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Home My WebLink About205-031Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:205-031 6.50-029-22053-01-00 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 10102 9300 8579 6998, 9092 9477 9300 6513, 8393 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 40 - 120 40 - 120 Surface 2621 13-3/8" 39 - 2660 39 - 2660 5020 2260 Intermediate 9359 9-5/8" 37 - 9396 37 - 8665 6870 4760 Production 519 7" 9142 - 9661 8437 - 8902 7240 5410 Perforation Depth: Measured depth: 7170 - 9888 feet True vertical depth:6669 - 9045 feet Tubing (size, grade, measured and true vertical depth) 6998 6513Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Packer Liner 625 3-1/2" x 2-7/8" 9477 - 10102 8737 - 9162 10160, 10570 10530, 11160 12. Stimulation or cement squeeze summary: Intervals treated (measured): 100-bbls 14.0-ppg Lead cement, 30-bbls 15.6# Permafrost C Tail cement Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 3001343137894 16881346 1428 533 357 305 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 GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9162 Sundry Number or N/A if C.O. Exempt: 321-119 4-1/2" Baker SB-3 Packer 9092 8393 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Patch 9-5/8" Casing Operations shutdown Change Approved Program 5 OA from 1974' MD to Surface 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 Casing5 Plug for Redrill 5Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028262 PBU Z-11A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" 9.2# 13cr / 4-1/2" 12.6# L80 35 - 7107 / 9076 - 9621 35 - 6612 / 8378 - 8866 Final Treating pressure = 2040-psi Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.02 13:52:52 -08'00' Stan Golis (880) By Samantha Carlisle at 8:42 am, Jul 06, 2021 MGR26JUL2021 SFD 7/6/2021RBDMS HEW 7/6/2021DSR-7/6/21 ACTIVITY DATE SUMMARY 3/2/2021 T/I/O = SSV/1650/175. Temp = SI. PPPOT-T (PASS), PPPOT-IC (FAIL) (pre RWO). AL SI @ CV (1650 psi). PPPOT-T: Stung into test port (1300 psi), bled void to 0 psi. Functioned LDS, all were tight but fully functioned. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: RU to hoke valve (1500 psi), unable to bleed void below 400 psi, pressure would return to 1600 psi slowly. Pack-off has been treated with Seal-tite several times. Functioned LDS, all but one functioned freely. Bad LDS (FMC ET) has been marked to be changed out during RWO. Unable to pressure void above 1600 psi (FAIL). SV, WV, SSV = C. MV = O. IA & OA = OTG. 13:30 3/19/2021 ***Cost Placeholder for glv latches*** 4/3/2021 ****WELL S/I ON ARRIVAL **** DRIFTED AND SET WHIDDON C-SUB(3.78) AT 9438' SLM / 9477' MD TOP OF LINER PULLED RM-SO FROM ST#1 @ 9054' MD ***OPEN POCKET*** PULLED WHIDDON C-SUB 9438' SLM ****WELL S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 4/5/2021 ***WELL S/I ON ARRIVAL*** (HES E-Line CIBP, TBG Cut) SET 4-1/2" NORTHERN SOLUTIONS CIBP AT 9300' MD. LOG CORRELATED TO TUBING TALLY DATED 02-JUL-1990. ***JOB CONTINUED ON 06-APR-2021*** 4/6/2021 T/I/O = 1882/1994/159. ***Circ Out*** Pumped 3bbls 60/40, 870bbls 1% SKL down tubing, up IA, to Z-39's flowline. Pumped 3bbls 60/40, 147bbls diesel, 3bbls 60/40 down IA, up tubing, to Z-39/2 flowline. U-tube freeze protect. Freeze protected Z-39 FL with 10bbls 60/40. Pumped 8.3bbls diesel to reach test pressure. ***CMIT TxIA FAILED*** Tubing lost 76psi 1st 15min, 39psi 2nd 15min. IA lost 53psi 1st 15min, 30psi 2nd 15min. Will come back in the morning to re-test. FW HP's = 644/640/221 4/7/2021 T/I/O = 330/330/181. ***CMIT TxIA to 3500psi PASSED*** Pressured up tubing w/ 8.3bbls diesel. Tubing lost 27psi 1st 15min, 9psi 2nd 15min. IA lost 31psi 1st 15min, 12psi 2nd 15min. Bled well down Z-39's flowline, and freeze protected flowline w/ 10bbls 60/40. Bled choke trailer and all hardline to zero. FWHP's = 220/220/180. 4/7/2021 ...Well shut in on arrival... (HES EL - chem cutter) FIRE STRING SHOT FROM 9,073.5' - 9,078.5'. CHEMICAL CUT TUBING AT 9,076'. ***Job Complete. Well shut in and secure on departure. Pad Op notified.*** 4/24/2021 T/I/O= 95/60/160 Temp=S/I (Pre RWO Capital) CMIT-TxIA Passed @ 3413/3428 psi. Pressured up T/IA to 3486/3495 psi with 10.5 bbls 30* diesel. 1st 15 min T/IA lost 34/28 psi. 2nd 15 min T/IA lost 20/21 psi. 3rd 15 min T/IA lost 19/18 psi for a total loss of 73/67 psi in 45 min. Bled T/IA to 130/100 psi and recovered 9 bbls disel. Tags hung. DSO notified. SV WV SSV= closed MV IA OA= open. Final Whp's=130/100/160 4/30/2021 T/I/O = 80/0/0. Set 4" H TWC #440 @120". RD Upper tree, RU Tree cap assy to MV, Leak tested against TWC 350/5000 PSI (Pass). Installed drilling platform. RDMO. ***Job Complete*** Daily Report of Well Operations PBU Z-11A Daily Report of Well Operations PBU Z-11A 5/6/2021 T/I/O = TWC/60/170. Temp = SI. WHPs (pre RWO). Well is disconnected from the system w/drill scaffold installed. MV = TWC. IA, OA = OTG. 12:00 5/9/2021 T/I/O = TWC/60/170. Temp = SI. Bleed WHPs (Pre RWO). No AL, flowline or wellhouse. Dry hole tree. IA FL @ surface. OA FL @ near surface. Bled IAP to BT from 60 psi to 10 psi in 10 min (Fluid, 1.2 bbls). Bled OAP to BT from 170 psi to 30 psi in 20 min (Gas). Monitored for 30 min. OAP increased 20 psi. Final WHPs = TWC/10/50. MV = O. IA, OA = OTG. 13:45 5/10/2021 T/I/O = 100/0+/0. Pre-RWO ND Tree / NU BOP Valve shop used lubricator to pull 4" H TWC #440 @ 64" and bled tubing to bleed tank. IA at 0 psi once tubing bled. T/I/O = 0/0/0. Set 4" H CTS BPV with dry rod. Sting into tubing hanger test void. 1850 psi on test void. Bled to 0 psi, clean hyd fluid and gas. Assist Worley to ND tree. Verify 0 PSI on 2 each 1/4" CCL, cut and cap CCL, clean void. Remove cut off CCL from FMC CCL nipples, replace CCL nipples and install 1/2" body lube fittings. Visually inspect 4-1/2" TDS tubing hanger lift threads and they look good. Installed CTS inner plug for BOP test. Clean and inspect ring groove, install new BX-160. Assist Worley with setting BOPs. Orient BOPs per Thunderbird tool pusher's marks. Worley crew continued with torquing 13-5/8" 5M connection. RDMO 5/14/2021 T/I/O = 0/40/120. Temp = SI. WHPs (post bleed). No AL, no flowline, no scaffold. Rig BOPs installed. IAP increased 30 psi and OAP increased 70 psi since 5/09/21. No SV, WV, SS or MV. Rig BOPs installed on tree. IA, OA = OTG. 00:30 5/16/2021 Thunderbird Rig 1 Job Scope: Tubing Swap, ...Continue WSR from 5/15/2021... MIRU. Spot equipment. Load pits. Test alarms. Function test BOP's. Perform weekly BOPE test - AOGCC state witness by Adam Earl. ...Continue WSR from 5/16/2021... 5/17/2021 Thunderbird Rig #1 Job Scope: TBG Swap & change out IC-Packoff. Complete BOPE test without AOGCC. Replace Valve #1 on the choke manifold. Performed passing BOPE test with AOGCC witness Adam Earl. Rock out diesel FP from TBG & IA. Install landing join't BOLDS ...Continue WSR on 5/18/2021... 5/18/2021 Thunderbird Rig #1 Job Scope: TBG Swap&m IC Pack-off C/O ...Continue WRS from 5/17/2021... 5/18/2021 ***RWO SUPPORT***(hes conveyed bond log) RU ELINE, LOG CEMENT BOND LOG. ***CONT ON 19-MAY-2021 WSR*** 5/19/2021 ***CONT FROM 18-MAY-2021 WSR***(hes conveyed cbl) LOG CEMENT BOND LOG FROM 2400'-9036'. EST TOC AT 2654'. ***WELL TURNED OVER TO RIG*** Daily Report of Well Operations PBU Z-11A 5/19/2021 Thunderbird Rig 1 Job Scope: TBG Swap, Cement Bond Log, Set Scoop Guide on 4 1/2" TBG stub. Eline logged from 9046' up. Recoverd good data. Sent to Brodie Wages for review. RU Slickline and set 8.20" OD x 76.75" scoop guide at 9068' MD. Attempt to C/O IC packof. Encounter Casing growth issues. Start Plan forward to cut and set 9-5/8" on slips. ND BOPE, MU Spear. ... Continue WSR on 2/20/2021... 5/19/2021 ***ASSIST THUNDERBIRD #1 RIG*** SET 9-5/8" x 5-1/2" SCOOP GUIDE W/ MULESHOE(oal-76.75", max od-8.20", min id- 3.958") ON TBG CUT @ 9076' MD. DRIFTED THROUGH SCOOP GUIDE W/ 3.80" SWEDGE, TOOLS S/D @ 9255' SLM. ***THUNDERBIRD #1 RIG IN CONTROL ON DEPARTURE*** 5/20/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Casing Growth repair plan: Attempt to set emergency slips. Run BOT spear. Unable to stretch 9-5/8" enough to set slips. LD spear PU & RIH with BOT Retrievable Bridge Plug & dump sand. Job in Progress... 5/21/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Casing Growth repair plan: . Set & test BOT "G" Lock Retrievable Bridge Plug at 2,196' md. RU & Dump sand on top of RPB. POOH, LD RBP running tool. PU/MU BOT Multi string cutter & RIH. MU power swivel. Wait on plan approval from AOGCC. Obtain Parameters for casing cut. C/O swivel Packing. Locate collar for casing cut. Job in Progress.... 5/22/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Casing Growth repair plan: Locate 9-5/8" collar for Mechanical Cut. Make cut mid joint at 1,988'. Break and LD swivel. Rig up LRS to load Casing with 150 bbls of diesel. POOH with BOT cutter & inspect. Make second cut below well head. Pull and laydown cut joint. C/O Variable rams to 9-5/8" solid body Rams. MU Test Joint. PT 9-5/8" casing rams. Job in Progress.... 5/23/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie Back: Spear 9-5/8" casing. Circ out arctic pak. Pull & LD 9-5/8" casing. Change Rams. Unable to set Test plug. C/O Annular element & Function Test. Tally 9-5/8" Casing. Job in Progress.. 5/24/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch: C/O annular element. Function test annular. RIG up floor. Tally 9-5/8" Pipe for casing run. Trouble shoot Accumulator. Full BOPTest with State witness.(Lou Laubenstein) 10-424 Test report sent to AOGCC. Dress off 9-5/8" Casing. Job In Progress... 5/25/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch: Dress off 9-5/8" casing stub at 1987'. Clear Floor. POOH LD assembly. Install 9-5/8" casing Rams & test 250 psi low 3000 psi high w/ 9-5/8" TJ. Run 9-5/8" casing and Patch. Patch set at 1,991' md Set slips. Cement 9-5/8" casing. Cut 9-5/8' at surface and set packoff. Cement 9-5/8" Tie back Patch. Job In Progress.... 5/26/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch: Cement 9-5/8" Tieback patch. Cut 9-5/8" Casing & Install Pack off. Insatll VBR's. MU Drill out assembly. RIH and mill out cement and Plug. Job In Progress..... 5/27/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch: Cement 9-5/8" Tieback patch. Mill out cement and plug from 9-5/8" Patch.MU & RIH with Junk Basket BHA ....Job In Progress.. / 5/28/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch:TIH wtih BOT Reverse Circulating Junk basket BHA, Clean out cement equipment and plug material.... Job in Progress. 5/29/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch: Run Reverse circulating Junk Basket to retrieve cementer & plug pieces until baskets are clean enough to pull the RBP. Job In Progress... Daily Report of Well Operations PBU Z-11A 5/30/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch: Run Reverse circulating Junk Basket to retrieve cementer & plug pieces until baskets are clean enough to pull the RBP. MU & RIH witih RBP Pulling tool. Circulate wellbore clean. Pull BOT RBP from 2,196'. POOH and LD RBP. MU Stack Washer and rinse BOP Stack. RU for Weekly BOPE Test. 24 notice given 5/29/21. Job in Progres.... 5/31/2021 Thunderbird Rig 1 Job Scope: 9-5/8" Tie back Patch: Continue rigging up BOP test equipment. Test 13-5/8" BOPE with fresh water to 250 low / 3000 high for Rams and Valves, 250 low / 2500 high for Annular.24hr notice given to AOGCC (5/29/21 @13:00. 2-7/8" & 3-1/2" Test Joints used. Wtness Waived by Brian Bixby. Function test Gas alarms and PVT's. Pull Test Plug & Install Wear Ring. MU & RIH with with BOT . 8-1/8 Overshot with 5-3/4" grapple.... Job In Progress.. 6/1/2021 Thunderbird Rig 1 Job Scope: Fish 9-5/8" spear. Prep for 3-1/2" completion.. RIH with Overshot fishing, washed down over the spear. Observed overpull and psi increase. POOH to check for fish. No fish recovered. MU new fishing BHA & RIH. Circulate well with High Vis sweeps. Make attempt to latch fish. Observe pressure increase, but no overpull. POOH to verify.... Job In Progress 6/2/2021 Thunderbird Rig 1 Job Scope: Fish 9-5/8" spear. Prep for 3-1/2" completion.. POOH with second Fishing BHA. Recovered lost spear. TIH w/ 139 Stds DP and POH LD DP. RU to run 3-1/2" completion. 