 05/09/03: MITIA Passed to 4000 psi. > > Current plans are to return the well to MI injection and continue to monitor > and bleed any IA pressure. Discussions with the Pad Operator indicated the > IA repressure rate seemed to be slowing as the well came up to operating > temperature. The IA has been MIT'ed to 4000 psi, above the max anticipated > injection pressure. We'll monitor the IA repressure rate and notify you if > IA repre~..~U/,j, za tion.~~.ues. > > Please call if you have any questions. > 1 of 2 SCANNED JUN 0 2003 5/21/2003 8:57 AM Re: FYI: Z-31 Return to MI Injection. > Joe > Joe Anders, P.E. / John Cubbon > Well Integrity Engineer, BP Exploration, (Alaska) Inc. > Work: (907) 659-5102 > Mobil: (907) 943 -1154 > Pager: (907) 659-5100, x1154 > Emai 1: NSUADWWel 1 In tegri tyEngineer@bp, com Name: oleO.bmp oleO.bmp Type: Bitmap Image (image/bmp) Encoding: base64 Jim Regg <jim regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration 2 of 2 8¢/ANNE~: JUN 0 9 2003 5/21/2003 8:57 AM Re: PBi';"Z-31 (PTD 1881120) MITIA Subject: Date: From: Organization: To: CC: Re: PBU Z-31 (PTD 1881120) MITIA Tue, 31 Dec 2002 09:15:06 -0900 Jim Regg <jim_regg~admin.state.ak.us> AOGCC "Cubbon, John R" <CubbonJR~BP.com> "Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us>, "Tom Maunder (E-mail)" <tom_maunder~admin.state.ak.us>, "Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> John - AOGCC approves you to begin MI injection into Well Z-31. Please remember the provisions of Rule 7 in Area Injection Order #3 - "Whenever operating pressure observances or pressure tests indicated pressure communication or leakage of any casing, tubing or packer, you must immediately cease injection, notify the Commission, and obtain approval for corrective action." Jim Regg "Cubbon, John R" wrote: > Hi Bob, > > Please see the attached MITIA form for the Z-31 converson to MI injection. > > If you have any questions, please let me know. > > Thanks and Happy New Year! > > John Cubbon > GPB Well Integrity Coordinator > 1-907-659-5102 > pgr. 659-5102, x. 1154 > > <<MIT PBU Z-31 12-29-02.xls>> > > > Name: MIT PBU Z-31 12-29-02.xls > MIT PBU Z-31 12-29-02.xls Type: Microsoft Excel Worksheet (appl i ca t i on/vnd, ms - excel ) > Encoding: base64 Jim Regg <jim_regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration 12/31/2002 9:15 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / Z 12~29~02 John Cubbon John Crisp ~ Packer Depths (ft.) I Pretest Initial 15 Min. 30 Min. WellI Z-31 I mYpelni'IG I M~VDI ~'~'1 8'477'1 mubingl 01 01 01 01 IntervalI I P.T.D.I 1881120I Typetestl P I Testpsil 35001 I Casingl 5801 35001 34201 33701 P/FI P Notes: Conversion to MI injection. WellI Type Inj. Notes: WellI Type Inj. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: Test Details: The AOGCC inspector on location said that the well exhibited adequate pressure stabilization to be called a pass. He did not wish to have us bump up the pressure a second time and repeat the test. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU Z-31 12-29-02.xls MEMORANDU~;~, State of A~aska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: December 29, 2002 SUBJECT: Mechanical Integrity Tests BPX PBU Z-31 Injector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I We,Iz-31 Imype,nj.I ~IT.M.D.I~ I Tubing] oI o I o jo J,nterval! OI P.T.D.I 1881120 Imypetestl P ITestpsiI 2500 I Casingl 580 I 3500 I 3420 I 3370 I P/FI PI I Notes: Conversion to MI injection WellI I Type Inj. P.T.D. I I Type test Notes: WellI Type Inj. P.T.D.I Notes: P.T.D. I I Type test Notes: I We,,I Type Inj. P.T.D.I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER I NJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover' O= Other (describe in notes) M.I.T.'s performed: 1_ Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. cc,' SCANNED FEB 0 MIT report form 5/12/00 L.G. MIT BPX PBU Z-31 12-29-02 JC.xls 1/19/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Conversion Conversion from Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ f! Prod to Inject Prod to Inject Well Change approved program _ Pull tubing _ Vadance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 92.0 feet 3. Address Exploratory__ 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 713' FNL, 1287' FWL, Sec. 19, T11N, R12E, UM (asp's 599O08, 5959360) Z-31 At top of productive interval 9. Permit number / appro~/~ ~u.~m~er 2250' FSL, 498' FWL, SEC 07, T11N, R12E, UU (asp's n/a) 188- ~.,~ At effective depth 10. APl number 2457' FSL, 605' FWL, Sec. 07, T11 N, R12E, UM (asp's 598216, 5967801) 50-029-21871 ~/' At total depth 11. Field / Pool 2482' FSL, 617' FWL, Sec 07 T11 N, R12E, UM (asp's 598228, 5967826) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13251 feet Plugs (measured) Effective depth: measured 13210 feet Junk true vertical 9131 feet Casing Length Size Cemented Meas~,..:z...,,. [1~ , --'ir;" Conductor 110' 20" 72 c.f. 146' 146' Surface 2910' 13-3/8" 4101 c.f. 2946' 2693' Intermediate 12605' 9-5/8" 2765 c.f. 12641' 8707' Liner 870' 7" 300 c.f. 12381' - 13251' 8512' - 9161' Perforation depth: measured Sqzd P. 12914' - 12942', 12952' - 12992', 13002' - 13022', 13032' - 13046', 13058' - 13084' true vertical Sqzd Perfs 8910' - 8932', 8940' - 8970', 8977' - 8992', 9000' - 9010', 9019' - 9039' Tubing (size, grade, and measured depth 3-1/2", 9.2#, L-80 TBG @ 12139' MD. Tubing Tail @ 12429'. Packers & SSSV (type & measured depth) 9-5/8" x 3-1/2" TIW HBBP Packer @ 12319' MD. 3-1/2" Otis SSSVLN @ 2102' MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 09/28/2001 16. If proposal was verbally approved Oil X Gas _ Suspended 'g I s-O I - - Name of approver Date approved Service 17. I hereby certify that the foregoing is tr~ and ¢~l'rrect to the best of.l~y knowledge. Questions? Call Beverly Luedke-Chan @ 564-5196. SignedBe,,~--~' ,"~'J~--~----~-~-~ri' Li" ~,h' - - Title: Prudhoe Bay Petroleum Engineer Date Au.qust 16, 2001 ve ¥ uedke-L; an Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ,..,L Approval no. Mechanical Integrity Test _~Plug integrity__ .B~OP Test__ Subsequent f.orm required lo-L°cati°n clearance_ .Approved by order of the Commission ... Cammy Oechsli Taylo~ commissioner Date .............. ,' Form 10-403 Rev 06/15/88 · ORIGINAl. SUBMIT IN TRIPLICATE Z-31 (PTD 188-122) Subject: Z-31 (PTD 188-122) Date: Thu, 22 Aug 2002 14:18:29 -0500 From: "NSU, ADVV Well Integrity Engineer" <NSUADVVVVelllntegrityEngineer@BP.com> To: "AOGCC Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak.us> Tom, per our conversation today, this is to confirm that the above mentioned well has not started injection yet and the plans are for a November time frame for possible injection to start up assuming the Sundry is completed. The well is shut in currently. Kevin. Joe Anders, P.E. / Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska) Inc. (907) 659-5102 email: NSUADWWelllntegrityEngineer@bp.com 1 of 1 8/22/2002 12:32 PM ALASKA INDIVIDUAL WELL PRODUCTION AS OF 08/22/2002 WELL-NAME: PRUDHOE BAY UNIT Z-31 FIELD/POOL: PRUDHOE BAY, PRUDHOE 1988 JAN METH DAYS OIL WTR GAS 1988 TOTALS FEB MAR APR OIL 22,394 WATER ] ~ jAN M~-~{ FLOWING DAYS 31 OIL 40,094 WTR 1,047 GAS 36,132 1989 TOTALS OIL API: 029-21871-00 LEASE: ADL0047450 OPERATOR: BP EXPLORATION (ALASKA) INC 1990 JAN METH FLOWING DAYS 24 OIL 20,740 WTR 1,107 G/MS 24,505 1990 TOTALS OIL 384 1991 JAN METH FLOWING DAYS 31 OIL 18,202 WTR 1,631 GAS 30,179 1 TOTALS OIL 1992 JAN METH FLOWING DAYS 24 OIL 18,716 WTR 22,003 GAS 13,902 1992 TOTALS OIL FEB MAR APR FLOWING FLOWING FLOWING 28 22 10 32,078 25,397 11,793 907 1,594 714 28,203 27,043 13,463 319,544 WATER 15,018 FEB MAR SHUT-IN FLOWING 18 14,755 807 14,269 200,404 WATER SALES CD - 60 ACCT GRP - 726 FINAL STATUS: DEV I-OIL CURRENT STATUS: SER 1WINJ ** OIL PRODUCTION ** MAY JUN JUL AUG SEP OCT GAS 16,351 CUM OIL 22,394 CUM WATER 384 MAY JUN JUL AUG SEP OCT FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 31 31 30 31 34,376 27,485 20,592 20,794 19,605 32,669 1,744 1,186 851 833 1,476 1,693 35,238 21,796 14,754 14,868 20,903 47,113 GAS 322,613 CUM OIL 341,938 CUM WATER 15,402 APR MAY JUN JUL AUG SEP OCT FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 3 16 30 28 31 30 31 2,466 14,167 23,261 22,596 23,619 20,832 20,813 135 757 1,203 1,205 1,275 1,150 1,159 2,136 10,561 24,279 27,383 25,748 20,515 28,062 11,230 GAS 236,848 CUM OIL 542,342 CUM WATER 26,632 NOV DEC FLOWING FLOWING 6 30 2,816 19,578 384 2,156 14,195 CUM GAS 16,351 FEB MAR APR FLOWING FLOWING FLOWING 28 31 30 15,329 15,649 14,750 1,363 1,398 1,316 27,845 30,396 29,057 195,795 WATER 23,688 FEB MAR APR FLOWING FLOWING FLOWING 26 31 30 20,106 16,002 6,186 47,230 190,975 24,738 15,721 23,571 8,827 179,028 WATER 484,889 NOV DEC FLOWING FLOWING 30 31 27,452 27,209 1,495 1,478 35,106 27,994 CUM GAS 338,964 1993 JAN FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING DAYS 31 20 31 30 OIL 15,847 9,455 13,751 13,122 WTR 29,399 17,176 26,033 22,009 GAS 53,831 35,146 50,206 47,126 1993 TOTALS OIL 91,130 WATER 189,636 NOV DEC FLOWING FLOWING 28 31 17,836 19,319 986 1,446 29,252 30,138 CUM GAS 575,812 MAY JUN JUL AUG SEP OCT FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 31 28 28 31 14,194 17,235 15,670 17,753 14,562 17,869 1,255 1,506 1,364 2,557 2,134 2,605 28,042 27,072 27,943 27,684 15,026 27,369 GAS 308,316 CUM OIL 738,137 CUM WATER 50,320 MAY JUN JUL AUG SEP OCT FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 31 25 30 30 7,774 16,277 17,075 12,962 17,170 17,845 21,572 31,367 30,274 20,755 25,529 23,457 18,509 34,075 38,950 30,113 43,517 49,567 GAS 373,195 CUM OIL 917,165 CUM WATER 535,209 NOV DEC FLOWING FLOWING 29 31 15,942 18,640 2,532 4,027 21,814 15,889 CUM GAS 884,128 NOV DEC FLOWING FLOWING 21 31 11,673 17,242 19,629 27,360 42,735 53,708 CUM GAS 1,257,323 MAY JUN JUL AUG SEP OCT FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 28 31 7 22 1 12,458 9,340 10,736 2,011 4,365 45 21,329 21,095 26,124 4,532 20,366 1,573 48,836 33,286 39,955 7,756 21,578 1,441 GAS 339,161 CUM OIL 1,008,295 CUM WATER 724,845 NOV DEC SHUT-IN SHUT-IN CUM GAS 1,596,484 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 08/22/2002 1994 JAN METH SHUT- IN DAYS OIL WTR GAS 1994 TOTALS OIL 1995 JAN METH SHUT- IN DAYS OIL WTR G' 1~ TOTALS OIL 1996 JAN METH SHUT- IN DAYS OIL WTR GAS 1996 TOTALS OIL 1997 JAN METH SHUT- IN DAYS OIL WTR GAS 1997 TOTALS OIL 1998 JAN METH SHUT-IN DAYS O' W~ GAS 1998 TOTALS OIL 1999 JAN METH SHUT- IN DAYS OIL WTR GAS 1999 TOTALS OIL 2000 JAN METH SHUT- IN DAYS OIL WTR GAS 2000 TOTALS OIL FEB MAR APR MAY SHUT-IN SHUT-IN SHUT-IN SHUT-IN 614 WATER 11,223 GAS FEB MAR APR MAY SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER FEB MAR SHUT-IN SHUT-IN 3,052 WATER FEB MAR SHUT-IN SHUT-IN WATER FEB MAR SHUT-IN SHUT-IN WATER FEB MAR SHUT-IN SHUT-IN WATER FEB MAR SHUT-IN SHUT-IN WATER GAS APR MAY SHUT- IN SHUT- IN 119,987 GAS APR MAY SHUT-IN SHUT-IN GAS APR MAY SHUT- IN SHUT- IN GAS APR MAY SHUT-IN SHUT-IN GAS APR MAY SHUT-IN SHUT-IN GAS JIJN J-U-L AUG SEP SHUT-IN FLOWING FLOWING SHUT-IN 3 6 531 83 2,960 8,263 3,613 6,694 10,307 CUM OIL 1,008,909 CLTM WATER JLTN JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 1,008,909 CUM WATER JUN JUL AUG SEP SHUT-IN SHUT-IN GAS LIFT GAS LIFT 19 29 583 1,097 33,766 43,484 1,279 854 3,202 CUM OIL 1,011,961 CUM WATER OCT SHUT- IN 736,068 OCT SHUT-IN 736,068 OCT GAS LIFT 31 1,257 40,445 979 856,055 NOV SHUT- IN CUM GAS NOV SHUT- IN CUM GAS NOV GAS LIFT 3 115 2,292 90 CUM GAS JUN J-U-L AUG SEP OCT NOV SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 856,055 OCT SHUT-IN 856,055 OCT SHUT-IN 856,055 OCT SHUT-IN 856,055 CUM OIL 1,011,961 CUM WATER JUN JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 1,011,961 CUM WATER JI/N JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 1,011,961 CUM WATER JIIN JUL AUG SEP SHtVf-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 1,011,961 CUM WATER CUM GAS NOV SHUT-IN CUM GAS NOV SHUT-IN CUM GAS NOV SHUT-IN CUM GAS DEC SHUT- IN 1,606,791 DEC SHUT-IN 1,606,791 DEC SHUT-IN 1,609,993 DEC SHUT-IN 1,609,993 DEC SHUT-IN 1,609,993 DEC SHUT-IN 1,609,993 DEC SHUT-IN 1,609,993 A3_J~SKA INDIVIDUAL WELL PRODUCTION AS OF 08/22/2002 2001 JAN METH SHUT- IN DAYS OIL WTR GAS 2001 TOTALS OIL FEB SHUT- IN MAR APR MAY JTJN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL 1,011,961 CUM WATER 856,055 CUM GAS 1,609,993 FIELD/POOL: PRUDHOE BAY, PRUDHOE SALES CD - 60 ACCT GRP - 726 FINAL STATUS: DEV i-OIL CURRENT STATUS: SER 1WINJ ** ENHANCED RECOVERY ** 2001 JAN M H 0~ WTR GAS 2001 TOTALS FEB MAR APR OIL WATER 900 MAY JUN JUL AUG SEP OCT NOV DEC WTR INJT SHUT-IN SHUT-IN SHUT-IN 3 GAS 900 CUM OIL CUM WATER 900 CUM GAS 2002 JAN METH SHUT- IN DAYS OIL WTR GAS 2002 TOTALS OIL FEB MAR APR MAY SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS JUN JUL AUG SEP OCT NOV SHUT-IN SHUT-IN CUM OIL CUM WATER 900 CUM GAS DEC November 6, 0450 Look at 404... 2001 PBU... Z-31 .... 188-122... repair well.., convert to injector...witnessed MIT... squeezed well and cleaned out July 11, 2002 Call from Justin...Z-14a His records show first MIT failed 7112101 Set IBP on 7/27/01...combo MIT passed 7130101 Sent email on 8/12/01 ...8115101 gave verbal approval...pulled plug on 8/19 Z-31 passed July 2001 witnessed July 11, 2002 1703 Return call to Justin Baikenbush... he does not have an email from me regarding the verbal...Z-14a...Joe does have a note in his file...will check the file on the pressures on the well... On Z-31 ... July 12, 2002 1120 Call from Duane Schnor...has Beverly's note regarding Z-31...also has a note regarding Z- 02... doesn't look like it was ever put on July 29, 2002 1430 Return call to Kevin Yeager...will send July NS information in advance of the meeting...discussed needing some information X-20, Z-31 and Z-14A August 1,2001 1233 Return call to Kevin...Z-31...pertmit 188-122...sundry was make up on 8/16/01 ...cover...ietter sent under Bev's signature...show a witnessed MIT 7/29/01 (Spaulding) FW: Z-31 Sundry Subject: FW: Z-31 Sundry Date: Fri, 12 Jul 2002 14:22:23-0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelilntegrityEngineer@BP.com > To: "AOGCC Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak.us> Tom, See the enclosed documents for Z-31. Please let me know if you need anything else. Thanks, Justin 659-5102 ..... Original Message ..... From: Schnorr, DeWayne R (GeoQuest) Sent: Friday, July 12, 2002 10:30 AM To: Frankenburg, Amy; NSU, ADW Well Integrity Engineer Subject: RE: W-37 Pre CTD Work & Z-31 Sundry Justin, this is the 10-403 application we submitted to AOGCC last year on well Z-31. I cannot find the 10-403 returned from the state with the approval number, and the clerk at AOGCC is out until Monday. We also submitted a 10-404 on October 22, 2001 reporting the work done during the conversion. If you need anything on this well or any other well, call me or email me. DeWayne <<Z-31 (08-14-2001) Conversion from Prod to Injector Sundry letter. ZIP>> <<Z-31 (08-16-2001) Conversion 'from Prod to Injector l O-403. ZIP>> ..... Original Message ..... From: Frankenburg, Amy Sent: Thursday, July 11, 2002 5:27 PM To: NSU, ADW Well Integrity Engineer; Schnorr, DeWayne R (GeoQuest) Subject: RE: W-37 Pre CTD Work & Z-31 Sundry Justin- W-37A well plan is before my time.., but reading through the coil package: * W-37 has a leaking packer = TbgxlA comm (do your ann corn notes agree with this?) * W-37A will be a cemented coil ST. The plan is to bring the cement into the parent liner and tbg tail to create isolation between IA and fm. DeWayne: can you help Justin w/the original Z-31 sundry?? Amy Amy Frankenburg Senior Engineer, GPB waterflood team W & Z Pad engineer (907)564-4503 office (907)564-5016 fax .... Original Message .... From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 11, 2002 5:11 PM To: Frankenburg, Amy Subject: W-37 Pre CTD Work & Z-31 Sundry 1 of 2 8/1/2002 12:46 PI~ FW: Z-31 Sundry Amy, I see W-37 on the CTD schedule. This well has confirmed T x IA communication. Am I correct in assuming that the CTD folks are planning on addressing this issue? Let us know and we can procedure with the Pre-Rig testing. Also, I just received a call from Tom Maunder with the AOGCC. He is searching for the Sundry for converting Z-31 from a producing well to an injector. I do not have any paperwork to that effect up here on the slope, but hoping that you have something in the files in Anchorage. Let me know as soon as you can, thanks. Regards, Justin x5102 [~Z-31 (08-14-2001) Conversion from Prod to Injector Sundry letter. ZIP Name: Z-31 (08-14-2001) Conversior from Prod to Injector Sundry letter. ZIP Type: Zip Compressed Data (application/x-zip-compressed Encoding: base64 ~'~Z-31 (08-16-2001) Conversion from Prod to Injector 10-403.ZIP Name: Z-31 (08-16-2001) Conversion from Prod to Injector 10-403.ZIP Type: Zip Compressed Data (application/x-zip-com pressed) Encoding: base64 2 of 2 8/1/2002 12:46 PIV Jul-Il-02 From-WELLS GRO( GPB WELLS GROUP PRUDHOE BAY, ALASKA FAX # (907) 659-5053 bp FROM: PAGES TO FOLLOW: DATE: TIME: m~ (excluding this cover) COMMENTS: RECEIVED · JUL 1 IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL (907) 659-5583 ',,Jul'Il'02 ]2.'3? From-WELLS BP Alaska, 'WE'EL - ' Z-31 7::)^'Ti= ...... 07/29/01 .ESTIMATE .... JOB~$C-OP~ ...................... I JOB NOMBER '" INJECTION CONVERSION I 0706011606.2. [~AILY WORK ............ I UR'IT NUMBER .... MIT-IA TO 2000 PSI PASSED } 'OPERATI-OI~I CO-MI~LETE ! s0'CCES-$FUL '" I KE~' F;iERSON ['SUPERVISOR ' - O Ye-. ~ No I t'"~ Y~s i~ No I VEC-SNOW I YEAGER AFE/OO ..... ! D-e'~li Code ]' DAILY CO-ST J AdCUI~I-COST ' - J Si~-ne~l ........ 4P1825 J EWE PROJ 933i $4.560 I $57,645 ] Initi~:l=l-bg ]'l~inalTb9 Ii-n'itiallA '" ]Finai~A 'l~nitiaFOA JFina~OK' I~CSize IMinlD-" ]DePth 6ooPs~I 5ooPS~l loooPs~l 5coPs!! lso_PSll ~6oPslI o,ooe." I.,O.oo0" I o FT _DAILY SUMMARY. _ MiT-iA TO 2000 PS.l. AoG(~c WITnESsED (PASSED), [An .n.. Corem! . TIME 00'.00 LOG ENTRY T/I/O = 600/1000/1~0-.' MI'~:-IA to 2000psi PASSED. IA FL @ Surface, Bled IA from 1000 psi to 350 psi in 10 min. Bled TBG from 600 psi to 350 psi in 10 min. RU HB&R and pressured IA to 2000 psi with 9 BBLS of diesel. Started 30 rain test. IA lost 30 psi in 15 rain and a total of 40 psi in 30 min. MIT.T to 2500 psi FAILED. WHP'$= 480/2000/200. Pressured TBG to 2500 psi. Started 30 rain test. In 15 rain TBG lost 570 psi. Repressumd TBG to 2500 psi. In 15 mtn TBG lost 600 psi. Could not establish LLR. Pumped .2{5 bpm and TBG prs increased to 2500 psi, State AOGCC Witnessed MIT-IA to 2000 psi PASSED. Pressured IA to 2190 psi. Started 30 rain test. IA lost 60 psi in the 1st 15 rain and a total o! 80 psi in 30 min. Bled IA to 500 psi. Final WHP's = 500/500/160. WITNESSED BY JOHN SPALDING ............ la i[ · . . _ · ~ , ~.JUL-[ ...... 2:'~' .......... , ..... , , i1 i i ,, , = i i i, , ~JU.id' summary ............. PUMPED APPROX 35-BBL$ OF-'[:)iEsEL:''~ -.. i . i _.1 ..... · , ,. ,1 . - .,. - . , , .-, i ... i _ =, · I ........ · ,. III , . II II I . IIIII · -- i q II I I "SERVICE COM P~,~IY - SERVICE .......... DAILY' COST ACCUM ':rOTAL $0.00 St ,858.00 . BP ,- ,,., $1,1,?.0,00 $1,120.00 .... , ....... , HALLIBORTON : .... . ...... ' ,, $0,00 ....... $43,183,,,00 HBR $2,730,00 $4,290,00 HBR ONE TROCK ....... $0,00 $1 ~080.00 HBR SEC. TRUCK $0,00 $2,860,00 1,. ,, , ,11 .... WAREHOUSE $0.00 $576.00 Il , I , 'J I '1 11111 -. I11 ' · , I I Itl TOTAL FIELD E~IMATE' $4,560.00 $87,645.00 WELL: Z-3t DATE: 07129/0t 1Z:37 From-WELLS GROI~ 659-5053 {' Annular Communication Testing Mechanical Integrity Test State Witnessed TYPE MIT/A to 2000 psi Well Statu.. Producing TBG: 600 , CONTROL: T-3§8 P.03/06 F-ST0 iNITIAl_ PRESSURE'D,~TA ' TYPE: Producer with A/L IA: 1000 OA: 160 L ....... I I _. I I , 1,, . -- BALANCE: MIT: PASS & - , .. . · " PRE-TEST PREPARATIONS BLED IA FROM 1000 PSI TC380 PSI Type of fluid and volume: N/A HRS IA FL ~,Urface 10 MIN TEST PRESSURES TIME TBG IA OA COMMENTS I 13'.~) SOO " 450 160 START PUMPING TIME I "'13:58' 550 'l' 2190 200 sTART TEST .......... 14:13',56O .... 2130 60 200 0 ........ ~'i4:28 '560 '" 2110 20 200 "'0 MIT-IA'PASSED ........ START TEST ., .... ............ START 'I:EST ..... 0 0 START TEST -' 11'--- · I I - I ' ... III 0 0 -- .-. ... I ill Il I .... Il TOTAL VOLUME PUMPED: 9 BBLs of Diesel 0 down the IA II II "- ~ -- TBG: IA: OA: '"' .... '- ' :"' "'" '~' oBS-~.~VATi'ONSI'"'O--'--T-C MMEN S" ' '" ~ ' "' "" ' FINAL STEPS MUST BE COMPLETED AND CHECKED OFFII! -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. -- NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: .... ' ...... '"' ' .... RECEIVED, 0il & GaS Cons. Commission UIC Check List Well Name: ~ \~._k~ '~_..- _'~ \ Operator: %~ New Well Conversion eTD: f/%~5_' '" ~ \ ') Sundry #: 2,~\.-~.-~. Order(s): ~x ~T~) &~ Date: Item Y/N Comments 1. Standard MIT test provided? ,Q[ ~>~:ve_x_X~:~x-~ %3,&..~a~-~ (~v,~%e~.._3 2. Notified of pressure communication or leakage? ~ 3. Diagnostics pl~ne~run? Method? ~ ~ 4. Form 10-403 submi~ed requesting waiver? 5. Alternate MIT passed? Method? AOGCC witnessed? ~ ~ ~,~ 6. MIT Pa~ Il verified? How? .~ %~ X~oX~'~"~x~"~&~ ~o~<c~& 7. Area or Review examined? ~ ~s~"~~e-~~~ ~~'~~ Definition of Terms T IA OA MIT CMIT LLRT Waiver Assessment (if necessary) Tubing Inner Annulus (tbg x csg) Outer Annulus (csg x csg) Mechanical Integrity Test Combined test of annular spaces Leak Loss Rate Test Integrity # Barriers Condition Enhanced Operational Restrictions Category Affected Monitoring Requirements~ TxlA communication (tubing leak; Annual MITIA/LLRT 4 I packer leak not quantifiable) 4 year CMIT T x IA Water only TxlA communication (tubing leak; 2 year CMIT T x IA (tubing leak) 3 1 packer leak quantifiable) 2 year MIT T (packer leak) Water only Annual CMIT IA x OA 2 1 Production casing leak MIT Tubing - 2 yrs Water only IAxOA communication Annual MITT Water only, Alarm w/injection shutdown on OA. Set point minimum 1000 psi < l 1 Annual CMIT IA x OA minimum burst strength of outside casing. Matrix applies to the following well configuration: 1. Conventional completion per regulations; monobore on case by case basis 2. Production casing designed for shut-in tubing pressure 3. USDW exemption or finding of no aquifer Reviewing Engineer: Recommended Action: Integrity Category: waiver chklst.doc:8/l 2/2002 -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: //Abandon_ Suspend_ SWAP Well from~ Alter casing _ Repair well _ H20 to MI (WAG) Change approved program _ Operational shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ SWAP WELL FROM H20 to MI INJECTION Other _X 2. Name of Operator BP Exploration IAlaskal, Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 714' FNL, 3665' FEL, Sec. 19, T11N, R12E, UM At top of productive interval 3029' FNL, 4420' FEL, SEC 07, T11N, R12E, UM At effective depth 2822' FNL, 4312' FEL, Sec. 07, T11N, R12E, UM At total depth 2797' FNL, 4299' FEL, Sec 07 T11 N, R12E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic __ Service_X (asp's 599008, 5959360) (asp's 598111, 5967592) (asp's 598216, 5967801) (asp's 598228, 5967826) 6. Datum elevation (DF or KB feet) RKB 92.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-31 9. Permit number / approval number 188- . 10. APl number 50-029~21871-00 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" Surface 2910' 13-3/8" Intermediate 12605' 9-5/8" Liner 870' 7" 13251 9161 13210 9131 feet Plugs (measured) feet feet Junk (measured) feet Cemented 72 c.f. 4101 c.f. 2765 c.f. 300 c.f. Measured Depth True ve~lcalDepth 146' 146' 2946' 2693' 12641' 8707' 12381'-13251' 8512'-9161' Perforation depth: Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) measured Open Perfs 12857'- 12897', 12914'- 12942', 12952'- 12967' Squeezed Perfs 12967'- 12992', 13002'- 13022', 13032'- 13046', 13058'- 13084' true vertical Open Perfs 8867' - 8898', 8911' - 8932', 8940' - 8951' Squeezed Perfs 8951'- 8970', 8978'- 8993', 9000'- 9010', 9019'- 9039' 3-1/2", 9.2#, L-80 TBG @ 12139' MD. Tubing Tail @ 12429'. R E C E IV ~ 9-5/8" x 3-1/2" TIW HBBP Packer @ 12319' MD. 8'1/2" Otis SSSVLN @ 2102' MD. JI !1 1 O 2002 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation// October2, 2002 / 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: ,1~a$~3. 