6/3/2021 Thunderbird Rig 1 Job Scope: R/U and Run 3-1/2" 13Cr JFE Bear completion while torque turning with Weatherford, Pump 450 bbls packer fluid into IA w/returns from Tbg. 1% SKL w/ 1% Baracor 100 and .1% Oxygon 125F. 4.5 bpm @ 200 psi. Land Hanger, RILDS. Drop Ball and Rod. Set Packer. MIT-T to 4,000 psi. Pressure after first15 minutes is 3,990 psi (10 psi loss). Pressure after full 30 minutes is 3,990 psi. (10 psi lost total, 0 psi lost in 2nd 15 minutes). PASS. MIT-IA to 4,080 psi. Pressure after first 15 minutes is 4,020 psi (60 psi loss). Pressure after full 30 minutes is 4,010 psi. (70 psi lost total, 10 psi lost in 2nd 15 minutes). PASS. Freeze Protect Tubing and IA with Diesel to 2,829' MD at 1.5 BPM and 200 psi... 6/3/2021 T/I/O=0/0/0 TFS unit # 1 (Assist Rig with Freeze Protect) Circ well to OTT for TBG & IA FP. Pumped 155 bbls DSL down IA up TBG taking returns to open top tank. ***Job continued on 06/04/2021*** 6/4/2021 Thunderbird Rig 1 Job Scope: Freeze Protect T and IA with diesel to 2,829'. Set BPV. **COMPLETE** 6/4/2021 ***Job continued from 06/03/2021*** TFS unit #1 (Assist RIG FP TBG & IA) Pumped 111 bbls DSL down IA up TBG to open top tank to FP IA & TBG. FWHP= 0/0/0 6/5/2021 T/I/O=TWC/0/0. Remove BOP'S, set TWC Torque to API specs. Well head techs PT. Install 4" CIW Tree and torque to API specs. PT to 350/5000psi for 5 minutes (PASS) Pull TWC. ***Job Complete*** 6/9/2021 ***WELL S/I ON ARRIVAL***(post rig) PULLED BALL & ROD FROM RHC @ 7,065' MD PULLED RKP-SHEAR VALVE FROM ST#5 (2,821'MD) SET RK-DGLV IN ST#5 (2,821' MD) PULLED 3-1/2" RHC FROM XN @ 7,065' MD DRIFTED W/ 30' x 2.50" DUMMY GUNS (max od = 2.66") TO 7,300' SLM ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU Z-11A 6/9/2021 ***WELL S/I ON ARRIVAL***(post rig) PULLED BALL & ROD FROM RHC @ 7,065' MD PULLED RKP-SHEAR VALVE FROM ST#5 (2,821'MD) SET RK-DGLV IN ST#5 (2,821' MD) PULLED 3-1/2" RHC FROM XN @ 7,065' MD DRIFTED W/ 30' x 2.50" DUMMY GUNS (max od = 2.66") TO 7,300' SLM ***WELL S/I ON DEPARTURE*** 6/10/2021 NES: 9-5/8" casing cut of at wellhead for pack-off installation 6/13/2021 ***WELL S/I ON ARRIVAL*** PERFORATE 7242' - 7257' W/ 15' x 2.5" HSC MILLENNIUM II (11.1 gram), 6 SPF, 60 DEG PHASING PERFORATE 7201.5' - 7224' W/ 22.5' x 2.5" HSC MILLENNIUM II (11.1 gram), 6 SPF, 60 DEG PHASING ***JOB TO BE CONTINUED ON 6-14-2021, WELL S/I ON DEPARTURE, DSO NOTIFIED*** 6/14/2021 ***JOB CONTINUED FROM 6-13-2021, WELL S/I ON ARRIVAL*** PERFORATE 7170' - 7201.5' W/ 31.5' x 2.5" HSC MILLENNIUM II (11.1 gram), 6 SPF, 60 DEG PHASING ***JOB COMPLETE, WELL LEFT S/I AND DSO NOTIFIED*** 6/16/2021 T/I/O = SSV/400/Vac. Temp = SI. Verify OA cement. AL SI @ CV, 400 psi. No OA companion valve. Verified 0 psi in OA. Removed OA jewelry and 2" bull plug. Cleaned out valve grease. Unable to see any cement. Weighted string dropped to approx 3" below the edge of the casing SSO. SV, WV, SSV = C. MV = O. IA & OA = OTG. 11:30. 6/18/2021 ***WELL S/I ON ARRIVAL*** SET/PULL 3 1/2" WHIDDON CATCHER ON XN @ 7091' MD PULL RK-DGLV's FROM STA. #3, 4, 5 SET RK- LGLV's IN STA. #5, 4, 3 ***WELL S/I ON DEPARTURE***(job complete) Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: November 23, 2020Subject: Changes to Approved Sundry Procedure for Well Z-11aSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCCby 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 Written Approval Received (Person and Date)215/19/2021BOP Stack modificationBWBWMel Rixse (5/19/21)625/21/2021Addition of Cut/Pull and cement operations BWBWBrian Mclellan (5/21/21)726/17/2021No witnessed MIT-IABWBWMel Rixse (6/17/21)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer DateDigitally signed by Brodie Wages(4604)DN: cn=Brodie Wages (4604),ou=UsersDate: 2021.07.02 13:53:28 -08'00'Brodie Wages(4604)Digitally signed by Stan Golis(880)DN: cn=Stan Golis (880),ou=UsersDate: 2021.07.05 14:36:13 -08'00'Stan Golis(880) 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 OIL AND GAS CONSERVATION COMMISSION Reviewed By - ,IL P.I. SuprvJQ �— /re_I BOPE Test Report for: PRUDHOE BAY UNIT Z-1 ]A - Comm Contractor/Rig No.: Hilcorp Thunderbird 1 • PTD#: 2050310 - DATE: 5/24/2021 - Inspector Lou Laubenstein - Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: Murphy/ Knowles Rig Rep: Flores / Dodsn Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopl-OL210526072058 Rams: Annular: Valves: HASP: Type Test: WKLY 3 21-1 19 250/3000 - 250/2500' 250/3000 - 2340 - Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F ACCUMULATOR SYSTEM: 0 NA - P/F 0 Visual Alarm Ball Type Time/Pressure P/F Location Gen.: P _ Trip Tank NA NA System Pressure -_ 3000 _ - P Housekeeping: P - Pit Level Indicators P P Pressure After Closure 1700 - P PTD On Location P Flow Indicator NA NA 200 PSI Attained 17 P Standing Order Posted P_ _ Meth Gas Detector P P- Full Pressure Attained 95 P Well Sign P _ H2S Gas Detector FP FP ✓ Blind Switch Covers: _- yes P Drl. Rig P - MS Misc NA NA Nitgn. Bottles (avg): 6*2250 P Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly 0 NA - Lower Kelly 0 NA " Ball Type 1 -P_ " Inside BOP I P " FSV Misc 0 NA BOP STACK: Quantity P/F Size P/F Stripper 0 2 NA Annular Preventer 1 ' 135/8 - P #1 Rams _ 1 _2_7/x5 1/2 vbr" F #2 Rams 1 Blinds P _ #3 Rams 0 NA #4 Rams - 0_ --NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 1 3 1/8 P Kill Line Valves 3 31/8 P Check Valve 0 -NA - - BOP Misc 2 FP ✓ CHOKE MANIFOLD: Quantity P/F No. Valves - 11 - P Manual Chokes 2 P " Hydraulic Chokes 0 NA" CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 5 Test Results Test Time 6 Remarks: Test was completed with 2-7/8 test joint. VBR rams failed completely and the test was completed using the annular. Pit 1 H2S detection FP on visual and audible. 2-7/8 x 5-1/2 VBR failed to hold completely. BOP mist failures - Ram doors leaked and were fixed: BOP stack wasn't chained down and was corrected. STATE OF ALASKA Reviewed By: J— OIL AND GAS CONSERVATION COMMISSION P.I. Supry J� 21 ZUZI ROPE Test Report for: PRUDHOE BAY UNIT Z-1 IA Comm Contractor/Rig No.: Hilcorp Thunderbird I PTDN: 2050310 - DATE: 5/17/2021 ' Inspector Adam Earl '" Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: Jay Muphey/ Dan Scarpella Rig Rep: Adan Flores/Rusty Dod Inspector Type Operation: WRKOV Sundry No: Test Pressures: Rams: Annular: Valves: Type Test: MIT 321-119 250/5000' 250/2500' 250/5000 MISC. INSPECTIONS: FLOOR SAFTY VALVES P/F Location Gen.: P Housekeeping: _ P " PTD On Location P Standing Order Posted _ P_ Well Sign P " Drl. Rig _P Hazard Sec. P --- Mise NA FLOOR SAFTY VALVES TEST DATA Quantity P/F Upper Kelly __ 0___, _NA - Lower Kelly 0 NA Ball Type 1 __P Inside BOP 1 P FSV Misc 0 NA TEST DATA 3000 - MUD SYSTEM: Pressure After Closure 1650 Visual Alarm 200 PSI Attained Trip Tank NA NA Pit Level Indicators P P Flow Indicator P P Meth Gas Detector _P _ " P H2S Gas Detector P P MS Mtsc 0 NA BOPSTACK: bIASP: Inspection No: bopAGE210518201427 2340 • Related Insp No: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3000 - P Pressure After Closure 1650 P 200 PSI Attained 22 P ' Full Pressure Attained 101 P Blind Switch Covers: All Stations P " Nitgn. Bottles (avg): 6@ 2250 P ACC Misc 0 NA Quantity Size P/F Stripper 0 P/F NA Annular Preventer 1 -135/8 P - #1 Rams 1 -2 7/8 X 5 1/2' P - #2 Rams 1 - Blind P - #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 -31/8 P HCR Valves 1 -31/8 P ' Kill Line Valves 3 '3 1/8 P ' Check Valve 0 NA BOP Misc 1 - Bange FP Number of Failures: 1 Test Results Remarks: Mud cross flange leaked , tightened and passed re -test CHOKE MANIFOLD: INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Test Time 6 Quantity P/F No. Valves _ 11_ P - Manual Chokes 2 P ' Hydraulic Chokes 0 NA CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Test Time 6 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:205-031 6.API Number:50-029-22053-01-00 PRUDHOE BAY, BOREALIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028262 Property Designation (Lease Number):10. 8. PBU Z-11A 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 Fracture Stimulate 5 Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10102 Effective Depth MD: L-80 11. 4/30/2021 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): 9162 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9092, 8393 No SSSV Installed Date: Liner 625 3-1/2" x 2-7/8"9477 - 10102 8737 - 9162 10160, 10570 10530, 11160 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 39 - 2660 39 - 2660 14. Estimated Date for Commencing Operations: BOP Sketch 40 - 120 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker SB3 Packer 9600 - 9888 8848 - 9045 4-1/2" 12.6#35 - 9621 Production 9300 8579 9300 9477 40 - 120 13-3/8" 9-5/8" Contact Phone:907.564.5006 Date: 4760 80 20"Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2621 5020 Intermediate 9358 37 - 9396 37 - 8665 519 7"9142 - 9661 8437 - 8902 7240 5410 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. By Samantha Carlisle at 9:11 am, Apr 12, 2021 321-189 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.11 14:41:31 -08'00' Stan Golis (880) DSR-4/12/21 BOREALIS OIL CDW 4/15/2021 SFD 4/21/2021MGR22APR21 10-404YesRequired? Comm 4/22/21 dts 4/22/2021 RBDMS HEW 4/23/2021 Recomplete to Kuparuk Well:Z-11a PTD:205-031 API: 50-029-22053-01 Well Name:Z-11a API Number:50-029-22053-01 Current Status:Operable Ivishak Producer Rig:Frac Estimated Start Date:April 2021 Estimated Duration:1days Reg.Approval Req’d?Yes Regulatory Contact:Abbie Barker Permit to Drill Number:205-031 First Call Engineer:David “Brodie” Wages 713.380.9836 (M) Second Call Engineer:Brian Glasheen 907.545.1144 (M) AFE Number:212-00229 Current Bottom Hole Pressure:3673 psi @ 8800’ TVD BHP Survey 11/2019 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 Min ID:2.377” @ 9618’ 3-1/2” x 2-7/8” XO Brief Well Summary Drilled in 2006, Z-11A has been a strong standalone Ivishak well, producing 1.27 mmbo to date. It has little utility left in the Ivishak in the current development plan and has relatively low ontime due to high watercut (~ 95%) and TGOR constraints through the EWE LDF. At this time, no further plans are in place for further Ivishak development. The proposed work will temporarily abandon the Ivishak interval and recomplete the well to be a Kuparuk producer. Z-11A is located in the southeast part of the Borealis pool that may contain additional potential for development. Notes Regarding Wellbore Condition 9-5/8” Production Casing cemented with 1979 cf Permafrost cement Shoe @ 9396’ MD (8665’ TVD) Calculated TOC in 12.25” hole @ 3077’ MD (3070’ TVD) 10/29/2001: Camera confirm liner collapse in motherbore 7/1/2003: Coil FCO, lots of sand and gravel 1/2006: CTD sidetrack, good returns during liner cement job Multiple acid jobs to good effect, wax bead diversions successful, treated well but had little effect on production SIT performed 2Q 2009, water rate up oil rate down post SIT Early 2011 oil rate up, water rate constant, likely MI buzz from Z-12 8/2016: 35’ ADP to little effect 11/2019: CMIT-TxIA passed to 3500 psi, MIT-OA to 1200 psi passed RWO Planned April 2021 Scope of Work The primary objective of this work is to frac the Kuparuk interval of this recently re-completed wellbore Post-Workover Well Condition Tubing: pressure tested to 3500 psi IA: pressure tested to 3500 psi Diesel freeze protect to 2200’ Kuparuk C sand perforations from: a. 7170’-7224’ b. 7242’-7257’ -00 temporarily abandon the Ivishak interval and recomplete the well to be a Kuparuk producer. o frac the Kuparuk interval of this recently re-completed wellbore 7170’-7224’ 7242’-7257’ Kuparuk C sand perforations from: Recomplete to Kuparuk Well:Z-11a PTD:205-031 API: 50-029-22053-01 CIBP in old tubing tail isolating the Ivishak Procedure: Special Projects:Frac 1. MIRU Frac Fleet a. LRS to hold pressure on the IA with PRV set to flow to a tank via spring pop-off set at 90% of 3500 psi b. RU treating line blowdown line to circ the treating line clean in the event of a screenout 2. Check wellhead valves and bolts Pressure testing Maximum Allowable Treating Pressure:5000 psi Stagger Pump Kickouts between:4500 psi and 4750 psi (90% to 95% of MATP) Global Kickout 4750 psi (95% of MATP) Treating Line Test Pressure 6000 psi Sand Requirement 77,000# 16/20 Carbolite, 49,000# CarboBond Minimum Water Requirement 1305 bbls (pump schedule: 905 bbls) Min IA Hold Pressure 2400 psi (Tubing stress analysis) Max IA Pop-Off Set Pressure 3150 psi (90% of MIT-IA) OA Monitor and/or maintain open to atmosphere 3. Frac well per pump schedule 4. RDMO Frac Slickline:Install LGLVs 1. Install Generic GL design, deep if possible a. Expected 400 bopd, little water little gas Testers/Coil:POP and FCO 1. MIRU Testers a. RU in a way that allows Coil to RU at the same time 2. POP well a. Expected instantaneous rate for Single stage frac producing: i. 400 bopd ii. Minimum Water iii. 500 mcfd iv. At the very beginning of POP, expect 100% water as we flow back frac fluids pumped b. Follow slow bean up procedure below Contingent coil FCO 3. Once well is flowing, MIRU coil CIBP in old tubing tail isolating the Ivishak 4750 psi (95% of MATP) Recomplete to Kuparuk Well:Z-11a PTD:205-031 API: 50-029-22053-01 4. MU JSN 5. RIH and FCO/Millout to PBTD 6. Testers advise coil if excess sand is seen. Discuss with OE. 7. After FCO, RDMO Coil 8. Testers continue to flow well Recomplete to Kuparuk Well:Z-11a PTD:205-031 API: 50-029-22053-01 Testers Slow Bean up Procedure: 1. POP the well to ASRC with 1-1.5 MMSCFD Lift gas at minimum choke, adjust GL rate as necessary to eliminate slugging. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 2. Limit flow to 500 bpd 3. If solids are < 1%, after 1.5 wellbore volumes (120 bbls) increase the production rate to 750 BLPD. 4. Flow bottoms up and sample for solids production. If solids are still below 1%, increase flow to 1000 BFPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 250 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. Notify OE if excessive solids returns 6. Once at FOC, stabilize the well for 4 hrs. Obtain an 8 hr welltest. Recomplete to Kuparuk Well:Z-11a PTD:205-031 API: 50-029-22053-01 Current WBD: Recomplete to Kuparuk Well:Z-11a PTD:205-031 API: 50-029-22053-01 TubeMove Analysis: Date:April9,2021 Subject:ZͲ11aFractureStimulation From:DavidWages O:907.564.5006 C:713.380.9836 To:AOGCC AttachedisHilcorp’sproposalandsupportingdocumentstoperformafracturestimulationonwellZͲ 11aintheKuparukreservoirofthePrudhoeBayUnit. WellZͲ11aiscurrentlyalongtermshutͲinIvishakproducerthatmakes~200bopdand3000+bwpd whenonline.ThereremainslittlebenefittoleavingtheIvishakonlineatthistime.Followingarig workover,ZͲ11awillbecompletedandfrac’dtoproducefromtheKuparukinterval.ZͲ11awillhelp draingthefaultblocksupportedbyZͲ103andZͲ102. TheobjectiveofthisprogramistoperformafracturestimulationpostRWOtoimprovewell performance. Hilcorparerequestingavariancetosections20AAC25.283,a,3Ͳ4whichrequireidentificationoffresh Ͳwateraquifersandaplanforbasewatersampling. PleasedirectquestionsorcommentstoDavidWages. AffidavitofNotification(20AAC25.283,a,1): Partnersnotified4Ͳ6Ͳ2021: ConocoPhillips ExxonMobil Chevron DepartmentofNaturalResources PlatIdentifyingWells(20AAC25.283,a,2): PlatofwellswithinoneͲhalfmileofSͲ44Awellboretrajectory. ListofwellsinPlat20AAC25.283,a,2 WellName WellClssification WellStatus ZͲ17A Development OilProducerShutͲIn HIGHLANDST Development Abandoned ZͲ17APB1 Development PluggedBackForRedrill ZͲ01 Development Abandoned ZͲ18 Service WaterInjectorInjecting ZͲ01A Development Abandoned ZͲ19 Development Abandoned ZͲ01APB1 Development PluggedBackForRedrill ZͲ19A Service WaterInjectorInjecting ZͲ01APB2 Development PluggedBackForRedrill ZͲ20 Development OilProducerGasLift ZͲ01B Development OilProducerShutͲIn ZͲ21 Development Abandoned ZͲ02 Development Abandoned ZͲ210 Service WaterAndGasInjector ZͲ02A Service WaterInjectorInjecting ZͲ210PB1 Service PluggedBackForRedrill ZͲ03 Development Abandoned ZͲ21A Development OilProducerShutͲIn ZͲ03A Development OilProducerShutͲIn ZͲ22 Development Abandoned ZͲ04 Development Abandoned ZͲ22A Development Abandoned ZͲ04A Development OilProducerGas Lift ZͲ22B Development OilProducerShutͲIn ZͲ05 Development Abandoned ZͲ23 Development Abandoned ZͲ05A Development OilProducerShutͲIn ZͲ23A Development Abandoned ZͲ05APB1 Development PluggedBackForRedrill ZͲ23B Development Abandoned ZͲ06 Development Abandoned ZͲ23C Development OilProducerShutͲIn ZͲ06A Development OilProducerShutͲIn ZͲ23PB1 Development PluggedBackForRedrill ZͲ07 Development Abandoned ZͲ24 Development OilProducerFlowing ZͲ07A Development Abandoned ZͲ25 Service MiscibleInjectorOperating ZͲ07B Development OilProducerShutͲIn ZͲ26 Development Abandoned ZͲ08 Development Abandoned ZͲ26A Development OilProducerGasLift ZͲ08A Development Suspended ZͲ27 Development OilProducerGasLift ZͲ09 Development Abandoned ZͲ28 Service WaterInjectorInjecting ZͲ09A Development OilProducerShutͲIn ZͲ29 Development OilProducerShutͲIn ZͲ10 Development Abandoned ZͲ30 Development Abandoned ZͲ100 Development OilProducerGas Lift ZͲ30A Development OilProducerShutͲIn ZͲ101 Development OilProducerShutͲIn ZͲ31 Service WaterInjectorShutͲIn ZͲ102 Service WaterInjectorInjecting ZͲ32 Development Abandoned ZͲ102PB1 Service PluggedBackForRedrill ZͲ32A Development Abandoned ZͲ103 Service WaterInjectorInjecting ZͲ32B Development Abandoned ZͲ103PB1 Service PluggedBackForRedrill ZͲ32BL1 Development Abandoned ZͲ103PB2 Service PluggedBackForRedrill ZͲ32BPB1 Service PluggedBackForRedrill ZͲ103PB2 Service PluggedBackForRedrill ZͲ32BPB2 Development PluggedBackForRedrill ZͲ108 Development OilProducerShutͲIn ZͲ32C Development OilProducerGasLift ZͲ10A Development OilProducerShutͲIn ZͲ33 Development Abandoned ZͲ11 Development Abandoned ZͲ33A Service WaterInjectorInjecting ZͲ112 Development OilProducerGas Lift ZͲ34 Development OilProducerGasLift ZͲ112PB1 Development PluggedBackForRedrill ZͲ35 Development OilProducerShutͲIn ZͲ112PB2 Development PluggedBackForRedrill ZͲ35PB1 Development PluggedBackForRedrill ZͲ113 Development OilProducerGas Lift ZͲ38 Development OilProducerGasLift ZͲ113PB1 Development PluggedBackForRedrill ZͲ38PB1 Development PluggedBackForRedrill ZͲ114 Service MiscibleInjectorOperating ZͲ39 Development Abandoned ZͲ115 Development OilProducerGas Lift ZͲ39A Development OilProducerShutͲIn ZͲ116 Service WaterInjectorInjecting ZͲ40 Development OilProducerGasLift ZͲ116PB1 Service PluggedBackForRedrill ZͲ46 Development Abandoned ZͲ116PB2 Service PluggedBackForRedrill ZͲ46A Development OilProducerGasLift ZͲ11A Development OilProducerShutͲIn ZͲ50 Development OilProducerGasLift ZͲ12 Service WaterInjectorInjecting ZͲ504A Service WaterInjectorShutͲIn ZͲ13 Development Abandoned ZͲ504B Service WaterInjectorShutͲIn ZͲ13A Development OilProducerGas Lift ZͲ61 Development OilProducerShutͲIn ZͲ13APB1 Development PluggedBackForRedrill ZͲ61PB1 Development PluggedBackForRedrill ZͲ14 Development Abandoned ZͲ65 Development OilProducerShutͲIn ZͲ14A Service Abandoned ZͲ65PB1 Development PluggedBackForRedrill ZͲ14B Development OilProducerShutͲIn ZͲ66 Development OilProducerGasLift ZͲ15 Development Abandoned ZͲ66PB1 Development PluggedBackForRedrill ZͲ15A Development OilProducerGas Lift ZͲ67 Service MiscibleInjectorOperating ZͲ15APB1 Development PluggedBackForRedrill ZͲ68 Development Suspended ZͲ15APB2 Development PluggedBackForRedrill ZͲ68PB1 Development PluggedBackForRedrill ZͲ16 Development Abandoned ZͲ69 Development OilProducerShutͲIn ZͲ16A Development OilProducerShutͲIn ZͲ70 Development Suspended ZͲ17 Development Abandoned ZͲ71 Development OilProducerShutͲIn ExemptionforFreshwaterAquifers(20AAC25.283,a,3Ͳ4): WellZͲ11aisintheWestOperatingAreaofPrudhoeBay.PerAquiferExemptionOrderNo.1datedJuly 11,1986whereStandardAlaskaProductionCompanyrequestedtheAlaskaOilandGasConservation CommissiontoissueanorderexemptingthoseportionsofallaquiferslyingdirectlybelowtheWestern OperatingAreaandKPadAreaofthePrudhoeBayUnitforClassIIInjectionactivities.Findings1Ͳ4 state: 1. ThoseportionsoffreshwateraquifersoccurringbeneaththeWesternOperatingandKpadareas ofthePrudhoeBayUnitdonotcurrentlyserveasasourceofdrinkingwater. 2. ThoseportionsoffreshwateraquifersoccurringbeneaththeWesternOperatingandKpadareas ofthePrudhoeBayUnitaresituatedatadepthandlocationthatmakesrecoveryofwaterfor drinkingwaterpurposeseconomicallyimpracticable. 3. ThoseportionsoffreshwateraquifersoccurringbeneaththeWesternOperatingandKpadareas ofthePrudhoeBayUnitarereportedtohavetotaldissolvedsolidscontentof7000mg/Ior more. 4. ByletterofJuly1,1986,EPAͲRegion10advisesthattheaquifersoccurringbeneaththe WesternOperatingandKpadareasofthePrudhoeBayUnitqualifyforexemption.Itis consideredtobeaminorexemptionandanonͲsubstantialprogramrevisionnotrequiring noticeintheFederalRegistrar. Pertheabovefindings,"ThoseportionsoffreshwateraquiferslyingdirectlybelowtheWestern OperatingandKPadAreasofthePrudhoeBayUnitqualifyasexemptfreshwateraquifersunder20AC 25.440"thusallowingBPexemptionfrom20AAC25.283,a,3Ͳ4whichrequireidentificationof freshwateraquifersandestablishingaplanforbasewatersampling. DetailedCasingandCementInformation(20AAC25.283,a,5Ͳ6A): WellZͲ11(PTD:190072)wasspudded6Ͳ15Ͳ1990 13Ͳ3/58”68#,LͲ80surfacecasingwassetat2660’andcementedinplace.Prioretodrillingouttheshoe track,thecasingwastestedto30000psi. A12Ͳ1/4”Productioncasingholewasdrilledto9404where9Ͳ5/8”47#NTͲ80Scasingwasrunandsetat 9396’thencementedwith1979cuftpermafrostcement.Priortodrillingouttheshoetrackthecasing waspressurestestedto3000psi. An8Ͳ1/2”holewasthendrilledtoTDof10,300’whenopenholelogswerethenrunandthen7” productionlinerwassetat9866’andcementedinplacewith363cuftclassGcement. Finally,4Ͳ1/2”tubingwasrunwiththeEOT@9621’andtheproductionpackersetinthe9Ͳ5/8”casing @9092’. On1/22/2006thewindowforthesidetrackwasmilledfrom9658’Ͳ9664’.Holesectiondrilledwellto 10,102’,MUandRIHwith2Ͳ7/8”liner,cementedwith10.6bblsofcement. SeeMechanicalreportandcementevaluationTable4insection"LocationofWellsandFaults(20AAC 25.283,a,10Ͳ11)"forconformancewith20AAC25.283,a,6B) PressureTesting(20AAC25.283,a,7): Table1—TubingandProductionCasingPressureTestingTubing DateTubingPressure (psi) ProductionCasingPressure (psi) DifferentialPressure (psi) TBD350003500* TBD200035002500 *Thetubingwillbepressuretestedto3500psiwhichisgreaterthan110%ofmaxdifferentialpressure (2500psi)duringfracturestimulationper20AAC25.283,c,2. AccuratePressureRatingsofTubularsandSchematic(20AAC25.283,a,8): Figure1—WellboreschematicforwellZͲ11a. Table2—TubularRatings Size/NameWeightGradeConnectionIDBurst,psiCollapse,psi 13Ͳ3/8”Surface68#LͲ8012.415”50202260 9Ͳ5/8”IntermediateCasing47#LͲ808.681”68704760 7”ProductionLiner26#LͲ806.276”72405410 2Ͳ7/8”ProductionLiner6.5#13CRSTL2.441”10,57011,160 4Ͳ1/2”ProductionTubing12.6#LͲ803.958”84307500 Wellhead FMCmanufacturedwellhead,ratedto5,000psi. Figure2—WellZͲ11aFMCwellhead. Tubingheadadaptor:13Ͳ5/8"5,000psix4Ͳ1/16"5,000psi TubingSpool:13Ͳ5/8"5,000psiw/2Ͳ1/16"sideoutlets CasingSpool:13Ͳ5/8"5,000psiw/2Ͳ1/16"sideoutlets Tree:Cameron4Ͳ1/16"6,5000psi GeologicalFracInformation(20AAC25.283,a,9): Table3—GeologicalInformationFormation FormationMDTopMD Bot TVDss Top TVDss BotTVDThicknessFracGrad psi/ftLith.Desc. THRZ68847139Ͳ6318Ͳ6548230Shale TKLB71397170Ͳ6548Ͳ657729Shale TKUP71707192Ͳ6577Ͳ659720SS TKC271927198Ͳ6597Ͳ66025SS TKC171987225Ͳ6602Ͳ662625SS LCU72257233Ͳ6626Ͳ66347Silt/SS TKA672337242Ͳ6634Ͳ66429Silt/SS TKA572427262Ͳ6642Ͳ666018Silt/SS TKA472627292Ͳ6660Ͳ668727Silt/SS TMLV72928003Ͳ6687Ͳ7324637Shale LocationofWells,MechanicalInformationandFaults(20AAC25.283,a,10Ͳ11): Figure3b—PlatofwellswithinoneͲhalfmileofZͲ11awellborereservoirtrajectoryandlocationoffaults.Theblueline indicatestheapproximatefracturelengthandorientationinthetoeofSͲ44A. Hilcorp’stechnicalanalysisbasedonseismic,wellandothersubsurfaceinformationavailableindicates thatthereare3mappedfaultsthattransecttheKuparukintervalandentertheconfiningzonewithin the½radiusoftheproductionandconfiningzonetrajectoryforZͲ11.Fracturegradientswithinthe confiningzone(KalubikandHRZ)willnotbeexceededduringfracturestimulationandwouldtherefore confineinjectedfluidstothepool.TheHRZandKalubikinthisareaarepredominatelyshalewithsome siltswithanestimatedfracturepressureof~13.5ppg. TherewerenomappedfaultsencounteredwhentheZͲ11wasdrilledthroughtheKuparukintervaland therewerenolossesobserved. Faults1Ͳ3intersecttheproductionintervalandconfiningzonewithinthe½mileradiusoftheplanned fracs.Theirdisplacements,senseofthrow,andzoneinwhichtheyterminateupwardsaregivenbelow. ThewellboretrajectoryisessentiallyaverticalpenetrationintheKuparuk.Maximumstressdirectionis estimatedtobe~30degWofN.Thefracsshouldnotreachanyofthemappedfaults Fault Throw Direction Distance toFrac.Top Bottom 1 <40' DTW 2200' Colville Kingak 2100Ͳ150' DTSW 1400' Sagavanirktok Basement 3 150' DTW 1600' Ugnu Basement Mechanicalreportandcementevaluation Table4–MechanicalReportandCementEvaluation HydraulicFractureProgram(20AAC25.283,a,12): FractureStimulationPumpSchedule Adatafracwillbepumpedpriortothefrac, TotalCleanFluidvolume:953bbls AnticipatedTreatingPressures Table5–AnticipatedPressures MaximumAnticipatedTreatingPressure:4500psi MaximumAllowableTreatingPressure:5000psi StaggerPumpKickoutsBetween:4500psiand4750psi(90%to95%ofMATP) GlobalKickout:4750psi(95%ofMATP) IAPopͲoffSetPressure:3300psi IAMinimumholdPressure:2400psi TreatingLineTestPressure:6000psi SandRequirement:77,000lbsCarboLite,49,000lbsCarboBOND MinimumWaterRequirements:1300bbls(PumpSchedule:950bbls) OAPressure:Monitorandmaintainopentoatmosphere Therearethreeoverpressuredevicesthatprotectthesurfaceequipmentandwellborefrom overpressure.1)Eachindividualfracpumphasanelectronickickoutthatwillshiftthepumpsinto neutralassoonasthesetpressureisreached.Sincetherearemultiplepumps,thesesetpressuresare staggeredbetween90%and95%ofthemaximumallowabletreatingpressure.2)Aprimarypressure transducerinthetreatinglinewilltriggeraglobalkickoutthatwillshiftallthepumpsintoneutral.3) Thereisamanualkickoutthatiscontrolledfromthefracvanthatcanshiftallpumpsintoneutral.All threeoftheseshutdownsystemswillbeindividuallytestedpriortohighpressurepumpingoperations. Additionally,thetreatingpressure,IApressureandOApressurewillbemonitoredinthefracvan. Basedonaregionalstressmap,themaximumhorizontalstressintheKuparuksandsisdeterminedto run30Ͳ45°WofN).Theheelandlateralofthewellaredrilledperpendiculartothemaximumhorizontal stressmeaningtheinducedfracturewillalsobeperpendiculartothewellbore. FracDimensions: Frac#MDLocation,ftTVDtop,ftTVDBottom,ftFracHalfͲLength,ft 17170’Ͳ7224’, 7242’Ͳ7257’ 6669’6747’~250’ Theabovevalueswerecalculatedusingmodelingsoftware. MaximumAnticipatedTreatingPressure:4500psi Surfacepressureiscalculatedbasedonaclosurepressureof~0.6psi/ftor~4000psi.Closurepressure plusanticipatednetpressuretobebuilt(500psi)andfrictionpressureminushydrostaticresultsina surfacepressureof5500psiatthetimeofflush. 4000psi(closure)+500psi(net)+2900psi(friction)Ͳ2900psi(hydrostatic)=4500psi(maxsurfacepress) Thedifferenceinclosurepressuresoftheconfiningshalelayersdeterminesheightofthefracture. Averageconfininglayerstressisanticipatedtobe~0.7psi/ftlimitingfractureheightto~100ftTVD. FracturehalfͲlengthisdeterminedfromconfininglayerstressaswellasleakͲoffandformationmodulus. ThemodeledfracisanticipatedtoreachahalfͲlengthof~250ft. PreͲJobAnticipatedChemicalstobepumped: 135,000gal 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage1April22,2021(a)ApplicationforSundryApproval(a)(1)AffidavitProvidedwithapplication.SFD4/14/2021(a)(2)PlatProvidedwithapplication.SFD4/14/2021(a)(2)(A)WelllocationProvidedwithapplication.WellliesinSection19ofT11N,R12E,UM.SFD4/14/2021(a)(2)(B)Eachwaterwellwithin½mileNone:AccordingtotheWaterEstatemapavailablethroughDNR’sAlaskaMapperapplication(accessedonlineApril14,2021),therearenowellsareusedfordrinkingwaterpurposesareknowntoliewithin½mileofthesurfacelocationofPBUZͲ11A.Therearenosubsurfacewaterrightsortemporarysubsurfacewaterrightswithin9.7milesofthesurfacelocationofPBUZͲ11A.SFD4/14/2021(a)(2)(C)Identifyallwelltypeswithin½mileProvidedwithapplication:97wellsandwellbranchesand26pluggedbackwellbores.SFD4/14/2021(a)(3)Freshwateraquifers:geologicalname;measuredandtrueverticaldepthNone.TertiaryͲagedSagavanirktokFormation,whichliesbeneathpermafrost.Inthisarea,permafrostappearstobeabout1,780’thick.UnderAquiferExemptionOrderNo.1,aquifersinthisareacannotbeconsideredfreshwateraquifersbecausethey1)donotserveasasourceofdrinkingwater,2)aresituatedatadepthandlocationthatmakesrecoveryofwaterfordrinkingwaterpurposeseconomicallyimpracticable,3)nativeformationfluidshaveSFD4/14/2021 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage2April22,2021TDSconcentrationsexceeding7,000mg/l,andtheyarenotreasonablyexpectedtosupplyapublicwatersystem,and4)EPARegion10,byletterdatedJuly1,1986,advisesthattheaquifersoccurringbeneaththeWesternOperatingandKͲPadAreasofthePrudhoeBayUnitqualifyforexemption.