0il & Gas Cons. Gommts~lu~, Anchorage Oil __ Gas _ Suspended __ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Prudhoe Bay Petroleum Engineer Amy Frankenbu1~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represent~ve may witness Plug integrity _ B~P Test _L~ Location clearance _ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission OflglliaJ Slglled By Questions? Call Amy Frankenberg @ 564-4503. Date JuN 10. 2002 Prepared by DeWayne R. Schnorr 564-5174 ] Approval Commissioner Date ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 08, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for Z-31 Swap from Water to MI Injection BP Exploration Alaska, Inc. proposes fo.l.~ew, ing wellwork to prepare to swap Z-31 from water injection to MI gas injection (est. MI start-up Nov-02). This is the first time for MI 'gas injection since the well was converted from a production well to an injection well. 1 S Drift and Tag 2 C Acid Stim Establish injectivity into new perfs 3 MITA Witness by AOGCC. Well Z-31 was converted from a shut-in producing well to a water injection well last September (9/01/01). The well took one tubing volume of water and the forma~n locked up. This well needs a formation acid stimulation before MI is injected. A copy of the wellbore diagram is attached. Please contact Amy Frankenburg at 564-4503 with any questions. Sincerely, Pre-acid Slickline 1. RU slickline and drift and tag. Correct to ELM tubing tail. Coiled Tubinq acid stim // 2. RU CT unit for acid stim.' TagtPBTD and corrected to ELM slickline tag. 3. Acid stim perforated interval. / 4. RDMO. Coiled Tubin.q Acid Proqram 2. Trap 1500 psi on the 3-1/2" by 9-5/8" inner annulus. 3. MIRU CT. RU return line to adjacent well or returns tank. Be aware of the potential for H2S in the returns. 4. MU jetting nozzle and RIH. Pump at m~ rate with slick water (your choice) while RIH. Circulate the tubing and liner clean of an[stuf~hat may be floating around.~ \ / 5. Pump minimum rate and tag PBTD for dept"ffi control. Circulate a bottoms-up volume prior to proceeding with the stimulation. Take care not to mash through and stir up and[/~cffmoo o~ bottom. · \/, 6. Pull above the top perfs and check fbr--Mjectivity with a maximum WHP of 3000 psi. If the perfs are taking fluid then skip to step 7. If the perfs are too tight then pump 10 bbls of 7.5% HC1 as an attempt to establish injecfivity. It may be necessary to take returns in order to stage acid to the nozzle. If the perfs are still too tight to ~,.e,d__wij,,th__the remainder of the stimulation then contact the Well Ops Supervisor and Paul Battle or a"~oup Make multiple passes across the perfs and pump, the following at maximum rate with a recommended maximum WHP of 2000 psi (*). Don't wash the acid below 12950' in order to minimize acid contacting the squeeze perfs. Make one pass to bottom while pumping the overflush in case acid has swapped in the sump. Avoid stirring up schmoo at PBTD. Don't POOH until the entire overflush has been pumped behind pipe in order to reduce the chance of stirring up schmoo. 25 bbls 100 bbls 50 bbls 150 bbls 3% NH4C1 with 10% U-66 and 0.2% Fl03 7.5% HC1 9% - 1% HC1-HF 3% NH4C1 with 10% U-66 and 0.2% F103 overflush (behind pipe) * Go to 3000psi during the first halfofthe HClstage if necessary to establish injection. Once mud add is at thepetfs the maximum treating pressure should be 2000 psi. _/l//fluids should be filtered to 3 microns. Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the EXCEL treating report (5 minute readings) to the program author. 8. POOH. Bleed IAP. RDMO. Immediately put on injection ~ 3000 BWPD. TRE~ = 3" MCEVOY WELLI-EAD= MCEVOY ACTUATOR= OTIS KB. ELEV = 91.46' BF. ELEV = 55.46' KOP = 1500' Max Angle = 57 @ 5500' Datum MD = 12889' Datum TV D= 8800' SS I 13-3/8 " CSG, 68#, L-80, ID = 12.415" H Z-31 SAFETY NOTES 2102' H 3-1/2" OTIS SSSV LAND. NiP, D :2.75" I GAS LIFT MANDRELS IMinimum ID = 2.750" @ 2102' I I 3-1/2" OTIS $$$V NIPPLE 12252' H 3-1/2" CAMCOSLIDING SLEEVE ID=2.750" I I TOPOF7"LNR H 12381' 3-1/Z' TBG, 9.2~, L-80, 0.0087 bpf, ID=2.992" H 12426' I 9-5/8"CSG, 47#,L-80, D=8.681" H 12641' 12303'H TIW PBR SEAL ASSEMBLYI 12319' H 9-5/8" x 3-1/2" TIW I-BBP PKR, ID = 2.99Z' I 12361' ~ 3-1/2"OTISXNIFPLE 19=2.750" i 12394' H 3-1/2" OTIS X NIPPLE, ID=2.750" I 12426' H3-1/2" 'rBGTAL I ~2429' I--I a-MDTTLOGGED08/22/911 PERFORATION SUrvlVIA RY RB: LOG: BHCS ON 11/11/88 - CBTON 11/15/88 ANGLEATTOP PERF: 40 @ 12914' Note: Refer to Rroduclion DB for historical :)erf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12857- 12897' O 09/06/01 ,,' 2-1/8" 4 12914- 12942' ..~ ..... 08/06/01 2" 6 12914- 12942' O 09/06/01 2" 6 12952- 12967' O 09/06/01 2-1/8" 4 12952- 12992' S 08/06/01 5" 4 13002- 13022' S 08/06/01 5" 4 13032- 13046' S 08/06/01 2-1/8" 4 13058- 13084' S 08/06/01 I PBTD H 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" H 13210' I 13251' I 12754' H MARKER JOINT I DATE REV BY COIVIVIENTS DATE REV BY COMMENTS 11/16/88 ORIGINAL COIVPLETION 108/13/01 SRB/TP SQZ PERFS 03/12/01 SIS-QAA CONVERTED TO CANVAS 109/06/01 CWS/tlh ADDPERFS 03/14/01 SIS-MD FINAL 05/19/91 RN/TP COI:~,ECTIONS 07/13/01 DAC/KAK UPDATE GLV INFO PRUDHOE BAY UNIT WB.L: Z-31 PERMIT No: 88-1120 APl No: 50-029-21871-00 Sec. 19, T11N, R12E BP Exploration (Alas ka) Jul-Il-02 WE'EL Z-31 DATE 07/29/01 12 -FIEi.'b :' ESTIMATE ..... 12:37' From-WELLS BP Alaska, Inc. JO~ sc-oPE ..... INJECTION CONVERSION DAILY WOhK ...... MIT-IA TO 2000 PSI PASSED 'OPERATION CO-I~IPLETE" '! SUCCESSFUL ..... I KE-~" PER$-OI~" ' ~'~ Yes ~ No i ("~ Yes ~ No l VEC-SNOW ,, AFE/CC- .... ! D-6tail Code 1' DAftlY CO-ST i Ac'cuI~I-CEJS-I'- ..... 4P1825 J EWE PROJ 933{ $4,560 I $57,645 Initi~tTbg IFinalTb9 llhitialiA-"' IFin~i'lA '[Initial-O.~, JFinalOA- 6poPsfl,. 5ooPSfl loooPs~! 500PS!l ~sOPS~i 160PS!,0.00~_.." 0706011606.2 U-Iq'IT NUMBER-' SIJPER~/i~bR . ,. YEAGER $i~ned ...... I ! Min ID-' Depth I..o.ooo." I o ET DAILY SUMMARY ......... t'MiT-IA TO 2000 PSI. AoGcc WITNESSED (PASSED), [Anr{ Cornm] ........ TIME oO:0o LOG ENTRY T/IlO = 6~)0/1000/160-i MIT-IA to ~'0'00'psi PASSED. IA FL'@ Suff~ce. Bled IA from lO00 p~i '" to 3{50 psi in lO min. Bled TBG from 600 psi to 350 psi in 10 min. RU HB&R and pressured IA to 200[3 psi with 9 BBLS of diesel. Started 30 rain test. IA tost 30 psi in 15 rain and a total of 40 psi in 30 min. MIT-T to 2B00 psi FAILED. WHP'$= 480/20001200. Pressured TBG to 2{500 psi. Started 30 rain test. In 1{5 min TBG lost B70 psi. Represaured TBG to 2500 psi, In 15 rain TBG lost 6130 psi. Could not establish LLR, Pumped .2{5 bpm and TBG prs increased to 2500 psi. State AOGCC Witnessed MIT-IA to 2000 psi PASSED. Pressured IA to 2190 psi. Started 30 rain test. IA lost 60 pa[ in the 1st 15 rain ancl a total o! 80 psi in 30 min, Bled iA to 500 psi. Final WHP's = 500/5001160. WITNESSED BY JOHN SPALDING .~iUid Summer's/ ............ . U_MPinED AP~p:RmOX 35-"lmaeS OF~:pIESELi'::: , SERVICE[ COMPANY - SERVICE ..... DAILY' COST "ACCUM':FOTAL .... ' ............. $o..oo .$~,056.,99 BP ..... $1,120.00 ..... $1,;.120.00 HALLiBORTON .............. $0,00 ,,$43,183:00 HBR' ' $2,730,00 $4,290,00 HBR ONE T.RL~'CK ...... " ... .' ' " _... ' $0.00 ,. $1, .080.00 HBR SEC. TRUCK_. ........... $0.00 __. $2,860.00 VECO $710.00 $2,680,00 i WAREHOUSE $0.00 $576.00 m , ' i I .3~! i I. .IJ~ "1 .i '11. _. i., ,~ TOTAl., FIELD E~'IMATE ..... [" $4,560.00 $~7,t~4S.00 Ju1-11-02 12:37 From-WELLS GRc~ -- , . . WELL: Z-31 DATE: ......07129101 ·.= TYPE MYI3A to 2000 psi Well Statu,, Produciag TBG: 600 CONTROL: Annular Communicati°n Testing Mechanical Integrity Test · ... State Witnessed -,, 'iNITIAL PRESSURE'DATA TYPE: Producer with A/L IA: 1000 OA: 160 BALANCE: '" ' PI~E-TEST PR'EPARATIO~S:''' BLED IA Type of fluid and volume: T-3g8 P.03/06 MI.T: PASS ., . FROM !000 PSI TC350 PSI HRS 10 MIN N/A IA FL ~surface "- .......... -' ' - ..... ';TEST'PRESsURI~S'' "' ..... ' .... ' ' TIME TBG IA OA COMMENTS 13:'50 500 450 160 [~TART [=UMP'iNG Ti'ME ...... 13:58' 550 .... 2t90 200 START TEST ' , -- ' , ..~ ' Il -- I ,! 14:13 560 .... 2130 60 200 0 --~'4:28 560 ' '2110 20 "200 ' 0 MIT-IA 1SASSED " START TEST · ' ""'b " :' 0 ' START. TEST_. .... . _ .. 0 ......... START TEST " __ , - . . ....... o o 0 0 TOTAL VOLUME PUMPED: 9 BBLs of Diesel 0 down the IA ~.. i i .. Ill -- I . I [ii I ii .... I .... II III ~ I III .... ......... Fi~IAL. pRESSURE$ TBG: IA: OA: · , ...... il i. "' ...... ' .... "' ' ......... OBSERVATIONS/COMM T'----"EN-S-:'" .... "' ' ' ~" '" FINAL STEPS MUST BE COMPLETED AND CHECKED OFFII! X -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. !'~ -- NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. '-' Witness: "' ....... ' .... '"' RECEIVED. inchorapl, e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Conversion -Prod to Inject 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, AK 99519-6612 4. Location of well at surface 713' FNL, 1287' FWL, Sec. 19, T11N, R12E, UM At top of productive interval 2250' FSL, 498' FWL, Sec. 07, T11N, R12E, UM At effective depth 2457' FSL, 605' FWL, Sec. 07, T11N, R12E, UM At total depth 2482' FSL, 617' FWL, Sec. 07, T11N, R12E, UM 5. Type of Well: Development Explorato~_._ Stratigraphic__ Service__X ~sp~ 599008, 5959360) (asp's n/a) (asp's 598216, 5967801) ~sp~ 598228, 596782~ 12. Present well condition summary Total depth: measured true vertical 13251 feet Plugs (measured) 9161 feet 6. Datum elevation (DF or KB feet) RKB 92 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-31 9. Permit number / approval numl~ell 10. APl number 50-029-21871 11. Field / Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical 13210 feet Junk (measured) 9131 feet Casing Length Conductor 110' Surface 2910' Production 12605' Liner 870' Liner Size Cemented Measured Depth True Vertical Depth 20" 72 c.f. 146' 146' .13-3/8" 4101 c.f. 2946' 2693' 9-5/8" 2765 c.f. 12641' 8707' 7" 300 c.f. 12381' - 13251' 8512' - 9161' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 12857'- 12897', 12914'- 12942', 12952'- 12967', Squeezed Perfs 12967' - 12992', 13002' - 13022', 13032' - 13046', 13058' - 13084' Open Peris 8867' - 8898', 8911' - 8932', 8940' - 8951' Squeezed Perfs 8951'- 8970', 8978'- 8993', 9000'- 9010', 9019' - 9039' 3-1/2", 9.2#, L-80 TBG @ 12319' MD. Tubing Tail @ 12429'. RECEIVED 9-5/8" X 3-1/2" TIW HBBP PACKER @ 12319' MD. 3-1/2" Otis SSSVLN @ 2102' MD. OCT 2 ~ ~001 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commissior~ Anchorage 14. Prior to well operation 09/27/2001 Subsequent to operation 09/29/2001 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Well Shut-in 0 400 Casing Pressure Tubing Pressure 0 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service PW INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant DeWayne R. Schnorr ~,~ j Form 10-404 Rev 06/15/88 · Date October 22, 2001 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE '~ 07/19/2001 07/23/2001 07/24/2001 07/25/2001 07/26/2001 07/27/2001 07/29/2001 07/30/2001 08/05/2001 08/06/2001 08/09/2001 08/12/2001 09/05/2001 09/06/2001 09/27/2001 10/16/2001 07/19/01 07/23/01 07/24/01 07/25/01 07/26/01 Z-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS INJECTION CONVERSION: INJECTION CONVERSION: PROGRESS INJECTION CONVERSION: INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION INJECTION CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CONVERSION: CMIT-T+ IA FOR INJECTION CONVERSION PULL XX PLUG & RESET (PRE CMIT) - IN PULL / RESET TTP (PRE CMIT) IN PROGRESS PULL / RESET TTP (PRE CMIT) IN PROGRESS BAILING/PULL TTP SET TTP/CMIT (PRE INJ CONVERSION) MIT-IA TO 2000 PSI PASSED PULL TTP ( POST CMIT ) SQUEEZE / INJ CONVERSION SQUEEZE/INJ CONVERSION PT CEMENT PLUG TAG W/2" CENT @ 13157'SLM, PERFO 2" HSD POWER JET @ 6 SPF PERFS 2" HSD / POWER JET @ 6 SPF INJ. TEST DRIFT TUBING (RATE) EVENT SUMMARY CMIT-T+ IA (FAILED) FOR PRE-INJECTOR CONVERSION. RUN LIB TO OBSTRUCTION AT 10,878' SLM (IMPRESSION INCONCLUSIVE). RUN MAGNET DOWNHOLE TO SEARCH FOR POSSIBLE 2.5" WHEEL LOST OFF ROLLER STEM (PREVIOUS JOB). TAG OBSTRUCTION @ 10,979' AND PUSH TO 11,O54'. S/D. OOH W/NOTHING ON MAGNET. MADE MULTIPLE BAILER RUNS TRYING TO GET DOWN TO XX PLUG @ 12332' SLM. GET TO PLUG RAN EQUILIZ. PRONG CAME BACK W/GOOD MARKS ON PRONG BUT NO CHANGE IN WHP, DECIDE WELL IS BALANCED AT PLUG, RAN DOWN W/3 1/2 GR UNABLE TO GET PAST 11145' SLM. WILL CONTINUE BAILING. ATTEMPTING TO PULL TTP. ONLY ABLE TO GET DOWN TO 11924' SLM W/GR ( ABLE TO GET TO TTP @ 12332' SLM W/EQUALIZ. PRONG AND W/2.25 BAILER ) RIH W/3 1/2 WIRE BRUSH 2.70 GR. MAKE 2 RUNS W/H W/5' 2 1/2 PUMP BAILER OOH W/FIRM CHUNKS OF ASPHALTINES. RUN 3 1/2" GR. UNABLE TO GET PAST 11,840' SLM. POOH W/3 1/2" GR, CAN'T PASS 11,835'. RUN 3 1/2" GS (SHORTER TOOL). UNABLE TO GET PAST 11,835' SLM (OOH W/METAL MARKS ON SKIRT). L/D EQUIPMENT FOR WEEKLY SAFETY MEETING AND TO MAKE IMPROVED JUNK BASKET TOOL AT W/L BLDG. RIH W/1.5 HYD STATIC BAILER W/2.50 07/26/01 (CONTINUED) 0~2~01 07/29/01 07/30/01 08/05/01 08/06/2001 08/09/01 08/12/01 09/05/01 Z-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FINGER CAGE SD & SHEAR DISK @ 12331' SLM (PLUG DEPTH). RIH W/DBL KNKL ABOVE GS & PULL PLUG FROM 12,328' SLM!!! RIH W/3 1/2 XX PLUG W/ FILL EXT. 40" OAL. COULD NOT WORK PAST 11,725' SLM. BRUSH TBG OUT TT. RUN 2.75" PLUG TO 12,367' SLM. WON'T SET. REDRESS & RIH W/SAME BUT SD HIGH @ 11752' SLM. RIH W/2.70 CENT, 3 1/2 BRUSH, & 2.70 GAUGE RING. RUN 3 1/2 XX PLUG W/FILL EXT (40" OAL) & SET @ 12359' SLM. CMIT TO 2000 PSI. AFTER 30 MINUTES T/IA/OA = 610/2000/200 PSI. GOOD TEST ON IA. PLUG LEFT IN HOLE. NOTIFY PAD OPER OF WELL STATUS. RDMO MIT-IA TO 2000 PSI. AOGCC WITNESSED (PASSED). PULL 3 1/2 XX PLUG FROM 12,359' SLM. NOTIFY PAD OPER - WELL LEFT SHUT IN. MIRU CTU#5, KILL WELL WITH 200 BBLS FILTERED 2% KCL-NONSLICK. RIH WITH 2" BDN, STINGER. KILL WELL WITH 200 BBLS FILTERED 2% KCL. RIH TO TAG AT 13147' CTD, PUH TO PLACE FLAG AT 13133' CORRECTED (-4') TO SLMD. ESTABLISH INJECTION RATES OF 0.5 BPM: 775 PSI, 1 BPM- 1015 PSI, 1.5 BPM: 1220 PSI, 1.75 BPM - 1350 PSI. INJECT 25 BBLS OF 12% HCL-10% XYLENE ACROSS PERFS. INJECTION AFTER ACID 1.4 BPM, 1700 PSI WHP AN INCREASE OF 480 PSI. PUMPED 47 BBLS OF 15.8# CLASS "G" CEMENT. LAY IN CEMENT FROM 13133' ACROSS PERFS MAINTAINING 500 PSIG WHP. BUILD SQUEEZE PRESSURE TO 1500 PSIG AND PUH TO SAFETY. BUILD SQUEEZE PRESSURE IN STAGES TO 3350 PSIG. ESTIMATE TOTAL OF 6 BBLS OF CEMENT BEHIND PIPE. RIH CONTAMINATING WITH 1.5# BIOZAN WHILE HOLDING 500 PSIG WHP. CLEAN OUT TO TD OF 13175' (VERY STICKY BOTTOM). LAY IN 10 BBLS TEA ACROSS PERFS. POH JETTING, CHASING CONTAMINATED CEMENT TO SURFACE MAINTAINING 500 PSIG WHP, GETTING I FOR I RETURNS. FP TUBING WITH METHANOL TO 2500' WHILE POH. SI WELL WITH 600 PSIG WHP. ATTEMPT TO MIT CEMENT PLUG IN TBG. MIT FAILED PRESSURE BLED OF FROM 1500 PSI TO 550 PSI IN 4 MINUTES. DRIFT AND TAG W/2" CENT @ 13157' SLM, 190' BELOW TARGET OF CEMENT TOP @ 12967' MD ***LEFT WELL SHUT IN *** PERFS @ 12857-12897' & 12952-12967' ( 3 GUN RUNS) GUN SYSTEM: 2" HSD. CHARGES TYPE: POWERJET PJ 2006 HMX @ 6 SPF / 60 DEG Z-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/05/01 PHASING. (CONTINUED) 09/06/01 PERFS @ 12914-12942'. TWO RUNS WITH 18' @ 10' GUN. 09/27/01 INJ. TEST/STEP RATE TEST 10/16/01 RIH W/2.3" CENT/1 3/4" DD BAILER & TAG FILL @ 13,139' SLM. OBTAINED SAMPLE OF INJECTION SCHMOO. RDMO (NOTE: ALL PERFS OPEN) WELL LEFT SHUT-IN. FLUIDS PUMPED BBLS 85 DIESEL 282 CRUDE OIL 75 60/40 METHANOL WATER 37 NEET METHANOL WATER 812 2% KCL WATER 250 2% KCL SLICK WATER 110 1.5# BIOZAN 25 12% HCL-- 10% XYLENE (TITRATED TO 12.3%, IRON < 50 PPM) 47 15.8 PPG CLASS 'G' CEMENT 10 :TEA 1733 TOTAL 09/06/2001 ADD / RE-PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING 2" POWERJET GUNS, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 12857'-12897' 12914'-12942' 12952'-12967' TREE = $" MCEVOY WFI LFEAD= MCEVOY a CTUATOR= OTIS KB. ELEV = 91.46' BF. ELEV = 55.46' KOP = 1500' Max Angle = 57 @ 5500' Datum MD = 12889' Datum TV D= 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" 2946' Z-31 SAFETY NOTES 2102' H 3-1/2" OTIS SSSV LAND. NIP, D = 2-75"I GAS LIFT MANDRELS IMinimum ID =2.750" @ 2102' 3-1/2" OTIS SSSV NIPPLE 12252' H 3-1/2" CArvlCOSLIDING SLEEVE, ID:2.750" I 12303'H TIW PBR SEAL ASSEMBLYI I TOP OF 7" LNR H 3-1/Z' TBG, 9.2#, L-80, 0.0087 bpf, ID=2.992" H I 9-5/8 " CSG, 47#, L-80, D = 8.681" H 12381' 12426' 12641' PERFORATION SUrvTvIA RY REF LOG: BHCS ON 11/11/88 - CBTON 11/15/88 ANGLEATTOP PERF: 40 @ 12914' Note: Refer to Produc~on DB for hisb3rical perf data SIZE SPF INTERVAL Opn/Sqz DATE Z' 6 12857- 12897' O 09/06/01 2-1/8" 4 12914- 12942' S 08/06/01 Z' 6 12914- 12942' O 09/06/01 Z' 6 12952- 12967' O 09/06/01 2-1/8" 4 12952- 12992' S 08/06/01 5" 4 13002 - 13022' S 08/06/01 5" 4 13032- 13046' S 08/06/01 2-1/8" 4 13058- 13084' S 08/06/01 I PBTD H 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.27ff' H 13210' 13251' 12319' 123 61' 12394' 12426' 12429' H9-5/8"x 3-11Z'TIW 1-13BP PKR, ID =2.99Z' I 3-1/2" OTIS X NIFPLE, ID = 2.750" I H 3-1/2 " OTIS X NIPPLE, ID=2.750" I H3-1/Z' TBG TALI H ELMDTTLOGGED08/22/91 I 12754' H MARKER JOINT I DATE REV BY COIVIVIENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT : 11/16/88 ORIGINAL COIVPLETION 08/13/01 SRB/TP SQZ PERFS WELL: Z-31 03/12/01 SIS-QAA CONVERTE3:) TO CANVAS 09/06/01 CWS/tlh ADDPE~-S PERMITNo: 88-1120 03/14/01 SIS-ND FINAL APINo: 50-029-21871-00 05/19/01 RN/TP CORRECTIONS Sec. 19, T11N, R12E 07/13/01 DAC/KAK UPDATE GLV INFO BP Exploration (Alaska) bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 14, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom' Re: Sundry Notice for Z-31 Conversion from Producer to Injector BP Exploration Alaska, Inc. proposes to convert well Z-31 from a shut-in producer to an active injector as part of the Eileen West End (EWE) Flood Development project. Well Z-31 was drilled in November of 1988 as a conventional rig well. Last production test was 60 BOPD, 1326 BWPD, 4270 GOR (03/11/1996). It has remained shut-in due to high water production since November of 1996. As part of the EWE Flood Development project, dry gas cap injection has been shut down in EWE and is being replaced by a water and miscible injectant flood. The objectives of this project are to reduce produced gas by injecting water to sweep out the expanded gas cap and gas underruns, provide additional oil recover through flood displacement, and access additional reserves through MI injection. Well Z-31 passed MIT-IA (07/29/2001). The plan to prepare for injection is attached. Water injection is scheduled to begin at EWE in September of 2001. MI injection will commence in mid 2002 at the earliest. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5196 or e-mail me at luedkeb@ bp.com. Beverly K, Luedke-Chan Greater Prudhoe Bay Production Engineer, W and Z Pads Well Z-31 Current Status: 11/15/88 CBT/CET shows adequate cement. All gas lift valves have been replaced with dummy valves. MIT-IA passed on 07/29/01 (State Witnessed). Well was squeezed on 08/06/2001 in an attempt to eliminate channel below perforations. Cement top @ 13157' SLM. Plan Forward: 1. Log to find leaking squeeze perforations. Possibility of sandback with a cement cap above the lowest perf interval (if that is what is leaking). 2. Perforate / reperforate intervals with 2", 6 spf, SWS Powerjet charges reference BHCS 11/11/88. 3. Perform step rate test. 4. Put well on injection. TRFF = 3" MCEVOY WB. LFEAD= MCEVOY ACTUATOR= OTIS' KB. ELEV = 91.46' BF. ELEV = 55.46' KOP = 1500' Max Angle = 57 @ 5500' Datum MD = 12889' Datum TV D= 8800' SS I 13.3/8" CSG, 68#, L-80, ID = 12.415" H 2946' Z-31 SAFETY NOTES 2102' H 3-1/2" OTIS SSSV LAND. NIP, D =2.75" I GAS LIFT MANDRELS Minimum ID = 2.750" @ 2102' 3-1/2" OTIS SSSV NIPPLE 12252' Id 3-1/2" CAMCOSLIDING SLEEVE, ID=2.750" [ I TOP OF '7" LNR H 3.1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID=2.992" H 9-5/8" CSG, 47#, L-80, D = 8.681" H 12381' 12426' 12641' 123 03' 12319' 12361' 12394' 12426' I 12429' I--I TIWPBRSEALASSEMBLY I 1--19-5/8" x 3-1/2" TIW FBBP FKR, ID= 2.992" Id 3-1/2"OTISXNIFPLE ID=2.750" I Id 3-1/2"OTISXNIFPLE ID: 2.750" H3-1/2" 'I"BG TA L I Id B_MDTTLOGGED08/22/91 I PEF~'ORATION SUMMA RY REF LOG: BHCS ON 11/11/88- CBTON 11/15/88 ANGLEATTOPPB~F: 40 @ 12914' Note: Refer to Production DB for historical perf data SIZE SPF INTB~VAL Opn/Sqz DATE 2-1/8" 4 12914- 12942' S 08/06/01 2-1/8" 4 12952- 12992' S 08/06/01 5" 4 13002 - 13022' S 08/06/01 5" 4 13032 - 13046' S 08/06/01 2-1/8" 4 13058 - 13084' S 08/06/01 H 13210' 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" H 13251' 12754' I--t MARKER JOINT I DATE REV BY COMMENTS DATE REV BY COMMENTS 11/16/88 ORIGINAL COFvPLETION 07/13/01 DAC/KAI< UPDATE GLV InfO 03/12/01 'SIS-QAA CONVERTEDTO CANVAS 08/13/01 SRB/TP SQZ PERFS 03/14/01 SIS-MD FINAL 05/19/01 RN/TP COF~ECTIONS FRUDHOE BAY UNIT WEt. L: Z-31 PERMIT No: 88-1120 APl No: 50-029-21871-00 Sec. 19, T11N, R12E BP Exploration (Alas ka) STATE OF ALASKA ALAdKA OIL AND GAS CONSERVATION COMMIS~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing Stimulate × Plugging . Perforate X Alter casing Repair well Other__ 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 714' SNL, 1288' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 2250' NSL, 498' EWL, SEC. 07, T11N, R12E, UPM At effective depth 2457' NSL, 607' EWL, SEC. 07, T11N, R12E, UPM At total depth 2482' NSL, 620' EWL, SEC. 07, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13251feet BKB 9161feet 13210feet BKB 9131feet 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 8 c.y. 146 Surface 2910 13 3/8 4101 c.f. 2946 Intermediate 12605 9 5/8 2765 c.f. 12641 Production -- Liner 870 7 300 c.f. 12381-13251 Perforation depth: measured 13002'- 13022', 13032'- 13046' 6. Datum elevation (DF or KB)"~ KBE = 91.46 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-31 (12-07-11-12) PBU 9. Permit number/approval number 88-112/ 10. APl number 50- 029-21871 11. Field/Pool Prudhoe 0il Pool True vertical depth BKB 146 2693 8707 8521-9161 true vertical subsea 8886' - 8919' (two intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 12319' with 3 1/2" tailpipe to 12426' Packers and SSSV (type and measured depth) 9 5/8" TlW packer at 12319'; 3 1/2" SSSV at 2102' RECEIVED 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure M AR 1 § 199; Alaska Oil & Gas Cons. Commissio Anchorage 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water~Bbl Casing Pressure Tubing Pressure Prior to well operation 820 848 115 1526 252 Subsequent to operation 1280 703 270 1680 270 15. Attachments J 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .k L. , C,~'"VMr.",/ Title Senior TechnicalAssistant I Form 10-404-'~'~Rev 06/15/88 ! Service Date '~ j /'~/~...~ SUBMIT IN DUPLICATE WELL Z-31(12-07-11-12) PBU ADD'L, PERF/HC! WASH OPERATIONS The following intervals were add perfed on November 18, 1991 using 2 1/8" guns, 4SPF, 0° orientation and 0° phasing. 12914' - 12942' MD BKB 12952' - 12992' MD BKB 13058' - 13084' MD BKB An HC1 tubing tail wash was performed via coiled tubing on November 27, 1991. Fluids were as follows: 36 bbls Filtered SW with .2% Surfactant 25 bbls 15% Hydrochloric Acid 10% Xylene(14.4% HCL with 10% Xylene,4 Gals ACI-274 Inhibitor, 20lbs Ferrotrol 210, 4 Gals Non-Emulsifier-41,8 Gals S-500 Dispersing Agent) 83 bbls Filtered SW An HCL Matrix Stim was performed on December 2, 1991 using the following fluids' 133 bbls 15% HCL W/Additives 343 bbls Filtered SW W/Surfactant 11 bbls Diverter 10 bbls MEOH fjh 10/17/92 ) ECEIVED MAR 1 5 1993 Alaska Oil & Gas Cons. LlornmisSto~: Anchorage BP EXPLORATION CASED HOLE FINALS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/21/91 T# 83029 Enclosed is your copy of the materials listed below. If you have any questions,.