(a)(4)BaselinewatersamplingplanNonerequired.SFD4/14/2021(a)(5)CasingandcementinginformationProvidedwithapplication.Proposedschematicattached,asbuiltnogeneratedtodate.MGR21APR21(a)(6)CasingandcementingoperationassessmentTOCexternalto9Ͳ5/8”casingreportedat3077’MD,3070’MDwith353bblsofcement.NoCBLavailable.Noissuesnotedwithcementing9Ͳ5/8”casing.MITͲIAwillbeperformedafterRWOto3500psi.Tubingwillbetestto4000psi.MGR21APR21(a)(6)(A)Casingcementedbelowlowermostfreshwateraquiferandconformsto20AAC25.030Nofreshwateraquiferspresent.(SeeSection(a)(3),above.)SFD4/14/2021(a)(6)(B)EachhydrocarbonzoneisisolatedYes:IntheoriginalwellPBUZͲ11,surfacecasingwassetat2,660’MD(Ͳ2,568’TVDSS)andcemented.Next12Ͳ1/4”SFD4/14/2021 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage3April22,2021holewasdrilledfromthebaseofsurfacecasingsetat2,660’MD(Ͳ2,568’TVDSS)tototaldepthof9,404’MD(Ͳ8,580’TVDSS).The9Ͳ5/8”casingshoeissetat9,396’MD(Ͳ8,573’TVDSS)andcementedwith1,979cubicfeetofpermafrostcement,whichyieldsacalculatedcementtopofabout4,540’MD(Ͳ4,291’TVDSS).Then8Ͳ1/2”holewasdrilledto10,300’MD(Ͳ10,208’TVDSS)with7”linersetat9,866’MD(Ͳ8,943’TVDSS)andcementedwith363cubicfeetofClassGcement,whichyieldsacalculatedcementtopofabout8,100’MD(Ͳ7,411’TVDSS).PBUZͲ11Akickedoffat9,661’MD(Ͳ8,810’TVDSS),4Ͳ1/8”holewasdrilledto10,102’MD(Ͳ9,070’TVDSS)andacombinationof3Ͳ1/2”x2Ͳ7/8”linerwascementedwith60cubicfeetofClassGcement,whichyieldsacalculatedtopofabout8,865’MD(Ͳ8,097’TVDSS).So,cementisolatestheKuparukfracturingtargetintervalfromtheoverlyingSchraderBluffandtheunderlyingSagRiver,ShublikandIvishakFormations.(SeecrossͲsection,below.)(a)(7)Pressuretest:informationandpressureͲtestplansforcasingandtubinginstalledinwellProvidedwithapplication.3500psiMITIAplanned,3500psiMITTplan.CDW4/15/2021 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage4April22,2021(a)(8)Pressureratingsandschematics:wellbore,wellhead,BOPE,treatingheadProvidedwithapplication.5000psiwellheadmax.frac.Pressure4500psi.Pumpknockout4500and4750psiandGORV4750psi.,linestest6000psi.CDW4/15/2021(a)(9)(A)Fracturingandconfiningzones:lithologicdescriptionforeachzone(a)(9)(B)Geologicalnameofeachzone(a)(9)(C)and(a)(9)(D)Measuredandtrueverticaldepths(a)(9)(E)FracturepressureforeachzoneUpperconfiningzones:Kalubik,Pebble,HRZ,andHueshales(inascendingstratigraphicorder),whichhaveanaggregatethicknessofabout870’trueverticalthickness(TVT).(SeecrossͲsection,below.)Fracturegradientisexpectedtobeabout0.70psi/ft(13.5ppgEMW).FracturingZone:Kuparukintervalbetween7,170’to7,257’MD(Ͳ6,577’toͲ6,655’TVDSS)thatcomprisesshallowmarinesandstonedeposits.Fracturegradientisexpectedtobeabout0.60psi/ft(11.5ppgEMW).Lowerconfiningzones:MiluveachandKingakshales(indescendingstratigraphicorder)thathaveanaggregateTVTofover1,900’.Fracturegradientisexpectedtobeabout0.70psi/ft(13.5ppgEMW).SFD4/14/2021(a)(10)Location,orientation,reportonmechanicalconditionofeachwellHilcorphasidentifiedover30+wellsandprovidedcementevaluationsintableformat.Cementinginformationontopofcementispresentedinthetableasvolumetric.CDW4/15/2021 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage5April22,2021(a)(11)Sufficientinformationtodeterminewellswillnotinterferewithcontainmentwithin½mileYes.Operatorevaluationofcementandzonalisolationof27wellsand4plugbackswithin½mileofPBUZͲ11AindicatestheKuparukintervaliscementisolated.Theplannedfracturinginterval(Kuparuk)inPBUZͲ11AiscementͲisolatedfromoverlyingandunderlingstrata.SFD4/14/2021(a)(11)Faultsandfractures,Location,orientation(a)(11)Faultsandfractures,Sufficientinformationtodeterminenointerferencewithcontainmentwithin½milePresent.Theoperatorhasidentifiedthreefaultsonseismicdatawithina½ͲmileradiusofPBUZͲ11A,butZͲ11AdidnotencounteranyfaultsorfluidͲlosszonesduringdrilling.AccordingtotheoperatorͲsuppliedfaultmap,theclosestapproachoftheinducedfracturesthenearestmappedfaultisabout1,400’.Itisunlikelythatanyfaultswillinterferewithcontainmentoftheinjectedfracturingfluids;however,ifthereareindicationsthatafracturehasintersectedafaultornaturalͲfractureintervalduringfracoperations,theoperatorwillgotoflushandterminatethestageimmediately.SFD4/19/2021(a)(12)ProposedprogramforfracturingoperationProvidedwithapplication.CDW4/15/2021(a)(12)(A)EstimatedvolumeProvidedwithapplication.1305bbltotaldirtyvol.126KlbtotalproppantCDW4/15/2021(a)(12)(B)Additives:names,purposes,concentrationsProvidedwithapplication.CDW4/15/2021 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage6April22,2021(a)(12)(C)ChemicalnameandCASnumberofeachProvidedwithapplication.Schlumbergerdisclosureprovided.CDW4/15/2021(a)(12)(D)Inertsubstances,weightorvolumeofeachProvidedwithapplication.CDW4/15/2021(a)(12)(E)MaximumtreatingpressurewithsupportinginfotodetermineappropriatenessforprogramSimulationshowsmaxsurfacepressure4500psi.Max.5000psiallowabletreatingpressure.Maxpressureis4500psito4750psitoPumpshutdown.With2400psibackpressureIA(IApopoffset3150psi),maxtubingdifferentialshouldbe2100psi.CDW4/15/2021(a)(12)(F)Fractures–height,length,MDandTVDtotop,descriptionoffracturingmodelProvidedwithapplication.Regionalstressanalysisindicatestheinducedfractureswilloccuralonganorientationof30to45degreeswestofnorth.TheanticipatedhalfͲlengthsofinducedfracturesareexpectedtobeabout250’accordingtotheOperator’scomputersimulation.Computersimulationindicatestheanticipatedheightoftheinducedfractureswillbeabout80’(topTVDofabout6,669’andbaseTVDofabout6,747’),sothesefractureswilllikelypenetrateinto,butcertainlynotthrough,theoverlyingconfiningshaleintervalsthathaveanaggregatethicknessofabout870’inthisarea.SFD4/14/2021(a)(13)ProposedprogramforpostͲfracturingwellcleanupandfluidrecoveryWellcleanoutandflowbackprocedureprovidedwithapplication.NodisposalidentifiedbutHilcorpNorthSlopehasmanyoptionsavailable.CDW4/15/2021 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage7April22,2021(b)TestingofcasingorintermediatecasingTested>110%ofmaxanticipatedpressure2400psiminimumbackpressure,plantotestto3500psi,popoffsetas3150psiCDW4/15/2021(c)Fracturingstring(c)(1)Packer>100’belowTOCofproductionorintermediatecasing3.5”tubingwillbeanchoredwitharetrievablepackersetat7050’MD.69’newKuparukperforationstobepunchedpostRWOfrom7171’Ͳ7224’&72542’Ͳ7257’.MGR21ͲAPRͲ21(c)(2)Tested>110%ofmaxanticipatedpressuredifferentialTubingtestof3500psi.Maxpressuredifferentialisestimatedas2600psi(5000with2400psibackpressure)sotestof3500psisatisfies110%CDW4/15/2021(d)PressurereliefvalveLinepressure<=testpressure,remotelycontrolledshutͲindevice6000psilinepressuretest,pumpknockout4500and4750psiwithmax.globalkickout4750psi.IAPRVsetas3150psi.CDW4/15/2021(e)ConfinementFracfluidsconfinedtoapprovedformationsProvidedwithapplication.CDW4/15/2021(f)SurfacecasingpressuresMonitoredwithgaugeandpressurereliefdeviceIAPRVsetat3150psi.Surfaceannulusopen.Fracpressurescontinuouslymonitored.CDW4/15/2021(g)Annuluspressure500psicriteriaDuringhydraulicfracturingoperations,allannuluspressuresmustbecontinuouslymonitoredandrecorded.Ifatanytimeduringhydraulicfracturingoperationstheannuluspressureincreasesmorethan500psigabovethoseCDW4/15/2021 20AAC25.283HydraulicFracturingApplication–ChecklistPBUZͲ11A(PTDNo.205Ͳ031;SundryNo.321Ͳ189)ParagraphSubͲParagraphSectionComplete?AOGCCPage8April22,2021monitoring&notificationanticipatedincreasescausedbypressureorthermaltransfer,theoperatorshall:(g)(1)NotifyAOGCCwithin24hours(g)(2)Correctiveactionorsurveillance(g)(3)SundrytoAOGCC(h)SundryReport(i)Reporting(i)(1)FracFocusReporting(i)(2)AOGCCReporting:printed&electronic(j)PostͲfracwatersamplingplanNotrequired(seeSection(a)(3),above),(k)ConfidentialinformationClearlymarkedandspecificfactssupportingnondisclosure(l)VariancesrequestedModificationsofdeadlines,requestsforvariancesorwaiversNoplanforpostfracturewaterwellanalysis.Commissionmayrequirethisdependingonperformanceofthefracturingoperation. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:205-031 6.API Number:50-029-22053-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028262 Property Designation (Lease Number):10. 471 8. PBU Z-11A 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 GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10102 Effective Depth MD: L-80 11. 4/22/2021 Commission Representative: 15. Suspended Contact Name: Brodie Wages Contact Email: david.wages@hilcorp.com Authorized Name: Stan Golis Authorized Title: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): 9162 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate 5Perforate New Pool 9092, 8393 No SSSV Installed Date: Liner 625 3-1/2" x 2-7/8"9477 - 10102 8737 - 9162 10160, 10570 10530, 11160 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 39 - 2660 39 - 2660 14. Estimated Date for Commencing Operations: BOP Sketch 40 - 120 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker SB3 Packer 9600 - 9888 8848 - 9045 4-1/2" 12.6#35 - 9621 Production 10067 9143 None 9477 40 - 120 13-3/8" 9-5/8" Contact Phone:(907)564-5006 Date: 4760 80 20"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 2621 5020 Intermediate 9358 37 - 9396 37 - 8665 519 7"9142 - 9661 8437 - 8902 7240 5410 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 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. 2340 By Samantha Carlisle at 3:32 pm, Mar 09, 2021 321-119 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.03.09 14:09:22 -09'00' Stan Golis (880) BOPE test to 3000 psi. Annular to 2500 psi. X DSR-3/11/21 Borealis Oil DLB 10-407 DLB03/10/2021MGR10MAR21 Yesion Required? Comm 3/11/21 dts 3/11/2021 RBDMS HEW 3/12/2021 Re-complete to Kuparuk Well: Z-11a PTD: 205-031 API: 50-029-22053-01 Well Name:Z-11a API Number:50-029-22053-01 Current Status:Operable Producer 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:205-031 First Call Engineer:David “Brodie” Wages 713.380.9836 (M) Second Call Engineer:Brian Glasheen 907.545.1144 (M) Current Bottom Hole Pressure:3673 psi @ 8800’ TVD BHP Survey 11/2019 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 Production Rates Post RWO 375 bopd 125 bwpd 1000 scf/stbo GOR Brief Well Summary Drilled in 2006, Z-11A has been a strong standalone Ivishak well, producing 1.27 mmbo to date. It has little utility left in the Ivishak in the current development plan and has relatively low ontime due to high watercut (~ 95%) and TGOR constraints through the EWE LDF. At this time, no further plans are in place for further Ivishak development. The proposed work will temporarily abandon the Ivishak interval and recomplete the well to be a Kuparuk producer. Z-11A is located in the southeast part of the Borealis pool that may contain additional potential for development. Notes Regarding Wellbore Condition 9-5/8” Production Casing cemented with 1979 cf Permafrost cement Shoe @ 9396’ MD (8665’ TVD) Calculated TOC in 12.25” hole @ 3077’ MD (3070’ TVD) Top of Kuparuk @ 7170’ MD (6669’) 10/29/2001: Camera confirm liner collapse in motherbore 7/1/2003: Coil FCO, lots of sand and gravel 1/2006: CTD sidetrack, good returns during liner cement job Multiple acid jobs to good effect, wax bead diversions successful, treated well but had little effect on production SIT performed 2Q 2009, water rate up oil rate down post SIT Early 2011 oil rate up, water rate constant, likely MI buzz from Z-12 8/2016: 35’ ADP to little effect 11/2019: CMIT-TxIA passed to 3500 psi, MIT-OA to 1200 psi passed Scope of Work The primary objective of the RWO is to temporarily abandon the Ivishak via bridge plug and recomplete this well as a Kuparuk producer. Pre Rig Prep Work: 1) MIT-OA. PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function and back out all LDS 2) SL: D&T, confirm SSSV status 3) MIRU E-Line, Set bridge plug @ ~9200’ in tubing tail, CMIT-TxIA to 3500 psi, cut tubing above packer 4) SL: Dump bail Sand/Cement on CIBP, lockout SSSV Proposed RWO Procedure: 1) MIRU 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. DLB Borealis -00 Ivishak Borealis pool t Re-complete to Kuparuk Well: Z-11a PTD: 205-031 API: 50-029-22053-01 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 5) Install scoop guide 6) Run 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. ~7170’-7225’ MD Kuparuk C sands, 6669’-6718’ TVD b. ~7242’-7258’ MD Kuparuk A Sands, 6734’-6748’ TVD ** Note, all work after this point will be covered under a separate Sundry request ** 5) Frac Kuparuk Interval a. ~120,000# 16/20 Ceramic b. ~30% Resin coated c. ~28# X-link frac fluid 6) SL install LGLVs 7) Flow well back to well testers for post frac cleanup 8) Handover to ops 9) Schedule SVS testing with AOGCC as per regulations CBL to AOGCC. Separate fracturing sundry. Re-complete to Kuparuk Well: Z-11a PTD: 205-031 API: 50-029-22053-01 Current WBD: Re-complete to Kuparuk Well: Z-11a PTD: 205-031 API: 50-029-22053-01 Proposed WBD: Re-complete to Kuparuk Well: Z-11a PTD: 205-031 API: 50-029-22053-01 BOP Schematic: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: March 8, 2021Subject: Changes to Approved Sundry Procedure for Well Z-11ASundry #: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 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Ope i ri /1 ❑ 0 Suspend ❑ Perforate Other Stimulate ❑ 9t�;hyt Alter Casing ElChan A 11 1e rih�- ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 205-031 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6API Number: 50-029.22053-01-00 1 7 Property Designation (Lease Number): ADL 028262 8. Well Name and Number: PBU Z-1 1A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10102 feet Plugs measured None feet true vertical 9162 feet Junk measured 9477 feet Effective Depth: measured 10067 feet Packer measured 9092 feet true vertical 9143 feet Packer true vertical 8393 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 40-120 40-120 0 0 Surface 2621 13-3/8" 39-2660 39-2660 5020 2260 Intermediate 9359 9-5/8" 37-9396 37-8665 6870 4760 Liner 519 7" 9142-9661 8437-8902 7240 5410 Liner 625 3-1/2" x 2-7/8" 9477-10102 8737-9162 Perforation Depth: Measured depth: 9600-9888 feet True vertical depth: 8848-9045 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 35-9621 35-8867 Packers and SSSV (type, measured and 4-1/2" Baker S83 Packer 9092 6393 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 58 182 296 1518 303 Subsequent to operation: 101 280 806 1594 295 14. Attachments:(rv,irea par 20 MC 25.070.25.071,325.263) 15. Well Class after work. Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 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: WA Authorized Name: Peru, Cale Contact Name: Peru, Cale Authorized Title: Petroleum E ear Contact Email: Cale.Peru@bp.com Authorized Signature: Date: ao Contact Phone: +1 9075644522 Form 10-404 Revised 04/2017 i/4/ M4R-?. d RBDMS.(A/JAN 2 32020 Submit Original Only Daily Report of Well Operations PBU Z -11A ACTIVITVDATF CI IMIIII ADV ***JOB STARTED ON 29 -DEC -2019*** (HES Perforating) PERFORATE 9632'- 9664' W/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN, CCL TO TOP SHOT = 27, CCL STOP DEPTH = 9629.3'. PERFORATE 9600'- 9632'W/ 2" MAXFORCE, 6 SPF, 60 DEG PHASE GUN, CCL TO TOP SHOT = 27, CCL STOP DEPTH = 9597.3'. ALL LOGS CORRELATED TO SLB CNL DATED 27 -JAN -19. 12/29/2019 ***JOB CONTINUED ON 30 -DEC -19 WSR*** ***JOB CONTINUED FROM 29 -DEC -2019*** (HES PERFORATING) FINISH RIGGING DOWN. FINAL TWO = 450/350/50. 12/30/2019 ***JOB COMPLETE ON 30 -DEC -2019*** IT/I/O = 270/1070/670. Temp = 112°. WHPs (eval high OAP). post OPs bleed. ALP =1070 psi, AL open @ casing valve. Heater in wellhouse. Treecap bled to 0 psi. 1/13/2020 1 SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:30 I" 13-3/8' CSG, 689, L-80, D =12.415'2660' Minimum ID = 2.377" @ 9618' 3-1/2" X 2-7/8" XO TOP OF 7" LNR 47#, NT -80S, D = 8.681' TOP OF 3-12' X 2-7/8' L 1 9142' 3-112 LNR, 8.81#, 13CR STL, —j 9678' .0087 bpf, D = 2.992' 2- TBG, 12.69, L-80, .0152 bpf, D = 3- 1 . 9621' TOP OF CEMENT (04111/05) 9655' CTM BKR WHIPSTOCK w/2 RA TAGS9655' CTM RA TAG 9664' 7" LNR, 26#, L-80, .0383 bpf, D = 6.276' —9655 PERFORATION SUMMARY REF LOG: MCNL-GR ON 0127/06 ANGLE AT TOP PERF: 26° @ 9600' Note: Referto Prodra:8on DB br historical perf data S12E SPF INTERVAL OpnfSqz SHOT SOZ 2' 6 9600-9664 O 1229/19 6083 2' 6 9671-9679 O 0820116 4 2' 6 9688-9699 O 0820116 2' 6 9709-9725 O 08/20/16 RM 16 2' 6 9750-9778 O 0128/06 DMY 2' 6 9794-9804 O 0128106 OTIS 2' 6 9822-9844 O 0128/06 2" 6 9870-9888 O 0128/06 Z-1 1A SAFETY NOTES: CHROME LNR — 14-12' OTIS SSSV NP, D = 3.813' 1 GAS I FT MAMIRR C ST MD TVD DEVI TYPE VLV LATCH I PORT DATE 6 2964 2963 7 OTIS DOME RM i6 12/06/07 5 6083 5698 29 OTIS GEJ RM 16 12/06/07 4 7127 6630 25 OTIS DMY RA WA 3 8093 7496 27 OTIS DOME RM 16 12/06/07 2 8649 7995 26 OTIS DMY RA 0 1 9054 8358 26 OTIS SO RM 20 12/06/07 1 9477' 1 RUBBER DEPLOY OTIS XN IX0 BEHIND CT LNR 1 V016" 1—j3-12- X 2-7/8" XO, D= 2.377' I 9623' 412' WLEG, D=3.958' 9621' E -MD Ti LOGGED 10/08/98 MLLOUT WINDOW (Z -11A) 9661' - 9668' (OFF MWD LOG) 12-78' LNR, 6.5#, 130R STL, .0058 bof. D = 2.441' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS. 06!18190 PGS ORIGINAL COMPLETION 0929/15 JMGJMD PULLED PX PLUG 8 XO EDIT 0128106 ORDICI CTD SIDETRACK 07/05/16 CP/JMD UPDATED PERF REF LOG 12/1517 TEUPJC GLV GO 12/06/07 0824/16 JCF/JMD ADPERFS 08/20/16 1211517 BSEIPJC FISH (121717) 01/15/20 W/JMD ADPERFS 1229/19) 0817111 CG PJ GLV CORRECTION 1216/07 01/1520 DD/JMD ADDED BF, COND DEPTH, FISH DEPT 05/08/15 MJGPJ SET PX PLUG (SECURE) PRUDHOE BAY UNIT WELL: Z -11A PEFJXTNo:R2050310 API No: 50-029-22053-01 1,711 N,R12E, 980' FNL 83198 BP Exploration (Abska) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-031 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22053-01-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU Z-11A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL E I V E D 11.Present Well Condition Summary: Total Depth: measured 10102 feet Plugs measured feet SEP p 2 2016 true vertical 9162 feet Junk measured 9477 feet )L f 2 U Effective Depth: measured 10067 feet Packer measured 9090 feet AO�1U CC true vertical 9143 feet Packer true vertical 8390 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#A-53 40-120 40-120 1533 515 Surface 2620 13-3/8"68#L-80 38-2658 38-2658 5020 2260 Intermediate 9360 9-5/8"47#L-80 37-9397 37-8666 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9671-9679 feet feet 9688-9699 feet 9709-9725 feet 9750-9778 feet 9794-9804 feet 9822-9844 feet 9870-9888 feet True vertical depth: 8911-8918 feet feet 8925-8934 feet 8942-8954 feet 8972-8989 feet 8999-9004 feet 9013-9023 feet 9036-9045 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 . ._ 5,,,,9621.,._...,. .._ 35-8866 Packers and SSSV(type,measured and 4-1/2"Baker SB3 Packer 9090 8390 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED FEE 1 3 2 21 ; Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 102 530 464 1456 235 Subsequent to operation: 333 743 968 1363 241 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ® Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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 Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ✓N4 Phone +1 907 564 4424 Date 9/20/16 Form 10-404 Revised 5/2015 17 7— (� Oat� �`%l 1 c,, RBDMS 0/SEP 1 6 2016 Submit Original Only • • CD Q.to O O O p car- cocfl � N p � i CO1. MON O� (O OM m (Oco c\I O O CO c, CO CO N N CO N LO CO O CO CO CO CO CO CA CO N— 00 N CO 00 CO O CO H 00 f� O CO N- CO CO CO C() CO CO V CO CO CO CO CO CD c, 00 CO Cn C)) CO (0 N CO M (0 O O S N CA CA CT) O CA v a i I i I i i . Q QCO CO O 00 I� 11') DI IV' COCOCO CO N CT) 0) 0') • d CO C'7Et 00 0 LU O O CO O 0 C) Q J J 00 co M I N. � N • 00 �Y cri r N °°00 U _ O co N N 00 (3) N N CO V t O OM �O N CO M CO C CO CO CO r "Ct 00 J N O "Cr O W Ca U W Z c W w W w m ODI— Z_ Z_ Z_ D • • g 2 a- G 0 - -- / / / o ± � co+ / 0 /• a L » pm as as 1 )' O 7 0 ? a a- ® 3 D c c . » f % 2 \ k EE = cC2CD o ( G - c - o 0) (0 pJ 0 co- Z ƒ c- £ 2 E g 0 - / a ■ t / E � R � 2 C » (1) A _ . § % Y ) » � = / / 30 / $ CO ■ < 5 0 o o I * % / $ ƒ 6 CO.) 0. 2 - ; e e ' m ® p < / G / / \ f f p _ a / g ._ eea 5 0 _1 c $ c 2 2 � e « $ • o + � R 2 / �\ E / / o0. a7 \ / / f & / f / co -c o t . E t O b \ ® @ O a) / 2 ƒ G %3 _' q t CC 2 0) . -0 & .c = o = ® < ' % \ k \ƒ % \ § / CU c« . o R- ( 0 2 \ CI . 2 : - CC wm # �� m / 2 R / § o k _ 2 0 _I &% § .e o ) / a = or m a o / = f \ 2 2 % 2 / 7 :ƒ 17 e 0 f U e / mak ƒ & .\...Co 0 f7 2 _ 0 � 2 ® O m c ® a U-2 0 C 0 ± 2 / fo 3I- f27 " ° — " — ' 0 � U : U -3 o _1 o co E o 2 t • 2 / \© e / CV C ƒ / \ \ / « TREE= 4-1/16"CNV WELLHEAD= RC • „ NOTES: CHROMELNR." ACTUATOR= O Z 11 A " 'KB ELEV= 91.7' _ _r_ BF.ELEV= 55.3' - KOP= 3107 Max Angle= 620 9824' --"CONDUCTOR, ? 2076' 4 912"OTIS SSSV NP =3.813" ,.__.._ Datum MD= 9649' —#• 1 Datum TVD= 8800'SS ID= • r � E ¢ GAS LFT MANDRELS 13-318"CSG,68#,L-80,D=12.415' ( 2660' ST MD TVD DEV TYPE VLV LATCH .FORT DATE 6 2964 2963 7 OTIS DOVE RM 16 12/06/07 T I 5 6083 5698 29 OTIS GEN RM 16 12/06/07 4 7127 6630 25 OTIS DANRA NA 3 8093 7496 27 OTIS DONE RM 16 12/06/07 Minimum ID =2.377"@ 9618' 2 8649 7995 26 OTIS DMY RA 0 3-1/2"X 2-7/8"XO 1 9054 8358 26 oTIS SO RM I 20 12/06/07 9084' I-44-1/2"PARKER 8WS NP,13=3.813" 1 z'-" 9092' i--19-5/8"X 4-1/2'BKR SB-3 PKR TOP OF 7"LNR-1— 9142• 9-5/8'CSG 47#,NT-80S,D=8.681" H 9396'I ? +i FISH-RUBBER E_ENENT FROM VVRP(12/07/07) I f TCW OF 3-1/2"X 2-7/8"LNR H9477' 9477 H 3.70'DEPLOY SLV,13=3.000" 9495' --I3-1/2"I-ES X MP,ID=2.813' i I I 9595' 1_14-1/2-PARI(ER SWS NP,003.813" J BEHIND I I CT LNR 3-1/2'LNR 8.89#,13CR STL, I- 9618' 9616' 1_14-1/2"OTS XN NP,MAILED D TO 3.80"(04/06/05)1 .0087 bpf,D=2.992" —1 14-1/2'TBG,12.6#,L-80,.0152 bpf,ID=3.958" H 9621" t 9618' �3 1/2"X 2-718"XO,13=2.377" �---- 9623` 1-14-1/2-WLEG,13=3.958" 1 f TOP OF CEMENT r(04/11/05) H 9655'CTM 9621' 1--1 ELMD TT Loco 10/06/98 I BKR VN-IPSTOCK w/2 RA TAGS 1--J 9655' CTM [ fuLOUT WINDOW(2-11A) 9661'-9668'(OFF MWD LOG) RA TAG H 9884' 1 7'LW,26#,L-80, .0383 bpf,13=6.276" H -.9655iz 11666, ` '1'1'1'1'1'1'1'1 ` PERFORATION SUMMARY X111111111111111 REF LOG:MCNL-GR ON 01/27/06 11111111 1111111 11111111 ANGLE AT TOP PERF: 32°@ 9671' '111111111111111 Note:Refer to Production DB for historical perf data '111111 1111411111 SIZE SPF IYTH2VAL OpnlSgz SHOT SQZ 4.1•••• .111..11 2" 6 9671-9679 0 08/20/16 1•/.,, ,...4 2' 6 9688-9699 0 08/20/16 2" 6 9709-9725 0 08/20/16 2" 6 9750-9778 O 01/28/06 �. 2" 6 9794-9804 0 01/28/06 PBTD H 10067' �� 2" 6 9822-9844 0 01/28/06 12-7/8"LW,6.5#,13CR STL,.0058 bpf,D=2.44- 1-I 10192'- 2" 6 9870-9888 0 01/28/06 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT06118/90 PGS ORIGINAL COMPLETION '09129/15 JMG/JMD PULLED FSC PLUG&XO EDIT WELL. Z-11A 01/28/06 MIMI CTD SIDETRACK 07/05/16 CP'JMD UPt7ATED F iF REF LOG 12/15/07 T13_/RIC GLV C/O(12/06/07) 08/24/16 JCF/JMD ADMITS(08/20/16) AA No'"2050310No: 50- 9- 12/15/07 BSE/PJC FISH(12/07/07) API 029 22053-01 08/07/11 SCG/PJC GLV CORRECTION(12/06/07) SEC 19,T11N R12 980'FN_&3198'Fa 05/08/15 MIC/PJC SET PX PLUG(SECUREt BP Exploration(Alaska) ` ct F - r4 Regg, James B (DOA) ZeScslo From: Cook, Guy D (DOA) Sent: Tuesday, August 09, 2016 1:03 PM To: AKOPSGC2FieIdMTL@bp.com; Akopsgc2wellpadlead@bp.com; AKOPSGC2FieIdOMTL1 @bp.com ��I� 1(0 Regg,Cc: James B (DOA) Subject: PBU Z-pad Deficiency Reports Attachments: Deficiency_Report_PBUZ-04 .xlsx; Deficiency_Report_PBUZ-11.xlsx; Deficiency_Report_PBUZ-13.xlsx; Deficiency_Report_PBUZ-15.xlsx; Deficiency_Report_PBUZ-26.xlsx Christy Lawler/Dave Spall, Attached are the deficiency reports for the PBU Z-Pad wells with incorrermit to drill numbers on their well signs. This is provided for your records and to ensure the deficiency is corrected. Please provide photo evidence of the well sign after installation when you return the completed deficiency report(date corrected). If you have any questions, please feel free to call or email. Thank you, Guy Cook Petroleum Inspector AOGCC 907-227-2614 JAN017 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Cook at 907-659-2714 or guy.cook@alaska.gov. 1 • State of Alaska Oil and Gas Conservation Commission 1g,--- 1t)( Deficiency Report Location: PBU Z-11A Date: 8/8/2016 PTD: 2050310 - Operator: BP Exploration Alaska Type Inspection: SVS Operator Rep: Joseph Perkowitz Inspector: Guy Cook - Position: GC2 Wellpad Lead Operator Op. Phone: 907-659-4128 Correct by(date): 9/8/2016 - Op. Email: Akopsgc2wellpadlead@bp.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Wellhouse sign needs to be updated with correct permit to drill number. - Operator Rep Signatures: AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 12/2015 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 09, 2015 9:42 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Ops Lead;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Burton, Kaity;AK, OPS Well Pad Z;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA) Subject: OPERABLE: Producer Z-11A(PTD#2050310) Passing MIT-T and CMIT TxIA Attachments: image001.png; image002.png All, Producer Z-11A(PTD#2050310) passed a MIT-T and a CMIT T x IA on 05/09/2015. The passing test indicates two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed • A SSSV is not required There is currently a tubing tail plug set in the well,for upcoming surface equipment repair. Please do not attempt to place well on production until plug is pulled. Thank you, Kevin Parks (Atte/nate Whitney Pettus) BP Alaska-Well Integrity Coordinator �1Erj W\ ,�Q�` GVVGlobal Wells � � �/�( Organization Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator(a)bp.com Fro • 'K, D&C Well Integrity Coordinator Sent: Tues.. ,, &•ril 21, 2015 7:38 PM To: AK, OPS GC2 OS', - •PS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C 7 - '.e Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB a , ells Opt Engr; Burton, Kaity; AK, OPS Well Pad Z; 'chris.wallace@alaska.gov'; 'Regg, James B (DOA) 1LL_e•' • alaska..ov)'; AK, OPS GC2 Ops Lead Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Proje . . -II Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus, Whi = • Hidalgo, Ramon Subject: UNDER EVALUATION: Producer Z-11A(PTD #2050310) Inner A . s exceeded MOASP All, 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, April 21, 2015 7:38 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity;AK, OPS Well Pad Z;Wallace, Chris D (DOA); Regg,James B (DOA);AK, OPS GC2 Ops Lead Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus, Whitney; Hidalgo, Ramon Subject: UNDER EVALUATION: Producer Z-11A (PTD#2050310)Inner Annulus exceeded MOASP Attachments: image001.png All, Producer Z-11A(PTD#2050310) inner annulus exceeded MOASP on April 18, 2015 with T/1/0= 2120/2080/200 psi. Due to surface constraints,the well will not be brought online within 28 days for diagnostics. The well is reclassified as Under Evaluation until it can be secured with a downhole plug. Plan Forward: • 1. Slickline: Secure well with downhole plug 2. Fullbore: MIT-T Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED APR 2 3 2015 (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator C71A4O'g r :dt On WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - Q~ ~ Well History File Identifier OrganlZing (done) ~..o,aea imiiiiiuiiuim o a.s~~~eed~ iiiuiiii~iiiiuu RESCAN DIGITAL DATA OVERSIZED (Scannable) C for Items: Diskettes, No. ' ^ Maps: Greyscale Items: ` ~0~~ ^ Other, No/Type: ^ Other Items Scannable by UU a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: 5 /s/ Project Proofing III IIIIII VIII II III BY: Maria Date: ~ V /s! Scanning Preparation _~ x 30 = ~a + ~ 3 =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: `j ~` .,, D U /s/ Production Scanning Stage 1 Page Count from Scanned File: --_,~- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~ ~, ~ $ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO r BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIII1111 VIII BY: Maria Date: /s/ Comments about this file: o~,~.