~/Dlease contact BP Well Records at (907) 564-4004. COMPLETION ii/i7/9i #i 12694.00-13115.00 SCH Information Control Well Records Adrian .J. Martin BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO DATE: 08/24/90 EXXON T#: 81536 PHILLIPS STATE OF ALASKA ARCHIVES SYSTEM TaDe & Transmittal Only BP MAGNETI~ LIS TAPE ~ LISTING Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. OPEN HOLE: Z-13 DIFL/BHC/CNL 08/09/90 #- 12336-1;3060 TAPE POS.#07269 ATLAS#4544 1600BPI AP1#50-029-22069 CASED HOLE; ! V Z-17 TMD 07/13/90 #1 12450-13104 HLS#378147 800BPI AP1#50-029-22001 v' Z-28 TMD 07/14/90 #1 9300-10205 h LS#378158 800B PI AP 1#50-029-21879 Z-29 DSN 06/22/90 #1 1192-12029 H LS#491337 800BPI AP 1#50-029-21954 Z-31 TMD 07/15/90 #1 12649-13193 H LS#378169 800BPI AP1#50-029-21871 TAPE POS.#07270 TAPE POS.#07271 TAPE POS.#07272 TAPE POS.#07273 7 Information Control Well Records LR 2-1 J. Dietz/S. McCurry EEEIVED A U G 3 0 1990 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO' DISTRIBUTION Date :08124/90 T#:81517 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedai listed below, if you have any questions, please contact BP Well Records at (907) 564-4~45. Z-17 TMD 07/13/90 #1 12450-13096 HLS 5" Z-28 TMD 07/14/90 #1 9300-11091 HLS 5" Z-31 TMD 07/15/90 #1 12650-13167 HLS 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RES~~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 3, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Z-31 (12-07-11-12) PBU Gent lemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, Manager Production Engineering JAB: JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File · · 1. Operations performed: Operation shutdown .__ Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3, Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Locati°n of well at sUrface 714' SNL, 1288' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 2250' NSL, 498' EWL, SEC. 07, T11N, R12E, UPM At effective depth 2457' NSL, 607' EWL, SEC. 07, T11N, R12E, UPM At total depth 2482' NSL, 620' EWL, SEC. 07, T11N, R12E, UPM 2~ present well condition summary Total depth: measured 13251 feet true vertical BKB 9161feet STATE OF ALASKA A~...,KA OIL AND GAS CONSERVATION COMMI. JN REPORT OF SUNDRY WELL OPERATION Stimulate X Plugging Perforate Repair well .. 5. Type of Well: Development X Exploratory Stratigraphlc Service Plugs (measured) Other 6. Datum elevation (DF or KB) KBE = 91.46 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-31 (12-07-11-12) PBU 9. Permit number/approval number 88-112 / 9-670 10. APl number 50- 029-21871 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 13210feet Junk (measured) true vertical BKB 9131feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 110 20 8 c.y. 2910 13 3/8 4101 c.f. 12605 9 5/8 2765 c.f. measured 870 7 300 c.f. 13002'- 13022', 13032'- 13046' Measured depth 146 2946 12641 12381-13251 True vertical depth BKB 146 2693 8707 8521-9161 true vertical subsea 8886'- 8919' (two intervals) Tubing (size, grade, and measured depth) 3 I/2" L-80 to 12319' with 3 1/2" tailpipe to 12426' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 12319'; 3 1/2" SSSV at 2102' 13. Stimulation or cement squeeze summary see attachment 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 560 279 24 1532 Subsequent to operation 1070 1507 58 1590 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1~/~T4 Rev 08/15/88 237 261 Service Manager Production Engineering Date/,/ SUBMIT IN DU~LICAT~ WELL Z.31 (12.07.11.12~ PBU STIMULATION OPERATIQI~S A diagnostic backflush followed by a perf wash and scale inhibition treatment was performed on the following Zone 4 intervals in Well Z-31. 13002' - 13022' MD BKB 13032' - 13046' MD BKB 8/10/89 Bullheaded 600 bbl.- seawater backflush at maximum rate. Returned well to production, then tested. 9/23/89 Performed thc following perforation wash via coiled tubing: 1000 gal. 15% HC1/10% xylene 36 bbls. diesel 40 bbls. seawater overflush Returned the well to production and tested. 10/2/89 Performed the following scale inhibition treatment via coiled tubing: 24 bbls. diesel w/mutual solvent 10 bbls. methanol 18 bbls. EDTA 36 bbls. scale inhibitor 200 bbls. seawater 26 bbls. diesel The well was left shut in for two hours, then returned to production and tested. jm 10/25/89 BP EXPLORATION BP Exoloratlon (AlasKal Inc. 900 £as[ 5enson Bou,evaro RO. Box 196612 Anchorage. Alaska 995!9-6612 (907) 561-5111 DATE: 10/24/91 T.~ 82948 BP CASED HOLE FINALS Enclosed is your copy of the materials listed ques%ions, please contact BP Well Records at below. If you have any (907) 564-4004. F-~ 4 / CL 09/22/91 ~$.1~ W-07/ ~'~ !O/05/qi 33.-,~~' Z- 3----~~' CA 08/22/91 ~/.~ ~-~ / C~L 0a/25/91 ---~, -. Y-.94'~ CCL 10/01/91 ~.f~-~o~ cch ..... ~ W-09'~-" CCL 09/21/91 ~-~>fS-!8~' GAS LiFT SUR%~Y 08/30/91 ~-~q Y-16/ PROD-F 10/04/91 ~,-~ A-!6 ~/ INJ 09/01/91 ~-,i E-i3 ~' PROD-F 09/24/91 ~'i~ S-07.~/ GAs' LIFT S~X~ !09/22/91:' ~t~ X-17/ ? ?~'~ Y-01~ ~'87 Y-23 X-il~ M-21 ~ >,'. - 14 ?.-27 TEMP 10/05/91 LEAK DET 09/29/91 PITS 09/22/91 LEAK DET 10/04/91 GAS LIFT SURVEY 09/26/91 LEAK DET 09/27/91 SPINNER 10/02/91 SPINNER 10/03/91 INJ 09/30/91 INJ 10/01/91 iNJ 10/07/91 INJ 10/06/91 TEMP 10/07/91 iNJ ~/~o/9! PETS 09/27/91 iNJ 09/29/91 !NJ 10/01/91 CCL !0/02/91 LEAK DET 10/03/91 JEWELRY 5 " ~AS ENTN¥ jEWELRY jEWELRY 5 " 9047.00-10650.00 CAMCO 5 " 13950 . ~0-1451£ . 12!01.00-13!75.00 CAMCO 5 " 9070.00- 9621.00 CAMCO 5 " 8869.00-!0162.00 CA,MC O 5 " 8780.00- 9331.00 CAMCO 5 " 14200.00-!4987.00 CAMCO 5 " 1800.00- 4550.00 CAMCO 2/5" 9000.00- 9405.00 CAMCO 5 " 10470.00-10900.00 CAMCO 5 " i0900.00-Ii290.00 CAi4C S 5 " 3.75.00-11191.00. CAMCO :12~2/5" - i>.~.-' ,~'-" #! 8800.00- 9812.00 CAMCO 5 " #i 7400.00- 7600.00 CAMCO 5 " #! 9100.00- 9547.00 CAMCO 5 " 91 '9770.00-10150.00 CAMCO 5 " ~ 100 00- 8550 00 CAMCO 2 " ~ 170 00-11350 00 CA~MCO 2 " #1 9000.00- 9230.00 CAMCO 5 " %1 12500.00-13125.00 CAMCO 5 " #1 9150.00- 9520.00 CAMCO 5 " ~1 9050.00- 9385.00 CAMCO 5 " =.;! 9650.00-10078.00 CAMCO 5 " oo.oo- 9100.00- 9430.00 CA~MCO 5 " 9450.00- 9734.00 ~'~'~ ~ 2~'0 .~,0- . 5 = i ,.~, 0 n 12650 00'~.~,~"''~'~-~ " =~ 10750.00-11297.00 CAMCO 5 " --2 8996.00-i!779.00 C ~-MC O 5 " ~ 9..,..,0 00 ~650 O0 CAMCO 5 8/30/91 ~1 10800 00-11150.0¢~,CAMC0 ~ -, 06/91 ~i !6639.:30-i1649. 33 C2~<CO !? '05/9! ~1 '.~6,.,u.09-14545 90 CAMCO ~. S-01~--- GAS ENTRY SURVEY 5 " '~ .... jEWELRY _cb 5 " 10,'06/91 9000 ,-10143.00 CA=MCO 9300.00- 9800.00 C.~MCO -~formation ...... Well Records Adrian J. Martin BP EXPLORATION August 3, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Z-31 (12-07-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, /~anager Production Engineering JAM: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File , .SKA OIL AND GAS CONSERVATION COMta, .ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Alter casing ~ Repair well Change approved program Operation Shutdown ~ Re-enter suspended well~ Plugging ~ Time extension ~ Stimulate x Pull tubing ~ Variance ~ Perforate ~ Other =., 5. Type of Well: 6. Datum elevation (DF or KB) Development X KBE = 91.46 AMSL feet Exploratory .. Stratigraphic" 7. Unit or Property name service ~ Prudhoe Bay Unit 8. Well number Z-31 (12-07-11-12) PBU . 9. Permit number 88-I 12 10. APl number 50- 029-21871 11. Field/Pool Prudhoe Oil Pool 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 714' SNL, 1288' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 2250' NSL, 498' EWL, SEC. 07, T11N, R12E, UPM At effective depth 2457'NSL, 607' EWL, SEC. 07, T11N, R12E, UPM At total depth 2482' NSL, 620' EWL, SEC. 07, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 13251 feet true vertical BKB 9161 feet Plugs (measured) Junk (measured) Effective depth: measured 13210 feet true vertical BKB 9131 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented .. 110 20 8 c.y. 2910 133/8 4101 c.f. 12605 9 5/8 2765 c.f. .. 870 7 300 c.f. measured 13002'- 13022', 13032'- 13046' Measured depth True vertical depth BKB 146 146 2946 2693 12641 8707 12381-13251 8521-9161 true vertical subsea Tubing (size, grade, and measured depth) 3 1/2"L-80 to 12319'with 3 I/2" tailpipe to 12426' Packers and SSSV (type and measur~ depth) 9 ~8" TIWpa~er at 12319'; 3 1/2" SSSV at 210E~,>~ A~aohm~nt~ D~oription ~umma~ of prenatal x D~tailod operation~ pr~ram 14. Estimated date for commencing operation August 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMI$$10N USE ONLY Congigd~s of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test _ ~...~ubseq~uent f~eq~r}ed 10- t~ ~ ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner Date ~;:::~° I oproval _ Approved Copy _ Returned., SUB, I~T I~TRIP~LICATE WELL Z-31 (12-07-11-12~ PBU ~TIMULATION PROPOSAL A diagnostic backflush followed by a contingent clay acid treatment is proposed for the following Zone 4 intervals in Well Z-31. 13002' - 13022' MD BKB 13032' - 13046' MD BKB The backflush will consist of 600 bbls. of treated seawater bullheaded at maximum rate. The well will be returned slowly to production, then tested. Depending on the results of the backflush, the following clay acid treatment will be pumped via coiled tubing: a) b) c) d) e) f) h) i) j) k) 12 bbls. Arctic diesel preflush 10 bbls. 10% HCI 3 bbls. diverter 10 bbls. 10% HCI 3 bbls. diverter 28 bbls. 10% HCI 48 bbls. 6% HCl-l.5% HF 36 bbls. 3% NH4CI 83 bbls. 8% HBF4 10 bbls. xylene Displace from coiled tubing with diesel The well will be left shut in for two hours, then returned to production and tested. jm 8/1/89 # . Coiled Tubing . o. · - ack-Of? .( ~2" Ch/-cksan (KIll Lin e) · .I ~ Slips 'j ' ~==~ Pipe Rams Pump-In Sub (CIrcu~a te/R e turn Swab Valve BP EXPLORATION HOUSTON ARCO CHEVRON I NOEXED BP Exploration (Alaska) Inc. --'""'- 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) S61-5.1 04-26-89 E-~QION - Oa*e: TEXACO 80011 'TO: T~: MOBIL PHILLIPS ~TATE OF ALASKA ARCStIVES REFERENCE: BP FLNAL DATA - PRESSURE SURVEY DATA The foi lowing ma~reriai Is being submi~h~ed herewi~ch. Please acknowledge receip~ by signing a copy of fhis .le~-I'er and returning if to this office: B-23 S ~atic Gradient 04-20-89 Camco D-17 Static Gradient 04-18-89 Camco D-26 Static Gradient 04-22.-89 Camco E-03 Static Gradient 04-16-89 Camco F-11 Static Gradient 04-20-89 Camco H-24 Flowing Gradient 04-19-89 Camco K-05 S ratio Gradient 04-18-89 Camco M-17 Static. Gradient 04-20-89 Camco S-18 : Static Gradient 04-16-89 Camco X-19 Static Gradient 04-20-89 Camco Z-25 Static Gradient 04-16-89 Camco Z-31 Static Gradient 04-21-89 Camco Race I ved '~ Alaska Oil & G~s Cons, Commiss;a~ ........ Anchorage _ Shirley R. McCurry I NFORHAT I ON CONTROL Wei I Records LR2-{ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To HOUSTON ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES R ES ERVO IR ARCHIVES Date: 04/17/89 TS: 79969 BP CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: C-23 Prod-F 03/25/89 $1 9800-10170 Camco D-04A PITS 03/22/89 $1 10300-10600 Camco 5" E-14 Prod-F 03/31/89 $1 11400-11680 Camco 5" H-02 CCL/GR 03/15/89 $1 7600-9100 Camco 5' M-06 Spin Temp 03/27/89 ~1 2500-11248 Camco 5" M-29 Inj-F 03/18/89 91 9450-10210 Camco 5' S-18 Leak Der 03/17/89 91 50-11550 Camco 2'/5' W-17 CNL-GR 04/11/89 $1 11350-11850 Sch X-26 Inj-F 03/17/89 91 9200-9530 Camco 5" Z-31 Prod-F 03/16/89 91 12900-13196 Camco 5" Date: Anchorage Information Control Well Records LR2-1 J. Dietz/S. McCurry Standard Alaska ~ Production Company 900 East Benson Bouleva~ P.O. Box 196612 Anchorage, Alaska '99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION Janaury 31, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Z-31 (12-07-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File /J~ A. B ragg ~/ k,44anager Production Engineering XEC IYED ~.., ~cl~orage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '~, operations performed: Operation shutdown Pull tubing 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 714' SNL, 1288' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 2250' NSL, 498' EWL, SEC. 07, T11N, R12E, UPM At effective depth 2457'NSL, 607'EWL, SEC. 07, T11N, R12E, UPM At total depth 2482' NSL, 620' EWL, SEC. 07, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 13251 feet true vertical BKB 9161feet Stimulate X Alter casing Plugging Repair well 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) Perforate Other 6. Datum elevation (DF or KB) KBE,, 91.46 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-31 (12-07-11-12) PBU 9. Permit number/approval number 88-112 / 8-960 10. APl number 50- 029-21871 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 13210feet Junk (measured) true vertical BKB 9131feet Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 8 c.y. 146 Surface 2910 13 3/8 4101 c.f. 2946 Intermediate 12605 9 5/8 2765 c.f. 12641 Production -- Liner 870 7 300 c.f. 12381-13251 Perforation depth: measured 13002'- 13022', 13032'. 13046' True vertical depth BKB 146 2693 8707 8521-9161 true vertical subsea 8886'- 8919' (two intervals) Tubing (size. grade, and measured depth) 3 1/2" L-80 to 12319' with 3 1/2" tailpipe to 12426' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 12319'; 3 1/2" SSSV at 2102' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re~3resentative Daily Average Production or Iniection Data OiI-Bbl Ga~-Mcf Water-Bbl Would not flow 1430 916 46 16. Status of well classification as: Casing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas . Suspended 1 ~'. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10~(4 Rev 06/15/88 ~ 1559 Tubing Pressure Service 273 Manager Production Engineering SUBMIT IN DUPLICATI~ WELL Z-31 (12-07-11-12} PBU STIMULATION OPERATIONS A mud acid breakdown treatment was performed 12/16/88 on the following perforated intervals in Well Z-31. 13002' - 13022' MD BKB 13032' - 13046' MD BKB Prior to the breakdown job a bullheaded HC1/xylene tubing wash was performed. The breakdown was performed as follows: a) b) c) c) d) 750 gal. 15% HC1 1200 gal. 7.5%HC1 - 1.5% HF 1200 gal. 5%HC1 - 0.8% HF 500 gal. 15%.HC12 750 bbls. 15% HC1 (dropped 140 7/8"OD 1.1 SG ballsealers evenly thoughout the fluid Steps a-d were repeated two more times, leaving balls out of the final stage, then the treatment fluids were displaced to within 10 bbls. of the top perforations with 95 bbls. dead crude. The well was surged three times to knock the balls off the perforations, then the well was returned to production and tested. jm 12/25/88 Standard Alaska ~-'" Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION December 16, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Z-31 (12-07-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (6) cc: L. Burke (MB12-1) Z-31 Well File ~/~anager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ OperalJon Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate X Change approved program . Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Standard Alaska Production Company Development X Exploratory __ 3. Address . S[ratigraphic __ 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 Service . 4. Location of well at surface 8. 714'SNL, 1288' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 2250' NSL, 498' EWL, SEC. 07, T11N, R12E, UPM At effective depth 2457' NSL, 607' EWL, SEC. 07° T11N, R12E, UPM At total depth 2482' NSL, 620' EWL, SEC. 07, T11N, R12E, UPM Datum elevation (DF or KB) KBE = 91.46 AMSL feet Unit or Property name Prudhoe Bay Un/t Well number Z-31 (12-07-11-12) PBU 9. Permit number 88-112 10. APl number 50- 029-21871 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 13251 feet BKB 9161 feet Effective depth: measured 13210 feet true vertical BKB 9131 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural -- Conductor 110 20 8 c.y. Surface 2910 13 3/8 4101 c.f. Intermediate 12605 9 5/8 2765 c.f. Production -- Liner 870 7 300 c.f. Perforation depth: measured 13002'- 13022; 13032'- 13046' Measured depth 146 2946 12641 12381-13251 True vertical depth BKB 146 2693 8707 8521-9161 true vertical subsea 8886' - 8919' (two intervaJs) Tubing (size, grade, and measured depth) 3 1/2"L-80 to 12319'with 3 1/2'tailp~oe to 12426' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 12319'; 3 1/2" SSSV at 2102' 13. Attachments Description summary of proposal x Detailed operations program__ BOP sketch 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ .,/~~ 1-rtle Manager Production Engineering _ FOR COMMISSION USE ONLY s of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- ....//~/-t l Approval No..~12..._~/0 Approved by order of the Commission ,i~iNAL SIGNED ::*,' LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL Z-31 (12-07-I1-12) PBU STIMULATION PROPO,$AL A mud acid breakdown treatment is proposed for the following perforated intervals in Well Z-31. 13002' - 13022' MD BKB 13032' - 13046' MD BKB Prior to the breakdown job a bullheaded HCl/xylene tubing wash will be performed. The breakdown will be performed as follows: a) b) c) c) d) 750 gal. 15% HC1 1200 gal. 7.5%HC1 - 1.5% HF 1200 gal. 5%HC1 - 0.8% HF 500 gal. 15% HC12 750 bbls. 15% HC1 (drop 140 7/8"OD 1.1 SG ballsealers evenly thoughout the fluid Repeat steps a-d two more times, leaving balls out of the final stage, then displace the treatment to within 10 bbls. of the top perforation with dead crude. The well will be surged three times to knock the balls off the perforations, then the well will be returned to production and tested. .jm 12/6/8 8 Slandard Ata$~a Production Compan,I 900 Earl Ben,on Boulevard P.O ~ 196612 Anchorage. Alaska ~19-~1~ [907) ~64-~ I I I INDEXED ..... HOUSTON, A~CO STANDARD CHP-V~0N ALASKA PRODUCTION EXXON Date: 12/06/88 TEXACO TO: T~: 79618 MOBIL PHILLIPS STATE OF ALASKA . . ARCHIVES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returnlng It to this offlce: B- 24 Flowing g~adient 11 / 24 / 88 H- 23 Flowing g~zdient F I / 22 / 88 H- 27 Flowing Gradient 11 / 28 / 88 H-28 Flowing G~d~znt I I/23/88. W-22 S~c: G~zzdient 11/21/88 W-25 Static G~z~ent 11/27/88 Y- 01 Flowing Gradi~n~ 11 / 27 / 88 Z-31 StSc G~zdient '11/25/88 CoJ/iCo Camco Camco Camco Camco Camco Camco Camco Race I ved Date ~,,,~'~ Alask,3 Oil & (~as Con~ Anchorage A un~l DJ the or;g;nol Slondord C~l Company Founded in Cle-elond. Ofl~o, in 1870. Jennifer Di~tz I NFORMAT I ON CONTROL Wel I Records LR2-1 I NDE×ED ttOUSTON ARCO CtIEVRON EXXON Date: 1 l- 18-88 TO: TEXACO rl: 79558 MARATHON MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: ARCHIVES SAPC OPEN HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a Copy of this letter and returning It to thls office: fIOU/UNIT/STATE: STANDARD ALASKA PRODUCTION Z-31 BHCS I. 11-11-88 #1 12541-13207 Sch 2"/5" Z-31 LDT/CNL Raw & Pore 11-11-88 #1 12641-13245 Sch 5" Z-31 DIL/SFL 11-11-88 #1 12641-13244 Sch 2"/5" Z-31' SW Core 11-11-88 #1 12641-13244 Sch 5" Z-31 SSTVD 11-11-88 #1 12641-13244 Sch 2" Gyroscopic Directio~~~~l~~_~ Da~ ]1~a5~88 Jobff: 73026 ~ { ~~ ~d~ ' ~~Pa.~11~l JobJ,; 660 Received .~.. .. ~;~ ~ ....... Shirley R. McCurry ~' , ;?~ I NF~T I ON C~TR~ o. to ~ alaska 0il & Gas Cons. Commission wos~ Records LR2-1 ~ ~lchorage STATE OF ALASKA ALASKAOIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SIJSPEN~ [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 88-112 3. Address 8. APl Number P. O. Box 196612; Anchorage, Alaska 99519-6612, .. s0- 029-21871 .......... 4. 'Location of well at surface 9. Unit or Lease Name 714' At Top SNL, Producing 3664' WEL, ~nterval SEC. 19, T11N, R12Ei ~-'""--""-~ i LOCATIONS ! 10. Prudhoe 'Well Number Bay Unit 3030' SNL, 4454' WEL, SEC. 7, T11N, R12E il VERIFI~..~ Z-31 (12-07-11-12) At Total Depth' ~ w ~,~r~'~- ~' 1prudhoel. Field andBayPOOl Field/Prudhoe Bay Pool 2798' SNL, 4332' WEL, SEC. 7, T11N, R12E ~ 5. 'Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and' Serial No. KBE--- 91.46' I ADL 47450 12. Date Spudded' 13. Date T.D. Reached 14. Date Comp., Susp'. or Aband. 115. Water Depth, if olfsho re 116. No. of Completions 10-17-88 11-12-88 11-17-88I N/A feet MSL . I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD', 19. Directional Survey 120. Depth where SSSV'sat 121. 'Thickness ol Permalrost 13251'MD 9161'TVD 13210'MD 9131'TVD Yes [] NO []I 2102 feet MD I 1995' 22'. Type Electric or Other Logs Run BHCS,. LDT/CNL Raw & Poro, DIL/SFL, SW. Core, SSTVD 23. CASING, LINER AND CEMENTING RE-COF~ SET'rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20~ ConductOr '" Surface 110' , . "8'cu'yds Concrete ' "~ "' 13-3/8'~ 68# L-80 Surface 2946' 17-1/2" 4101 cu ft Permafrost '9-5/8" 47# NSCC Surface 12481; ' 12-1/4" 9-5/8" 47# L-80 12481' 12641' 12-1/4" 2765 cufl Class G ' .... 7~ 26# IJ4S 12381' 13251' 8-1/2" 300 cu ft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET {MD) PACKER SET {MDI Schlumberger 5" ~ 4 spf 3-1/2" 9.3~ .... 12426' 12319' MD TVDss L'80 ......... 13002'-13022' 8886'-8901' 26. .ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13032'-13046' 8908'-8919' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8" x 9-5/8" Freeze Protect 13-3/8" x 9-5/8" AnnUlus Wit..h 150 BBL. S .Drz,, C. ruSe~ ,,, 27. PRODUCTION TEST ..... Date First Production IMethod of Operation (Flowing, gas lift, etc.) November 15, 1988 I Flowing Da're of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL ~SIZE IGAS-OIL RATIO TEST PERIOD I~ I 'Flow' T~bing" Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) "' Press. 24-HOUR RATE I~ 2~. '" CORE DATA ,', r' r' ~ t \/~ ['1 Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core Chips. K ~- ~ L I '~ I.. ~ DEC ' 7 98B Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS ' 'I~TION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. SAG 12638' 8704' SHUBLIK A 12683' 8737' ZONE 4 12857' 8867' (Top Sadlerochit) 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge q~ Signed /.~~~~.~ Title PRU Drilling Engineering Sur~ervisor 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 STANDARD ALASKA PRODUCTION' Daily Drilling Report -- PRUDIIOE BAY October 17, 1988 at 0600 hrs Rig: AUDI #2 Well: Z-31 (12-07-11-12) AFE# 120717 AFE Amount: Current Amount: 0600 Depth: Day: -4 72- Hour Ftg: Water Used: 800 Current Operation: Rigging up top drive. Moved rig to Z-31. Rigged up. Mud Type: WT: VIS: PV: YP: FL: Solids: Temp: STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY October 18, 1988 at 0600 hfs Rig: AUDI #2 Well: Z-31 (12-07-11-12) AFE# 120717 AFE Amount: Current Amount: 0600 Depth: 608' Day: 1 24- Hour Ftg: 491' Water Used: 800 Current Operation: Drilling 17-1/2" hole. Rigged up & spudded well @ 2000 hrs on 10-17-88. Drilled 17-1/2" hole to 608'. Mud Type: Spud WT: 9.5 VIS: 150 PV: 24 YP: 46 FL: 1 1.2 Solids: 6 Temp: 48o1:: STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY October 19, 1988 at 0600 hfs Rig: AUDI//2 Well: Z-31 (12-07-I1-12) AYE # 120717 AYE Amount: Current Amount: 0600 Depth: 1071' Day: 2 24- Hour Ftg: 463' Water Used: Current Operation: Drilling 17-1/2" hole. Drilled 17-1/2" hole to 800'. PU motor & kicked off/drilled to 1071'. Mud Type: Spud WT: 9.8 VIS: 142 PV: 29 YP: 50 FL: 9 Solids: 9 Temp: STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDItOE BAY October 20, 1988 at 0600 hfs Rig: AUDI #2 Well: Z-31 (12-07-11-12) AFE # 120717 AFE Amount: Current Amount: 0600 Depth: 1666' Day: 3 24- HourFtg: 595' Water Used: I 100 Current Operation: POOH for bit. Drill 17-1/2" hole with surveyS'to 1666'. Mud Type: Spud WT: 9.7 VIS: 162 PV: 24 YP: 43 FL: 10.6 Solids: 9 Temp: 63'F Daily Drilling Report -- PRUDIIOE BAY October 21, 1988 at 0600 hfs STANDARD ALASKA PRODUCTION Rig: AUDI/12 Well: Z-31 (12-07-11-12) AFE# 120717 AFE Amount: Current Amount: 0600 Depth: 2965' Day: 4 24- HourFtg: 1277' Water Used: Current Operation: Wiper trip. Drilled 17-1/2" hole with survdys to 17-1/2" TD @ 2965'. Mud Type: Spud WT: 9.8 VIS: 170 PV: 26 YP: 39 FL: 11.6 Solids: 10 Temp: 65°F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY October 24, 1988 at 0600 hfs Rig: AUDI/t2 Well: Z-31 (12-07-11-12) AFE # 120717 AFE Amount: Current Amount: 0600 Depth: 6123' Day: 7 72- Hour Ftg: 3158' Water Used: 3900 Current Operation: Ran & cemented 13-3/8" casing. Pumped 50 sacks top up job. Nippled up & tested BOP. RIH & tested 13-3/8". Drilled out shoe & performed LOT. Drilled 12-1/4" hole with surveys to 6123'. Mud Type: Dispersed WT: 10.05 VIS: 40 PV: 11 YP: 7 FL: 7.0 Solids: 11.5 Temp: 70'1:: STANDARD ALASKA PRODUCTION Rig: AUDI #2 Well: Z-31 (12-07-11-12) Daily Drilling Report -- PRUDHOE BAY October 25, 1988 at 0600 hfs AFE # 120717 AFE Amount: Current Amount: 0600 Depth: 7560' Day: 8 24- HourFtg: 1437' Water Used: 1 I00 Current Operation: POOH. Drilled 12-I/4" hole with surveys to 7560'. Mud Type: Dispersed WT: I0.0 VIS: 38 PV: 11 YP: 7 FL: 8.0 ; Solids: 11.5 Temp: 83~F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDIIOE BAY October 26, 1985 at 0600 hfs Rig: AUDI/12 Well: Z-31 (12-07-11-12) AFE tt 120717 AFE Amount: Current Amount: 0(¢X) Depth: 8461' Day: 9 24- Hour Ftg: 901' Water Used: 2100 Current Operation': RIH. Drilled 12-I/4" hole with surveys to 8461'. RHt with motor. MudType: Dispersed WT: 10.3 VIS'40 PV: 15 YP: 5 FL:5.6 Solids: 13.5 Temp: 90°F STANDARD ALASKA PRODUCTION Daily Drilling Repot! -- I'RUI)IIOE BAY October 27, 1988 al 0600 hfs :Rig: AUDI #2 Welt: Z-31 (12-07-11-12) AFE# 120717 AFE Amount: Current Amount: 0600 Depth: 8663' Day: I0 24- ttour Ftg' 202' Water Used: 600 Current Operation: RIH. Motor drilled to 8665', POOH. Mud Type: Dispersed WT.' 10.4 VIS'40 PV: 14 YP: 8 Solids: 13.5 Temp: 85 °F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDIIOE BAY October 28, 1988 at 0600 hrs Rig: AUDI #2 Well: Z-31 (12-07-11-12) AFE # 120717 AFE Amount: Current Amount: 0600 Depth: 4060' Day: I 1 24- Hour Ftg: 402 Water Used: Current Operation: Rill. Drilled 12-1/4" hole with surveys to 4060' Mud Type: DisPersed WT: t0.4 VIS:40 PV: 16 YP: 8 FL:6 Solids: 13.5 Temp: 82 ~F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDtIOE BAY October 31, 1988 at 0600 hrs Rig: AUDI #2 Wet4:Z-31 (12-07-11-12) AFE# 120717 AFE Amount: Current Amount: 0600 Depth: 10,001' Day: 14 72- Hour Ftg: 940' Water Used: 1400' Current Operation: RIH. Drilled 12-1/4" hole with surveys to 10,001'. POOH for repairs t.o top drive RIH. Mud Type: Dis~rsed WT: 10.5 VIS:42 PV: I5 YP:8 FL: 3.6 Solids: 14 Temp: __- STANDARD ALASKA PRODUCTION Daily Drilling Report -- I"I,'[JI)II()E iIAY November 1, 1988 at 0600 hrs Rig: AUDI #2 Well' Z-31 (12-07-11-12) AFE# 120717 AFE A~nount: Current Amount: 0600 Depth' 10,600' Day: 15 24- Hour Ftg: 59,6' Water Used: 700 Current Operation: Drilling 12-1/4" hole. Drilled 12-1/4" hole with surveys to 10,600'. Mud Type: Dispersed WT: 10,5 V.IS:42 PV: 13 YP: 13 FL:4 Solids: 14 Temp: 88 CF STANDARD ALASKA PRODUCTION Daily Drilling Report -- I'I~UI)IIOE IlAY November 2, 1988 at 0600 hfs ~;,,' AUDI#2 ,, x ,. ,..~. Well: Z-31 (12-07-11-12) AVE# 120717 AI:E Amount: Current Amount' 0600 Depth' 10,900' Day: 16 24- Hour Ftg: 300' Water Used: 700 Current Operation: Drilling 12-1/4" hole. Drilled 12-1/4" hole to 10,900' with surveys. Mud Type: Dispersed WT: t0.5 VIS:42 PV: 12 YP:7 FL:4.4 Solids: 14.5 Temp: 88 CF STANDARD ALASKA PRODUCTION Rig: AUDI#2 Well: Z-31 (12-07-11-12) Daily Drilling Rel)orl -- i'RUi)iI()E Nove[]'~l)er 3, 19,";,"; a! ()6(1()hfs Al:li.¢,~ 12()717 Al:l:. (Turz'cnt Current Operation: 0600 Del)th: 11,118' l)av: 17 24- Hour Ftg: 218' Water Used: Drilling 12-1/4" hole. Drilled 12-1/4" hole with surveys to It,118'. Mud Type: Dispersed WT: 10.5 VIS:ag) PV: 11 YP: 6 FL:4.4 Solids: 14 Temp: 89 ~ STANDARD "ALASKA PRODUCTION Rig: AUDI/12 Well: Z-31 (12-07-II-12) Daily Drilling Report -- PRUDII.OE BAY November 4, 1988 at 0600 hrs AVE# 120717 AVE Amount: Current An~ount: Current Operation: 0600 Depth: 11,510' Day: t 8 24- Hour Ftg: 392' Water Used: 5(X) POH f/bit. Drilled 12-I/4" hole to 11,510'. Mud Type: Dispersed WT: 10.5 VIS:45 PV: 16 YP: 11 FL:4.4 Solids: 14.2 Temp: 1,08 STANDARD ALASKA PRODUCTION Daily Drilling Report -- I~I~UI)II()E BAY NOvember 7, 1988 at 0600 hrs Rig: AUDI#2 We!l: Z-31 (12-07-11-12) AFE# 120717 AI:E A mount: Current Amount' 0600 Depth' 12,647' Day: 21 72- Hour Ftg: I137' Water Used: 1400 Current Operation: Short trip @ 12,647', TD 12-1/4" hole. Dritiling 12-1/4" .hole to 11,939'. Dry job & POll. Pull wear ring & test BOPE & set wear ring. RIH. Drilling 12' 1/4" hole to 12,647'. Short trip f/9-5/8" casing. Mud Type: Dispersed WT: 10.5 V'IS:40 PV: 14 YP:8 FL: 4.8 Solids: 14.3 Temp' 108 °F STANDARD ALASKA PRODUCTION Daily Drilling Report -- i'RUI)ilOE BAY November 8, 1988 at 0600 hfs Rig: AUDI#2 Well' Z-31 (12-07.11-12) AFEit 120717 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Water Used: 12,647' 22 Current Operation' Running 9-5/8" casing. POH. Rig up & run 9-5/8" Mud Type: Dispersed WT: 10.5 VIS:48 PV: 16 YP: II FL:4.2 Solids: 14.4 Tem.p' 86°F STANDARD ALASKA PRODUCTION ,Rig: AUDI #2 Well' Z-31 (12-07-11-12) Daily I)rilling Report -- I~RUDI-I()E BAY November 9, 1988 at 0600 hfs AFE# I20717 Al:f:. Amount: Currcnt Amount: Current Operation: RIH 0600 Depth' Day' 24- Hour Ftg: Water Used' 12,647 23 Ran and cemented 9-5/8". Tested BOPE. P.U 8 1/2" BHA. Mud Type: Disp. WT: 9.5 VIS- 31 PV: 3 YP: 2 FL: 6.5 Solids: 8.5 Temp: STANDARD ALASKA PRODUCTION Daily Drilling Report -- I'RUDIIOE BAY November 10, 1988 at 0600 hfs Rig: AUDI #2 Well' Z-31 (12-07-11-12) AFE # 120717 AFE Amount: Current Amount: 0600 Depth' I2,832 Day: 24 24- HourFtg: 185 Water Used: 140. Current OperatiOn: RIH Tested casing to 3,000 psi. Drilled shoe. Drilled 8-1/2" to 12,832'. POH. Mud Type: Disp. WT: 9.5 VIS: 38 PV: 6 YP: 6 FL: 8.4 Solids: 8 Temp' 106 cF STANDARD ALASKA PRODUCTION Daily l)rilling Report -- i'RUDIIOE November 11, 19,'-;8 at 0600 hfs Rig: AUDI#2 Well: Z-31 (12-07-11-12) AFE# 120717 AFE Amount' Current Amount: 0600 Depth: 13,251 Day: 25 24- Hour Ftg: 419 Water Used' 500 Current Operation: POH for logs Drilled 8-1/2" hole to TD @ 13,251' Mud Type: Disp. WT: 9.4 VIS' 36 PV: 9 YP: 6 FL: 5.6 Solids: 7.5 Temp: t02 °F STANDARD ALASKA PRODUCTION l)aily Drilling Report -- PRUDIIOE BAY November 14, 1988 at 0600 hrs 'Rig: AUDI#2 Well' Z-31 (12-07-11-12) AFEtt 120717 AVE Amot~nt: Current A~n()unt' 0600 Depth: 13,251 Day: 28 72- Hour Ftg: Water Used: 2,600 Current Operation' Drilling on landing collar Ran togs. Wiper trip. Run & cemented liner. RIIt & cleaned ()tit to top of liner @ 12,381'. RIH w/6" bit. Tested liner lap. Cleaned liner to landing collar. Mud Type' Disp. WT: 9.3 VIS: 36 PV' 6 YP: 3 FL: 16.2 Solids: 6.5 Temp' °F STANDARD ALASKA PRODUCTION .... Daily Drilling Report -- PRUD.IIO'E BAY November 15, 195g at 0600 hfs Rig: AUDI#2 Well: Z-31 (I2-07-11-12) AFE# 120717 AFE Amount: Current Amount: 0600 Depth: 13,210 Day: 29 24- Hour Ftg: Water Used' 1,000 Current Operation: POH ~for cased hole logs Cleaned out liner to float collar. Displaced hole to filtered brine. Mud Type: Brine WT: 9.4 VIS: 16 PV: YP: FL: Solids: Temp: STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDIIOE BAY November 16, 1988 at 0600 hfs Rig: AUDI#2 Well' Z-31 (12-07-11-12) AFE# 120717 AFE Amount: Current Amount: 0600 Depth: Day: 24- ltour Ftg: Water Used' 13,2 I'0 30 Current Operation: RtrH with 3-1/2" tubing P~,un CBT/CET/GR/CCL & Gyro. PERF: (13,002'- 13,022') & (13,032' - 13,046') with 5" .perf. guns @ 4 shots/ft. Mud Type: Brine WT: 9.4 VIS' 1.6 PV: YP: FL: Solids: Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI 1t2 Well: Z-31 (12-07-11-12) Daily Drilling Report -- PRU:DiIOE BAY November 17, 1988 at 0600 hfs AFE# 120717 A FE Amount' Current Amount' 0(ff)O Depth' Day- 24 - ltour Ftg: Water Used' 13,210 31 Current Operation: Attempting to set W.L. Plug in X-nipple. Landed 3-1/2" tubing. NU & tested tree. RIH with W.L. & attempted to set plug in X-nipple. Circ. 120 bbls around packer. Mud Type: Brine WT: 9.4 VIS: 26 PV: YP: FL: Solids: Temp- STANDARD ALASKA PRODUCTION Rig- AUI)I #2 Well: Z-31 (12-07-11-12) Daily Drilling Report -- PRUDll()E BAY November 18, 1988 at 0600 hfs AFE# 120717 AFE A mount: Current Amount: 0600 Depth' Day: 24- Hour Ftg: Water Used: 13,210' 32 Current Operation' Release .rig @ 2100 Hrs. Moving to Z-28 Set W.L. plug. Set packer @ 12,319'. Test backside. Displace annulus w/Brine. Displace tubing and 40 bbls annulus with diesel. Test tubing and annulus. Rig down CAMCO, set BPV & secure tree. Release rig. Mud Type: Brine WT: 9.6 VIS: PV: YP: FL: Solids: Temp: °F ~I TELE£OJ Teleeo Oilfield Se, _.es of AI.sk. Inc. 61 16 Nielsen Way Anchorage, AK 99502 (907) 562-2646 November 10, 1988 JOB #660 STANDARD ALASKA PRODUCTION CO. WELL: Z-31 PRUDHOE BAY UNIT RIG: AUD #2 Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to Standard Alaska Production Company. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures A ~¢,~17 COMPANY TELECO OILFIELD SERVICES JOB #660 SURVEY CALCULATIONS **************************************** Date 11/8/88 Page 1 Company: STANDARD ALASKA PRODUCTION CO. Well: Z-31 Location: · PRUDHOE BAY Rig: A.U.D.I. RIG #2 TELECO Job # 660 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 356.07 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' ********** *********** *********************************************** ******************************** TIE IN TO VERTICAL 110.00 0.0 356.0 N 03 55'W 110.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD 786.00 0.5 30.4 N' 30 24 E 785.99 -1.36 1.24S 1.81E 2.20 S 55.577E 0.341 881.00 1.6 4.4 N 04 24 E 880.97 0.24 0.40N 2.33E 2.36 ~ 80.196E 1.233 971.00 2.1 4.8 N 04 48 E 970.92 3.11 3.29N 2.56E 4.17i N 37.864E 0.556 569.00 0.4 140.5 S 39 30 E 568.99 -1.38 1.36S 0.36E 1.40 S 15.068E 0.146 385.00 0.2 177.1 S 02 54 E 384.99 -0.47 0.47S 0.02E 0.47 S 2.900E 0.073 TELECO Job # 690 TAK 11/8/88 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg. deg/100' **************************************************************************************************** 1066.00 2.6 8.0 N 08 00 E 1065.84 6.94 7.17N 2.99E 7.77 N 22.698E 0.545 1158.00 2.5 7.9 N 07 54 E 1157.75 10.95 11.22N 3.56E 11.77 N 17.620E 0.114 1221.00 2.5 9.0 N 09 00 E 1220.69 13.63 13.94N 3.96E 14.49 N 15.889E 0.089 1345.00 5.1 0.6 N 00 36 E 1344.41 21.75 22.12N 4.65E 22.60 N 11.884E 2.139 1438.00 8.5 350.4 N 09 36 W 1436.74 32.74 33.08N 3.79E 33.30 N 6.540E 3.866 1529.00 11.5 343.0 N 17 00 W 1526.35 48.32 48.45N 0.16E 48.45 N 0.190E 3.580 1609.00 14.6 344.4 N 15 36 W 1604.27 65.96 65.78N 4.90W 65.96 N 4.267W 3.895 1717.00 18.6 345.8 N 14 12 W 1707.75 96.25 95.59N 12.84W 96.45 N 7.650W 3.722 1902.00 24.3 346.9 N 13 06 W 1879.86 162.90 161.31N 28.79W 163.86 N 10.122W 3.089 2087.00 30.6 344.0 N 16 00 W 2043.'95 246.67 243.80N 50.21W 248.92 N 11.637W 3.480 2180.00 32.4 344.4 N 15 36 W 2123.25 294.22 290.55N 63.44W 297.40 N 12.317W 1.948 2273.00 34.4 345.4 N 14 36 W 2200.88 344.44 339.98N 76.77W 348.54 N 12.725W 2.230 2367.00 35.7 346.2 N 13 48 W 2277.83 397.56 392.31N 90.01W 402.50 N 12.923W 1.467 2501.00 39.1 346.2 N 13 48 W 2384.27 477.74 471.35N 109.38W 483.88 N 13.066W 2.537 2595.00 40.5 345.1 N 14 54 W 2456.49 536.92 529.64N 124.30W 544.03 N 13.208W 1.667 2690.00 44.4 345.8 N 14 12 W 2526.57 599.93 591.69N 140.40W 608.12 N 13.349W 4.135 2784.00 48.6 346.2 N 13 48 W 2591.26 667.05 657.84N 156.89W 676.29 N 13.415W 4.479 TELECO Job # 6~0 TAK 11/8/88 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' **~********************************************************************************************** 2878.00 52.4 346.5 N 13 30 W 2651.04 738.52 728.31N 174.01W 748.81 N 13.437W 4.050 3156.00 54.1 345.1 N 14 54 W 2817.37 957.69 944.24N 228.65W 971.53 N 13.612W 0.733 3437.00 53.8 345.4 N 14 36 W 2982.74 1180.84 1163.94N 286.48W 1198.68 N 13.828W 0.137 3720.00 53.3 345.8 N 14 12 W 3150.87 1404.69 1384.43N 4189.00 53.3 346.5 N 13 30 W 3431.16 1775.09 1749.52N 343.10W 1426.31 433.11W 1802.33 N 13. 919W 0. 210 o. 5506.00 56.7 348.0 N 12 00 W 4197.31 2831.21 2790.97N 682.89W 2873.30 N 13.749W 0.778 5786.00 56.5 348.6 N 11 24 W 4351.44 3062.82 3019.86N 730.30W 3106.91 N 13.595W 0.193 6069.00 55.3 347.9 N 12 06 W 4510.10 3294.97 3249.29N 778.02W 3341.14 N 13.466W 0.471 6351.00 55.5 347.6 N 12 24 W 4670.23 3524.66 3476.13N 827.27W 3573.21 N 13.387W 0.113 6632.00 56.1 347.6 N 12 24 W 4828.18 3754.56 3703.16N 877.08W 3805.61 N 13.325W 0.214 6913.00 55.8 347.6 N 12 24 W 4985.51 3984.88 3930.59N 926.98W 4038.42 N 13.270W 0.108 7194.00 54.8 346.2 N 13 48 W 5145.48 4212.94 4155.59N 979.34W 4269.43 N 13.261W 0.543 7477.00 53.5 345.0 N 15 00 W 5311.22 4438.50 4377.76N 1036.38W 4498.76 N 13.319W 0.574 7759.00 52.3 344.4 N 15 36 W 5481.32 4659.00 4594.70N 1095.73W 4723.55 N 13.413W 0.458 5225.00 55.1 346.2 N 13 48 W 4039.77 2601.39 2564.17N 630.95W 2640.66 N 13.824W 0.299 5039.00 54.6 346.5 N 13 30 W 3932.69 2451.49 2416.39N 595.06W 2488.58 N 13.834W 0.221 4660.00 53.8 346.2 N 13 48 W 3710.99 2148.51 2117.68N 522.52W 2181.19 N 13.860W 0.118 TELECO Job # 6~0 TAK 11/8/88 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' **************************************************************************************************** 8042.00 50.6 344.4 N 15 36 W 5657.68 4875.73 4807.87N 1155.14W 4944.69 N 13.510W 0.601 8324.00 49..0 343.3 N 16 42 W 5839.69 5086.23 5014.75N 1215.05W 5159.85 N 13.620W 0.641 8569.00 48.3 351.8 N 08 12 W 6001.55 5267.95 5194.17N 1254.66W 5343.56 N 13.580W 2.619 8692.00 48.8 359.2 N 00 48 W 6082.97 5360.08 5286.02N 8799.00 48.5 359.6 N 00 24 W 6153.66 5440.27 5366.34N 1261.89W 5434.55 1262.73W 5512.90 N 13.427W 4.526 N 13.241W 0.397 9456.00 48.7 7.6 N 07 36 E 6594.40 5924.17 5852.71N 1243.35W 5983.32 N 11.994W 1.512 9740.00. 49.9 7.6 N 07 36 E 6779.59 6135.12 6066.13N 1214.75W 6186.56 N 11.324W 0.423 9937.00 50.0 9.0 N 09 00 E 6906.36 6282.49 6215.34N 1192.98W 6328.80 N 10.865W 0.546 10347.00 50.9 11.8 N 11 48 E 7167.42 6588.76 6526.25N 1135.91W 6624.37 N 9.874W 0.570 10720.00 51.7 15.0 N 15 00 E 7400.63 6866.61 6809.39N 1068.46W 6892.70 N 8.918W 0.703 10940.00 51.5 14.6 N 14 36 E 7537.29 7029.88 6976.08N 1024.42W 7050.89 N 8.354W 0.170 11067.00 51.2 16.4 ~ N 16 24 E 7616.60 7123.42 7071.65N 997.92W 7141.71 N 8.032W 1.132 11437.00 49.4 18.1 N 18 06 E 7852.94 7388.84 7343.50N 913.50W 7400.10 N 7.091W 0.601. 11720.00 48.4 16.0 N 16 00 E 8038.97 7587.95 7547.37N 850.98W 7595.20 N 6.433W 0.661 9363.00 48.3 5.8 N 05 48 E 6532.77 5855~71 5783.54N 1251.48W 5917.39 N 12.210W 1.551 9174.00 47.5 2.0 N 02 00 E 6406.06 5716.81 5643.65N 1261.01W 5782.82 N 12.595W 0.816 8984.00 47.4 359.9 N 00 06 W 6277.57 5577.35 5503.71N 1263.33W 5646.84 N 12.928W 0.607 TELECO Job # 6~0 TAK 11/8/88 ~age 5 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 11941.00 46.8 18.8 N 18 48 E 12128.00 46.1 20.6 N 20 36 E 8316.83 12378.00 45.1 24.1 N 24 06 E 8491.74 12566.00 44.1 27.6 N 27 36 E 8625.60 8187.99 7739.95 7703.08N 7864.11 7830.68N 8024.24 7995.85N 8138.79 8114.62N 802.18W 7744.74 N 5.945W 756.50W 7867.13 N 5.518W 688.59W 8025.44 N 4.922W 631.04W 8139.12 N 4.447W 1.183 0.792 1.077 1.411 TELECO Oi 1 ~ i ~i d S~rv ices ~' -PLAN VIEW WEST 8000 8400 4800 :9~ O0 1600 0 12800 CO 1 1200 9800 8000 l- O 4800 z 9200 1600 1600 1600 2000 4000 6000 TELECO 0 i 1F i e 1 d S~rv i VERT I £AL PRO;ECT I ON .J fJ LL! 8000 i 0000 2000 14000 16000 18000 - 1000 1000 9000 5000 7000 gO00 11000 Fi i:r~'~. ~F'f~r- ['I"Fi ! ~ ..... m- ~ ~ ii ' i-Nz,~~~I,~~ t_~_ ~ '~_ ~ .[' ici ~., I I I ~._ ' ~' ' ~ ~ ~ ~ [ , ~ ' Li ~_I ~ l ii i t ~!.j.~!_~~.~,, i i_ i ~ i i ¢ ''i ~ ;' i ~ : ................. ~ . ~_ [ .] ~ ~. r..t ~..~' ~ , , · ~ ~ · I .l I ' ~ ~ I I . i ,] i i , ,i I ' ' ' 1 t , I : , , , , · , i p · , ,,. . ....,-.. OB~ 66D T4KZ t ,. ~ ! I ~, , . · I j I CO VERTICAL SECTION (Ft) SUB.~URFACE DIRECTIONAL ~URVEY F'~UIDANCE [~]ONTINUOUS F'flooL Company Well Name STANDARD ALASKA PRODUCTION COMPANY Z.-31..(12-07-11-12)(714'. SNL,3664' WE.L..,SEC 19,TllN~R]2E) Field/Location PRUDHOE BAY, NORT,,H SLOpE~ ALASK,A Job Reference No. 73026 Oate~_~E 15- NOV- 88 Computed WARNER SINES * SCHLU~OERG£R * GCT DIRECTIONAL SURVEY CUSTOMER LISTING ARCO ALASKA, INC, Z-31 (12-07-11-12) PRUDHOE BAY NORTH SLOPE:, ALASKA DATES 15-N0¥-88 WARNER ~ETHODS OF Cn~POTATION TOOL [.OCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTIOn!: HORIZ. DIST, PROOECTED ONTO A TARGET AZIMUTH OF NORTH 4 DEG 44 ~IN WEST ARCO ALASKA, [NC. Z-3] (12-07-11-12) P~UDHO£ BAY NORTH SLOPE,ALASKA COMPUTATION DAT£: 18-NOV-88 PAGE DATE OF SURVEY{ 15-NOV-88 KELLY BUSHING EbEVATION{ 91,46 FT ENGINEERI WARNER INTERPOLATED VALUES FOR EVEN 100 f'EET Of' MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTii DEPTH DEPTH DEPTH DEG NIN DEG o n0 100 O0 200 O0 300 O0 400 O0 500 O0 6OO O0 700 O0 BO0 O0 900 O0 0 O0 lO0 O0 200 O0 3OO O0 400 O0 5O0 O0 600.00 700,00 799,99 899,96 -91,46 0 0 N 0 0 E 8,54 0 B $ 59 b5 E 108,54 0 6 $ 7133 E 20fl.54 0 2 N 2150 W 308,54 0 3 N 7027 E 408,54 0 11 S 511 28 E 508,54 0 7 S 9 6 E 608,54 017 N 513 W 708,53 058 N 1645 E 808,50 1 52 N 11 36 E 1000 O0 1100 1200 1~00 I 00 1500 1600 1700 1800 1900 99989 908,43 216 O0 109981 1008,35 225 O0 1199 71 1108,25 237 O0 129956 1208,10 4 9 O0 139907 1307.61 710 O0 149784 1406,38 1024 O0 159569 1504,23 1338 O0 1692 O0 1600.54 17 ]2 O0 178632 1694,86 2056 O0 187872 1787,26 24 0 VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 000 O0 1968,68 1877,22 2737 ~100 O0 2056,01 1964,55 3025 2200 O0 214130 2049,84 3229 2300 O0 2224:69 2133.23 3425 2400 O0 230640 2214,94 36 In 2500 O0 2385~62 2294,1b 3H 52 2600.00' 2462.53 2371.07 4056 2700.00 2535.70 2444.24 45 6 2800,00 2603.47 2512,01 4929 2900,00 2665,59 2574,13 53 ll 0.00 0,00 0,06 0,10 ~o.19 0.20 -0,13 0,05 -0.09 0.10 '0.1.7 0,16 '0,38 0,24 -0,31 0,56 0,71 0,84 3.15 0,57 3000 O0 2724,98 3100 O0 2784,34 3200 O0 2843,52 3300 3400 3500 3600 3700 380O 3900 2633.52 53 28 2692,88 53 35 2752,06 53 52 O0 2902.52 2811.06 53 52 O0 2961,66 2870.20 5327 O0 3021,24 2929,78 5327 003080.832989.375317 O0 3140~7191~' 3049i~ 53 12 O0 3200:5 3109 53 8 O0 3260 b5~': 38359 53 12 h 10 8 E 6,63 0,61 N 10 18 E 10.66 0,06 N 9 33 E 14,83 0,42 N 616 £ 20 15 2'95 N 629 W 29:81 4,07 N 1421 W 45,27 ~ 40 N 16 11 W 65'44 ~:77 N 1458 W 91.78 4,40 N lb 18 W 124 44 3,18 N 14 32 W 161:9B 3,37 14 49 ~ 205 O1 16 lb W 252:79 15 56 W 303.94 15 14 ~ 358.13 1.5 lq w 414.83 lb 13 W 474,69 1557 ~ 537.31 1522 W 504.19 15 5 W 676.46 15 0 W 753,52 N 15 6 W 832,67 N 15 13 W 911 83 N 15 26 W 991:05 1544 W 1070,35 1548 W 1149,48 N 15 b4 W 1228,30 N 1552 W 1307.08 N 15 56 W 1385,65 ~ 1556 W 1464,21 N 16 11 w 1542.61 3.34 2.00 2.09 1. 75 2:68 1.90 3.37 4.49 3 89 2:17 0,36 0,32 0,10 0,38 0,37 0,20 0,52 o.½ O~ 0,68 RECTANGULAR COORDINATES BORIZ, DEPARTURE NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET FEET FEET DEG BIN 0,00 N 0,00 0,05 $ 0,15 0,16 $ 0.36 0,10 S 0,40 0,05 S 0,42 0,12 S 0,60 0,32 S 0,78 0,25 S 0,73 0,79 N 0,~ 3,29 N 1, 0 O0 N 0 0 E 0 16 $ 70 50 E 039 $ 66 28 E 0 41 $ 76 2 E 09.2 $ 8257 E ) 0 bl B 78 53 E . 0 84 S 67 52 E 0 77. S 71 7 E ,2 N 49 1,625 N 25 ~01 EE 6,84 N 1094 N 15:18 N 20,bO N 30,28 N 45 54 N 65 30 N 9114 N 123 20 N 160 05 N 2,22 E 7,19 N 18 1 g 2,95 E 11,33 N 15 7 E 3,70 E 15,63 N 13 41E 4.57 E 21,10 N 12 20 E 4,40 E 30,60 N 8 16 E 1 38 E 45,56 N ~ 43 E 4:30 W 65,45 N ~ 46 W 11 43 W' N 7 8 w 202 33 N 249!18 N 299 31 N 352,45 N 408,10 N 466,79 N 528,15 N 593,74 N 664 b6 N 740:~0 N 40,80 W 206. 14 W 68.54 w 307.06 N 1~ 53 W 83.4b W 362.19 N !~ 19 W 98!40 a 419.80 N 13 33 W 115 10 W 480,77 N ,3 51W ; 132 94 ~ 544.62 N 14 7 W ' 151.27 W 612.71 N 14 17 W 170.57 ~ 686.20 N ~4 23 W 190.90 ~ 764.52 N 14 27 W 818,00 N 211,76 W 844,96 N 14 30 W 895'68 N 232,81 W 925,44 N 14 34 W 973,41N 254,15 W 1006,04 N i437 W 1051,18 N 275,82 W 1086,77 N 14 42 W 1128 76 N 297,84 ~ 1167.40 N 14 46 W 120604 N 319,70 w 1247,69 N 14 50 W 1283 26 N 341,75 w 1327,99 N 14 54 W 1360 29 N 363,64 W 1408,06 N i4 58 W 1437 30 N 385,66 W 1488,15 N 15 I ~ 1514,14 N 407,78 W 1568,09 N 15 4 W COMPUTATION DATE: 18-NOV-S8 PAGE 2 ARCO AbASKA, ~N.C z-31 {12-07-1 177 PRUOHOE NORTH SLOPE,ALASKA DATE OF SURVEY1 15-NOV-88 KELLY BbSHING ELEVATION~ 91,46 FT ENGINEERI WARNER INTERPOLATED VALUES ~Ot{ EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAl, VERTICAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULA~ COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4000 O0 3320 53 3229 4100 4400 4500 46 4800 4900 O0 3380 53 3289'07 53 7 .07 53 5 00 3440 42 1348,96 53 ~2 O0 3500 29 3408.83 53 27 O0 3559 67 3468,21 53 38 00 3618 93 3527,47 53 29 O0 3678 27 3586.81 53 47 O0 3737.51 3646,05 53 33 O0 3796 91 3705.45 53 32 O0 3856:33 3764,87 53 38 N ~6 16 W 1621.08 N 16 1 W 1699.49 N 16 2 W 1778.02 N 15 49 W 1856.59 N 15 43 W 1935.57 N 15 37 W 2014.64 N 15 35 W 2093.70 N 15 39 W 2172,81 N 15 52 W 2251.77 N 15 55 W 2330.67 0.20 0.66 0,5~ 0.59 0.50 0.29 0,28 0,30 0 14 0~45 1591.03 N 430 20 ~ 1648,16 N 15 7 W 1667 86 N 452 50 W 1728,~5 N 15 10 W 1744:83 N 474 59 W 1808,~2 N 15 12 W ,31 N 1821 85 N 496 1899 29 N 518 1976 83 N 540 2054 36 N 561 2131 95 N 583 2209,37 N 605 2286,71N 627 58 W 1888 15 14 W 22 W 2049 31 N 15 17 L 53 ~ 2210 37 N 15 18 w 39 w ~290 8t S 15 19 w 5000 O0 3915 19 3823.73 54 12 51 O0 3 5200~ O0 4~]~ 74 3940.28 54 33 54O 5500 5600 5700 5800 5900 50 3882.04 54 19 00 4089 37 3997.91 55 8 00 4146 00 4054.54 55 49 O0 4201 73 4110,27 56 21 O0 4257 28 4165.82 56 3 O0 43{3,24 4221,78 55 55 O0 4369,i0 4277,65 56 3 O0 4425,45 4333.99 55 34 N 15 27 W 2410.03 N 15 22 w 2489 87 N 15 9 W 2569:79 N 14 23 W 2650.24 N 13 56 W 2731.56 N 13 41W .2813 54 N 13 29 W 2895~71 N 13 31 W 2977.62 N 13 27 W 3059.60 N 13 38 W 3141.22 0.34 0,28 0,32 1 O8 0~59 0.48 0.33 0,28 0.79 0,13 2364,54 N 649 34 W 2452,08 N 15 21 w 2442 87 N 670 91 W 2533 32 15 21 2521 28 N 692 36 k 2614 62 N 15 21 W 15 20 w 5 18 2600 28 N 713 2680 22 N 733 2760 84 N 753 2841 67 N 772 2922,26 N 792 3002.92 N 811 3083.22 N 830 N ~ 26 W 2696 33 N 31 W 2778 73 N W 18 W 2861,73 N 15 15 W 67 ~ 2944,85 N 15 12 W 03 ~ 3027,69 N 15 9 W 30 k 3110,59 N 15 7 W 74 W 3193,18 N 15 4 W 6000 O0 4482 36 6100 O0 4539:08 6200 630O 640O 65OO 6600 6700 6800 --, 6900 4390.90 54 59 4448,22 55 5 O0 4596.87 4505.41 55 4 O0 4653.75 4562.29 55 28 00 4710.55 4619.t79 55 25 O0 4767.24 4675.78 55 38 O0 4823.49 4732.03 55 45 O0 4879.84 4788.38 55 30 O0 4936.01 4845.15 55 33 O0 4993,~8 4901.72 55 27 ~ 13 44 ~ 3222.44 ~ 13 57 W 3303,36 h 14 13 ~ 3384.29 ~ 14 12 W 3465.40 N 14 19 ~ 3546.57 N 14 24 W 3627.79 N 14 25 k 3709.29 N 14 28 ~ 3790.71 h 14 41 k 3871 83 ~ 14 57 ~ 3953~00 0,81 0,75 0.36 0,24 0 47 0:8! 0,34 0,57 0,57 0,72 3163 11 N 850 ~8 W 3275,37 N 1~ 2 W 3242:69 N 869:.4 W 3357,30 N 1~ 0 W 3322:23 N 889 80 ~ 3439.32 N !4 59 W 3401 95 N 910:02 W 3521,56 N 14 58 W 14 57 W 3481.72 N 930,29 W 3603,86 N ~ 3561 53 N 950.71 W 3686,24 N 14 56 ~ 3641 59 N 971,33 N 3768,91 N 14 56 W 3721 59 N 991.94 W 3851,5! N 14 55 W 3801 28 N 1012,63 W 3933,84 N 14 55 W 3880 97 N 1033.79 N 4016,30 N 14 54 W 7000 O0 5050 09 4958.63 55 17 7100 O0 5107:21 5015.75 54 59 7200 O0 5164~87 5073.41 54 30 7300 O0 5223.27 5131.8! 54 ~ 7400 O0 5282.03 5190.57 53 45 7500 O0 5341.62 5250.1~ 53 11 7600 O0 5401.75 5310.29 52 54 7700 00 5462 39 5370.93 52 27 7800 O0 5523:69 5432.23 51 47 7900 O0 5585,97 5494,51 51 6 N 15 12 w 4033,90 N 15 32 W 4114.56 ~ 15 54 m 4194,77 N 16 12 w 4274,37 h 16 25 w 4353,62 N 16 29 W 4432.26 N 16 30 ~ 4510.48 ~ 16 39 W 4588.30 ~ 16 51 k 4665.57 N 17 8 W 4742.03 0.35 0.43 0.61 0,49 1,07 0,49 0,44 0,37 o. t O, 3960 38 N 1055.15 W 4098,53 N 14 55 W 4039 52 N 1076,92 W 4180.60 N 14 55 W 1099.02 k 4262 30 N 14 56 w 4118 4196 4273 4350 4427 4503 4579 4654 17 N 18 N 1121,46 W 4343 46 N 14 57 ~ 82 N 1144,26 W 4424 35 N 14 59 W 85 N 1166.99 W 4504 63 N15 0 W 45 N 1189,71 W 4584 51 N 15 2 W 66 N 1212,37 W 4663.99 N 15 4 W 32 h 1235.1! W 4742,96 N 15 5 W 14 N 1258.01 ~ 4821,17 N 15 7 W Z 31 (12-07-1 ~) PRUDHOE BAY NORTH SLOPE,ALASKA COMPLiTATION DATE: 18-NOV-88 PAGE 3 DATE OF SURVEYI 15-NOV-88 KELLY BUSHING ELEVATIONI 91.46 FT ENGINEER{ WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMbTH DEPTH DEPTH DEPTH DEG NIN DEG nih VtRTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH f'EET DEG/IO0 FEET FEET FEET DEG 8000 O0 5649 11 8100 O0 5712:87 8200 8]00 8400 8500 8600 8700 8800 8900 5557,65 50 38 5621,41 50 5 O0 5777,46 56~6,00 49 26 O0 5842,72 5751,26 49 O0 5908 ~1 5817,35 48 17 O0 5975 47 5884,01 48 19 O0 6042 02 5950,56 48 O0 6!08 44 6016,98 48 O0 6174 69 6083,23 48 19 O0 6241 60 6150.14 47 48 9000 O0 6309 03 6217.57 47 12 9100 9200 9300 9400 9500 9600 9 9900 O0 6377 O0 6445 O0 6512 O0 6579 O0 6645 O0 6711 O0 6776 00 6841 39 6285.93 46 51 40 6353,94 47 24 86 6421,40 47 51. 