~~,~k.a iiiuiiiuiiumii 10/6/2005 Well History File Cover Page.doc 1 c • STATE OF ALASKA RE C E I V E D ALA. OIL AND GAS CONSERVATION COM ION AUG 0 8 2012 REPORT OF SUNDRY WELL OPERATIONS A 1. Operations Abandon 11 Repair Well Li Plug Perforations U Perforate U Other Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other El Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 115 Exploratory ❑ 205 -031 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service [❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22053 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: -, — ADL0028262 PBU Z -11A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): •r To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10102 feet Plugs measured None feet true vertical 9161.63 feet Junk measured 9477 feet Effective Depth measured 10067 feet Packer measured See Below feet true vertical 9142.82 feet true vertical See Below feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.1# H-40 30 - 110 30 - 110 1530 520 Surface 2631 13 -3/8" 68# L -80 29 - 2660 29 - 2659.81 5020 2260 Intermediate None None None None None None Production 9368 9 -5/8" 47# NT8OS 28 - 9396 28 - 8665.03 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L -80 27 - 9621 27 - 8866.42 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker SB3 Packs 9092 8392.15 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 34 240 282 279 Subsequent to operation: 32 360 307 250 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development Q r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — le Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summer' = Title Petrotechnical Data Technician Signatu /£ Phone 564-4035 Date 8/8/2012 RI3DMS AI !. 2012 gr+ v L r ,,r g %� - ti Form 10-404 Revised 10/2010 e 1 i { r' S ubmit Original Only y �`� • • Perforation Attachment ADL0028262 Pelf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base Z -11A 1/28/06 PER 9750 9778 8971.56 8989.28 Z -11A 1/28/06 PER 9794 9804 8906.83 8912.23 Z -11A 1/28/06 PER 9822 9844 8921.25 8931.74 Z -11A 1/28/06 PER 9870 9888 8944.44 8953.55 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADL0028262 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20" 91.1# H -40 30 - 110 30 - 110 1530 520 LINER 526 7" 26# L -80 9142 - 9668 8437 - 8908.41 7240 5410 PRODUCTION 9368 9 -5/8" 47# NT8OS 28 - 9396 28 - 8665.03 6870 4760 SURFACE 2631 13 -3/8" 68# L -80 29 - 2660 29 - 2659.81 5020 2260 TUBING 9594 4 -1/2" 12.6# L -80 27 - 9621 27 - 8866.42 8430 7500 LINER 141 3 -1/2" 8.81# 13CR STL 9477 - 9618 8737.39 8772.03 LINER 484 2 -7/8' 6.5# 13CR STL 9618 - 10102 8772.03 9161.63 • 1 1 A TREE = 4- 1/16" CM/ WELLHEAD = FMC SAFETOTES: ** *3 -1/2" X 2 -7/8" CHROME LN OTIS I ACTUATOR = Z 1 A KB. ELEV 91.7' BF. ELEV = 55.3' KOP = 3102' Max Angle = 62 @ 9824' Datum MD = 9649' 2076' H4-1/2" OTIS SSSV NIP, ID = 3.813" Datum TVD = 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 2660' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2964 2963 7 OTIS DOME RM 16 12/06/07 5 6083 5698 29 OTIS GEN RM 16 12/06/07 4 7127 6630 25 OTIS DMY RA N/A 3 8093 7496 27 OTIS DOME RM 16 12/06/07 Minimum ID = 2.377" @ 9618' 2 8649 7995 26 OTIS DMY RA 0 TOP OF 2 -7/8" LINER 1 9054 8358 26 OTIS SO RM 20 12/06/07 I 9084' I _14 -1/2" PARKER SWS NIP, ID = 3.813" I �Zt oM4 9092' J -19-5/8" X 4 -1/2" BKR SB -3 PKR I TOP OF 7" LNR I 9142' ? 1_I FISH - RUBBER ELEMENT FROM WRP (12/07/07) I 9 -5/8" CSG, 47 #, NT -80S, ID = 8.681" H 9396' ' 9477' J-13.70" DEPLOY SLV, ID = 3.000" I 4 A � ' I 9477' I -1TOP OF CEMENT LNR I 94 95' HES X NIP ID = 2 I 1 1 1-1443:11//22:: 1 �1 � P A RK ER 5WS NIP 3 . 813" (BEHIND PIP 9595 ( PIPE) 1 1 1 1 NIP, = 80 " 04/06/05 1 4 1/2" OTIS XN N MILLED ID 3. I 9616' ( ) I3 -1/2" LNR, 8.81 #, 13CR STL, .0087 bpf, ID = 2.992" I 9618' (BEHIND PIPE) I V ∎1. 1111' 9618' 1-13-1/2" X 2 -7/8" XO, ID = 2.441" I I4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9621' ∎-� N Ws 9623' H4 -1/2" TBG TAIL ID = 3.958" (BEHIND PIPE) I 111 1111 ■1/ 111 1 1 1 1 1 1 1 1 1 1 1 1 I 9621' H ELMD TT LOGGED 10/06/98 (BEHIND PIPE) I 111 • 1111 1 1 11 I TOP OF CEMENT (04/11/05) H 9655' CTM 0*. 1 1 <, I BKR WHIPSTOCK w /2 RA TAGS H 9655' CTM I °' .7�11', 1 �' MILLOUT WINDOW (Z -11 A) 13 ' 1∎• 9661' - 9668' (OFF OF MWD LOG) RA TAG I 9664' ,' t � . , 11111111 X 11111111 11111111. * 11111111 I 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I-1 10306' *jljljljljl01 \1111111 111111 PERFORATION SUMMARY 1 / 1 1 1 1 1 / 1 / tf REF LOG: BHCS ON 06/28/90 40.001 11.. • .411 ANGLE AT TOP PERF: 49 @ 9750' � . 41141 •• Note: Refer to Production DB for historical pert data ■4444440evi I PBTD H 10067' 'Iv SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 9750 - 9778 0 01/28/06 2 -7/8" LNR, 6.5 #, 13CR STL, .0058 bpf, ID = 2.441" I—I 10102' I 2" 6 9794 - 9804 0 01 /28/06 2" 6 9822 - 9844 0 01 /28 /06 2" 6 9870 - 9888 0 01/28/06 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/18/90 PGS ORIGINAL COMPLETION 12/15/07 TEL /PJC GLV C/O (12/06/07) WELL: Z -11A 01/28/06 NORDIC1 CTD SIDETRACK 12/15/07 BSE/PJC FISH (12/07/07) PERMIT No: Y 2050310 01/30/06 RCC /TLH DRLG DRAFT CORRECTIONS 08/07/11 SCG/ PJC GLV CORRECTION (12/06/07) API No: 50- 029 - 22053 -01 02/13/06 KSB /PAG GLV C/O (02/11/06) SEC 19,T11N,R12E, 980' FNL & 3198' FEL 06/04/06 KSB /PAG GLV C/O (05/31/06) 11/20/07 SWC /SV GLV C/O (11/11/07) BP Exploration (Alaska) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well jJ Plug Perforations U Perforate Li Other ❑ SEALTITE Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development © Exploratory ❑ ° 205 -031 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 22053 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: v ADL 028262 PRUDHOE BAY FIELD / PRUDHOE OIL POOL 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): PBU Z -11A 11. Present Well Condition Summary: Total Depth measured 10102 feet Plugs measured NONE feet true vertical 9162 feet Junk measured 9477 feet Effective Depth measured 10067 feet Packer measured 9092 feet true vertical 9143 feet true vertical 8392 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91# H -40 30' -110' 30' -110' 1490 470 Surface 2631' 13 -3/8" 68# L -80 29' -2660' 29'-2660' , ---- .5.82•fJ - 2260 Production 9368' 9 -5/8" 47# L -80 28'-9396' 28'-8665' 6870 4760 Liner 513' 7" 26# L -80 9142' -9655' 8437' -8897' 7240 5410 Liner 141' 3 -1/2" 8.81# 13CR STL 9477' -9618' 8737' -8864' Liner 484' 2 -7/8" 6.5# 13CR STL 9618'- 10102' 8864' -9162' Perforation depth Measured depth SEE ATTACHED feet (r��q True Vertical depth feet S wA NED JUN Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27' -9621' 27'-8866' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR SB -3 PKR 9092' 8392' 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): JUN 1 9 2012 Treatment descriptions including volumes used and final pressure: CC 13. Representative Daily Average Product - ion or Injection Injection D to Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 152 497 6 0 2 354 Subsequent to operation: 35 223 3 04 279 14. Attachments: 15. Well Class after work: • Copies of Logs and Surveys Run Exploratory ❑ Development © • Service ❑ Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil © Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nita Summerhays Printed Name '. ita Summ •rhays Title Petrotechnical Data Technician j /� Signal /j�J / / /Iv� // �- Phone 564 -4035 Date 06/13/2012 WIDMS JUN 2 0 2012 A*frrt-3eit 1I/ �� / � Form 10 -404 Revised 11/2011 ..0 Submit Original Only • • 1 ! o01M1et In' 0 N ef,N c M cci1 m O O O m oc a of d, 1 ' 'CI �' Q, V) to W ' r 1 1 N ti C e'M I t o1 of O O 0 y'Z O I W > I ! n, H' w J O 0 ! 0 ■ 0 ''� C0 W,W W 010 moio)o)oi Z,m as �j JOC u W W X1 LL iW' J J N N O 0 O, Ce l-' a-'w'w10 O y. 'IUWHOOW'W, ea m0zlz> >ix a 'a WU J W'J 4 4 O a H'H Z CL OC'm m m'm'N CO c/) E Q. 1 Q I -21=+'-'''. 1 : 43 .!!! ) . 0 ) 0) CD CD 1 r o Q r 1 1 1 N O H d N Q O . : y Q a m ! a LL H W O i WI U' r' to 1 ' 1 w Q. .0 O 0, W1W t mmmm ' LU ~~ a a a'a a', 'J 1- _J cc �w ;OO mcomm aN cn , J y O O C C (' (, O J -.1-.1 � 1ap aolao O Q Q Q O N N N N w 'J JI Z' V,V V J r r r r ci '0 W W IJ < = L Z a I C' C I 0. 112',Z m QO 0. C0 rE2 ,d d Lulu .wa O Q Q'm MIT. w 2 212,0 E Q ' , QQQ Zrrrr tLa1n0 rey) CO i < I Q I ' , m m;U. Li 2;2 0 • • Z -11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Ie EVENT SUMMARY 1d4 0 5/20/2012 T/I/0= 1890/670/630. Temp = SI. Bleed IA & OA to 0 psi, assist Sealtite. (Seal tite treatment). ALP @ 1690 psi & SI @ IA casing valve. IA FL © 4343' (233'), OA FL @ 54' (4 bbl). Bled OAP from 630 psi to 40 psi in 20 minutes. Bled IAP from 670 psi to 450 psi in 3 hours 30 minutes. Rig down for end of job, (PPPOT -IC PASSED, 3500 psi w/ 0 psi loss in 1 hour). Final WHP's = 1890/450/40. Job Complete. SV & WV = C. MV &SSV = 0. IA & OA = OTG. NOVP. 15:45. 5/20/2012 Z -11 had an inner casing hanger void leak that was allowing the. IA to cnmmunicatP with the OA at a rate that would not allow BP to prodiir.e the well On location flushed diesel through the void to clean out the void. Pumped diesel into the void and obtained a leak rate of 350psi pressure loss at 3,500psi in 5 i. the Pumped GI Flo into the void and obtained a seal at 2,000psi. s Staged t e P P 9 Y re ure up in i increments n h v id. Once 3,500psi ss p 500 s on the o si was achieved p P p monitored the pressure for 1 hour no leak, bleed the pressure on the void to 2,000psi and trapped the pressure on the void. 5/21/2012 T /I /0 = 1890/460/70. Temp =SI. OART (Eval IAxOA Post Seal Tite Treatment). AL is connected, SI @ casing valve. ALP =1690 psi. IAP increased 10 psi, OAP increased 30 psi overnight. IA FL @ 4200', OA FL near surface. Increased IAP, using AL, to 1100 psi. During IA pressurization, OAP increased 20 psi. Bled OAP from 90 psi to 10 psi in 20 min, gas. Monitor for 1 hr. IAP unchanged, OAP unchanged. Hung OART tags. Job complete. Final WHPs= 1890/1100/10. (0200 hrs). SV,WV= Closed. SSV,MV =Open. IA,OA =OTG. NOVP. FLUIDS PUMPED LITERS <2 GLY -FLO <2 TOTAL TREE = 4 -1/16" CM/ WELLHEAD = FMC • SAFET NOTES: *"*3 -1/2" X 2 -7/8" CHROME LNR*"* I ACTUATOR = OTIS Z -11 A KB. ELEV = 91.7' BF. ELEV = 55.3' KOP = 3102' Max Angle = 62 @ 9824' I 2076' H4 -1/2" OTIS SSSV NIP, ID= 3.813" Datum MD = 9649' Datum TVD = 8800' SS • GAS LIFT MANDRELS 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 2660' ST MD ND DEV TYPE VLV LATCH PORT DATE 6 2964 2963 7 OTIS DOME RM 16 12/06/07 5 6083 5698 29 OTIS GEN RM 16 12/06/07 4 7127 6630 25 OTIS DMY RA N/A 3 8093 7496 27 OTIS DOME RM 16 12/06/07 Minimum ID = 2.377" @ 9618' 2 8649 7995 26 OTIS DMY RA 0 TOP OF 2 -7/8" LINER 1 9054 8358 26 OTIS SO RM 20 12/06/07 I 9084' I _14 -1/2" PARKER SWS NIP, ID = 3.813" 1 �� 9092' 1-19-5/8" X 4-1/2" BKR SB -3 PKR I TOP OF 7" LNR I 9142' % '; ? 1_I FISH - RUBBER ELEMENT FROM WRP (12/07/07) I 19 -5/8" CSG, 47 #, NT -80S, ID = 8.681" H 9396' 9477' H3.70" DEPLOY SLV, ID = 3.000" I � � � 1 9477' HTOP OF CEMENT LNR I • 71 ',I 9495' 1-13-1/2" HES X NIP, ID = 2.813" I ∎ i I 9595' 1_I4 -1/2" PARKER SWS NIP,ID= 3.813" (BEHIND PIPE) ■4 1 ( 9616' I_ 4 -1/2" OTIS XN NIP, MILLED ID = 3.80" (04/06/05) I3 -1/2" LNR, 8.81 #, 13CR STL, .0087 bpf, ID = 2.992" I 9618' � � (BEHIND PIPE) • 1 1 1 o• 1• 9618' H3-1/2" X 2 -7/8" XO, ID = 2.441" I I4 -112" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" 1-1 9621' ;.,$ IO Os 9623' 1-14-1/2" TBG TAIL ID = 3.958" (BEHIND PIPE) I 111 1••1 ■••• ••• 1 1 1 9621' H ELMD TT LOGGED 10/06/98 (BEHIND PIPE) 1 •• 1111 1 1 1 !TOP OF CEMENT (04/11/05) 1 9655' CTM 1 ∎1111• 11111 I BKR WHIPSTOCK w /2 RA TAGS H 9655' CTM I v1, ♦' MILLOUT WINDOW (Z -11A) 44 RA TAG I-1 9664' 1 =• , � f . 41 9661' - 9668' (OFF OF MWD LOG) ,o ,%F 4 11111111 111 1 1 11111111 1111111 • 11111111 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" 10306' , 11111111 I H ' X1111111111111 1111 PERFORATION SUMMARY 11111111111 REF LOG: BHCS ON 06/28/90 1 ∎�1 1 . ; x.1 ANGLE AT TOPPERF: 49 @ 9750' 11v . ••1 •� • Note: Refer to Production DB for historical pert data 44 ♦444 • .a � ♦1 IPBTD H 10067' I �� SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 9750 - 9778 0 01/28/06 12-7/8" LNR, 6.5 #, 13CR STL, .0058 bpf, ID = 2.441" 11 10102' 1 2" 6 9794 - 9804 0 01/28/06 2" 6 9822 - 9844 0 01/28/06 2" 6 9870 - 9888 0 01/28/06 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/18/90 PGS ORIGINAL COMPLETION 12/15/07 TEL /PJC GLV C/O (12/06/07) WELL: Z -11A 01/28/06 NORDIC! CTD SIDETRACK 12/15/07 BSE/PJC FISH (12/07/07) PERMIT No: 2050310 01/30/06 RCC /TLH DRLG DRAFT CORRECTIONS 08/07/11 SCG/ PJC GLV CORRECTION (12/06/07) API No: 50- 029 - 22053 -01 02/13/06 KSB /PAG GLV C/O (02/11/06) SEC 19,T11N,R12E, 980' FNL & 3198' FEL 06/04/06 KSB /PAG GLV C/0 (05/31/06) 11/20/07 SWC /SV GLV C/O (11/11/07) BP Exploration (Alaska) Producers with sustained casing pressgn IA and OA due to proration Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, January 18, 2011 1:40 PM �e-t IZ r To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Ramsay, Gavin; Kirchner, Carolyn J; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 15 -18. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 04 -24 (PTD #1853010) K -20C (PTD #2080490) EB 7 '' al ' b V -02 (PTD #2040770) Z -14B (PTD # 2060990) The following producer was found to have sustained casing pressure on the OA during the proration January 15 -18. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. i .., ✓ Z -11A (PTD #2050310) All the wells listed above will be classified as Not Operable until start-up operations are complete and are stable or the well passes a pressure test proving integrity. After start-up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/25/2011 • 4 ky .v~;L ' ~ ~~ ~ ,~. ~- ~~ .. Y ~• !"F ~'1 T y~~y~ '~R MICROFILMED 6/30/2010. DO NOT PLACE ANY NEW MATERIAL UNDER THIS. PAGE C:\temp\Temporary Internet Files\OLK91Microfilm_Marker.doc • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~,~; ~r~F"v~k''~~,° ~ i ~i~ l= 2~ ~tJ~~! r `_c~ 3 as~ J4`- Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, r 1 U ~~ ~~~~~~~~ OCT 0 ~ 2009 ~l~sk~ ~il 8~ Gas Cons. Con~ni~~ian Anchora~e ~p~-- 0 31 Z'~f~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator . • BP Expioration (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 Weil Name PTD # API # Initial top of cement Voi. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ seatant date ft bbis ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-06 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-O8A 1931280 50029217870100 NA 02 NA 2.55 7/24/2009 Z-09A 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-14B 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-16 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 02 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA t.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA t.70 7/26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-22B 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219t70000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 500292t8790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 500292t9540000 NA 0.2 NA t.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-326L1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 S/S/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 1 t.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 1020 7/25/2009 Z-108 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-112 2071720 50029233800000 NA surface NA a~~~ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2050310 Well Name/No. PRUDHOE BAY UNIT Z-11A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22053-01-00 MD 10102 TVD 9162 Completion Date 1/28/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION - -~ Mud Log No Samples No Directional Surve Yes ~,r „~-~ DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, MGR / CCL /CNL Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name D Asc Directional Survey D ~ Lis 13782.~fnduction/Resistivity pt 13782 iLIS Verification 't'og Neutron ~,f-`" C Ems L.IS 13847 ~eutron +.EL~ C lames P.l S 14445 ~fnduction/Resistivity Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Chips Received? ~P7Td°-~ Analysis / N Received? Comments: (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No _---- - - Start Stop CH Received Comments - 0 10102 --Open - - --- 9592 10058 Open 3/9/2006 GR EWR4 ROP 9592 10058 Open 3/9/2006 GR EWR4 ROP 25 Blu 1 9035 9977 Open 3/16/2006 Memory CNL in Carrier, Memory LEE CCUGR/CNL in Carrier 27-Jan-2006 25 1 9035 9977 Open 3/16/2006 Memory CNL in Carrier, Memory LEE CCUGR/CNL in Carrier 27-Jan-2006 9592 10072 Open 1/29/2007 LIS Veri, GR, ROP, FET w/Graphics Sample Set Sent Received Number Comments Daily History Received? Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2050310 Well Name/No. PRUDHOE BAY UNIT Z-11A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22053-01-00 MD 10102 TVD 9162 Compliance Reviewed By: _ _ Completion Date 1/28/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Date: U _.~~ STATE OF ALASKA ~ ~~~~ ALAS OIL AND GAS CONSERVATION COMM~SION REPORT OF SUNDRY WELL OPERATIONS ~ECEIi~E® JAN ®9 2008 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate ~ AS~(~~~~~x-~tfA K~ r1 Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension h ~c arage Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory 205-0310 ~ 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22053-01-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 91.7 KB ~ PBU Z-11A 8. Property Designation: 10. Field/Pool(s): ADLO-028262 _ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10102 ~ feet Plugs (measured) None true vertical 9161.63 - feet Junk (measured) None Effective Depth measured 10067 feet true vertical 9143 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91# H-40 30' - 110' 30' - 110' 1490 470 Surface 2629' 13-3/8" 68# L-80 31' - 2660' 31' - 2660' 5020 2260 Production 9364' 9-5/8" 47# L-80 32' - 9396' 32' - 8665' 6870 4760 Liner 520' 7" 26# L-80 9142' - 9662' 8437' - 8903' 7240 5410 Liner 625' 3-3/169" 6.2# 13CR80 9477' - 10102' 8737' - 9162' Perforation depth: Measured depth: 9750 - 9778 9794 - 9804 9822 - 9844 9870 - 9888 True Vertical depth: 8971.56 - 8989.28 8998.53 - 9003.93 9012.95 - 9023.44 9036.14 - 9045.25 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 33' - 9621' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BKR SB-3 9092' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1187 2098 790 212 Subsequent to operation: 1169 2116 764 279 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory (~" Development ~` Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~' Gas WAG ~ GINJ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature a ~ Phone 564-4944 Date 1/8/2008 ~~ ~~#~ ``~`~ ~" ~ `~~~ ~ ~` Submit Original Only Form 10-404 Re ised 04/2006 ~ ~' ~~ Z-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUM_ MARY ACTIVITYDAT~ SUMMARY 11/19/2007 T/IA/OA= SSV/ 0/0 Temp=S1 (warm) Assist Seal-Tite (Function LDS on IC void `Pre Seal-tite } Cycle LDS "ET style" all were functioned and moved, (1) was tight under the OA valve at 9:00 but was moved. 11/20/2007'T/I/O=SSV/8/6. Temp=S1. Monitor (pre-sealtite). A/L SI @ casing valve. ::ALP=1580 psi. IAP increased 8 psi, OAP increased 6 psi overnight. 12/1/2007'T/I/O =SSV/0+/10. Temp = SI. Bleed WHP to 0 (Assist Sealtite). AL SI C gate -valve (1580 psi). Bled IAP and OAP to 0 psi. Assisted Sea{tite. SI, monitored for 30 min. IAP and OAP increased to 0+ psi. Final WHPs =SSV/0+/0+. 12/1 /2007 T/I/0= SSV/0/10, Temp=S1. Assist Seal Tite International with IC void repair. DHD bled IAP and OAP to 0 psi, maintained open bleed. Hoke valves installed on both IC test ports. IC test void @ 0 psi. Rigged up Seal Tite pump equipment to IC test void. Pumped fluid through void taking returns out off side port, returned 1/2 gal of plastic sealant. Removed gland nut and pin nearest to test port valve. Pumped small amount of fluid to verify comunication between test port and LDS position, re-installed LDS. Continued until all LDS positions/ comunication were verified. Pressured void to 3500 psi, lost 1000 psi in 10 min. Pumped 1 liter of Tur-Flo into test void until 30 min test could be achieved with no pressure decrease. 12/5/2007;**'`WELL S/I ON ARRIVAL***(post wh repair/ seal tite) 'RIG UP SLICK LINE UNIT 12/6/2007 "'`'`CONY FROM WSR 12/5/07"" (post wh repair/seal tite) SET WHIDDON CATCHER ON WRP PLUG @ 9124' MD PULL RM-CIRC VALVE FROM STA# 1 ~ 9054' MD PULL RM-DGLV STA# 3 @ 8093' MD, PULL RM-DGLV STA# 5 @ 6083' MD PULL RM-DGLV STA# 6 @ 2964' MD SET RM-LGLV STA# 6 @ 2964' MD, SET RM-LGLV STA# 5 @ 6083' MD, SET RM-LGLV STA# 3 @ 8093' MD SET RM-OGLV IN ST # 1 @ 9054' MD. RIH TO PULL CATCHER '`*"CONTINUED ON 12-07-07*'`* __ __ _: • • _. _. 12/7/2007 ~**CONT FROM WSR 12/6/07**' (post wh repair /seal tite) ', PULLED 4 1/2" WHIDDON CATCHER SUB FROM 9124' MD PULLED 4 1/2"WRP FROM 9124' MD, RAN 3 1/2 BRUSH, 3.805 GAUGE TO DEPLOYMENT SLEEVE @ 9477 MD. (NO ELEMENT RECOVERED). *'`'`OPERATOR NOTIFIED WELL LEFT S/I*** ***NOTE: 1/2 OF ONE WRP ELEMENT LEFT IN HOLE**** 12/9/2007T/I/O= SSV/0/0, Temp=S1. IC packoff repair (Seal Tite). 12/10/2007 12/ 10!2007 Installed jewelry on IC test port, stage pump equipment. Will bring well online in AM as per FO. T/I/0=500/0/0. Temp=S1. Pressure IC void to 2000 psi (for Sealtite). Pumped tur-flo sealant to bring IC void to 2000 psi. FO brought well online to warm up sealant. Bleed as needed to maintain IC pressures below 3504 psi max. Final T/I/0=500/0/0. ._._ .~_ TIU0=500/0/0, Tempe=51. IC packoff repair (Seal Tite). Rigged up Seal Tite pump equipment, pumped up void pressure to 2000 psi. FO brought well on line. Monitored IC void pressure. In 2 hrs, void pressure increased to 2500 psi, relieved by DHD. 12/11 /2007 jT/I/O = 310/1210/620. Temp = 104 deg. Monitor WHP (Sealtite). AL line open @ casing valve. WELL POP 12/11/07 ~ ~' 8 '~I STATE OF ALASKA ~~~~~ ALAS OIL AND GAS CONSERVATION COMM~ION ~'i-~~'- ~ ~ ?ilO7 REPORT OF SUNDRY WELL OPERATIONS ,,, ;~., ~ t ,~~ t,s~mmissinn 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q Other , . , ~ ' " 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. Current Well Class: 5. Permit to Drill Number: Name: Development ' Exploratory 205-0310 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22053-01-00 7. KB Elevation (ft): 9. Well Name and Number: 91.7 KB ~ PBU Z-11A ° 8. Property Designation: 10. Field/Pool(s): ADLO-028262 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10102 ~ feet Plugs (measured) None true vertical 9161.63 feet Junk (measured) None Effective Depth measured 10067 feet true vertical 9143 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91# H-40 30' - 110' 30' - 110' 1490 470 Surface 2629' 13-3/8" 68# L-80 31' - 2660' 31' - 2660' 5020 2260 Production 9364' 9-5/8" 47# L-80 32' - 9396' 32' - 8665' 6870 4760 Liner 520' 7" 26# L-80 9142' - 9662' 8437' - 8903' 7240 5410 Liner 625' 3-3/16" 6.2# 13CR 9477' - 101.02' 8737' - 9162' Perforation depth: Measured depth: 9750 - 9778 9794 - 9804 9822 - 9844 9870 - 9888 True Vertical depth: 8971.56 - 8989.28 8998.53 - 9003.93 9012.95 - 9023.44 9036.14 - 9045.25 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 33' - 9621' Packers and SSSV (type and measured depth) 9-5/8"x4"-1/2" bkr sb-3 9092' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 209 130 467 0 224 Subsequent to operation: 348 6733 234 0 259 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development v' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ WINJ WDSPL ~~ 17. {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 Gary Preble Printed Name Gary Pr b Title Data Management Engineer Signature Phone 564-4944 Date 7/3/2007 Form 10-404 Re sed 04/2006 D } (1 ~ n j /- ~ ~i DT-L ~U~ ~ ~ 2~~ ~ ~`~ Submit r~~~l Only s • Z-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY f ACTIVITYDATE I SUMMARY 6/27/2007 CTU # 8 -Acid Treatment - MIRU CTU - Z-Pad lost electric power- ..__._ - - 6/28/2007;CTU #8, FCO/Acid Stim; ... Cont' from WSR 06/27/07 ... Cont' to standby until Z- "Pad is up and runnning. Flow well to ASRC and let well stabilize. RIH with 1.75" 'JSN. Clean out from 9650' to 9712'. Could jet no further. POOH. MU and RIH `:with WFD jars, 1-11/16" motor and 2.25" junk mill. Tools temporailly hung up in '':!tree. Get tools free and cont' RIH with mill. ... Cont' on WSR 06/29/07 ... 6/29/2007f CTU #8, Mill /Acid Stim; ... Cont' from WSR 06/28/07 ... InterACT publishing during job. Begin milling scale in liner starting from 9608' ctmd down to TD at ::10042' ctmd. Hit several hard bridges through perf zones. Last hard bridge :encountered at 9855' ctmd. POOH at 80%. LD milling BHA; 4 broken buttons on ': ;edge of mill. MU and RIH with 2.0" BDN. Unable to bullhead into well at high enough rate to flush gas. Circuiate btms up 2% KCL followed by diesel and ensure: :well is fluid packed. Cool sump with 2% KCL. Perform acid treatment with 50 bbls of 90:10 DAD acid while recip'ing across interval 9750'-9888' ctmd. Overflush with ':50 bbls of 2% KCL. PUH above perfs and pumped diversion stage of 10 bbls (300 Ib) wax heeds followed by 50 bbls of 12% HCL bullheaded above the perfs. Final overflush 100 bbls of 2% KCL. Observed an initial increase in injectivity from 1950 '..:psi at 1.5 bpm to 1460 psi at 1.5 bpm as first stage of acid hit the perfs. Also `^observed excellent diversion as wax heeds hit the perfs; injectivity decreased to 0.4 bpm at 1850 psi. Injectivity steadily increased as second stage as acid hit the °`perfs. ... Cont' on WSR 06/30/07 ... 