62 6488.16 48 14 91 6554.45 48 40 64 6620.18 49 97 6685 51 49 27 52 6750~06 50 2 O0 6905.81 6814.35 49 55 1.0000 O0 6970.01 6878,55 508 10100 O0 7033.94 6942.48 50 28 10200 10]00 104 10600 10700 10800 --.,10900 O0 7097.5! 7006.05 50 36 O0 7160.86 7069,40 50 45 00 7224.17 713~.7! 50 45 O0 7287.10 7195.64 51 17 O0 7349.24 7257.78 51 47 O0 7411.13 7319.67 51 37 O0 7473.45 7381.99 51 23 O0 7535,79 74~4.33 51 27 I 000 1200 11300 11400 1 O0 1 O0 11900 O0 7598 15 7506.09 51 18 O0 7661:1g 7569.73 50 31 O0 7725,14 7633.68 49 58 O0 7789.75 7698.29 49 37 00 7854.71 7763.25 49 2~ O0 7919.94 7828.48 49 11 O0 7985.68 789~.22 48 40 O0 8051.90 79~0.44 48 22 O0 8118.44 8026,98 47 58 O0 8186.07 8094.61 46 51 N 17 21 W 4817.73 N 17 52 W 4892.83 N 18 21 w ~967.09 N 18 37 ~ 5040.69 N 18 38 ~ 5113.53 N 16 41 k 5185,99 N 8 54 W 5259.73 N 2 56 W 5334,44 N 2 29 W 5409,29 N 2 1 W 5483.55 N 1 37 ~ 5557.29 N 1 ! w 5630.14 N 0 32 E 5703.25 N 2 37 E 5776.61 N 4 28 E 5850.27 N 6 10 E 5923.98 N 6 45 E 5997.88 N 6 13 E 6072 11 N 6 8 E b147~14 N 6 49 E 6222~28 N 7 41E 0297.27 N 8 8 E 6372,29 N 8 36 E 6447.47 N 9 14 E 6522.66 N 10 4 F 0597 66 N 11 29 F 6672:56 N 12 33 E 6747.52 N 12 34 E 6822,53 N 12 41 E 6897,16 N 13 2 E 0971,74 h 14 19 E 7045.95 ~ 15 14 E 7119.02 N 15 23 E 7191,25 h 15 41E 7262.86 N 16 13 E 7333.94 ~ 16 1E ~404 76 ~ 14 47 E .475~44 ~ 14 30 E 7546.24 ~ 14 58 E 7616.65 ~ 16 37 E 7685.64 0,62 0,86 0.54 0,67 0,74 4,01 6,88 1,14 0.84 0,64 0,90 0,91 1,31 1,90 1,28 1,17 0,24 0 96 0~82 0,78 0,70 0.40 0'49 0,46 0,83 1,42 0,19 0,62 0,24 0,86 1.50 0.75 0,66 0,56 0.29 0,41 1,08 0,45 1,55 1,96 4801,63 N 1304.29 ~ 49715 62 Nlt~ I1 W 4874,i8 N 1328,04 W 505 86 N 1 4 W 4946,04 N 1352.09 W 5127 52 N 17 W 44 N 15 20 ' 5017.15 N 1376,08 W 5202 5087,92 N 1399,46 W 527 6 5160,51N 1416,47 W 5351 5234.92 N 1423,08 W 542 4 5309,74 N 1426 52 W 5498 5~84,01N 1429:48 W 5570 88 N 15 22 ~. N5 20 W . 54 N 1 5457,81N 1431,76 W 5642 49 5530 77 N 1433,53 W 57~3 5604 10 N 1433,91 ~ 57 84 5677 86 N 1431 95 ~ 5855 5752 17 N 1427~23 W 5926 5826 71N 1420 27 W 5997 5901 58 N 1411 61 W 6068 5976 78 N 1402 91 W 6139 6052 74 N ~394 84 W 6128 '84 N 1386 25 W 6283 6204,90 N 1376 ~ ~ 6355,75 N 1) ~0 W 6281,05 N 1365: W 6427,85 N I 6 W 6357,4~ N 1354,65 W 6500,14 N 12 I W 6433,86 N 1342.64 W 6572 46 N 11 47 W 6510 18 N 1329.70 W 6644 59 N 1~ 32 P 6586:53 N 1315,27 w 6716 57 N 1. 17 t 6663,12 h 1298,74 W 6788 51 NII I W 6739,80 N 1281,68 W 6860 58 N 10 46 W 6816,10 N 1264 55 W 6932 41 N 10 30 W 6892,36 N 1247~31 w 7004 31 N 10 15 W 6968 35 N 1228 89 k 7075,88 N I0 0 W 7043~32 N 1208:80 W 7146 30 N 9 44 W 7117~48 N 1188,54 W 7216 03 N 9 29 W 7191 03 N 1168.16 k 7285 29 N 9 13 W 7264~09 N 1147.14 W 7354 11 N 8 58 W 7336i89 N 1126.07 W 7422 80 N 8 43 W 7409 49 N 1105,86 k 7491 56 N 8 29 W 7482,07 N 1087.19 W 7560 64 N 8 16 W 7554.28 N 1068.31 W 7629:45 N 8 2 W 7625.16 N 1048,32 W 7696,89 N 7 49 W COMPUTATION DATE: PAGE 4 ARCO ALASKA IN.~ z. l c 2.07.' PRUDHOE BAY NORTH SLOPE,ALASKA DATE OF SURVEYI 15 NOV-88 KELLY BUSHING ELEVATIONI 9~.46 FT ENGINEER~ WARNER INTERPOLATE[) VALUES FOR EYEN 100 FEET OF MEASURED DEPTH TRLIE SUB-SEA COURSE "EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH'~' DEG VERTICAl..., DOGbEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/~EST DIST,AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 1 000 1~100 1 2oo 11300 12400 12500 12600 12700 12800 12900 O0 8254 74 8163,28 46 28 O0 8323:89 8232,43 46 7 O0 8393 36 8301.90 45 48 00 8463 33 8371,88 45 18 O0 8533 98 8442.52 44 56 O0 8605 20 8513,74 44 17 O0 8677 02 8585.56 43 51 O0 8749:12 8657.66 43 24 O0 8823:21 8731.75 40 54 00 8899 69 8808.23 40 9 N 17 56 F': 7752 98 N !8 34 E 7819~47 N 19 41 E 7885.29 N 20 59 ~ 7950,01 N 22 26 E 8013.39 N 24 31 E B075.27 h 26 54 F 8135 27 N 27 50 E 8193:77 N 28 51 E 8250.0b N 28 16 ~: d303.90 1.00 0,57 1,14 1,14 1,75 1,69 1 85 2~21 2.67 1.00 7694,53 N 10~ 53 W 7762,71 N 7 35 ~ 7763,13 ~ 10~.:89 ~ 7827,76 N 7 22 N 7831,11 N 980,43 W 7892 25 N 7 8 W 7898.11 N 955,b2 W 7955 71 N 6 53 W 7963,87 N 929 46 W 8017 ~ N 6 39 ' ~ 8028,27 N 901152 ~9 807~,. N 6 24 ~ ? 8090,97 N 871 37 W 813 76 N 6 8 W 8J52,33 N 83 ~9 ~ 819 41 N 5 52 W 8211.45 N 807,37 W 8251,05 N 5 36 W 8268.02 N 776.53 N 8304,41 N 5 21W 13000.00 8975,61 8884.15 41 6 13100,00 9050,27 8958,81 42 14 13200,00 9123,82 9032,36 42 50 13251,00 9161,21 g069,75 42 50 N 28 14 F ~358.49 N 27 41 E 8414.44 N 2b 26 g ~472.11 N 26 26 E ~501.79 1.51 1,38 0,00 0.00 8325. ~5 N 745,73 W 8358,68 N 5 7 W 8384,08 ~ 7~4~ 46 ~ 8414,47 N 4 5~ ~ 8444.48 N 6~:81 W 8472,12 N 4~, W 8475,54 N bb8.36 W 8501,85 N 4 30 W PRUDHO£ BAY NORTH SLOPE,ALASKA COi~PUTATION I)ATE: 18-NOV-88 PAGE 5 · DATE OF SURVEY{ 15-NOV-88 KELLY BUSHING ELEVATION{ 91,46 FT ENGINEER~ WARNER INTERPOLATE[) VALUE'S FOR fl;VEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION' AZIM[JTH DEPTH DEPTH DEPTH DEG SIN DEG ~I~ VERTICAL DtJGGEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 0 O0 1000 2000 3OOO 4OOO 5OOO 6000 7OO0 8000 9000 0 O0 -91 46 0 0 O0 999 89 908:43 2 16 O0 1968 68 1877'22 27 37 oo O0 4482 36 4390,90 54 59 O0 5050 09 4958,63 55 17 O0 5649 I1 5557,65 50 38 O0 6309~03 6217,57 47 12 N 0 0 E 0,00 N 10 8 E 6.63 N 14 49 W 205,01 N 15 6 W 832.67 N 16 16 W 1621.08 N 15 27 w 2410.03 N 13 44 W 3222,44 N 15 12 W 4033,90 N 17 21 w 4817,73 N 1 37 W 5557.29 0,00 0,00 N 0,00 E 0,61 6,84 N 2,22 E 3,34 202,33 N 40,80 ~ 206 0,36 818,00 N 211,76 W 844 o. o , 0,34 2364,54 N 649,34 W 0,81 3163,11N 850,18 W 3275 0,35 3960,38 N 1055,15 W 4098 0,62 4728,20 N 1281,00 W 4898 0,90 5457,81N 1431,76 ~ 5642 0,00 N 0 0 E 7 19 N 18 1 E "II 1 96 N 0 W 16 5 7 W ') N 14 55 W 65 N 15 9 W 49 N 14 4! W 0000 1000 2OOO 3000 3251 O0 6970,01 68'18,55 50 8 O0 7598,15 7506,69 51 18 O0 8254,74 8163.28 46 28 O0 8975,61 8884,15 41 6 O0 9161.21 9069,75 42 50 N 7 41 E 6297.27 N 14 19 E 7045,95 N 17 56 E 7752,98 N 28 14 g 8358 49 N 20 26 E U501:79 0,70 1,50 1,00 1,51 0,00 6204 90 N 1376,52 W 6355 75 N 12 30 W 6968 35 N 1228,89 W 7075 88 N 10 0 W 7694 53 N 1026,53 W 7762 71 N: 7 35 W 8325 35 N 745,73 W 8358 68 N 5 7 W 8475 54 N 668,36 W 8501 85 N 4 30 W ARCO AL, ASKA, Z-31 (12-07-1 :~) PRUDHOE BAY NORTH SLOPE,ALASKA COMPUTATION DATE: 1R-NOV-88 PAGE 6 DATE] OF SURVEYI 1S-NOV-88 KELbY BUSHING EbEVATZONI 91,46 FT ENGXNEERI WARNER · INTERPOLATED VALUE~ FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN DE(; MIN 0 O0 9~ 46 ~9 46 29~ 46 391. 46 491 46 591 46 69] 46 79 0,00 '91,46 0 0 N 0 0 E 91,46 0.00 0 8 $ 61 0 E 191,46 100,00 0 6 $ 73 23 E 291,46 200,00 0 2 N 18 35 W 391,46 300,00 0 2 N 64 37 E 491,46 400,00 0 I0 S 54 35 E 591.46 500,00 0 7 S 17 46 E 691'46 600,00 0 14 N 8 8 W 791:46 700,00 0 54 N 16 17 E 891 46 800,00 I 49 N 12 8 E 991 991 1091'~ , 1091 1392.33 46 900.00 2 13 46 1000.00 2 25 46 1100,00 2 35 46 1200.00 3 55 46 1300.00 0 52 1493; 1595,~5 1699, 1805,~ i914,00 1491 46 1400.00 10 15 1591 46 1500.00 1] 28 1691 46 1600.00 17 31 1791,46 1700,00 21 7 1891,46 1800.00 24 30 2025 2141 2259 2381 2507 2638 2781 2943 3111 328 82 1991.46 1900.00 28 26 30 2091.46 2000,00 31 16 87 2191 46 2100.00 33 42 56 2291:46 2200.00 35 44 53 2391.46 2300.06 38 59 70 2491.46 2400.00 42 25 73 soo.oo 62 2691:46 2600.00 53 35 9 8 2791 46 2700°00 53 34 8oo.oo s3 50 3449 3617 3784 3951 4118 4285 4453 462~ 479 4959 99 2991,46 2900,00 53 25 75 3091,46 3000,00 53 14 78 3191,46 3100,00 53 11 55 3291,46 3200.00 53 12 16 3391,46 3300.00 53 7 15 3491 46 3400,00 53 22 73 3591 46 3500,00 53 39 36 3691 46 3600,00 53 46 82 3791 46 3700,00 53 31 49 3891 46 3800,00 54 0 VERTICAL [OGLEG RECTANGULAR COORDINATES HORXZ, SECTION SEVERITY NORTH/SOUTH EAST/WEST DXST, FEET DEG/IO0 f'EET FEET FEET 0.00 0,00 0,00 N 0,00 '0.05 0.06 0,04 S 0,13 '0.18 O,Og 0,15 S 0 35 -0.14 0.08 0,10 S 0:40 -0.00 0 06 0,05 S 0,41 '0.15 0~17 0,10 S 0.57 -0.36 0.24 0,30 S 0,77 '0.35 0.54 0,29 $ 0,73 0.58 0.80 0,66 N 0.88 2.88 0,66 3,02 N 1,53 N 10 3 E 6.31 0,68 N 10 90 E 10.32 0,06 N 921E 14.46 0.53 N 7 8 E 19.57 3 06 k 5 41 W 28.86 3~41 N 14 3 W 44.12 2.55 N lb 15 W 64.46 3.84 N 14 59 W 91,61 4,39 N 15 21 W 126.36 3,24 N 14 22 W 167.70 3.66 N 15 19 W 216.95 N 16 12 W 273.54 N 15 38 W 336.02 N 15 8 W 404.20 ~ 16 14 w 479.34 N 15 40 W 562.52 N 15 7 W 662.92 N 15 1 W 788.08 N 15 15 ~ 921.31 n 15 40 W 1055.48 DEPARTURE AZIMUTH DEG N 15 47 w 1188.87 n 15 50 W 1321.02 N 15 56 W 1452,27 N 16 15 W 1583.11 N 15 59 W 1713,71 ~ 15 51 W 1844.88 N 15 41 ~ 1978.09 N 15 35 W 2111.43 N 15 52 W 2244,52 N ~5 38 W 2377,77 0,00 N 0 0 E 0,14 'S 72 6 E 0,38 $ 66 4 E 0,42 $ 75 27 E 0,41 $ 82 29 F '~! 0,58 $ 80 5 E 0,83 S 68 ~3 E 0,79 $ 68 38 E 1,10 N 53 15 E 3,38 N 26 48 E 6 51 N 10 59 n 14 81 N 20 01 N 29 33 N 44 41N 64 35 N 90 98 N 125,09 N 165.67 N 2 17 E 2 89 E 3 63 E 4 50 E 4 51 E 1 67 E 4,02 11.39 20, 31.49 6.86 N 18 24 E 10,98 N 15 16 E 15.25 N 13 47 E 20 51 N 12 40 E 29 68 N8 44 E 44 44 N 2 8 E 64 47 N 3 34 W 91 69 N 7 8 W 56 W 126 77 N 9 19 W 168 63 N 10 45 W 3,22 2,10 2,03 2.21 1.68 4.32 4,13 0.70 0.31 0,27 2.14 05 N 43,96 W 218,52 N 11 36 W 269'51 N 59,96 W 276,10 N 12 32 W 330,76 N 77,47 W 339,71 N 13 10 W o .oo . w 552.87 N 139,95 W 570 30 N 14 1, . ) 651,37 N 166,98 W 672 43 N 14 22 W 774,23 N 199.98 W 799 64 N 1428 W 904,98 N 235.34 W 935 08 N 14 34 W 1036,61 N 27i,72 W 1071 63 N 14 41 ~ 0.15 0.24 0,27 0.35 0 8O 0 67 0 34 o 37 o 1167 39 N 308 74 W 1207,53 N 14 48 W 1296 94 N 345 63 W 1342,20 N 14 55 W 1425 59 N 382 32 W 1475.97 N 15 0 W 1553 82 N 419 33 w 1609,41 N 15 6 W 1681 80 N 456 48 W 1742,65 N 15 11 W 1810.36 N 493 32 W 1876,38 N 15 14 W 1940.99 N 530 17 W 2012,09 N 15 t6 W 2071.76 N 566.69 W 2147.86 N 15 17 W 2202.27 N 603,37 W 2283,43 N i5 19 W 2332,90 N 640,56 W 2419.24 N 15 21W PRUDHOE BAY NORTH 8LOPE,ALASKA COMPUTATION bATEc 18-NOV-88 PAGE 7 DATE OF SURVEY{ 15-NOV-88~ BUSHING ELEVATION{ 91,46 FT ENGINEER{ WARNER , INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MERSURFD VERTICAl, VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH PEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DI8~, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 51 5481 5661 5839 6015 6190 6366 6543 6720 76 3991,46 3900,00 54 18 64 4091 46 4000,00 55 9 48 4191:46 4100,00 56 18 12 4291~46 4200,00 55 57 87 4391 46 4300,00 55 4~ 80 4491:46 4400,00 54 57 oo.oo 40 4691,46 4600,00 55 22 09 4791,46 4700,00 55 47 54 4891,46 4800,00 55 24 6896 7072 7245 7415 7582 7747 7908 8373 95 4991 46 4900,00 55 28 53 5091 46 5000,00 55 4 67 5191 46 5100,00 54 16 92 5291 46 5200,00 53 38 93 5391 46 5300,00 52 58 62 5491 46 5400,00 52 13 75 5591 46 5500,00 51 54 5691,46 5600,00 50 18 5791,46 5700,00 49 22 7 5891,46 5800,00 48 26 8524 08 5991,46 5900.00 48 20 8674 37 6091,46 6000,00 48 28 88 9120 9268 94 972~ 987 19 6191 46 6100,00 48 7 07 6291:46 6700.00 47 26 61 6391,46 6300.00 46 58 18 6491,46 b400,O0 47 38 79 6591,46 65,)0.00 48 18 19 6691,46 6600,00 49 (~ 31 6791,46 6700.00 49 36 72 6891,46 6800,00 49 56 10033 10190 0348 0506 10668 1082~ 1098 11147 I 302 1~456 43 6991 46 6900,00 50 8 46 7091:46 7000,00 50 35 35 7191 46 7100.00 50 43 97 7291 46 7200,00 51 19 25 7391 46 7300.00 51 44 85 7491 46 7400.00 51 25 29 7591 46 7500,00 51 23 46 7691.46 7600.00 50 15 64 7791.46 7700.00 49 36 37 7891,46 7800.00 49 16 15 19 W 2514.42 14 21W 2653.18 13 45 W 2798.32 13 30 W 2945,79 13 35 W 3092 22 13 46 ~ 3235:20 14 12 W 3376,66 1,4 16 ~ 3519.31 1.4 26 W 3662,92 14 29 W 3807.40 N 14 56 W 3950.53 ~ 15 27 W 4092.45 N 16 2 W 4231.19 N 16 26 W 4366.18 ~ 16 30 W ~497,14 N 16 43 W 4625 lg N 17 10 W 4748168 N 17 41 W 4867,78 N 18 25 W ~982.96 N 18 38 W 5094,56 N 15 12 W 5203.64 N 3 36 W 5315.2b N 2 22 W 5428.07 N 1 41 W 5538.25 N 0 44 ~ 5645 17 N 1 53 E 5753~24 L 4 46 E 5863,37 N 6 42 E 5975.07 N o 4 E 0088.78 N b 38 E 6205,57 N 7 53 E 0322,30 N 8 33 E 6440 30 N 9 36 E 6558:96 N 11 36 E b677,78 N 12 32 E 6798,73 N 12 40 E b9~8 67' N 14 8 E 70~8~04 N 15 15 E 7153.38 N 15 42 E 7264.75 N 16 7 E 7373,88 0,28 11 0,25 0,92 0,63 0,47 0,40 0,12 1.03 0,70 0,53 0,55 1,00 0,26 0,77 0 65 0~70 0,31 0,49 5.06 2,80 0,90 0,99 1,20 1,78 1,34 0,49 0,72 0,~2 0 79 0~50 0,65 1,38 0,36 0,39 1,20 0,55 0,56 0,22 246b 95 N 677 53 W 2558 29 N 15 21 W 2603 16 N 714 O0 W 2699 N 15 20 W N tS 16 W 2745 87 N 749 52 W 2846 288 331.4 73 N 887 91 W 343~ 3454 93 N 923:46 ~ 357 3596,04 N 959.60 W 3721 3737,99 N 996,17 W 3868 50 N 15 10 w 59 N 15 6 w 29 N 15 ~2~ ~ 59 N t4 ~ 21 N 14 W 87 N 14 56 W 45 N 14 55 w 3878 54 N 1033,14 W 4013 79 N 14 54 W 26 99 42 i4 57 W 1109. W 42 N 4153 86 N 4286 13 N 1147 89 W 4437 4414 39 N 1185 85 W 4570 4539 79 N 1223 20 W 4701 4660,65 N 1260 01 ~ 4827 777,14 N 1296 45 W 4949 889,67 N 1333 20 W 5068 4998,63 N 1369,84 W 5182 7 N 14 59 W 9 N 15 2 W 69 N 15 4 W 98 N 15 7 W 17 N I W 93 N 15 19 W 5105.22 N 1404 41 W 5294.87 N 15 22 W 5215,75 N 1422 07 W 5406 14 N 15 15 w 5328,52 N 1427 33 W 5516 37 N 14 59 W 5438,75 N 1431 21 W 5623 91 N 14 44 W 5545,83 N 1433 77 W 5728 17 N 14 29 W 5654,34 N 1432 89 W 5833 07 N 14 13 W 5765 40 N 1426 16 W 5939 17 N 13 53 W 5878:46 N 1414,34 W 6046 21 N 13 31W 5993i65 N 1401,10 W 6155,24 N 13 9 W 6111 91N 1388,24 W 6267,59 N 12 47 w 6230 29 N 1373 03 W 6379,79 N 12 25 W 6350 13 N 1355 76 ~ 6493,24 N 12 3 W 647079 N 1336 53 W 6607.37 h 11 40 W 6591 86 N 1314 17 w 6721.58 N 11 16 W 6715 47 N 1287 08 W 6837,70 N10 50 W 6838 09 N 1259.60 W 6953,14 N 10 26 W 6960 24 N 1230,96 W 7068,25 N 10 1W 7078 60 N 1199.20 W 7179,46 N 9 36 W 7192 96 N 1167,61W 7287,11 N 9 13 W 7305 15 N 1135,23 W 7392,83 N 8 49 W Z 31 ( 12-0 11 PRUDHOE BAY NORTH SLOPE,AhASKA COMPUTATION DATE: 18-NOV-88 PAGE 8 DATE OF SURVEY{ 15-NOV-88 KELLY BUSHING EbEVATION{ 91,46 FT ENGINEERt WARNER INTERPOLATED VAI.UE$ FOR EVEN 100 FEET OF' SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIR VERTICAl, DOGbEG RECTANGULAR COORDINATES HORIZ, DEPARTURE &ECTION SEVERITY NORTH/SOOT['t EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 75 799i 46 7900,00 48 40 54 8091 46 8000,00 48 16 85 8191 46 8100,00 46 48 18 8291 46 8200.00 46 13 27 8391 46 8300,00 45 48 92 8491 46 8400,00 45 4 82 8591 46 8500.00 44 21 02 8691 46 8600,00 43 52 66 8791,46 8700,00 42 0 24 8891,46 8800.00 40 2 13021,09 8991.46 8900,00 41 22 13251,00 9161,21 9069.75 42 50 ~ 14 40 E 7481.63 ~ 14 4O ~: 7588 21 N 16 47 E 7690:95 N 18 16 E 7788,4! N 19 39 E 788~ 51 N 21 31 E 797o:48 N 24 4 E 8063.57 N 27 20 E 8147,03 N 28 23 E 8226 71 N 28 18 E 6298:08 N 28 11E ~370.1,7 N 26 26 E 8501.79 0 93 0!51 1 78 0,4~ 1,17 1,38 1,96 1,51 2,90 1,02 1,13 0,00 7415.84 N 1104,19 W 7497' 59 N 8 28 W 7525 il N 1075,97 ~ 760 65 N 8 8 W 7731 07 N 1014'56 W 779 7 28 W ! 7630 63 N 1046 66 W 7702 7 7829 27 N 981 09 W 7890 7924 52 N 945 35 W 7980 8016 08 N 907 06 W 8067 8103,30 N 865 03 W 8149 818b,90 N 820 84 W 8227 8261'92 N 08 N 7 48 W 36 N 5O N 7 8 W '% 70 N 6 48 W / 23 N 6 27 w 34 N 6 5 W 95 N 5 43 W 779 81 W 8298'64 N 5 23 W 8337,b2 N 739 1~ W 8370,32 N 5 3 W 8475.54 N 668:3 ~ 8501,85 N 4 30 W SCHLUMBERGER 0 1 REC T I ONAL SURVE Y COMPANY STANOARO ALASKA PRODUCTION WELL FI ELD PRUDHOE BAY COUNTRY USA RUN ONE BATE LOOOED iS - NOV 88 REFERENCE "7302'6 WELL (714' Zm31 (12-07-11-12/-` SNL, 3664' WEL, SE,. 19, TllN, R12E) "'"'HORIZONTAL PROJECTION NORTH 12000 REF 10000 8OOO 4000 2000 -2000 SOLrrH -4000 SCALE : 1/2000 IN/FT i i _~ f ~ : ~ ~ ! ~ ~ ~ ~ ~ , ! ! : i ! : : ~ ~ ' ; :: i ! i ! ; ; ; : ~ ! i-~T .."~T '~'-? ,-T-i"?-?'"T"' ...... 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' ' * ~ ..... e-f .... ~- * ' ' ..... -'..'-r-r--;-~-+---+~.?-~ .... '-ii! ~' !! -4-!-~-.! ---;.-+--f--.*.'-~.~-.-.~--~--;-i-[--;-;-;-4-.-'+-'r'"~ ......... *-~-'~",-m"-r'~'--: .............................. ~ ..... -8000 -6000 - 4000 -2000 0 2000 4000 6000 8000 HEST ERST WELL: (714' Z-31 (12-07-11-12) SNL, 3664' WEL, SEC 19, TllN, R12E) VERTICAL PROJECTION -4000 -2000 0 0 ZOO0 4000 6000 8000 10000 12000 PROJECTION ON YERTICRL PLRNE 3SS. - 17[~. (~::~.EB IN VERTICFI OEPTH~S HORIZ ~CALE = 1/2000 IN/FT GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD ALASKA PRODUCTION COMPANY COMPANY WEST EILEEN # Z-31 WELL NAME PRUDHOE BAY LOCATION AL1088-D35 SINGLE SHOT & MWD 11/10/88 JOB NUMBER TYPE SURVEY DIRECTIONAL KEVIN DESORMEAUX SUPERVISOR NAME TITLE DATE S I GNATURE 385 FT 12566 FT DEPTH INTERVAL FROM TO 10/14/88 FROM DATE SURVEY TAKEN THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE KEPT ZN A LOCKED FILE ~D ~E HE~ IN CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING,INC C]$ent .............. : STANDARD ALASKA PRODUCTION CO. We]] ................ : WEST EILEEN WELL ~ Z-31 Vest,cai Section at.: N 3.93 W Magnetic Declination: 30 deg 50 mtn E Data ft]e name ...... : B:WZ31D.DAT RECORD OF SURVEY IWe]] assumed ve=t~ca] to MD of Computot~on: RADIUS OF CURVATURE Su=vey date: ]0/]9/88 Method ..... : SINGLE SHOT & MWD RKB Height.: 91.S ft 0.0! MEAS DRIFT TRUVERT SUBSEA SECT]ON DIRECT]ON RELATIVE COORDINATES ( ~EPTH DG NN DEPTH DEPTH DIST ANGLE FROM WELL-HEAD 0 0 0 0.00 -91.46 0.00 N 0.00 E 0.00 N 38S 0 12 38S.00 293.54 -0.67 S 2.90 E 0.67 S 569 0 24 569.00 477.54 -1.58 S 39.50 E 1.55 S 786 0 30 78S.99 694.S3 -1.S6 N 30.40 E 1.44 S 881 1 36 880.97 789.S1 O.OS N 4.40 E 0.21N 0.00 E 0.03 E 0.38 E 1.83 E 2.34 E 991 2 6 990.91 899.4S 3.S6 N 4.80 E 3.75 N 2.63. E 1066 2 34 104S.85 974.39 6.S8 N 8.00 E 6.80 N 2.97 E 11S8 2 30 1157.76 1046.30 10.S9 N 7.90 E 10.84 N 3.54 E 1221 2 30 1220.70 1129.24 13.27 N 9.00 E 13.S8 N 3.94 E 134S S 42 1344.37 12S2.91 ,21.96 N 4.00 E . 22.34 N S.10 E 1438 8 30 1436.84 134S.18 1S29 11 30 1526.25 1434.79 1609 14 34 1604.18 1512.72 1717 18 36 1707.65 1616.19 1902 24 18 1879.77 1788.31 33.41 N 9.00 W 49.00 N 17.00 W 64.44 N 15.60 W ~6.93 N 14.20 W 183.58 N 13.10 W 33.82 N 4.80 E 49.20 N 1.24 E 46.54 N 3.82 W 96.35 N 11.78 W 142.06 N 27.71 W 2087 30 36 2043.86 1952.40 2180 32 6 2123.28 2031.82 2273 34 24 2201.05 2109.59 2345 35 42 2276.36 2184.90 2501 39 6 2384.39 2292.93 247.35 N 16.00 W 294.70 N 15.60 W 344.72 N 14.60 W 396.71 N 13.80 W ~78.07 N 13.80 W 244.S4 N 49.13 W 291.11N 62.30 W 340.34 N 7S.S8 W 391.S4 N 88.S4 W 471.76 N 108.24 W 2595 40 30 24S4.60 2365.1~ 2690 44 24 2526.69 2435.23 2784 48 36 2S91.38 2499.92 2878 53 24 2450.52 2559.04 3156 54 4 2814.90 2723.44 S37.25 N 14.90 W 400.26 N 14.20 W 667.38 N 13.80 W 739.34 N 13.S0 W 959.92 N 15.00 W S30.06 N 592.11N 6S8.2S N 729.22 N 946.50 N 123.14 W 139.24 W 1SS.TS W 172.99 W 228.17 W CLOSURE DISTANCE DG MN S 0.00 N 0 0 0 E 0.67 S 2 54 0 E 1.60 S 13 37 S E 2.32 S S1 45 42 E 2.35 N 84 SS 12 E 4.58 N 35 1 31E 7.42 N 23 34 46 E 11.42 N 18 2 15 E 14.].4 N 16 10 SS E 22.94 N 12 SO 16 E 34.16 N 8 4 18 E 49.22 N I 26 58 E 66.65 N 3 17 22 W 97.06 N 6 57 24 W 249.44 N 11 21 30 W 297.70 N 12 4 46 W 348.63 N 12 31 16 W 484.02 N 12 SS 21 W 544.17 N 13 4 49 W 608.26 N 13 14 7 W 676.43 N 13 18 44 W 749.46 N 13 20 43 W 973.42 N 13 33 13 W LEG deg/lO0 0.000 0.0S2 0.109 0.046 1.158 0.455 0. 667 O. 109 0.003 2. S81 3.031 3.315 3.877 3.706 3.083 3.430 1.617 2.497 2.500 1.569 4.121 S.111 0.434 WEST EILEEN WELL N Z-31 11/10/88 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WEi..L-HEAD 3437 53 48 2980.27 2888.81 1183.03 N 14.60 W 1166.16 N 3720 S3 18 3148.40 3056.94 1406.88 N 14.20 W 1386.64 N 4189 S3 18 3428.69 3337.23 1777.29 N 13.50 W 1751.74 N 4660 S3 48 3708.52 3617.06 2150.71 N 13.80 W 2119.90 N 3039 S4 36 3930.22 3838.76 2453.68 N 13.S0 W 2418.61 N 286.21W 342.82 W 432.83 W S22.24 W 594.78 W S225 SS 6 4037.30 3945.84 2603.65 N 13.S0 W 2566.49 N SS06 S~ 42 4194.83 4103.37 2833.57 N 12.00 W 2793.42 N S786 S6 30 4348.97 4257.51 3065.18 N 11.40 W 3022.32 N 6069 SS 18 4507.63 4416.17 3297.33 N 12.10 W 3251.74 N 6351 SS 30 4667.76 4576.30 3527.02 N 12.40 W 3478.58 N 630.28 W 681.63 W 729.03 W 776.75 W 826.01W 6632 S6 6 4825.70 4734.24 3756.89 N 12.~0 W 3705.57 N 875.91'W 6913 SS 48 4983.04 4891.58 3987.17 N 12.40 W 3932.96 N 925.91W 7194 S4 48 5143.00 SOSI.S4 4215.23 N 13.80 W 4157.96 N 978.27 W 7477 S3 30 5308.74. S217.28 4440.79 N 15.00 W 4380.13 N 1035.31 W 7759 S2 18 S478.84 S387.38 4661.29 N 15.60 W 4597.08 N 1094.66 W 8042 SO 12 S655.97 5564.51 4877.42 N 15.60 W 4809.64 N 1154.01W 8324 49 0 S838.74 S747.28 S087.31 N 16.70 W S015.91 N 1213.74 W 8569 48 18 6000.60 5909.14 S269.03 N 8.20 W S195.34 N 1253.36 W 8692 48 48 6082.02 5990.56 S361.15 N 0.80 W S287.19 N 1260.58 W 8799 48 30 6152.71 6061.25 S441.34 N 0.50 W S367.50 N 1261.49 W 8984 47 24 6276.62 6185.16 SS78.44 N 0.10 W S504.87 N 1262.21 W 9174 47 30 6405.10 6313.64 5717.89 N 2.00 E 5644.82 N 1259.89 W 9363 48 18 6531.81 6440.35 S856.88 N S.30 E S784.7~ N 1250.97 W 9456 48 42 6593.43 6501.97 5925.39 N 7.60 E 5853.95 N 1243.14 W 9740 49 54 6778.63 6687.17 6136.35 N 7.60 E 6067.37 N 1214.67 W 9937 SO 0 6905.39 6813.93 6283.72 N 9.00 E 6216.58 N 1192.90 W 10347 SO 54 7166.45 707q.99 6589.99 N 11'.80 E 6527.49 N 1135.8~ W 10720 S1 42 7399.67 7308.21 6867.84 N 15.00 E 6810.63 N 1068.38 W 10940 S1 30 7536.32 7444.86 7031.12 N 14.60 E 6977.32 N 1024.34 W 11067 51 12 7615.64 752~.18 7124.65 N 16.40 E 7072.90 N 997.84 W CLOSURE DISTANCE DG MN S 1200.76 N 13 47 22 W 1428.39 N 13 S3 12 W 1804.42 N 13 S2 44 W 2183.28 N 13 SO 21W 2490.67 N 13 48 57 W 2642.75 N 13 47 S2 W 2875.38 N 13 42 47 W 3109.00 N 13 33 42 W 3343.23 N 13 26 S W 3575.31 N 13 21 28 W 3807.69 N 13 17 S8 W 4040.~8 N 13 1~ S1 W 4271.49 N 13 14 22 W 4500.83 N 13 17 55 W ~725.61 N 13 23 38 W ~946.15 N 13 29 32 W S160.67 N 13 36 10 W 5344.39 N 13 33 48 W S435.38 N 13 2~ 37 W SS13.75 N 13 13 33 W 5647.73 N 12 S4 51W S783.71 N 12 3~ SS W S918.46 N 12 12 9 W S984.~9 N 11 59 21 W 6187.76 N 11 19 1S W 6330.00 N 10 S1 45 W 6625.58 N 9 S2 16 W 6893.92 N 8 Sq SS W 7052.11 N 8 21 7 W 7142.94 N 8 1 49 W DOG LEG deg/lO0 0.1~1 0.199 0.096 0.11q 0.218 O. 269 O. 681 0. 165 0.456 0.101 0.2]4 O. 107 0.487 0. 535 0 .z~46 O. 0.480 1. 955 3.430 0. 321 0. 606 O. 603 '1.061 1.461 0.423 0.420 0.1~66 O. S70 O. 144 O. 893 WEST EILEEN WELL ;~ Z-31 ' 11/10/88 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELAT]VE COORDINATES ANGLE FRON WEI.i.-HEAD 11437 49 24 7851.97 7760.51 7390.08 N 18.10 E 7344.75 N 11720 48 24 8038.01 794~.55 7589.19 N 1~.00 E 75~8.~2 N 12128 46 6 8314.94 8223.h8 786~.43 N 20.60 E 7832.97 N 12566 44 6 8624.10 8532.~ 8140.11 N 27.~0 E 8115.99 N 913.~3 W 8S0.90 W 7S~.86 W ~30.2~ W CLOSURE DISTANCE DG MN S 7401.33 N 7 5 21 W 7596.43 N 6 25 53 W 81q0.43 N ~ 2~ 26 W DOG LEG deg/100 0. S54 O. 0.813 O. 899 WEST EILEEN WELL ~ Z-31 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 11/10/88 MEAS. DEPTH TRU VERT SUB SEA MD-TVD VERTICAL. DEPTH DEPTH DIFF. CORRECT 91 9]. 0 0 0 191 191 100 0 0 29]. 291 200 0 0 391 391 300 0 0 491 491 qO0 0 0 S91 S9]. SOO 0 0 691 691 600 0 0 791 791 700 0 0 891 891 800 0 0 992 991 900 1092 1192 1292 1392 1494 1700 1807 1915 2028 2143 2262 2384 2S10 2642 2784 2947 3116 3286 1091 1000 1 0 1].91 1100 1 0 1291 1200 1 0 1391 1300 1 0 1491 1400 3 2 1591 1S00 S 2 1691 1600 9 4 1791 1700 16 7 1891 1800 24 8 1991 19 00 37 13 2091 2000 S2 1S 2191 2100 71 19 2291 2200 93 22 2391 2300 119 26 2491 2400 1S1 32 2S9]. 2S00 193 42 2~91 2500 2S~ $3 2791 2700 32S 69 2891 2800 395 70 2991 2900 4~S 70 REL.AT]VE COORDINATES FROM WELL-HEAD 0.16 S 0.01 E 0.33 S 0.02 E O.S1 S 0.03 E 0.70 S O.OS E 1.18 S 0.23 E 1.S4 S 1.49 S 1.34 S O.SS N 3.77 N 0.S3 E 1.19 E 1.8~ E 2.37 E 2.63 E 7.93 N 12.31 N 18.60 N 28.21 N 43.23 N 3.13 E 3.7S E 4.60 E 4.94 E 2.62 E 63.71 N 91.68 N 128.3S N 167.94 N 218.21 N 3.00 W 10. S1 W 19. S3 W 29.24 W 42.29 W 272.46 N 334.27 N 402.77 N 477.47 N S60.92 N S7.02 W 73.94 W 91.30 W 109.70 W 131.17 W 6S8.3S N 783.34 N 915.S2 N 1048.20 N 1180.84 N 1SS. 78 W 186.73 W 220.30 W 2SS. 04 W 289.97 W ~EST E]'LEE~:_ ~LL Il' Z-31 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH MEAS. TRU VERT SL~ SEA MO-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3624 3792 39S9 4127 4295 4463 4631 4802 4973 5145 5322 5500 5682 5862 604O 6217 6393 6571 6749 6928 7103 7277 7447 76].4 7779 7939 8097 8251 8404 8555 3091 3000 S33 68 3191 3100 601 68 3291 3200 668 67 3391 3300 736 68 3491 3400 804 68 3591 3500 872 68 3691 3600 940 68 3791 3700 1011 71 3891 3800 1.082 71 3991 3900 1154 72 409]. 4000 1231 77 419]. 4100 1309 78 429]. 4200 1391 82 4391 4300 1471 80 449]. 4400 1549 78 4591 4500 1626 77 469]. 4600 1702 76 4791 4700 1780 78 4891 4800 1858 78 4991 4900 1937 79 S091 SO00 2012 75 S191 SIO0 2086 74 S291 S200 2156 70 5391 5300 2223 67 S491 S400 2288 65 SS91 SSO0 2348 60 S691 S600 2406 S8 S791 S700 2460 S4 5891 S800 2513 S3 S991 S900 2564 SI RELATIVE COORDINATES FROM WELL-HEAD 1311.97 N 1442.73 N 1572.99 N 1703.25 N ].834.33 N 323.64 id 356.64 id 388.76 id 420.87 id 452.89 id 1965.89 N 2097.46 N 2231.65 N 2366.39 N 2503.18 N 484.84 id S16.79 id S49.38 id S82.10 id 615.08 id 2644.S1N 2788.56 N 2936.92 N 3083.76 N 3228.37 N 647.94 id 680.53 id 711.35 id 741.82 id 771.89 id 3370.S0 N 3512.65 N 3656.36 N 3800.61N 3944.81N 802. S4 W 833. SO W 865.09 W 896.81 W 928.66 id 4085.46 N 4222.92 N 4356.97 N 4485.63 N 4612.21N 961.40 id 994.94 id 1029.36 id 1064.17 id 1098.89 id 4732.22 N 4849.69 N 4962.SS N S074.36 N 5185.21N 1132.39 W 1165.61W 1198.29 W 1226.64 W 1251.12 id WEST EILEEN WELL ~' Z-31 DATA ]NTERPOL.ATED FOR EVEN 100 FEET OF SUELSEADEPTH 11/10/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL. DEPTH DEPTH DEPTH DIFF. CORRECT 8706 6091 6000 261S S1 8857 6191 6100 2666 S1 9006 6291 6200 271S 49 91S4 6391 6300 2763 48 9303 6491 6400 2812 49 9606 9760 991S 10072 10229 10387 10S47 10707 ('.0868 11028 11186 11342 11497 11649 11799 11946 12093 12236 12378 6S91 6S00 2862 SO 6691 6600 291S S3 679]. 6700 2969 S4 6891 6800 3024 SS 6991 6900 3081 57 7091 7000 3138 S7 7191 7100 3196 55 7291 7200 32S6 60 739.1. 7300 3316 60 7491 7400 3377 61 7S91 7SOO 3437 60 7691 7600 349S S8 7791 7700 3SS1 S6 7891 7800 3606 SS 7991 7900 36S8 S2 8091 8000 3708 SO 8191 8100 37SS 47 8291 8200 3802 47 8391 8300 384S 43 8491 8400 3887 42 RELATIVE COOROINATES FROM WEL.L.-HEAD S297.91N S410.46 N SS21.04 N S629.96 N S740.18 N 1260.71 W 126_1..72 W 1261.95 14 1260.14 14 12S3.81 14 S8S1.73 N S966.92 N 6082.47 N 6200.19 N 6319.09 N 1243.39 W · 1228.07 14 1212.46 14 1174. O9 14 6438.18 N 6SS7.8S N 6679.26 N 6800.67 N 6922.60 N 1152.23 1125.60 1099.68 1070.76 1038.80 7043.76 N 7160.11 N 7275.14 N 7388.02 N 7497.61 N lOOS. 92 14 970.76 14 93S. 04 14 900.1S 14 866. S4 14 7603. SO N 7706.19 N 7808.87 N 7903.03 N 7994. S7 N 532.7S 14 798.79 14 764.83 14 72S. S2 14 684. S7 14 12S20 8S91 8S00 3929 42 8086. :].2 N 643.62 W WEST EILEEN WELL ~ Z-31 DATA INTERPOLATED FOR EVEN 1000 FEET OF NEASURED DEPTH 11/10/88 NEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FRONWEL. L-HEAD 8000 46S8 4S~7 319S.81 N 765.12 W 7000 S292 S201 4002.82 N 942.12 W 8000 S788 S897 4778.09 N 114S.20 W 9000 ~S86 649S SS16.6~ N 1282.02 W 10000 721S 7124 ~2~4.3~ N 1184.13 W 11000 784S 77S4 7022.48 N 1011.82 W 12000 8347 82S~ 7743.77 N 78~.3~ W 1000 1300 1209 4.11N 2.&7 E 2000 2189 2098 205.7& N 39.0& W 3000 29&0 28&9 824.57 N 197.20 W 4000 3458 3367 l&O4.&l N 39&.~& W 5000 4018 3927 2387.87 N 587.31W 750 t500 2~50 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 tO500 -750 VERTICAL SECTION STANDARD ALASKA PRODUCTION CO. WEST EILEEN NELL # Z-3! .,, SECTION AT N 3.93 W _ , TVD SCALE' t inch = i500 feet DEP SCALE · t inch = 1500 feet DRAWN · ll/10/§8 .... Narker IOent~flcaNlon ND TVD DEPR7 A} ~ o o o ........... ~ '1 .... B} TO i2566 8624 Bi40 ,,, 0 750 tSO0 2250 3000 3750 4500 5250 6000 6750 7500 8250 Departure Marker Identtflcat~on MD TYD DEPRT A) Ka o o o B) TO i2586 BB24 B{40 HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. NEST EILEEN WELL # Z-3! CLOSURE: 8140 ft N 4.4 W DECLINATION: 30.83 deg E SCALE: t inch = i250 feet DRAWN: it/lO/BB 7500 6875 6250 5625 5000 4375 3750 3`125 2500 `1675 ~250 625 625 3750 3t25 2500 I / , .... i I ! ! '- .... ~,875 `1250 625 0 625 ~250 i875 P.500 3'125 3750 WELL NAME : ~D~ WELL LOG INVENTORY PAGE 1 of l LOG CDM (mudlog) DIL/SFL (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ litho-density) LOG COUNT DATE REC , RUN# CFD (compensated formation density) BHC/SL (borehole compensated sonic) LSS (long spaced sonic) SSS (short spaced sonic) CYB (cyberlook) GCT (groscopic survey) DIPMETER SAMPLES: Required yes (~ Date Received: Comments: A~CO EXXON STANDARD ALASKA PI,}('.)DI.JC l'lC'~hJ Date: 11/28/88 PHILLIPS T~: 79578 STATE OF AK SYSTEMS (Transmit, tal& Tape) ARCHIVES SAPC MAGNETI~ LIS TAPES & LISTINGS ~]e following material is being suk~mitted herewith. Please ac?~ledge receipt by signing a copy of this letter and retuming it to this office: Cased Hole Tape~ ~W-34 CH/CNL 4 Pass 11/14/88 #I 9489.9-10818.91 Sch#73016 1600bpi API#50-029-21867 ARCHVIES ONLY: W-34 CH/CNL field tape 11/14/88 #I Tape Pos.#06172 Sch#73016 1600bpi API#50-029-21867 Tape Pos. #06171 Open Hole Ta;3es Z-31 0H/DIL/BHC/LDT/CNL/Casing CNL/GR 11/11/88 #I 9472-13280.5 Tape Pos.#06173 Sch#73011 1600bpi API#50-029-21871 ARCHVIF~ ONLY: :. Z-31 OHi field Tape 11/11/88 #I Ta~e Pos.#06174 Sch#73011 1600bp.i API#50-029-21871 * EX~(ON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly rom the respective service company. Please confirm this. Received Date A u",~ OI ~he o~,,~/',~ol Founded ,,, Clevelo.d 0~,o ,. 187( ' ~cl~orage .Comml~lon Jennif ~r Dietz INFORMATION C~[ROL Well Records LR2-1 Slanda~d Alaska .~ Production Compan 900 Eas~ Benson Bou,. .'d P.O. Box 196612 Anchorage. Alosi~o 99519.66 REFERENCE: HOUSTON ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS SZATZ OZ AriAs~ GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Date: 11/22/88 fl: 79566 The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: B-22 Compl~ion 11/16/88 #I 9628-11120 Sch 5" N-22 CNL/GR 2.5" Tool 11/14/88 #I 10000-10829 Sch 5" M-03 Prod-R 11/15/88 #- 9740-10990 Sch 5" W-34 CNL/GR 2.5" Tool 11/14/88 #I 9500-10794 Sch 5" Z-31 CET 11/15/88 ~I 12350-13212 Sch 5" Z-31 CBT 11/15/88 #I 12350-13189 Sch 5" Z-31 P~f-R 11/16/88 #I 12600-12190 Sch 5" I NFORMAT I ON CONTROL Date Well Records LR2-1 Founded ;n Cle-elond. Ohio. ;n 1810. October 3, 1988 Telecopy~ (907)276-7542 Ted Stagg Prudhoe Bay Unit Drilling Engineering Supervisor Standard Alaska Production Company- P.O. Box 196612 Anchorage, Alaska 99519-6612 Re ~ Prudhoe Bay' Unit Z-31 Standard Alaska Production Compamy Permit No. 88-112 Sur. Loc. 714'SNL, 3664'WEL, Sec. 19' TllN, R12E, UM. Btmhole Loc. 2407'SNL, 4238'WEL, Sec. 7, TllN, R12E, UM. Dear Mr. S tagg .. Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other gover~ental agencies prior to commencing operations at the well site. To aid us in scheduling field.work, please notify this office 24 hours prior to c~encing in~'~altation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing .shoe is drilled.. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. BY O~ER OF ~HE COMMISSION dlf · Enclosure Department of Fish & Game,. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA elL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work 'Drill [] RedrillCIIlb. Type of well. Exploratoryl-I Stratigraphic Testl-'! Development Oill[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Comoanv 92 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anch~rac/e_ Al~.~ka ~9~19-~12 ADL zl7,f~O 4. Location of well at sur]race 7. Unit or property Name 11. Type Bond(see 20 ^^c 2s.o25) 714' SNL, 3664' WEL, SEC 19, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2600' SNL, 4225' WEL, SEC 7, T11N, T12E Z-31 (12-07-11-12) KOO683449-G- 14 At total depth 9. Approximate spud date Amount 2407' SNL, 4238' WEL, SEC 7, T11N, R12E October 6, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandTVD) property line ADL 28240 691 feet WellZ-08 262 feet 2469 13201'MD 9131' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^AC 25.035 (e)(2)) Kickoff depth 800 feet Maximum hole angle50. 79o Maximum surface 3330 pslg At total depth (TVD) 8800 4390pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Cond. Surface 110' 110' 8 cu yds concrete 17-1/2" 13-3/8" 68# L-80 Butt 2922' Surface 2952' 2650' 4101 cuft Permafrost 12-1/4" 9-5/8" 47# L-80 NSCC 5845' Surface 5875' 4500' 12-1/4" 9-5/8" 47# L-80 Butt 6709' 5875' 4500' 12584' 8738' 2762 cu fl Class G 8-1/2" 7" 26# L-80 IJ4S 877' 12324' 8577' 13201' 9131' 269 cu ft Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify, th~t.,.the foregoing is true and correct to the best of my knowledge Signed-.c~J~ Title PBUDrillin. EnoineerinaSuoervisor Date?l' /~' /' / ~ Commission Use Only - - - /- // Permit Number IAPI number IApproval date ISee cover letter ~'~--/'/'~_. I5o-(D,~.?- .2../~' 7/ I '10/03/88 Ifor other requirements Conditions of approval Samples required [] Yes ,]~'No Mud log requir.ed I-lYes ~ No Hydrogen sulfide measures .J[;] Yes~,[~[ No D~rection.al survey requ~reo ~ Yes [] No Required work~'~~'//~~E~~_~ r"llOM; I-I15M; Other: ' ' by order of //~ Approved by ~ ,/. ( ~./~'~ Commissioner the comm,ssion Date Form 10-401 Rev. 12-1-85 / Submit :riplicate AFE No. 120717 PROPOSED DRILLING AND COMPLETION PROGRAM WELL Z-31 [12-%11-121 PBU Install and cement 80' of 20" conductor to surface. Install 20" diverter. The Drilling fluid program will consist of an 9.5 - 10.0 ppg spud mud in the 17- 1/2" hole, a 9.5 - 10.4 ppg water base mud in the 12-1/4" hole and a 9.4 ppg water base mud in the 8-1/2" hole. Drill 17-1/2" hole to 2972' and cement 13-3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12-1/4" hole to the 9-5/8" casing point at the Sadlerochit Sandstone. Run 9-5/8" 47# L-80 Butt/NSCC casing to within 5' of 12-1/4" TD and cement in two stages: First stage using Class G cement around the 9-5/8" shoe. The second stage to be downsqueezed in the 13-3/8" x 9-5/8" annulus followed by nonfreezing fluid. Directionally drill 8-1/2" hole to TD. Run 7" liner from TD to 250' inside 9-5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.4 ppg. filtered NaCL completion fluid. Test Casing and lap to 3000 psi. Perforate well with wireline conveyed guns. Run 9-5/8" production packer on 3.5" tubing with a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Tubing Size: 3-1/2", 9.3# L-80 EUE 8 Round A/B Mod IPC TBG with 8 GLM's. Tailpipe Size: 3-1/2" TAILPIPE RIS' 20-Sept-88 PROPOSED DOWNHOLE DIAGRAM WELL Z-31 [12-7-11-12] PBU/EWE PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 2045 13-3/8" Casing Shoe 17-1/2" Open Hole 2952 2972 3-1/2" 9.3# L-80 A/B Mod EUE 8RD IPC Tubing with 8 GLM's 9-5/8" Packer 12274 7" Tieback Assembly 12324 9-5/8" Shoe 12584 12-1/4" Open Hole 12589 7" 26# L-80 IJ4S Liner 7" PBTD 13161 7" Liner Shoe 13201 8-1/2" Open Hole 13201 FLOWLINE 10 3/4" Hydra~c operated__ Butterfly' valve a~tically~ 12" MAX. nEVEL DRILLING RISER 20" 2000 PSI WP ANNULAR PREVENTOR DRILLING SPOOL DIVERTER SYST~-M DETAIL DRILL. DEPT. April 1982 20" CONDUCTOR PIPE NOTE: DIVERTER ~INE HAS TWO DIRECTION DISCHARGE CAPABILITY AFTER LEAVING RIG SUB-BASES. SURFACE HOLE DIVERTER SYSTEM Two lines venting 90© apart in directions that insure safe down wind ventihg, and extending to a point at least 100' (feet) from any potential source of ignition. 10 3/~" manual t~otterfly valves NOTES I. Ail pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 2. Manual 10-3/4" butterfly valves, mechanically connected to insure that one valve is fail- safe open at all times. 3. All turns are 90° (degrees) and targeted. 10 3/4" 55~ Buttress "' 10 3/4" Hydraulic operated Butterfly valve B.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAM STACK S000 PSI WP DRILLING ANNULAR PREVENTER .I I I PIPE RAMS I I I I BL IND"RAI'IS I 2 IN KILL LINE I ' GATE GATE DRILLING SPOOL I PIPE RAMS 4 IN. CHOKE LINE GATE GATE NORTH WELL 1~ Z-31 SURFACE LOCATION LAT. · 70 17' 54. 298 LONG. · 149 o I !' 53.482" A.S.P. Y · 5, 959, 359.96 X · 599, 008.01 ZONE 4 714' FROM N. LINE SECT 19 1288' FROM W. LINE SECT. '9 T. Il N {~12 7 .ii TIIN. T. ION. i 14 I3 ~)le 23 Z4 SCALE ! ( MILES ) 28 1: W. 'C' IZ$~ i ~) 3,4 I CERTIFICATE OF SURVEYOR: I HEREBY CERTIIry THAT ! Aid PROPERLY REGISTERED AND LICENSED TO PRACTICE LAN~ SURVEYING ~1~ THE STATE OF ALASKA AND THAT THIS PLAT REPRESEHT$ A LOCATION SURVEY MADE BY ME OR UNDER MY 6U"=ER'VIS~ON, AND THAT ALL DIMENSIONS AND OTHER DETAILS &R/E CORRECT. SURVEYOR DATE: WELL PAD Z J II WELL N° Z - 31 AS-BUILT LDCATE D IN PROTRACTED SECT. Ig , t. It N. , R. IZ [.. U. lld SURVEYED FOR : PREPAR[D IY : KUUKPIK - TECHNICAL ~RV. INC. ,DATE : NOV. Z0,86 DRAWN BY: I,T. NW CORN. OF SECT. 19 NORTH LINE OF SECTION SUMP 1~88' J'L J N · · · · · · · · · · 1_1 · · · · · · SUMP 1 IIOR TN SHEET I~ OF !, ! WELL PAD Z WELL Ne Z-:~l AI-IUILT LOCATED IIII SEC"[ lO , T. I t. ,, I. I!~ Ir, U, It. IURYEYED POI : ITAN~D AL~ PI~::X:Nd~T~ CO. KUUKPIK -. TECH# ICAL I.[RV. INC. PlUOl~OE ~Y olrlrlC E DATE: 10¥. I~O, 04 HAWN BY s I~- CNK[ BI': _$15DUAlO:'[DRANO25]Z31_CLOSAP_SHORT. LIS;2 Search Radius= 200 COURSE LINE For proposed well: Z-31 [12- 7-11-12] Location = W-E S-N TVD(SBS) Top 599008.00 59~93b0.00 -~2.00 Bottom 598284.21 59~8208.00 9038.99 Note: All depths in Feet Below Kell~ Bushing (BKB) 20-SEP-1988 13:07 --- Closest Approach Analqsis --- Date: ~O-SEP-88 Time: 13:0&:5~ Page I Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART Vertical CLOSEST /PROPOSED\ DISTANCE TVD DEPART A0~9-~006=00 71112 ~ 7822.8 7274. I 7547. D 1046.4 1052.2 A0~-=006201 7111~R 7759.6 7196.6 7502.4 ~90o8 1039.9 A0~-2051100 CHEVTR 5918. I 493~.6 5925.2 1945. I 693. 5 A029-~178700 Z-8 0.4 O. 0 O. 0 O. 0 262. 0 SUMMARY Intersection /NEARBY\ TVD DEPART VERTICAL DISTANCE The well ~hich comes closest to the proposed well is: A029-2178700 Z-8 Closest approach distance KICK OFF For this run 262.0 Feet 800.0 Feet _IISDUAIO' [DRANO25]Z31_CLOSAP_SHORT7. LIS;2 20-SEP-1988 13:08 --- Closest Approach Analusis --- Date: 20-SEP-88 Time: 13:08:20 Search Radius- 200 7 DEGREE LEAD LINE For proposed well: Z-31 [12- 7-11-12] Location - W-E S-N TVD(SBS) Top 599008.00 5959360.00 -92.00 Bottom 597211.31 5968053.84 9038.99 Note: All depths in Feet Below Kellg Bushing (BKB) .~ Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOSEST DISTANCE A029-2006200 71112 7443.5 6809,2 6912,0 899,1 1871.3 A029-~006201 71112R 7466.6 6837. 5 7004. 5 901.8 1862.9 A029-2051100 CHEVTR 5859.8 4868.2 5963.5 1973.3 1290.8 A029-2178700 Z-8 0.4 0.0 0.0 0.0 262.0 /PROPOSED\ TVD DEPART Vertical Intersection /NEARBY\ TVD DEPART SUMMARY well which comes closest to the proposed well AO29-217B700 Z-8 Closest approach distance KICK OFF For this run 262.0 Feet 800.0 Feet Page I VERTICAL D I STANCE SUC?~ON ro 1 - ~ ~-12" Cone $~e Desander 1 - ~ ~fH w/~f cones & (1) Dem~ 48H w/16 cones (Desilter) 1 - Drilco Atmospheric Mud Degasser O£~CO IZ 3 50 5'0 ~. TAH~ 2 1- 200 gpm Operating Capacity. Centrifuge 15 - Brandt MA5 Mud Mix Agitators 1- 150 bbl. Trip Tank 1 - Recording drilling fluid pit level indicator with both visual and audio warning devices at driller ' s oonsole 1'0 ~/r I r,,~. I r~o,, --4 r ,(,, L_ mUD 1 - ~ll~g fled fl~ ~or wi~ rea~ut at ~ill~.',s CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE 'DATE · Loc (~ th~ 8) (8) (3) Admin ~PC ~/z ~ (9 t:hru i3)' (10 and 13) (4) Cas (14 thru 22) (5) BOPE (23 thru 28) (29 thru 31) (6) Add: Geology: EnEi~neer lng: rev: 08/11/88 6.011 Company .~/z~ /2)~ Lease & Well No. " YES NO Is the permit fee attached .......................................... ~ _ 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... ~_~ . 5. Is sufficient undedicated acreage available in this pool ............ ~_~ ........ 6. Is well to be deviated and is wellbore plat included .......... 7. Is operator the only affected party .................. '. ...... 8. Can permit be approved before fifteen-day-wait ...................... 9. Does operator have a bond in force .................................. ~_~ 10. Is a conservation order needed ...................................... 11. Is administratiVe approval needed ................................... ,, 12. Is the lease number appropriate ..................................... 13. Does the well have a unique name and number ......................... ~.'~z ... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ,, , Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ....~ Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment.procedure included on 10-403 ............ Is adequate wellbore separation proposed .... · ....................... 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate.~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to~_~l~__psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' No special'effort has been made to chronologically organize this category of information. Z -31 PRUDHOE BAY :::::::::::::::::::::::::::::::::: :::::: ;{;~i! ........ ::'::.~ ::::: i{ i},; :::::::::::::::::::::::::::::::: ................. ~ ...... ¥... :.. .... :: ......... , :::::::x:::~2:::¥: :::¥i::::::::~ ~:~ ................... '.~:::: =============================================== :::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ......, ........... ========================= ================================== ...::~i.;..:~-.i::::: ........ :::::::::::::::::::::::::::::::::::::::::::::::::::::: 5~5[~:::: ........ ::: 12350' Run 1' 09 - August - 1996 PDK-1001GR WESTERN ATLAS Logging Services 13150' Tape Subfile, 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: 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 Z - 31 500292187100 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 21-AUG-96 6767.00 D. CAIN B. ROCHIN 19 llN 12E 714 3664 91.50 55.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 12641.0 3RD STRING 7.000 13251.0 PRODUCTION STRING 3.500 12429.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 12600.5 12605.5 12636.5 12657.5 12658.5 12675.0 12675.5 12676.5 12678.5 12679.5 12690.5 12691.0 12692.5 BHCS GR 2 1 19-APR-89 SWS ......... EQUIVALENT UNSHIFTED DEPTH GRCH 12599.5 12604.5 12635.0 12656.0 12656.5 12674.5 12675.0 12675.5 12677.5 12678.0 12689.0 12690.0 12691.5 47.00 26.00 9.30 12693.5 12697.5 12698.0 12706.0 12706.5 12707.0 12708.0 12746.0 12747.0 12752.5 12764.5 12770.0 12771.0 12776.0 12776.5 12827.0 12827.5 12829.5 12830.5 12831.0 12833.0 12834.0 12841.5 12842.5 12852.0 12852.5 12862.5 12863.5 12904.5 12905.0 12914.0 12915.0 12916.0 12916.5 12917.0 12919.0 12920.0 12929.0 12939.0 12939.5 12940.5 12941.0 12941.5 12942.5 12943.5 12950.5 12953.5 12954.5 12978.0 12978.5 12979.5 12980.0 12981.5 13002.0 13002.5 13005.0 13017.5 13019.0 13019 · 5 13027.0 12692.0 12696.0 12697.0 12705.0 12706.0 12706.5 12707.0 12745.0 12745.5 12751.0 12763.5 12769.0 12769.5 12774.5 12775.5 12826.0 12827.0 12829.0 12829.5 12830.5 12832.5 12833.0 12840.5 12841.0 12850.5 12851.5 12861.5 128.62.0 12903.0 12904.0 12913.0 12913.5 12914.5 12915.5 12916.0 12918.0 12918.5 12927.5 12938.5 12939.0 12939.5 12940.0 12941.0 12942.0 12942.5 12949.0 12952.0 12952.5 12977.0 12977.5 12978.0 12978.5 12980.5 13001.0 13002.0 13004.5 13016.5 13018.0 13019.0 13026.5 1302.7.5 13031.5 13040.5 13041.0 13042.0 13042.5 13046.0 13055.0 13060.0 13064.0 13066.0 13067.0 13069.0 13069.5 13072.5 13073.5 13082.5 13083.0 13093.0 13094.0 13094.5 13129.0 13130.0 $ REMARKS: 13027.5 13031.5 13040.0 13040.5 13041.0 13042.0 13045.5 13055.0 13061.0 13064.0 13066.0 13066.5 13068.5 13069.5 13072.5 13073.0 13082.0 13083.0 13093.0 13093.5 13094.5 13129.0 13129.5 PDK-100/GR. LOG WAS TIED INTO CEMENT BOND LOG RECORDED 15-NOV-88. WELL SHUT-IN SINCE 06-AUG-94. LOGGING SUITE ORGANIZATION: 1) LOGGED TWO PASSES. A DIFFUSION CORRECTED SGMA CURVE IS NOT INCLUDED SINCE BOREHOLE FLUID SALINITY COULD NOT BE DETERMINED FROM AVAILABLE INFORMATION. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR BOTH PASSES. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA (PDK) DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT PDK PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS PDK. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: I START DEPTH 12318.0 12330.0 ......... EQUIVALENT UNSHIFTED DEPTH STOP DEPTH 13138.0 13150.0 (MEASURED DEPTH) BASELINE DEPTH SGMA 12652.5 12650.5 12675.5 12673.5 12676.5 12675.5 12677.0 12676.0 12678.5 12676.5 12680.5 12678.5 12681.5 12679.0 12683.0 12680.5 12684.0 12682.0 12687.5 12685.5 12688.0 12687.0 12689.5 12688.5 12690.5 12689.0 12691.0 12690.0 12692.5 12691.5 12707.0 12705.0 12707.5 12705.5 12709.0 12706.0 12709.5 12707.0 12714.0 12711.5 12743.0 12742.0 12746.0 12745.0 12746.5 12746.0 12755.0 12754.5 12777.0 12776.0 12778.5 12777.5 12779.5 12778.0 12780.5 12779.0 12781.0 12780.0 12800.5 12799.5 12801.5 12800.0 12819.5 12818.0 12827.0 12826.0 12827.5 12827.0 12829.5 12829.0 12830.5 12829.5 12831.0 12830.5 12833.0 12832.5 12834.0 12833.0 1284'1.5 12842.5 12852.0 12852.5 12862.5 12863.5 12873.0 12883.5 12897.0 12914.0 12915.0 12916.0 12916.5 12939.5 12940.0 12943.0 12944.0 12952.5 12953.5 12955.0 12980.0 12995.0 12996.0 12997.0 12997.5 13002.5 13003.0 13005.0 13006.0 13006.5 13018.5 13047.0 13054.5 13069.5 13070.5 13081.5 13082.0 13083.0 13089.5 13090.0 13091.0 13091.5 13099.5 13100.0 13119.0 13120.0 13129.5 13130.5 13132.0 13133.0 13135.0 13135.5 13141.5 13142.5 $ REMARKS: 12840.5 12841.0 12850.5 12851.5 12861.5 12862.0 12871.5 12882.0 12896.0 12913.0 12913.5 12914.5 12915.5 12938.5 12939.5 12942.5 12943.0 12951.5 12952.0 12953.5 12979.0 12994.0 12994.5 12995.5 12996.5 13001.5 13002.5 13004.5 13005.0 13005.5 13018.0 13046.5 13055.0 13069.5 13070.5 13082.0 13082.5 13083.0 13089.5 13090.0 13090.5 13091.5 13099.5 13100.5 13119.5 13120.0 13129.5 13130.0 13131.5 13132.0 13134.0 13135.0 13141.0 13141.5 PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ??MATCH1B. OUT $ CN : BP EXPLORATION WN : Z - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 i CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 i CU 13 SGMB PDK 68 i CU 14 SS PDK 68 i CPS 15 PHI PDK 68 i PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 60 * DATA RECORD (TYPE# 0 ) Total Data Records: 113 966 BYTES * Tape File Start Depth = 12315.000000 Tape File End Depth = 13155.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26897 datums Tape Subfile: 2 412 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Su'bfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: I START DEPTH 12788.0 12800.0 STOP DEPTH 13138.0 13150.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 12793.5 12792.5 12797.0 12803.0 12804.0 12817.0 12817.5 12839.5 12838.5 12840.5 12839.0 12847.0 12845.5 12847.5 12848.0 12847.0 12864.0 12863.0 12865.5 12863.5 12866.0 12864.5 12866.5 12869.5 12870.5 12872.0 12877.0 12877.5 12883.0 12881.5 12904.0 12903.0 12906.0 12905.0 12906.5 12906.0 12908.0 12907.5 12909.0 12908.0 12912.5 12911.5 12913.0 12912.5 12914.0 12913.5 12919.5 12918.5 12927.0 12926.0 12928.5 12937.5 12938.0 12938.0 12938.5 12939.0 12939.5 12939.0 12941.5 12941.0 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 12796.0 12802.0 12802.5 12815.5 12816.5 12838.5 12839.0 12845.5 12846.5 12865.5 12867.5 12868.5 12870.5 12875.5 12876.5 12927.5 12937.5 12938.0 12938.5 12942.0 12942.5 12943.0 12949.0 12950.0 12952.0 12952.5 12953.0 12954.0 12954.5 12963.0 12963.5 12964.0 12964.5 12965.0 12969.0 12976.0 12977.5 12978.0 12979.0 12984.0 12985.0 12985.5 12987.5 12988.5 12992.5 13001.5 13002.0 13002.5 13003.0 13005.0 13005.5 13018.0 13018.5 13019.5 13020.0 13020.5 13024.0 13024.5 13025.0 13026.5 13027.0 13040.5 13041.5 13049.5 13050.0 13052.0 13055.0 13057.0 13057.5 13059.5 13060.5 13063.5 13064.5 13065.5 13071.5 13072.0 13073.5 13074.5 13075.0 12941.5 12948.0 12948.5 12950.5 12951.5 12952.0 12952.5 12953.0 12962.0 12963.0 12963.5 12967.5 12976.5 12977.0 12977.5 12982.5 12991.5 13001.5 13002.5 13004.5 13005.5 13017.5 13018.0 13018.5 13019.0 13020.0 13026.0 13027.0 13040.5 13041.0 13049.0 13050.0 13057.0 13058.0 13060.0 13060.5 13064.5 13065.0 13071.0 13072.0 13074.5 12941.5 12942.0 12962.5 12963.0 12975.0 12984.0 12985.0 12987.0 12987.5 13000.5 13001.5 13023.5 13024.0 13024.5 13049.0 13050.0 13052.0 13055.5 13064.0 13064.5 13073.5 13075.5 13079.5 13082.0 13082.5 13083.0 13083.5 13096.5 13097.0 13097.5 13100.0 13100.5 13101.5 13102.5 13103.0 13109.5 13115.5 13116.5 13117.5 13118.0 13120.0 13121.0 13128.0 13128.5 13129.0 13129.5 13132.0 13133.0 13145.0 13145.5 $ REMARKS: 13080.0 13082.5 13083.0 13096.5 13097.0 13097.5 13100.5 13101.0 13103.0 13118.5 13120.5 13121.0 13128.0 13129.0 13129.5 13130.0 13083.0 13083.5 13100.0 13101.0 13103.0 13110.5 13116.5 13117.0 13117.5 13132.0 13132.5 13144.5 13145.0 PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH2A. OUT / ??MATCH2B . OUT $ CN : BP EXPLORATION WN : Z - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT .: ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units I GRCH PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 i GAPI 1 i CPS I CPS Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 I 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 I CU 13 SGMB PDK 68 i CU 14 SS PDK 68 i CPS 15 PHI PDK 68 i PU-S * DATA RECORD (TYPES 0) Total Data Records: 50 966 BYTES * 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 6O Tape File Start Depth = 12785.000000 Tape File End Depth = 13155.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11857 datums Tape Subfile: 3 209 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 · AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass i gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS PDK GRCH $ REMARKS: 1, 2 1 AVERAGED PASS. PASSES 1, & 2 WERE AVERAGED. $ CN : BP EXPLORATION WN : Z - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 MSD PNAV 68 1 CU 4 8 RATO PNAV 68 1 4 9 RBOR PNAV 68 1 4 10 RICS PNAV 68 1 4 11 RIN PNAV 68 i 4 12 SGMA PNAV 68 1 CU 4 13 SGMB PNAV 68 1 CU 4 14 SS PNAV 68 1 CPS 4 15 PHI PNAV 68 1 PU-S 4 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 4 53 995 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 6O * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 113 Tape File Start Depth = 12315.000000 Tape File End Depth = 13155.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53794 datums Tape Subfile: 4 135 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12306.5 PDK 12318.5 $ LOG HEADER DATA 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): STOP DEPTH 13156.5 13168.5 09 -AUG- 96 FSYS REV. J001 VER. 1.1 2010 09-AUG-96 13210.0 13150.0 12350.0 13150.0 2100.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 3913NA 2735XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 13251.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 65000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS $ CN : BP EXPLORATION WN : Z - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units 1 GR PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 GElS PDK 68 I CPS 11 ISS PDK 68 1 CPS 12 LS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 18 RIN PDK 68 1 19 SGMA PDK 68 i CU 20 SGMB PDK 68 i CU 21 SPD PDK 68 i F/MN 22 SS PDK 68 i CPS 23 PHI PDK 68 i PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 51 310 01 1 4 4 51 995 99 1 4 4 51 391 51 1 4 4 51 390 51 1 4 4 51 150 01 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 01 1 4 4 51 995 02 1 4 4 51 995 99 1 4 4 51 391 99 1 4 4 51 391 99 1 4 4 51 430 01 1 4 4 51 995 99 1 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 400 01 4 4 51 995 99 1 4 4 51 636 99 1 4 4 51 390 99 1 4 4 51 635 99 1 92 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 343 Tape File Start Depth = 12310.000000 Tape File End Depth = 13165.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 93962 datums Tape Subfile: 5 418 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12779.0 PDK 12791.0 $ LOG HEADER DATA 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): STOP DEPTH 13156.0 13168.0 09 -AUG- 96 FSYS REV. J001 VER. 1.1 1950 09-AUG-96 13210.0 13150.0 12350.0 13150.0 2100.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 3913NA 2735XA BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 13251.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 65000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : Z - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ els Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 i CPS 4 10 GElS PDK 68 i CPS 4 11 ISS PDK 68 I CPS 4 12 LS PDK 68 i CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 i 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 I CPS 4 23 PHI PDK 68 i PU-S 4 4 51 310 01 4 51 995 99 4 51 391 51 4 51 390 51 4' 51 150 01 4 51 995 99 4 51 995 99 4 51 995 01 4 51 995 02 4 51 995 99 4 51 391 99 4 51 391 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 636 99 4 51 390 99 4 51 995 99 92 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 155 Tape File Start Depth = 12780.000000 Tape File End Depth = 13165.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 90779 datums Tape Subfile: 6 230 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile'7 is type: LIS 96/ 8/21 01 **** REEL TRAILER **** 96/ 8/21 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 21 AUG 96 l:17p Elapsed execution time = 22.24 seconds. SYSTEM RETURN CODE = 0 DIRECT DIGITAL LOGGING COMPUTER PRO CE$SE D ANALYSIS i LLLLLLLL LLLLLLLLL I I I I I I I I i I SSSS$SSS IIIIIIIiii oo~oo~.~:'"'"'--'"'- ........ II SS SS II SS Ii SS I I SSSSSSSSS I I SSS$$SSSS II SS ii SS ii SS SS i i i I I i i i i i ~~~ I i I i I I I i I i SSSSSS~:' DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DDDDDDDDDD UUUUUUUUUUUU DDDDDDDDD UUUUUUUUUU MM MH Mi'Iii MMbl MNMM MHMM NM NM MN MM NM HNHH MH MM NH MM MM HH MM HH Hbi NH him MH Mbl MM NM NH PPPPPPPPPPP PPPPPPPPPPP PP P PP P PP P PPPPPPPPPPP PPPPPPPPPPP PP PP PP PP PP ii iii ilii ii ii li Ii ii ii li iliI ii iii iiii ii ii Ii ii ii il iI iiii tili llli 1111 ii iii iliI 1! 11 ii ii I1 ii ii liiliiiili 555555555555 555555555555 55 55 55 555555555 5555555555 55 55 555555555555 55555555555 AA AAAA AA AA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 11 iii iiii ii 11 il ii ii ii I1 iitiiliiil lillllllil UU UU UU UU Ui.J UU UU UU UU UU UU UU U U U U UU UU UU UU UU UU ULltJUUUUUUUUU ULIUUUUUUUU 444 4444 44 44 44 44 44 44 44444444444 444444444444 44 44 44 44 44 GGGGGGGGGG GGGGGGGGGGGG GG GG GG GG GG GG GGGGG GQ GGGGG GG GG GGGGGGGGGGGG GGGGGGGGGG AA AAAA AA AA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 lin H HMH HH HHHM MHH MM HM PIN H HH Mi'iMM H 1'i1'1 MM M MM H MM H HM H MM H HH H HH H 00000000 0000000000 O0 0 O0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 0000000000 00000000 REEL HEADER .~ :~.: m S~r-vice name: &G5F01 Date: 90/'08,/!5 Co~lm~_Fit ~: HEADER Origin RECORDS Reel name: Page Continuation :~:~ TAPE HEADER Ssrvice name: &GSFOi Previous tape: Date: 907087i5 Comments: Origin: Tape name: 278169 Continuation #: Oi Fils name: ,001 Haximum length: 1.024 name: File t~pe: LO Version Previous ?ile: Date: INFORMATION RECORDS Pag~ i,lt-t E M C: H c; T A T C. T F.:"r" ["~ F' I t,i i !_OHG SECT T ~:~ i,J i',l R F! i'.i G EDF I-' L:' L i"i F [:, I"i F R t.l H T I H E [:, A T E 1... C C S 0 t',I i...UH FL. i.. t.it_ E H G i I.O i TN D D DI_ CBDi C 8 I. 1 TL I TCS 'FLAB HR l' t'IT i.lSS D F D i',i',,,' ! S D F P H D F L RM R i"l F' H F S T t.,IF c.~ P.. I'l C CONTENTS BP EXPLORATION Z-Si PRUDHOE BAY NORTH SLOPE ALASKA USA 21871,000 ..... 0 Deg, 0 Min 0 DeQ, 0 Min lin ............... 12E ........ ; ...... O.OOO ............. 91.50'0 ............ 53.900 ............ DF ................. DF ................. 110'0.000 ........... 157 7,;90 ........... 378169 ......... iillliiIlilllmll AP1 NIJM: 50-029-2i87i ................ DATE LOGGED: 07-i5-90 ................ ilmi&illiilIiilimIIlIllmllmIlIliI&ll IIlIlmI imliiiiiliIIIlImIIIIIIIImIiI iflljlj W iiIiiII Iiiii illmliIitSIlI II I IlIIimI ml · mm m m m~ mmmI ii~iIImIImI Illm III tm, mai imllIlliiII iItmImIIIal IIIaJIIIIII IIIlIIIllII i m . · i i i , '" 6'.' o 0 0 Smc 51301 ............................... NORTH SLOPE ..................... III|lmIIUliI IlIIaiIlI IltmIIIIIllI IlIll/ImI IIlIlllllIII IlIIIIlIII IIlIII IIIIIIIlIIIIIIIIIIIIllIlI allIlIlII III II · ,I · m . i . e mi · illlmll il iIttlmmaIaiI ilIllllllllllllll NORTH SLOPE YARBRO LUECKER 13210,000. 13177.000. O.OOO ..... 0,000 ..... 12650.000. 13167,000. 0..000 ..... I100.000 ......... 0.000 ............ 0..000 ............ PRODUCED II lelIlI illIllIIlI iiIlIlIIlI O, O0 o,. O. 000, . 0.000.. O, 0'0 O, . 0.000.. 0.00 O, , 6' '66" m m · m I m . I . · ~ m & t UNIT TYPE CATG 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 FT 0 3 FT 0 3 FT 0 3 0 3 0 3 0 0 0 0 0 O 0 ,O 0 O 0 .0 0 O 0 0 0 0 0 0 FT 0 3 FT 0 ~ FT 0 ~ FT 0 3 FT 0 ~ FT 0 ~ HR 0 2 HR 0 4 DEGF 0 'I DEGF O 'I 0 2 0 2 LB/6 0 2 CP O 2 8 2 0 2 OHMM O 2 OHMH 0 2 DEGF 0 2 0 2 OHHH 0 2 SIZE 40 40 40 20 20 20 4 34 .34 2 3 3 4 4 4 2 2 2 2 4 2 10 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 6,5 6,5 65 65 65 6,5 68 65 65 6,5 65 65 6,8 68 65 65 6,5 79 65 7'9 65 6,5 65 65 65 65 6,8 68 68 68 68 68 65 68 68. 68 68 65 68 ERROR I NFORMA TIOH RECORDS Page Mi-IEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR M C S T HC:SS B S DEGF 0 2. 4 68 0 2 i2 ~5 0 3 4 68 COMMENT RECORDS i.,le 1 1 ~,lel 1 ~,t,~ 1 1 ~.,~e 1 1 h! a 1 i file 1 1 i.,.i ,a 1 1 i.j e 1 I Location Comment i: Location Comment 2: Location Comment 3: Location Comment 4: File Comment 1: TIED Film Comment 2: File Comment 3: Film Commmnt 4: SURFACE: 715' FHL & 3559' FEL INTO SCHLUMBER;]ER CEMENT BOND LOG DATED 11-15-88. LiS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most clo~ml~, match ** Halliburton curve and tool mnemonics, HALLIBURTOH TO SCHLUMBE~GEa TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 12640.'00 13200,00 SGFN TMD CU SGFN TMD CU 12649,25 13193.00 SGFF TMD CU SGFF TMD CU 12649.25 13193.00 SGBH TMD CU SGBH TMD CU 12649,25 13193.:00 NSBF TMD CHTS NSBF TMD CNTS 12649,25 13'193,00 FSBF TMD CNTS FSBF TMD CNTS 12649.25 13'193.00 HTMD TMD NTMD TMD 12649.25 13193.00 FTMD TMD FTMD TMD 12649,25 13193.00 RTMD TMD RTMD TMD 12649,25 13'193.00 PHIT TMD PHIT TMD 12649,25 13t93,00 Page SGFM G4ER RSBF ABTN SGIH GR C:CL C:S AVGP SDDP AVGS SDDS TMD TMD TMD TMD TMD TMD TMD TMD TMD COMPUT COMPUT COHPUT COMPUT CU F/MI SGFM SIGQ G4ER RSBF ABTN SGIN GR CCL CS AVGP SDDP AVGS SDDS TMD TMD TMD TMD TMD TMD TMD TMD TMD COMPUT COMPUT COHPUT COMPUT CU F?MI 12649.25 i2649,25 12649.25 12649 25 12649 25 12649 25 i2649 25 12649 25 12649 25 12649,25 12649,25 12649,25 12649.25 13'193 13193 13193 13193 13193 13193 13193 13193 13193 13193 13193 13193 13193 ,00 .00 ,00 .00 ,00 ,00 .00 ,00 .00 ,00 .O0 .O0 ,OO DATA ~, ,+-' ENTRY BLOCK~ .~ m .-~.'~ E H T R FORMA T SPEC I F I CAT IONS TYPE SIZE CODE :~--'* ENTRY BLOCK LEGEND T",'PE DESCRIPTION 16 Datum speciPicati.on block ~ub-t~pe 0 Terminator ( no more entries ) 16 1 66 Page DATA FORMA T SPEC I I CAT IONS Page SERVICE SERVICE AP1 iti.lEM ID ORDER # UNIT LOG APl AP1 APl FILE TYPE CLASS MOD ~ PRC # SIZE LVL SHPL PROCESS INDICATORS DEPT 378169 FT 0 S~FH TMD 378169 CU 94 SGFF THD 378169 CU 94 SGSH TMD ~78169 CU 94 HSSF TMD 378169 CNTS 94 i=SBF TMD ~781~9 CNTS 94 NTMD THE) 378169 94 FTHD TMD 378i69 94 R'TMD TMD ~78169 94 PHIT THD ~78169 94 SQFM TMD 378169 CU 94 SIGQ THO ~78169 94 G4ER TMD ~78169 94 RSBF THO ~78169 94 A~TN THD 378169 94 SGiN TMD ~78i69 94 GR l'MD ~78169 94 C[:L TMD 378169 94 CS THD ~78169 F/HI 94 AVGP COMPUT 378169 94 SDDP COHPUT 378169 g4 A¥GS COHPUT ~78169 94 SDDS COMPUT ~78169 94 0 0 0 i 0 0 1 0 0 0 i 0 0 0 1 0 0 0 i 0 0 0 1 0 0 0 1 0 0 0 i 0 0 0 i 0 0 0 i 0 0 0 i 0 0 0 1 0 0 0 '1 0 0 0 1 0 0 0 i 0 0 0 1 0 0 0 i 0 0 0 i 0 0 0 1 0 0 O i- 0 0 0 i 0 0 0 i 0 0 0 1 0 4 0 1 68 4 0 I 68 4 0 I 68 4 0 1 68 4 0 '1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 t 68 4 0 I 68 4 0 i 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 i ~8 4 0 1 68 4 0 I 68 4 0 1 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000:000 000000 000000 000000 000000 000000 000000 000000 000000 000000 .000000 000000 000'000 000000 000.000 000000 0000.00 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT R T F10 SGFN PHIT CCL SGFF SGFhl CS DATA SGBH SiGQ AVQP RECORDS NSBF Q4ER SDDP FSBF RSBF AVGS NTMD ASTN SDDS FTMD 8QiN · i 3 i 9 3. O, iSlO0. 4. i5. i 3000 5. 22 12900 5. 24 i2800 3 i'2700, 4· ,37, 000 000 000 772 000 :397 777 OOO I52 808 000 993 914 000 946 22. 777 ,001 -i .000 20.010 .236 79. 150 22.442 ,272 -.44.3 23, 078 .223 ! 4,479 18.809 .lO0 -4.981 25,690 .227 -4,500 19.376 17.714 16,00i 16,854 16,42i 16,001 19.684 19,186 15.775 20.845 19.862 16,314 14,380 13,449 15,928 22,180 22,503 16,383 81.682 · ~ .OOl 93.422 .993 .248 67,845 ,99:3 ,284 60,609 .974 ,250 66.'098 .979 ,102 75,333 ,989 ,234 1 04,953 ,014 0,000 86,181 -,003 ,006 87.481 -,00i .018 91,790 ,006 .051 95,421 .Oi3 · 009 99.705 ,009 .016 11.510 i5.918 7.884 i.Oii 15.977 9, 169 .356 17,514 9,783 ,586 18.271 I 1 .660 .653 I 1 .'029 10. 569 ,440 22,249 0,000 i5093.703 ,824 8504.465 19609.684 .213 13352.281 11'870,645 ,247 11467.945 16173,281 ·820 15038,844 20631.090 .373 1'1705.34-0 13617.309 .569 O.O00 i5.992 1789.832 15.755 2473.826 i7,522 2226.841 18.327 3766,553 10.692 2366,437 21,472 FILE TRAILER File name: &~SFOI , 001 i"1..~::<imum length: 1 024 TRAILER RECORDS Service name: Version File type: LO Next. ¢ila: Date: Page File name: .002 Service name: Version #: Date: Haximum length: 1024 File type: LO Previous ¢ile: M N E it F: N i;.iil Fi.I C 0 U STAT F_: i- R Y LATi LONG SECT T 0 W N R A N G EKB ED F EGL PD L.M F D H F R Li i.i DATE i_CC SON L. Ut4 FL LUL ENGi tit i T t4 DD DL C:Bb i CBL i 'fi_ i BLi TCS TLA8 8HT H R T i'IT I'ISS D F D HV tS DFPH DFL RI'IF HFST HFSS RHC INFORMATION RECORDS COHTENTS LI H I T BP EXPLORATION Z-~i PRUDHOE BAY NORTH SLOPE ALASKA USA 2187i , OOO .......... 0 Deg. 0 Min. O 0 Drag. 0 Min, 0 liN ................ 12E ........ , O. 000 .............. 91 ,500 ............. 53. 900 ............. I m m I a ~ a i a ~ m i m 1100. 000 ...... 3'0 ............ 3F8~69 ..... NORTH SLOPE NORTH ~LOPE YARBRO LUECKER 1 ~21 O, 000 ...... ~,000 .......... ~,000 .......... 12650.000 ...... 0.00~ ...... .... IlO0,OOO ....... ~,00~ .......... ~.0~0 .......... PRODUCED APl 6'666 ................. · 0.000 ................. 0,000 ................. O. O00 ................. 0.000 ................. O, 000 ................. O, 0'00 ................. m . a mm m , . , · m · .i I t 4, w ~1 DATE a I , ma , ,m i i m , 0 IlIll'l'llIlIlll NLIM: 50-029-2187i ................ immmiimami · · LOGGED: m ~ ~ m · · · ! m · ! i i I I . i 07-15-90 ..... i Iii · iii · ·Iii a Ill, i · i a ,I I II I. Ii imm ii IIII IlII Iltl iitlai 1 i IIl·ll I IlIIll I I ItlltlI Ill Illllll IIIIl·l llmlIII II·II IllIlIlIIllim III! III III I a I I I · m m m m I · I m m a a i I m a aa i· · · m mm mI m , i .i I mmI ii m i I . i mm Ii · amlml i · · II ! i I II mmII I mmmI iii I iii milll iii IlIll iii Illll III llliI Ill iIIti III lallI iii IlIiI lli iimmI lit IiIil iii IIIII ill · Iii iii iii· ill IllI III illl III IIII III iIiaiiii I I m t it . m I · · I m I I ,m · m m i I, i TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 o 3 2 65 0 0 2 79 · 0 0 4 68 0 0 8 65 0 0 2 79 :o 0 10 65 0 0 10 65 · 0 0 20 65 0 0 20 65 0 :0 20 65 0 0 20 65 FT 0 3 4 68 FT O 3 4 68 FT 0 3 4 68 FT O 3 4 68 FT O 3 4 68 FT -O 3 4 68 HR O 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF O 1. 4 68 .0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP .o 2 4 68 O 2 4 68 0 2 4 68 OHMH 0 2 4 68 OHHM 0 2 4 68 DEGF O 2 4 68 0 2 12 65 OHHM 0 2 4 68 Page ERROR M t.l E M i,i C: S T i.i C S S C:S I HFORMAT I ON RECORDS CONTENTS UNIT DEGF TYPE CATG SIZE 4 4 4 CODE 68 ~8 68 Pag~ ERROR 10 COMMENT REC. ORD$ !,l~_l 1 &icl 1 h.I c 11 i.,!,~ 11 t.,I e I 1 &i ~ 11 i.,.i ~: 11 i.:l ~ 1 1 Location Comment 1: Location Comment 2: Location Comment 3: Location Comment 4: File Comment 1: TIED File Comment 2: File Comment 3: File Comment 4: SURFACE: ?15' FNL & 3559' FEL INTO SCHLUMBERGER CEMENT BOND LOG DATED li-15-88. *************************************************************************************** *************************************************************************************** LIS tape writ.ten b~ ANCHORAGE COMPUTING CENTER ** Ail curve and tool mnemonics used are those which most closely match ** Halliburton curve and tool mnemonics, ** ************************************************************************************** HALLIBURTON TO SCHLUHBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT SGFNi TND CU SGFN THD SGFFI TND CU SGFF TMD SGBHI THD CU SGBH THD NSBFI THD CNTS HSBF TMD FSBF1 TMD CNTS FSBF TMD HTMD! TMD NTMD TMD FTMDI TMD FTMD TMD RTMDI TMD RTMD THD PHIT1 TMD PHIT THD FT CU CU CU CNTS CNTS i2640,00 12649,25 12649.25 i2649 25 12649 25 12649 25 12649 25 12649 25 12649 25 12649.25 i 3200. O0 13193,00 131 93, O0 1-3193,00 131 93. O0 13193, O0 131.93, O0 131.9~, O0 13193, O0 13193,0'19 Page 11 ~4ERI RSBF1 ABTHI CCL1 CS1 THD THD TMD THD THD TMD THD TMD THD CU F/MI SGFM SIGQ G4ER RSBF ABTN SGIN GR CCL CS THD THD TMD TMD TMD THD TMD TMD TMD CU F/MI 12649 25 i2649 25 i2649 25 12649 25 12649 25 12649 25 12649,25 12649,25 13193.80 13193,00 13t93.08 1 31 93, O0 i 31 93,00 1 3t93, Oe 13193,80 13t-93,00 13193.80 DATA E N TRY FORMA TYPE T SPEC I F I CA SIZE CODE 16 I 66 0 1 ~6 TIONS Pag~ 12 ENTRY BLOCK LEGEND T'fPE DESCRIPTION Datum ~eci~ication block sub-type Terminasor ( r,o more entries FORMAT SPECIFICATIONS Pag~ 13 SERVICE SERVICE AP1 AP1 AP1 APl i'iNEti ID OP, DER # UNIT LOG TYPE CLASS HOD FILE # PRC SIZE LVL SMPL RC PROCESS INDICATORS PEPT 378169 FT 0 0 0 O SGFN THO 378169 CU 94 0 O 3 SGFF THD 378169 CU 94 0 0 3 SGBH THD 378i69 CU 94 0 0 3 f-iSBF THD 378169 CNTS 94 O 0 3 FSSF THO 378i69 CNTS 94 O 0 3 NTHD THD 378169 94 0 0 3 F'TND T~D 378i69 94 0 0 3 RTHD THD 3781~9 94 0 O 3 PHiT THD 378169 94 O O 3 SGFH THO 378.169 CU 94 O O 3 SiGQ THD 378169 94 O 0 3 G4ER TMD 378169' 94 0 O 3 RSBF THD 378169 94 O 0 3 ~BTN THD 378169 94 0 0 3 SGiN THD 378169 94 O 0 3 GR THD 378i69 94 0 0 3 CCL THD 378169 94 O O 3 CS THD 378169 F/HI 94 O O 3 4 0 1 68 4 0 i 68 4 O i 68 4 0 i 68 4 O i 68 4 O i 68 4 0 1 68 4 0 1 68 4 0 i 68 4 O I 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 t 68 4 O i 68 4 0 i 68 4 0 'l 68 4 O t 68 000000 O00000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 O00OO0 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT RTHD GR SGFN PHiT CCL SGFF SGFH -- -- DRTR SGBH SiGQ RECORDS HSBF G4ER FSSF NTHD ABTN F T H D SGiN .Page i4 i 3 i 9 3, O. iSlO0, 4. 13000, 5. 27, 12900, 5. 28, 12800. 52, 12700, 5, 47, 000 000 000 000 835 810 000 620 531 O00 242 082 OOO 976 000 251 22,711 ,OOi -1 ,000 20.369 ,248 8,706 22,414 ,318 1. 594 24,373 ,257 -3,006 19,220 .103 -3.4,91 26. 044 ,235 -4,456 i8.871 i 7, 083 t5,31& 16.814 16,832 16,532 18.787 19. 157 16. 085 20,309 21 ,237 16.611 14.518 t3.67S 16.611 21 . 484 22,912 16,641 84.767 , '-J'~ ~ 94.878 .993 73.610 ,991 71 ,287 · 986 68.486 .990 74.791 ,992 1 06,388 ,012 I 04,552 ,007 1 04,666 ,004 1 07,254 ,003 1 09,454 .013 111 ,970 .01 0 11,701 .585 10.916 .996 10,643 ,357 11.450 ,395 11,899 ,548 12,993 .415 0.000 15389.180 8649. 055 20031 .660 13805,547 12158.660 I 1784.281 12095,891 14721,051 IS267.312 I 1528,2.5 0 12842,379 0.000 15,694 1788.887 i6,179 2456,584 17,488 2248,t82 i9,965 3702.286 10,965 2297,926 21,958 FiLE TRAILER **** name: ~GSFO1 ,002 Haximum length: 1024 TRAILER RECORDS $~rvic~ name: Version #: File type: LO Next ~il~: Date: Pag~ 15 Film name: .003 Maximum length: 1'024 Service name: File type: LO Version #: Previous {'ile: Date: H N E t'l C N i.,.i i',l FN C:OtlN STA'f C: T R ¥ RP iN L. hT I LOHG SECT T C.I t,J N RAN6 E t':: B EDF EGi. PD LHF' D H F RUN II HE PATE LCC SOl'.1 [..Ut-I FL LIJL Et. IC~ i id I 'f i',l DD D L C: B [:, i CBL t TLi TCS 'FLAB 8H T HR'f H T f,lSS DFD t'i U i S DFPH OFt. P. H R I"i F H F S T HFSS R I',t C I NFORMAT I ON RECORDS CONTENTS BP EXPLORATION Z-3i PRUDHOE BAV [)ATE LOGGED: 07-i5-90 ........ NORTH SLOPE ............................ ALASKA ............................ USA ............................ 2i U,' 1 ,O00 ....................................... O Deg, 0 H in, O. 0 Sec. N ......... 0 Deg. 0 Min. O, 0 Sec. W ......... llN ....... i2E ...... 0.000 .... 91 . 5:00... 53..900... HS ....... DF ....... I 1.00. 000. . . , . . . 15,,' 7,"9 0 ....... 378169 ....... 513,01 . ..... Ho 'rH SLOPe- NORTH SLOPE YARBRO LUECKER 13210,000, 1~177, OOO. 0. ~00 ..... O, 000 ..... 12650,000. 1~167, O00. O, .000 ..... 1100.000... O. O0 O ...... O.OOO ...... PRODUCED ImlmmmlI1 lllmIlllI ·m11·mmm~m 6'666' ' ' :. .,. O, 000 .... 0.000 .... 0.000 .... 0 . 0 0 0 .... O. 000 .... O. 000 .... APl NUN: 50-029-2i871 ................ ii1111 am·l· ·11al 11iillmll·1111 ! i i111Ill·*llllWlml · Fill Ilml· l.lll ·11l e 11 : I i i · ! I i i l . · llllllm Ilml·lI Iii1111 i I m m * i I · i i i · i · · · I i · i I i · · , · m · m m i · i i i · · · m . ,, · . · i m , ,· · · . i i* , m · I I· II i ~ ii I i · · IF· I imml I i I · m i · m i . I · m · m · TYPE CATC, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 FT 0 3 FT 0 3 0 3 0 3 0 3 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 0 0 0 0 0 FT .0 FT 0 FT 0 3 FT 0 FT 0 3 FT 0 HR 0 2 HR '0 4 DEGF 0 I DEGF 0 1 0 2 0 2 LB/G 0 2 CP 0 2 0 2 0 2 OHMM 0 2 OHMH 0 2 DEGF 0 2 0 2 OHMH 0 2 SIZE I~i~ 40 40 40 20 20 20 4 34 34 2 4 4 4 2 2 2 2 4 8 2 10 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 4 4 4 4 4 4 4 12 4 CODE 65 65 65 65 68 65 65 65 65 68 68 65 65 65 79 65 79 65 65 65 65 65 65 68 68 68 68 68 68 68 68 68 65 65 68 68 68 68 68 68 65 68 Page ERROR t6 H I'.1E M ~'i L'.: S T ~'i C: SS L.: '.5 EtS I NFORMAT I ON RECORDS CONTENTS UNIT 0 -000 I I · I · I I I I I I · · I I I · I I · I I I · I I I I I I I I I I I I I II · I I I I · I I I I & I I I ~ I ~ ~ ~ ................................................... I I i I I I I I I I I I I I I I I I 8,500 ................................................... DEGF TYPE CATG SIZE 4 4 CODE Page ERROR i7 COMMENT RECORDS Well Location Comment I: W~ll Location Comment 2: !~cil Location Comment 3: ~ell Location Comment 4: i.~ell File Comment i: TIED Well File Comment 2: W~ll File Comment 3: SURFACE: ?15' FNL & 3559' FEL INTO SCHLUMBERGER CEMENT BOND LOG DATED 11-15-88, t.~ell File Comment 4: LIS tap~ w~itt~n b~:. ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most clo~el~ match H~llibupton cup~e and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT ~NEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 12640.00 132.00.00 SGFN2 TND CU SGFN THD CU 12649,25 13193.00 SGFF2 THD CU SGFF TMD GU 12649.25 13193.00 SGBH2 TMD CU SGBH TMD CU 12649.25 13'193.00 NSBF2 THD CNTS NSBF TMD CNTS 12649,25 13193.00 FSBF2 TND CNTS FSBF TMD CNTS 12649,25 13193,00 NTMD2 THD NTMD TND 12649.25 13'193.00 FTMD2 TRD FT~D TMD 126~9,25 13193,00 RTMD2 THD RTMD TMD 12649,25 13193,00 PHIT2 TMD PHIT TMD 12649.25 13193.00 Page 18 SGFH2 SIGQ2 ~4ER2 RSBF2 ABTH2 SG I f,12 GR2 CCL2 CS2 TMD THD TMD THD THD TMD THD THD THD CU F/MI SGFM SIGQ G4ER RSBF ASTH SGIN GE CCL CS THD THD THD THD TMD THD THD THD TPID CU F/MI 12649,25 12649.25 12649.25 12649.25 12649,25 12649,25 12649,25 12649,25 12649,25 13193.98 13193.00 13193, O0 13193,88 131 93. O0 13193.00 13193,00 13193,00 13193,.00 DATA FORMAT :~:~ ENTRY BLOCKS EHTRY ::~:~ ENTRY BLOCK LEGEND TYPE DESCRIPTION Datum spec. i?ication block sub-ts~pe Terminator ( no more mntries ) SPECIFICATIONS TYPE SIZE CODE 16 1 66 0 i 66 Page 19 DATA FORMA T SPEC I F I CA TIONS Pagm 2O DATUM SPECIFICATION 8LOCKS MNEM SERVICE SERVICE AP1 AP1 AP1 APl FILE ID ORDER # UNIT LOG TYPE CLASS MOD # PRC SIZE LVL SNPL RC PROCESS INDICATORS DEPT SGFN TMD SGFF TMD SGBH TM[) NSSF THD FSBF TMD NTMD TMD F'FMD TMD RTHD TMD PHiT TMD SGFM TMD SIGQ TMD G4ER TMD RSBF TMD A8TN TMD SGiN TMD GR TMD CCL 'fMD CS TMD 378169 FT '0 0 0 0 3 378169 CU 94 0 0 4 2 378169 CU 94 0 0 4 2 37816g CU 94 0 0 4 2 378169 CNTS 94 O O 4 2 378169 CNTS 94 O O 4 2 378i69 94 8 O 4 2 378169' 94 0 O 4 2 378169 94 O 0 4 2 378169 94 0 0 4 2 378169 CU 94 0 0 4 2 378169 94 O 0 4 2 378169. 94 8 O 4 2 378169 94 8 O 4 2 378169 94 8 0 4 2 378169 94 0 0 4 2 378i69 94 0 0 4 2 378169 94 8 O 4 2 378i69 F/MI 94 0 O 4 2 4 0 1 68 4 O i 68 4 0 1 68 4 0 i 68 4 O 1 G8 4 0 i 68 4 O 1 68 4 O 1 68 4 0 1 68 4 0 1 68 4 O t Ge 4 0 1 68 4 0 i 68 4 0 Ge 4 0 i 68 4 0 4 0 4 0 4 0 000000 OOOO00 000000 O00OO0 O0000O 000000 000000 000000 O00000 000000 O00000 000000 OOOOOO 800000 OOO000 . 000000 O0000O 000000 000000 O0000O OOOO00 000000 000000 000000 OOOO00 O00000 000000 000000 OOOOO0 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 O00000 O0000O 000000 000000 O00OO0 000000 000000 68' 000000 000000 000000 68 OOO000 O0000O 000000 68 000000 000000 000000 68 000000 OOOOOO 000000 DEPT RTHD SGFN PNiT CCL SGFF CS DATA SGBH RECORDS NSBF G4ER FSBF RSBF NTND ABTH FTMD SGiN Page 2I 3193. 000 0,000 -i , 000 iSiO0,O00 4,856 31.453 13000,.000 5,4ii 31,369 2900. '000 5, 16G 35,528 2800. 000 4,i20 52,873 12700. 000 4.906 52.514 23. 3. 22. le. . 26, ~4 . 104 OOi 000 816 250 456 715 287 620 383 228 487 989 121 5'06 806 525 20. i8.5i3 15.?Oi 17,405 i6.4i0 16,085 19,369 19,476 16.383 19.815 19,124 16,774 15,0'03 i4,259 16,45i 21.875 23.379 16. 156 86.290 .996 93.925 .993 73.627 .988 62.059 ,988 70.298 ,987 80,4'19 .994 116,661 -,008 1 06,517 ,OOi 111.532 . .018 111 .030 ,007 113.648 ,018 115,775 ,0.09 13.467 .535 12,517 11 .363 .351 12,432 .472 14. 134 .569 I I . 569 ,363 0.000 14040,125 8484,957 19701 .504 13040.770 ! 1491. 223 11511 ,781 14363.164 15225..02,0 18872.477 1'1199.:375 11373,848 0.000 17,470 1747.378 i5.743 2410.171 17,868 2228.391 i7,449 3695.024 11,657 2282,755 22,532 Film name: ~GSF01 .003 Maximum length: 1024 TRAILER RECORDS Service name: Version #: File type: LO Next ~ile: Date: Page 22 :** FILE HEADER : :~: :~ :~ :~ ~ :~ :~ ~ :~ :~ ~ · :~ :~ ~ File name: Maximum length: 1024 Service namm: File tppe: LO Version #: Previous ~ile: Date: MI't EM CN FN C 0 i.i N S T R T CTRY AP iN I..ATi LONG SECT TOWN RANG EKB EDF EGL PD L. MF DHF ~UN T i ME PATE LCC SON LUt.i FL LUL ENG~ Y~ TN PD CBDI CBL1 TLI BLI TCS TLAB BHT MR T HT MSS PFD MVIS DFPH PFL RMF HFST HFSS R M C I NFORMAT I ON RECORDS CONTENTS UNIT TYPE CATG SIZE BP EXPLORATION Z-~l PRUDHOE BAY NORTH SLOPE ALRSKA USA Ri87i.OOO ........................ 0 Deg. 0 N . 0 Deg, 0 W . i2E ....... 0.000 ..... 91.50~ .... , 53.900 .... . ~S 11'00.000 ......... ~5/ ~/9.0 ......... 30 ............... NORTH SLOP~ HORTH SLOPE YAR~RO LUECKER ., 1~210 i illli/IliililIImII II 13177, 0 ~'00 I itlllllllllllllJtlllll 0 i iliiiIiilljilIIiIlII i ii 12650 000 13167o:000 0 000 1100 000 O 00'0 0.000 ....................... PRODUCED ........ 0..000... 0.0'00.,. 0,000, , , 0.-000.,, .0,000.,. 0,.0~00,,, 0 -000 APi HUH: 50-029-21071 .............. D~TE LOGGED~ 07-15-90 .............. imiilIIlIIIIIlIlI iiIiIIIIlIIIlIIIl IiliIIIIlIIIlIIII Min, O, 0 Sec, Min, O, 0 Sec, IIlIlI I IIlIlI I iIlIII I imaele m IilIIi illlIIllIlIIII'l illlIllIlIlIIlIl itiilielIlIllIll , iiI|$IeIII'IlIll IWm/I|llIIIeIlII iiOIIlIIIeIleIII tIiIIlIIlIIlllII IlIlllIlIIIIlIII iliillIlItIllItI IllI III IIIlIIIlllI IIIlllllllII I I i i iefiii ii ii, iiiI .III.I lltlII IIIl$I I;llfI IIllII IlIml·IfilI! IIlI|II||I ImII|IIIII I iiiiiIIIi iIiIliili IlilIiIli illlIIIlI iiiliilII iiIIiitlI iillIIIII IiIIlilIII IelIlIIIII 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '0 FT 0 FT 0 FT .0 0 3 0 3 0 3 0 0 0 0 0 :0 0 0 0 0 0 0 0 0 0 0 O 0 0 FT 0 FT 0 FT 0 3 FT 0 FT 0 3 FT 0 HR 0 2 HR 0 4 DEGF 0 1 DEGF 0 1. LB/G 0 2 CP .0 2 0 2 OHHH 0 2 OHMM 0 2 DEGF O 2 0 2 OHMH 0 2 40 40 40 20 20 20 4 34 34 2 3 4 4 4 2: 2 2 2 4 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 65 65 65 65 65 65 65 65 65 68 68 65 65 65 79 68 65 79 65 65 65 65 65 65 6@ 68 6@ 68 68 68 68 68 65 65 68 68 68 68 68 68 68 65 Page ERROR 23 M H E F1 H C: S T HCSS CS BS I HFORMAT I ON RECORDS CONTENTS UNIT IIII DEGF TYPE CATG SIZE 4 i2 4 4 CODE 65 ~8 ~8 Page ERROR 24 COMMENT RECORDS Location Comment I: Location Comment 2~ Location Comment 3: Location Comment 4: File Comment 1: TIED File Comment 2: File Comment 3: SURFACE: 715' FNL ~ 3559' FEL INTO SCHLUMBERGER CEMENT BOND LOG DATED 11-15-88. File Comment 4: ********************************************************************************** ***************************************************************************** S tape w~ittcn by: ANCHORAGE COMPUTING CENTER ** 1 curve and tool mnemonics used a~e those which most closely match ** Halliburton curYe and tool mnemonics. ** HALLIBURTON TO SCHLUMBERGER TOP BOTTOM HNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 12640.00 132:0'0,00 SGFN3 TMD CU SGFH TMD CU 12649,25 13193.00 SGFF3 TMD CU SGFF TMD CU 12649.25 13193.00 SGBH3 TMD CU SGBH TMD CU 12649.25 13193.00 NSBF3 TMD CNTS NSBF TMD CNTS 12649.25 13193.60 FSBF3 TMD CNTS FSBF TMD CNTS 12649.25 13193,80 NTMD3 TMD NTMD THD 12649,25 13193,00 FTMD3 TMD FTMD TMD 12649.25 '13'193,00 RTMD3 TMD RTMD TMD 12649.25 13193.00 PHIT3 TMD PHIT TMD 12649.25 13193,'60 Page 25 SGFH3 SIGQ3 G4ER3 RSBF3 ABTtI3 SGIH3 GR3 CCL3 CS3 TMD · TMD -TMD TM~ TMD TMD TMD TMD CU F/MI SGFH SIGQ G4ER RSBF ASTN SGIN GR CCL CS TMD THD THD THD THi) THD TMD THD TMD CU F/MI 12649,25 12649,25 12649,25 12649,25 12649,25 12649,25 12649,25 12649,25 12649.25 131 93, .0.0 13193, O0 131 93,00 13193,00 131 93,00 13193, O0 13193, O0 13193,80 13193,8O DATA ENTRY 8LOCKS mm~m E N T R Y FORMAT SPECIFICATIONS TYPE SIZE CODE 16 I 66 Pmgm ~G ENTRY BLOCK LEGEND mmmm TYPE DESCRIPTION Datum speci{'ication block sub-type Tmrminator ( no morm mntrims ) DATA FORMAT SPEC I F I CAT IONS Page 27 DATUM SPECIFICATION BLOCKS MNEH SERVICE SERVICE API API AP1 APl FILE ID ORDER # UNIT LOG TYPE CLASS MOD # PRC SIZE LVL SHPL RC PROCESS INDICATORS QEPT S~FN TMD SGFF THD SGBH TMD NSBF TMD FSBF TMD NTMD TMD FTHO THO RTHD THD PHIT THD SGFH THD SIGQ THO G4ER TMD RSBF THD ABTN THD SGIN THD GR TMD CCL THO CS TMD 378169 FT 0 0 0 '0 4 4 0 378169 CU 94 0 0 5 3 4 0 378169 CU 94 0 0 5 3 4 0 378169 CU 94 0 0 5 3 4 0 378169 CNTS 94 0 0 5 3 4 0 ~78169 CNTS 94 0 0 5 ~ 4 0 378i6~ 94 0 0 5 3 4 ~78169 94 0 0 5 3 4 0 378169 94 0 0 5 3 4 0 378169 94 .O 0 5 3 4 0 378169 CU 94 0 O 5 3 4 0 378~69 94 0 8 5 3 4 0 378169' 94 O 'O 5 3 4 0 378169 94 0 O 5 3 4 0 378169 94 0 0 5 3 4 0 378~69 94 O 0 5 3 4 0 378169 94 O 0 5 3 4 O 378'~69 94 .O 0 5 3 4 0 378169 F/MI 94 O O 5 3 4 O 1 68 ! 68 i 68 ! 68 1 68 1 68 ! 68 ~ 68 1 68 1 68 ! 68 ~ 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O000OO 000000 000000 000000 000000 000000 000000 O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O000OO 68' 000000 OOOO00 000000 68 000000 000000 000000 68 O000OO OOO000 000000 68 000000 000000 000000 DEPT RTl'iD ......... J~jg:3. 00'0 0,000 -1 ,000 31 00,000 4,040 34. 063 3000. O00 5.467 35, J 38 2900,000 5,898 39,378 2800..000 3.960 53,609 2700,000 5.151 47.644 SGFN PHIT CCL 22,589 .001 -1 . 000 20,390 ,248 -, 193 22.269 ,277 30,327 22. 899 .359 -'4,975 19.612 ,iOi -3.994 26. 822 ,270 -1 .747 SGFF SGFH 19,008 i7.225 15.775 16.811 16.885 16,544 19. 022 19,003 15,855 19,920 J9.672 16,085 14,685 13,750 16,611 22.24'0 23.731 15,855 DRTR SGBH 80.690 .992 94.196 .996 65.446 ,98~ 72.176 ,989 68.532 ,990 82.711 .995 RECORDS NSBF G4ER FSBF RSBF NTMD ~BTN FTMD 1 i 6. 766 ,017 115.905 -,001 11l .010 .016 11 8,08;3 .:015 I i 7,638 · '014 115.512 -°005 13.276 .596 12.073 .950 12,232 .439 12.309 ,373 14,193 ,536 13. :164 .334 0,000 149i4.87t 8875.711 19077,656 13881 ,703 14381 .660 1 2626. 039 12516,555 15037,621 17977.883 I 1605,832 I 1051 . 44'1 O.OOO 15.284 1833.873 16,233 2539,281 17.305 2140.555 18.101 3797,345 11,050 2253,034 23,032 Page 28 ** FILE TRAILER File name: &GSF01,004 Maximum length~ 1024 TRAILER RECORDS ~eP~ice name: File t~pe: LO Next Version ¢ile: Datm: Page 2.9 ~:** REEL TRAILER Service name,: &G5F01 Date: 90/08/15 Origin: Nmxt reel: Commentz: Reel name: Continuation #: 01 ,~:** TAPE TRAILER **** Service name: &G5F'O'~ Next tape: Date: 90/08/'i5 Origin: Comments: Tape name: 3781 69 Continuation CO~P~N¥ N~.ME : ST~&N~ARD AL~.SKA WSLL N~ : Z - ]1 ~Z~L~ NAqE : PRUDH05 STATE : AL~SK6 BOROUGH : NORTH SLOPE ~P~ NU'HB',E~ : 50-029-21871-00 ~E=~ENC= NO : PRODUCTION CS. IS T,~p~-. ~ V~IFiC~TrDN:.. ~ ~ L~S~TNS· ~ , .. CHL~J~E:PGE~ ~L~SK6 30~PUTIN~ C~NTER 2Z-NOV-198B 14: S3 P .~ S E · S:PVICE N~.E : ~['"'?.. BATE : ~:PI1 iIEZ ~qISIN ::LIC REEL NAME : V~9!! CONTINUATIC~ ~ ' P~EVIOUS qEEL : CSY~ENT : LIS T~PE, S.' PC. .50-029-21871 SERVICE NA~= : :git gAT-- : 8~/11/~2~ ORIGIN : =LIC T~P~ NA~ : 7301! CONTINUATION ~ ' ! PR~Vi,~US T~'P~ " COMMENT ' LIS TAP~ ~50-029-21871 ~- o,- .,- FIL= HEADER " .... "' FILE NAME : EDIT .OOl SERVICE : =LIC VERSION : OO1AO2 DAY'.,:. : 88/11/22 M&X REC SIZE : 1096 FILE T¥OE LAS'T FILE C3MP~NY NAME: ST~NO~RO .~LASK~ WELL: Z - 31 FIELD: ~R!JDHO E BAY ~OROUGH~ NORTH SLOPE STATE: ALASKA API NUM~E~: 50-0 29-218 71-0 0 PRODUCTION C'O. LOCATION: 71.4' FNL 3644' FEL SECTION:' 19 TOWNSHIP' lIN PERMANENT O'ATU~' MSL ELEVf~TI~N: RANG 6: 1 Z E CHLUM-~,EegER.., , ~LaSK. a, rO:',~DUTZNG~ , , 22-NOV-1988 14:53 LOG M6A SUPE,2 ELEVATIONS K~: 91. ~ CATE LO GG E,-rl: !!-NSV-8~ RUN NUMBER: TD ORILLER: 13251. TD LCGG'=~: t325~. GL: CASING: 9 5/~ £ CRiLL~R D']-P'TH gm 12541 ~Ng LOGGER D:PTH g~- 12.541 BIT SIZE: ~, I/2 TYPE FLUI$ MUD R FILTR MUD C IN HOLE: DiS°SRSEC· DEHSZTY: 9.4 L~IS VISCOSITY: 36. S PHi 9.9 FLUID L9SS: 5.6 C3 ESISTIVITY: !.g9 @ 60. ATE R=SISTIVITY: 0.B27 ~ 60. AK"_- '~ESISTIVIT¥: 3.01 3 60. TIME CIRCULATION ENOFD: 04:BO !!-NOV TIME LgGG:R C',I ~DTTO~: 11:50 Il-NOV MAXIMUM T~MP RECORDED' 206. L OG$1 LOGGI WITNE TOgL FIELD HG DISTRICT: PRtJONOE B.AY NG ENGINS~m: G. SARBER SS: COLTRIN/LEWIS SLS-WA-20O4 D IC-D ~-41 ? IEM-SO-l&38 SLM-DA-!619 TCC-A-123 CNC-H~-~9~ ORS-B-4908 TC~-A B-21 ~ R EM 6RKS: :'IG,qT ?" STaNOO=FS ~NO A ~' HOLm FINDER USED ON THE DtL-BHC N~UTRON ~ATRZX = SAND~ N~ATRIX DENSITY = 2.65 G/CC. HOLr:E CO~ECTION : C~LIPER, FILTRATE DENSITY = 1 0 G/CC. OTH '~,O~4SPR~NG ~ND ROLOVER DEVICES ~JSED ON TOOL~ . DATE JO,S STAR'TEg: 2Z-NOV-88 JOB REFERENCE NO: 7'3011 LDP/ANA: J. KOHRING THIS DATA HA'~ NOT BEEN DEPTH SHIFT,=g - OVERLAYS FTELD PRIN'TS .~ .~o..,. IS T4,~E V~RI~IC,~T!O',I LISTING 2Z-NOV-19B8 14: 53 .,. SCN" U,~.,~=p,r-=9... ~. ,..,_ LOG~., TNCt. U~c~_ .. WIT~ THIS FTLS. (=D'rT~ .,,. .001). '"'-,. ~ U '" L.., ! N D U C T "r O N, ,. S.o H = o I C ~L L Y,, = 0 C 0 S ~ O, L3G ( . DIL) -,-'"' ~ FIRST TO L.~ST ~E~DING: 13244' T3 !2641' '" ~.n-~:qOtE C3~,~ENS.t~TcD LO"':- ( BHC) '"' ~: FIRST TO LAST R,'_--~OIHG: 13207' TO 12.641' ~.' L!r~O-gSNS!T¥ CO'~P=N$~TED LO~ (oLgT) ~ ~IPST TO LAST ~aDING: 1324~' TO 12641' g CO~4P~NSAT':D NSUTRO,",I LOg (.CNL) ~ ~IRST Tg LAST R~',DING: 13217' TO !2641' -'..¢ N'::UTPON,_ , ~N"",, S.~'~,. '~AY IN C~SING (·CHL) x~- :~ FIRST Tq L,~ST RF~DTNG: 12641' TO 9z, 72' ~'- TABLE TYP= : CONS TUNI V~LU DEFI C ~,; F N WN NATI ST~T COUN SECT TOWN RANG FL ENGI SON ~PIN STAND&RD ~L~SKA PROOUCTION CO COMPANY P~UDHOE BAY Z - 31 U.S.A. ALASK~ NORTH SLOPE lin 714' FNL 3644' FEL G. SARBER 5~8729 50-029-21871-00 FIELD WELL NAME NATION STAT5 OR P~OVINCE COUNTY SECTION TOWNSHIP RANGE FIELg LOCATION ENGINEER'S SERVZC5 OROER NU~5~ APl SE~!&L T~BLE TYPE ' CURV DEFI DEP'T TENS SFLU 'IL~ ILO SP GR TEN:S DT GR TENS DE P'TH CH:&NNEL TENS IL-N ~D~, RESZSTZVITY ZL-~EEP RESISTIVITY SPONTANEOUS POTENT Z~.L TENSION OELT~-T T E N S Z IS TAoE V:RZ~IC~TIO~ LISTZNc CHLUF'B.=RC~:ER ~LASK'& C~?~'PUTZN.S CENT--_R 2~_-NDV-I~.]8 1~4:53 NPHI NEUTRON ,~O~ OSZTY TNR~ CALISR.'&T'-D ?H.:.RN&L N:UTP3N RTNR R~W TH:P~!~L ',1EIJT~N RCFT RC=T RCNT CFTC CF'TC CNTC CNTC ~ZI~ &ZZ~UT~ q~ H~L: ~RZFT DEVI 'DEVIATION RB ~.ELflTIV~ H~ZI ~0L? ~RES MU] ~ES~ST~VITY M'TE~ '4UD TE~,~p~p~TU~E ~TE>,~ HE~D T~NSZQN T EFtS TE'~S Z ~N Oe~I gE?~S ZTY og~ O SI'TY g~Hg 2ELT ~ Rdg RHO~ 3ULK DENSITY PCF. ~HOTn-~LCCTRIC,~ :.. F~C'TOR CLS QUALITY CONTROL OF L]N~ ~SS QtJ~LITY CgNTPOL gN SHORT S~4CZNG LS LONG SPACIN~ C]MPUTEO COUNT PATE LU L~NG UPP~P 1-2 WINDOW COUNT R~TE LL LONG LOWER WINOOW COUNT RATE LZTH LITHOLOG WINDOW COUNT SS1 SHORT SP~CINS ! WINDOW COUNT SS2 'SHORT Sg~CIN~ 2 t4INgCW COUNT R~TS LSHV LONG SPACING HiG:q VCLTAG': OUTPUT SSHV SHO~T SP4CING ~I,SH V'OLT.~,SE LggP C~LI CAL~PE~ AZI~ ~ZZ~UTH :gF HOLE OEVI OEVIATIO'N H4ZI HOLS AZ Z ~4U'TH PI~Z P~O l M~ES ~q:Ug ~ESIST IVIT'Y MTE~4 ~HUD TE?qPERATUR = HTEN HE:~C TEF~SZON GR GA~ ~ T EN:S 'TENSZON NPH! NEUTRON TNRfl CALiI~R~T'~D THERM~:L ~'EU'TRON RATIO RTNR R~N TH~R~4AL ~ :~l~, UT RD N RST~O R C F 'T R C F T RCNT RCNT CFTC CFTC CNTC CN'TC AZIM ~ZI~UTH OF HeL~ DRIFT DEVI DEVIATION RB RELA'TIVE ~R'I~'JG HAZE HOLE AZI~'~UTH FOra, LDT (LL+LU/2) (LUl+LU2) qUTPgT IS T~°: VERZ~:ZC&T'~nN= I "tTTN'.S~,, CHLUN ¢. E 2G ~!e~ ~L~i SK~ Cg ~PUT*N~,., r ~NT ER~ 22-,~0V-1988 1~: 53 D:FI gAT A VALUE O 276 ! FT 3 0 CT 68 1 NAME 'SERV UNIT ID DEPT F'T TENS OIL L'~ SFLU OIL ~ H ~,. ,~4 ILM DIL CHNH ILO OIL GH~'~M $? OIL MV G~ OIL GAP! TENS ~HC k~ DT BHC US/= G q 3 H C g ~ P l TENS CN[ LB NPHZ CNL PU T NRA CNL RTNR CNL SmRVlr~ /~p,~ ~pr AoI ~PI =ILE n~'gE'P, ~ LOG TYp~ CL~,SS ....... 54~725 O0 goo O0 0 1 548729 OO OOO OO O 1 5 f~ :~ 72 9 00 000 0 54~729 O0 000 O0 0 1 5~8729 O0 OOO O0 0 1 548729 00 ~0,9 0 0 0 1 543729 OO OOO O0 0 ! 548729 00 000 O0 0 1 54:~729 OO OOO O 5497~q , ~. O0 OOO O0 O 1 54 :,~ 729 00 O 00 00 O 1 54~729 O0 000 O0 0 1 54~729 O0 go0 OO 0 1 545729 00 900 00 0 NUMB NUN'5 SIZE REPR PPOCESS S~MP ELEN CODE (HEX) I ! 4 68 ~ 1 4 6 8 I ! 4 6 8 1 1 4 68 1 1 4 68 1 1 4 68 I 1 4 68 1 t ~ 68 1 1 4 68 1 1 4 69 t 1 ~+ 68 i 1 a_ 6 8 1 1 4 58 0000000000 O000OOOOOO OO900OOOOO O000OO00OO 0000009030 OOOO OOOOOO OOOOOOOOO0 0000000090 0000000090 0090000000 O000OO0000 O00000OOOO O00000OO00 O00000OO00 TAPE VERIFIC~TYOH LIST!N5 ,CHLU~E?'3=R ~,LASK~ CC~.'~PUTIH$ CFNTER 22-NOV-19B8 14: 53 N~M= SE~V UqlT SERVICE ~PI ~PI ~PI :~Pl tILE NUM: NUmB gRDEq ~ L~G TYpe· -- CLCSS ~"~q.~ .... NU~-~ S-E~,P SIZE REPR PRO 'E SS C H eX ) RCFT CNL CPS 54~729 OS RCNT CNL C°S 5487]9 00 999 CFTC CNL CPS -T,'.437 29 O0 gOO CqTC CNL CPS 548?29 09 000 AZIM CNL BEG 54,3'729 gO gOO DEVI CNL C£G 5487)-9 Og 900 RS CNL CEG 5~729 OO OOO H~ZI CNL DEG $4~729 O0 OOO PI~Z CNL CEG 543729 O0 900 MRES CNL DHM~ 54~729 O0 MTEM CNL CEG: 54~729 O0 HTEN CNL L? 548729 GR CNL G.~PI 54~729 O0 000 T~NS LDT LB 543729 OO DPHI LDT PU 54'~T29 O0 DRHO LOT ~/C3 543729 O0 gO0 RH~B LOT G/C3 :,548729 gO goo PSF LOT 54~727 0,.9 000 QLS LOT 54:~729 O0 OOO QSS LDT 5~,~T£9 09 LS LOT CPS 548729 OO OOO LU LDT C°S 548729 O0 000 LL LOT CPS 548'729 O0 000 LITH LDT CPS 548729 O0 000 SS1 LOT CDS S48729 O0 gO0 SS2 LgT CPS 548729 O0 gOO LSHV LDT V 548729 O0 000 SSHV LDT V 543729 O0 gOO C :~L.I LDT IN 548'729 Og 000 ~ZI~ LDT gEG 548729 OO 000 DEVI LDT OEG 548'729 O0 OOO RB LD'T BEG 54...8729 gO OOO HAZI LDT SSG 54~729 OO 000 P1AZ LOT CEG 54~729 O0 000 MRES LDT gHMH 5497.2.9 OO 000 MTEM LDT ~SG= 548729 OD gO0 HTEN LDT LS 548729 O0 gO0 GR LDT GAPI 548729 O0 OOO TENS CHL L5 '543729 OO 000 NPHI CHL PU 548729 OO gO0 TNRa CHL 548729 OO OOO R'TNR CHL 548729 O0 gO0 RCFT CHL CPS 548729 00 OOg R, CNT CHL COS 54~729 O0 000 CFTC CHL CPS :54'8729 O0 OOO CNTC CHL CPS 54'tit 29 OO OOO AZIM CML OEG 54~729 O0 000 DEVI CHL OEG 54.~729 O0 000 R ~ CHL :D ES ~48719 03 OOO HAZI CML BEG 548729 03 goo PI~Z CML OSG 5¢8729 OO OOO O0 O ! ! I 4 O0 0 1 1 1 e+ O0 0 ! 1 1 4 63 0 ? 0 ! 1 I 4 68 O0 O 1 ! 1 4 58 OO 0 1 1 ] 4 O0 0 1 1 I 4 68 O0 O I 1 1 4 .aB O0 0 1 I 1 4 68 O0 0 ~ 1 1 ~ 68 O0 0 1 1 1 4 68 OO 0 1 1 1 4 68 OO 0 ! 1 1 4 68 OO g 1 ! I z, 6~ 0 O 0 ! I 1 ,~ 6 8 0 Lq g 1 1 1 :~ 6 '3 O0 0 I I I 4 68 OO 0 I 1 1 4 68 00 0 ! I 1 .4 58 O0 0 I 1 1 4 68 O0 0 ! 1 1 4 68 O0 0 ! 1 1 4 00 0 ! 1 ! 4 68 O0 O 1 1 1 4 65 OO 0 ! 1 1 4 68 00 0 1 1 1 4 68 Og 0 ! :1 1 4 68 0 r,j 0 1 1 ! 4 68 0 9 0 ! 1 I 4 6 8 00 0 1 1 i ,4 6 $ O0 0 ! 1 1 4 68 0 O O ! 1 1 '~ 68 0 0 0 1 1 1 4 6:,~ 00 0 1 t 1 4 68 00 0 ! t 1 '4 6 ,~ 00 0 1 1 1 4 6 '8 00 0 1 1 1 ~, 68 O0 0 1 1 ! 4 68 O0 0 t ! 1 4 68 O O 0 t 1 1 4 6 8 0 g 0 1 1 I 4 68 09 0 1 1 t 4 6 $ 0 ~ :.~ 0 ]., 1 1 68 0 O O 1 I 1 ~ 6 B O O 0 1 1 1 4 69 O O 0 ! ! 1 4 6 ~J 0 g 0 1 1 I 4 6 ~ 00 0 1 1 I 4 68 OO 0 1 1 1 4 6B 0 0 0 1 ! 1 4 68 0 O 0 ! 1 1 4 68 0000009000 CO00000000 O000OOO000 O00000OO0e OOOO00OOO0 0000000000 O000000OO0 0000000090 0000900000 gO0000OO00 OOOOOOO000 0090000090 0000000000 0000000090 0000000000 0000000000 OODO000000 0000000000 0030009009 O0000000OO O0000000OO O0000000gO OOOO000000 0000900000 O00000OO00 O0000COO00 0000000000 O00000OO00 0000000000 0000000000 0000000000 O000OO0000 O0000000OO O00000OO00 0000000000 0000000000 0000000000 O00000OO00 0000000000 O00000OO00 OOOO000000 0000009000 0000000000 0000000000 OOOO000000 0000000000 0000000000 0000000000 0000000000 OOOOOO0000 O000OOO000 22-NUV-19B8 14:53 ,":~&N~- SERV IJNI? SE~:VIC= ---- TYPE CL aSS HOg =ILE NU!'~,B NUMB NU'4.~ SAMP ;-L~ S lZ ~ PROCESS (~=X) 003 00 0 ! 1 ! 4 6~ 000 OO 0 1 1 1 4 6~ 900 Og 0 ! 1 1 4 68 900 09 0 1 1 ! ~ 63 0000009030 OO9000OOOO O0000OO000 D~PTo 13130.500 ILO.OIL -999.250 gT.SH~' -9~q TNR ~, CNL 2.071 C FTC, CNL i578,329 RB,CNL 91,213 MTEM,CNL 203,1.25 DPHI.,LOT 38. 132 ~LS. LOI -0.067 LL.LD'T 375.250 h SHV, LOT 14 57 , 0 g 0 DEVI, LOT 4~, 9 90 MRES,LDT 0,565 TENS. CHL '-99~9,250 RCFT,CHL -999.250 AZIM,CHL '-9 99,2'~0 PlA ' 'CH - ~. L -'999. Z ~ 0 GR. CHL -9 99. Z 50 DEPT. 13200. ILO.OIL 2.3 '37 DT. BHC 75. 313 TNRA.CNL 1.9'~6 CFTC. CML 192.4.922 RS,:CNL 186.636 MTE~4, CNL 202,2 50 DPHI.LgT 9.1 t6 QLS.LDT 0.014 LL.LDT 131. LSHV.LDT '14 ~1. DEVI.LOT ~B. 230 MRES .LOT O. 578 TENS. CHL -999.250 RCFT. CHL -999.2 50 AZIM.CHL -999.2'50 P1AZ,CHL -999,2:50 GR. CHL -9 99 · 2:50 DEPT. ],.3100.000 ILO.OIL 3.223 OT.BHC 7,6.438 TNR~.CNL 1.958 ~ E N S. O 'I L SP.gIL RTNR.CNL rNTC CNL ~AZI .CML HT EN. CNL 9PHO.LDT qSS .LOT LITH.LDT S S '~V. L'DT q~. LDT HT ~. LgT NPHI.CHL RCNT.CHL DEVI ,CHL '~RES,CHL TENS.OIL SP.DSL GR.BHC R T N P,. C 'N L rN'Tr CNL HAZ~.CNL HTEN .CNL ~RH~.LDT C'SS.LDT LZTH,LOT S S HV. [ gT RB. LOT ~TEM.LOT Nm HI. CHL RCNT .CHL gEVZ TENS ,OIL SP,DIL GR,BHC RTNR, CNL -999. -399.250 -999.250 2.172 3226.588 28.B04 -273. 500 0.139 0.029 176.625 1~41.000 81.213 203.125 -999.250 -999. 250 -999.250 -999. 250 6420.000 -70.625 23.016 2.055. 3759.648 28.367 957,000 0,012 0.917 66.438 1343.000 1~6,636 202.250 -999.Z50 -999.250 -999.~50.~. -999,250 6488.000 -24.203 2.117 S=LU,OIL GR,DIL TENS ,CNL RCCT.CNL AZIM.CNL Pl AZ,CNL GR,CNL qHgB.LDT LS .LOT SS1.LDT CALI .LOT NAZI.LOT HTEN.LOT TNR A. CHL CFTC.CHL RB.CHL MTEM.CHL SFLU,DIL GR.D!L TENS,CNL RC'~T ,CNL ~aZ!M,CNL Pl AZ. C NL GR.CNL RHOS,LOT LS,LDT SS1,LDT C~LI ,LgT H~ZZ ,L~T HT~N,LOT TNRA. CHL CFTC.CHL '~..CHL ~4T E N. C HL SFLU,DIL GR,O'IL TENS,CNL RC~T,CNL -999.250 -999.250 2544.000 1532.7_11 .2 B.B04 112.5~5 33.439 2,021 717.000 28!.750 6,391 28,804 -278.500 -999,250 -99'9.250 -999. 250 -99 9.150 4.497 23.015 684~.000 1920.605 28.367 21 7.439 27.094 Z. 500 250.375 20'7,375 8.500 28.367 957,000 -999,250 -999.250 -999 -999.250 6.493 30.234 6720.000 2t46.08~ lt~'~. OIL TEN S. BHC NPHI "'NL RCNT,CNL ~EV ~, CNL MRES,CNL TENS.LDT PE:.LgT LU.LDT SSZ.LDT AZ'IM,L~T P 1 ,~ Z. t D T G~.LDT RTNR .CML CNTC.CHL HAZI .CHL ~TEN.C,HL ILH.DIL TENS N~HT CNL RCNT.CNL gEVI,CNL TENS,LOT ~EF,LDT LU,LgT SS2,LgT AZ]M,LgT gR,LDT RTN~,CHL CNTC,CHL H~ZZ,CHL HTEN.CHL ILM,DIL TENS.~HC NPHI.CNL RCNT,CNL -999.2~0 -999.250 22.1t4 3~75.208 44.9aO 0.5,65 2~44.000 4.219 6~= 500 427.250 28.804. 112,565 33,438 -999,250 -999,250 -999,250 -999,250 2.532 6420.000 18.691 4015.710 43.230 0.578 3,014 2,37.250 2~8,500 28.367 217.439 27,094 -999.250 -99'9.250 -999.250 '-999.250 3.54] !8,322 4552,908 CHLUN~,E~'GER ~L:~SK.& CO~'~P~JTINr-, CENTE~ 22-NCV-198~ !~+: 53 C~TC.CNL 2157.~74 CNTC.CNL 4134.120 ~ZiM.CNL PS.CNL !.36.149 H~ZI.C~L 29.927 ~I ~'Z.CNL MT E M. CNL ~ O 2.7 50 w~ EN. CNL 960. 500 SR. CNL CPHI.LOT 14.1f~ 9RHC.LST -0.017 ~H3~.LDT QLS.LDT -0.00~ C SS.LOT O. 30! LS.LOT LL.LDT 1~3. 500 LITU. LOT 71. 513 SS1. LOT LSHV.LDT 1455.000 SS~V.LOT 1345.000 CALZ.LST DEVZ.LDT ~1.~78 R~.LDT 186. t49 H~,ZI.L~T MRES.LOT C.570 ~T~.LOT 202.750 HTEN.LDT TENS.CHL -999.250 NPHI,CHL -999.250 TN'qA.CHL RCFT.CHL -S~9.250 RCNT.CHL -99~.250 CFTC.CHL ~ZI~.CHL -999,2 5G 5EVI.CHL -999. 250 RS.CHL P1AZ.CHL -9~9.2~0 ~PES.CHL -999.250 MTEM.CHL GR,CHL -9~9,2~0 DEFT. 13000.000 TENS.OIL 6400.000 SFLU.D!L IL'D. OIL 9.3'0D SP.DIL -24. 750 GR. D IL DT.BMC 75.313 GP.BHC 42.405 TENS.CNL TNRA.CNL 2.057 RTHR.CNL 2.256 RC~T.CNL C~TC.CNL 2019,853 CNTC.CNL 405T.645 ~ZIM.CNL RB.CNL 1~4.1~3 H~ZI.'CNL ~0.~55 Pl~Z.CNL MTEM.CNL 200.875 ~TEN.CNL 947. 500 SR.CNL D~HI.LOT B.599 ORHC.LOT -0.008 RHOB.LOT ~LS.LDT 0.029 ~SS.LOT O.OOO LS.LOT LL.LDT 126. 875 LiTH.LgT 69. 250 SS1.LOT LSHV.LDT 1467.000 SSHV.LDT 1345.000 CALI.LDT DEVi.LDT .40.723 RB.LDT 184.113 H.~ZI.LDT MRES.LDT 0. 571 ~TE~. LDT 200. 875 HTEN.LOT TENS.CHL -999.2~0 NPHI.CHL -999.250 TNRA.CHL RCF'T.CHL .-999.250 RCN'T.CHL -999.250 CFTC.CHL AZI ~. CHL -999. 250 gEVI.CHL - :~99. 250 .2B. CHL PIAZ.CHL -999.250 ~RES.CHL -9q. 9.250 MTE.~.CHL G~.CHL -999.250 29. 927 2!'~.16! 3 1.23 ¢ 2.~!6 17 3. 500 195.000 Z 9.92? 960.500 -999.250 -999.250 -999.250 -999.250 11.532 42.405 674',3.000 197 7. T80 30.155 215.574 43. 781 2. '510 240.125 1~: 125 8.727 30.155 947.500 -~999. 250 -999.250 -999.250 -999.250 DEPT. 1!900.000 TENS.DIL 6420.000 SFLU.OIL 16.345 ILO. OIL 14.822 S P. g IL -34.250 GR. O IL 25.39 t CT.3HC 82.875 GR.BHC 25.39t TENS.CNL 6712.000 TNRA.CN~ 2.0~5 RTNR.CNL 2.123 RC~T.CNL 2075.926 CFTr~ . CNL =.~O&5 .029 CN'TC . CNL 4221 .518, ~ZIM .. CML 30 .192 RB.CNL 134.142 H~ZI.CNL 30.192 ~IAZ.CNL 215.572 MTEM.CNL 198.875 HT:EN.CNL lO!4.00O GR.CNL 25.969 DPHI.LDT 19,.71~ ORHO.LOT -0.004 R~OB.L, gT 2.325 QLS.LDT 0.017 '~SS.LDT O, 016 LS.LOT 332. Z~O LL.LOT :179.12:..~ LITH.LOT !15. .9~8_ SS1.LOT 108.125 LSHV.LOT 1459.000 SSHV.LDT 1346.000 CALl. LOT 8.695 gEV!. LDT 39.748 'R~ .LOT IB4. !42 H~.ZI.LDT 30.t92 MRES.LDT 0.554 MTEM.LDT 198. ',375 HTEN,.LDT 1014.000 TENS.CML -999.250 NPHI.CHL -999.250 TNRA.CHL -999.250 RrFT CHi -999 250 RCNT CHL -999.250 CFTC CHL -999 ZSO ,..,~HL -9q9.250 DE'VI CHL 999 250 o:.CHL -999 250 P1A;Z.CHL -999.250 ~,~RmS rilL -999 ,:50 MTEM C~L 999 P~O GR.CHL -999. 250 DEVZ.CNL NRES.CNL TENS.LOT gE: .LDT LU.LCT SS2.LDT ~ZZM.LDT PIAZ.LDT G~.LDT CNTC .CHL H&ZI.CNL HTE~,~. CHL IL'q. OIL TENS. 5HC NPHI.CNL RCNT .CNL DEVE.CNL MRES.CNL TENS.LOT PE~ .EDT LU. LOT SSZ .LOT AZEM.LDT Pt~Z.LOT GR. t,P..,T RTNq.CHL CNTC.CHL HAZi,CHL ~iTEN.CHL i t ,'~. D I L TENS.BHC NPHZoCNL RCNT.CNL DEVI.CNL MPES .CNL TENS.LOT PE~,LOT LU.LOT SSZ ,LOT ~ZI'q,LDT P .I ,~ Z. L O T GR.LDT R'TN~. CHL CNTC.CHL H:itZ. I. CHL H 'T E N . 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CNL -0. glo RHO~.LgT 0.003 LS.LOT 58.500 SS!.LDT I347.000 C~LI.LOT 180.013 HAZI.LOT 191.750 HTEN.LD'T 10.007 TNR~.CHL 4~76.636 CFTC.CHL q2. 927 RB.CML 0.578 MTEM.CHL 6252.000 SFLU.DIL -2.496 GR.D![ 53.594 TENS.CNL 5.153 RCFT.CNL 1468o444 ~Z!M.CNL 6,5.564 P!~Z,CNL 1066. 813 GR.CNL -1.029 RHOS.LOT -0.096 L$.LOT 10. 109 SS1 .LOT 1349.000 CALl.LOT 97.825 H~.ZI. LOT t86.375 H'TEN.LDT 56.446 TNq~ !570.B32 CFTC.CHL ~9.998 ~.CHL 0. 596 MTEM. CHL 36.599 80.125 6748.000 2553.!45 29. '802 209.819 90.563 2.55.8 220.250 19 O. 525 8.86? 29.802 1084.259 1.754 2549 .~96 173.596 188.000 ZO00.O00 53.594 6708.000 323.721 66.564 163.165 55.500 2. Z29 · 90.2 5 O 45.906 8,680 66.564 1066.~!3 4. ~99 320.58:5 143.505 185.500 i L 'a. g I L TENS.~HC NPHI. CNL RCNT .CNL DEVI.CNL N2ES.CNL T~NS.LDT PE,=.LgT LU. LOT S S .g. L D T ~ZIq. LDT PIAZ.LBT GR.LDT RTNR.CHL CNTC .CHL H ~ Z I. C H L HTEN.CHL 'IL ~. OIL TENS.~HC NPHI .CNL RCNT.CNL DEVI.CNL MRES.CNL T_z. NS.LDT PE~.LOT L U. L D T S S 2. 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T'R,~!LF~,.. *"'"'*..,--~- mILE N~'qE : E~IT .001 SERVICE : =LiC VERSION : 001/~02 D~T_:. ; 9..,, 8 t! 1 / 22 MAX REC S!Z~ : '1096 FILE TYPE L ~ST FiLE SERVICE N,~ME : EOIT DATE : 88/1tf12 ORIG.-~N .' FL '~C TAP5 NA~,~E ' 730t, 1 CONTINUATICN ~ : 1 PREVIOUS TA~E COM~ENT : LIS TA~E, SERVICE N&NE : SOI'T O~TE : 88/11/22 ORIGIN ~: ~LIC R~EEL NAME : 7~glt CONTINU,&TIQN ~ : PREVIOUS REEL : COMMENT : LIS TAOE~ S.~.P.C. S.A.P.C. Z-31, a PI ~50-029-2t871 · ~ 50-0 29-2t 8 71