6/30/2007 CTU #8, Acid Stim; ... Cont' from WSR 06/29/07 ... Finish pumping overflush. ';POOH. RDMO and turn well over to ASRC test separator for acid flow back. **" Job Complete'** FLUIDS PUMPED BBLS 275 XS 2% KCL 37 150k LSRV FLO PRO 346 2% KCL 127 DIESEL 50 90:10 DAD ACID 12% HCL. TITRATION IS 12.1 %HCL. IRON IS <20PPM 50 12% HCL. TITRATION IS 12.1 %HCL. IRON IS <20PPM 10 30PPT HEC GEL WITH 300 # OF WAX BEEDS 168E MELTING TEMP 895 TOTAL • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: X-08A, X-09B, X-31 Ll & Z-11A. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 x-oBA: X03 - i t ~ ~` r ~1Gi ~1 ~ Digital Log Images: 1 CD Rom 50-029-20463-01 Digital Log Images: 1 CD Rom 50-029-20455-02 X-31 L 1: 2 U~- 6~ 3~ ~~~/~(Ll Digital Log Images: 1 CD Rom 50-029-20435-60 Z-11A: aOS C~3 ! ~ j~~G//~S Digital Log Images: 1 CD Rom 50-029-22053-O1 5 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMISSI REPO OF SUNDRY WELL OPERATI a° b 1. Operations Abandon ^ pair Well Plug Perforations ^ Stimulate Q Other`;^1 ' r Performed: Alter Casing ^ ^ull Tubing Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Oper^Shutdown Perforate ^ Re-enter Suspended Well^ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number.- Name: Development Exploratory W ~ 205-031~~ 3. Address: P.O. Box 196612 Stratigraphic Service ) 6. API Number: Anchorage, AK 99519-6612 50-029-22053-01-00 7. KB Elevation (ft): 9. Well Name and Number: 91.7 KB PBU Z-11A 8. Property Designation: 10. Field/Pool(s): ADLO-028262 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10102 feet Plugs (measured) None. true vertical 9162 feet Junk (measured) None Effective Depth measured 10067 feet true vertical 9143 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 30' - 110' 30' - 110' 1490 470 Surface 2629' 13-3/8" 68# L-80 31' - 2660' 31' - 2660' 5020 2260 Production 9364' 9-5/8" 47# L-80 32' - 9396' 32' - 8665' 6870 4760 Liner 520' 7" 26# L-80 9142' - 9662' 8437 - 8903' 7240 5410 Liner 625' 3-1/2" 8.81# 13Cr 9477' - 10102' 8737' - 9162' 3-3/16' 6.2# 2-7/8" 6.5# 13Cr Perforation depth: Measured depth: 9750 - 9778 9794 - 9804 9822 - 9844 9870 - 9888 True Vertical depth: 8971.56 - 8989.28 8998.53 - 9003.93 9012.95 - 9023.44 9036.14 - 9045.25 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 33' - 9621' Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" BKR SB-3 9092' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): am'a Treatment descriptions including volumes used and final pressure: '?' _ ' "~ ~'~> k;~ ;Y~ 1 ~ L}~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 221 224 1 0 255 Subsequent to operation: NA 0 0 0 0 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ~ Service ~'' Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ ~ WINJ ~ WDSPL 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: Contact Gary Preble Printed Name Gary Preble Title Data Engineer Signature Phone 564-4944 Date 11/14/2006 O'21C~NAL Form 10-404 Revised 04/2004 Submit Original Only ~,_ • Z-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY I 11/9/2006!' CTU #8, FCO, Acid Stim; Stand-by for ASRC test separator to finish well test on 'Z-14. Continue standby on WSR11/10/06 ... __ 11/10/2006 CTU #8, FCO/Acid; Cont' from WSR 11/09/06 ... Stand by for ASRC test ;. ';separator rig up. MIRU CTU #8. Cont' on WSR 11/11/06 ... 11/10/2006; Start rig up, complete rig up, wait on CTU 11/11/2006!,Assisting CTU 11/11/2006 CTU #8, FCO/Acid; Cont' from WSR 11/10/06 ... Complete RU. Well is flowing. ',RIH with 2.0" JSN assy. Sat down at 9848` ctmd. Could not jet through 'obstruction. POOH for motor and mill. RIH w/ WFD 1-11/16" motor with 2.29" ;concave mill. Mill through bridge and work mill through pert area. Tag bottom at '',10056' ctmd. Pooh. RIH with 2.0" big hole JSN assy. Load well with 212 bbls ':NH4CL. Cont' on WSR 11/12/06 ... 11/12/2006'!CTU #8, Acid Treat; Cont' from WSR 11/11/06 ... Pump 50 bbls diesel down 'backside to establish positive WHP. Cool perfs with 3% NH4CL. Pump acid "'..treatment as per program. Saw initial breakdown of perfs with first stages of acid. Saw good diversion when wax beads hit. Over flushed treatment with 3% INH4CL. Freeze protect coil with 60/40 methanol while pooh. Rig down. Move to Milne Point J-25. Turn well over to ASRC well test unit #3 for acid flowback. :Notify pad operator of well status. **"*Job Complete**** __ t. ~. 11/12/2006 Assisting CTU, CTU Pumping Acid, Start Flowback FLUIDS PUMPED BBLS 40 METHANOL 222 3% NH4CL 40 DIESEL 50 12% 90:10 DAD ACID 51 12% HCL ACID 103 9:1 MUD ACID 12 30 PPT HEC W/500# WAX BEADS 518 TOTAL M s WELL LOG TRANSMITTAL To: State of Alaska March 07, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7`i' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: Z-11A, AK-MW-4173216 1 LDWG formatted Disc with verification listing. API#:50-029-22053-O1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: ~ Si ed: cos - ~~c ~~~ STATE OF ALASKA ALASK~L AND GAS CONSERVATION COM SIGN WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVEC3 MAR 0 8 2006 Alaska Oil & Gas Cons. Commission Anchorane 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAAC 2s.toe 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 1/28/2006 12. Permit to Drill Number 205-031 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/23/2006 13. API Number 50-029-22053-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/24/2006 14. Well Name and Number: PBU Z-11A 980 FNL, 3202 FEL, SEC. 19, T11 N, R12E, UM Top of Productive Horizon: 3936' FNL, 3317' FEL, SEC. 19, T11 N, R12E, UM g. KB Elevation (ft): 91.7' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 3827' FNL, 3609' FEL, SEC. 19, T11 N, R12E, UM 9. Plug Back Depth (MD+TVD) 10067 + 9143 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599475 y- 959100 Zone- ASP4 5 10. Total Depth (MD+TVD) 10102 + 9162 Ft 16. Property Designation: ADL 028262 _ __ _ _ TPI: x- 599412 y-_5956143 Zone- ASP4 Total Depth: x-~ 599117 y- 5956248 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: -------- - 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD GR / EWR, MGR / CCL / CNL 2. CASING, LINER AND CEMENTING RECORD CASING ET71NG EPTH MD ETTING EPTH TVD FIOLE OUNT SIZE WT. PER FT. - GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED `. 20" Surface 110' Surtace 110' 13-3/8" 68# L-80 Surface 2660' Surface 2660' 17-1/2" 723 cu ft Permafrost 9-5/8" 47# L-80 Surtace 9396' Surface 8665' 12-1/4" 1979 cu ft Class'G' 7" 26# L-80 9142' 9662' 8437' 8903' 8-1/2" 363 cu ft Class 'G' 3-1/2" x 3-3/16" 8.81# / 6.2# 13Cr 9477' 10102' 8737' 9162' 4-1/8" 0 cu ft Class'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TusiNG RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9623' 9092' MD TVD MD TVD 9750' - 9778' 8972' - 8989' 9794' - 9804' 8999' - 9004' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9822' - 9844' 9013' - 9023' 9870' 9688' 9036' 9045' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 2500' Freeze Protect with 22 Bbls of McOH 26• PRODUCTION TEST Date First Production: February 12, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 2/13/2006 Hours Tested 12 PRODUCTION FOR TEST PERIOD OIL-BBL 624 GAS'MCF 921 WATER-BBL 168 CHOKE SIZE 176° GAS-OIL RATIO 1,477 Flow Tubing Press. 24 Casing Pressure 1,450 CALCULATED 24-HOUR RATE OIL-BBL 1,248 GAS-MCF 1,842 WATER-BBL 336 OIL GRAVITY-API (CORK) 30.7 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~ /~ ~~ - 1 1"~• ~~( ~~~~~/~~ ~ ~1 ~U~ ~ .~L~ ~....~.~~ . ~: o FOrm 10-407 ReVISed 12/2003 ~ { ~'~ ~ CQNTftJU~D CN REVERSE SIDE ~ ~r 28. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sadlerochit /Zone 4 9602' 8849' None (From Z-11, Parent Well) Zone 3 / 31 N 9883' 9043' Zone 2 / 27P 9992' 9102' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terris Hubble ~ Title Technical Assistant Date O~,/D7~~~p PBU Z-11 A 205-031 Prepared By Name/Number Terris Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Sean McLaughlin, 564-4387 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this welt should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one Interval (multiple completion), so state in Item 1, and In item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION: Page of 6 Opperations Summary Report Legal Well Name: Z-11 Common Wefl Name: Z-11 Spud Date: 6/15/1990 Event Name: REENTER+COMPLETE Start: 1/1/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 1/28/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/20/2006 00:00 - 01:30 1.50 RIGD P PRE Prep rig for move 01:30 - 02:00 0.50 MOB P PRE PJSM on moving rig w/ rig crews, toolservice and security. 02:00 - 22:00 20.00 MOB P + PRE Move rig off well, post pad inspection, moving rig f/ G-Pad to ~ Z-Pad, performed pre-pad inspection, accept rig at 22:00 hrs i on 01/20/2006 22:00 - 22:30 0.50 MOB P PRE PJSM on spotting rig over well 22:30 - 23:00 0.50 MOB P PRE Attempt to spot rig over well, drive wheel slipping, scarfed location with rig loader and blade 1/21/2006 23:00 - 00:00 00 00 06 1.00 MOB P PRE Spot rig over well Z-11 : - :00 6.OO i BOPSU P PRE C/O spool, lubr, RD tree cap, NU BOP, C/O rams to 2", chained and centered up I I Spot tanks and trailers. R/U hardline to tiger tank. Grease ~ choke manifold valves & R/U BOP test joint. 06:00 - 06:30 06:30 - 15:30 0.50 9 O BOPSUF I B ~ P PRE Crew change. TLM &PJSM for PT BOPE. . O OPSUR P PRE Perform initial BOPE pressure /function test. AOGCC test ~ ~ witness waived by John Spaulding. Test witnessed by BP WSL. Had to regrease a lot of valves to get a test due to the extreme cold temp. Meanwhile spot outside shacks. Finish I BOP test with the exception of the inner reel valve. ~ GPB is in level 1 driving conditions with ambient temps up to -40degsF & -80degsF wind chill. 15:30 - 15:45 0.25 RIGU P PRE Held PJSM & HA/HM for stabbing CT. 15:45 - 18:00 2.25 RIGU P PRE P/U injector head. Sfip grapple into CT & pull test. Puli CT over pipe shed with winch & stab into injector. C/O packoffs & M/U injector to stripper. 18:00 - 19:10 1.17 RIGU P PRE PJSM on welding and permitting, GBR install SLB weld-on CTC. Pull test to 35k. Meanwhile fill rig pits with 2% double-slick KCL-water with 2ppb biozan. 19:10 - 20:00 0.83 STWHIP P WEXIT RU, Circ, fill CT w/ 2ppb Biozan w/ 2% double slick KCL 20:00 - 20:15 0.25 BOPSU P WEXIT P/T CTC and inner reel valve, OK 20:15 - 22:00 1.75 STWHIP P WEXIT Bled off trap pressure, monitor well, OK, MU window milling BHA, stab injector 22:00 - 00:00 2.00 STWHIP N SFAL WEXIT SLB computer locking up, troubleshooting mother board circuitry 1/22/2006 00:00 - 03:30 3.50 STWHIP N SFAL WEXIT SLB computer locking up, troubleshooting mother board circuitry 03:30 - 05:15 1.75 STWHIP P WEXIT RIH w/ window milling BHA, tagged up at 9662', corrected back to 9655', Up Wt 22k, S/O Wt 15k, Free Spin 2047 psi at 2.44 bpm, 05:15 - 06:00 0.75 STWHIP P WEXIT Milling cmt to 9657.8', pinch point at 9658'. 06:00 - 07:00 1.00 STWHIP P WEXIT Mill window from 9658' to 9660' with 2.45/2.45bpm, 2050/2250psi & 2k WOB. 07:00 - 07:30 0.50 STW HIP P WEXIT Mill window to 9660' with 2.45/2.45bpm, 2050/2350psi & 3k WOB. 07:30 - 08:30 1.00 STW HIP P WEXIT Mill window to 9661' with 2.45/2.45bpm, 2050/2500psi & 4k WOB. Getting metal shavings on ditch magnets. 08:30 - 09:40 1.17 STWHIP P WEXIT Mill window to 9662' with 2.45/2.45bpm, 2050/2650psi & 4k WOB. 09:40 - 11:30 1.83 STWHIP P WEXIT Mill window to 9663' with 2.45/2.45bpm, 2050/2650psi & 4k WOB. GPB is presently in Phase-2 on all roads & pads with winds of Printed: 1/30/2006 11:20:37 AM BP EXPLORATION Page 2 of,s Opperations Summary'Report Legal Well Name: Z-11 Common Well Name: Z-11 Spud Date: 6/15/1990 Event Name: REENTER+COMPLETE Start: 1/1/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 1/28/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT`. Phase Description of Operations 1/22/2006 09:40 - 11:30 1.83 STWHIP P WEXIT 30mph & gusting up to 45mph. 11:30 - 12:55 1.42 STWHIP P WEXIT Mill window to 9664' with 2.45/2.45bpm, 2050/2550psi & 4k WOB. Inspect wellhead bolts & found no loose bolts/nuts. 12:55 - 13:30 0.58 STWHIP P WEXIT Mill window to 9664.4' with 2.45/2.45bpm, 2050/2450psi & 6k WOB. Exit into formation ~ 9664.4' & mill to 9665'. 13:30 - 14:40 1.17 STWHIP P WEXIT Mill 10' formation to 9675' with 2.45/2.45bpm, 2050/2450psi, 8fph ave ROP & 8k WOB. 14:40 - 15:30 0.83 STWHIP P WEXIT Backream/dress window/rat hole 3x & drift 2x. Window looks clean. Tentative window depths are: TOWS = 9653.4' TOW = 9658', BOW = 9664.4', RA PIP Tag = 9663.4'. Meanwhile swap ~ the wellbore to 100% reconditioned 8.6 ppg Flo-Pro mud with 15:30 - 17:30 2.00 STWHIP P WEXIT 4% L-T & 12ppb K-G. Paint EOP flag ~ 9300' & POOH window milling BHA #1, ~ while displacing well to mud. 17:30 - 18:00 0.50 STWHIP P WEXIT ; PJSM. UD BHA #1 & inspect mills, OK - DWM & DSR gauge 3.79" go/3.78" no go. 18:00 - 18:30 0.50 DRILL P PROD1 PJSM on Phase 2 weather conditions and handling BHA 18:30 - 20:15 1.75 DRILL P PROD1 ( MU Building BHA, orient to MWD, MHA, stab injector 20:15 - 22:30 2.25 DRILL P PROD1 RIH w/ BHA to 9645', shallow hole test MWD and Orientor, OK, EOP correction - 6', Up wt 25.5 K, 22:30 - 22:50 0.33 DRILL P PROD1 Tie in pass f/ 9645' - 9624', did not see GR spike of TSAD, stopped logging up to avoid bit f/ entering 4 1/2" tbg tail w/ 3 degree motor, RIH to 9642' 22:50 - 23:30 0.67 DRILL P PROD1 Orient around to HS, 20 - 30 degrees/click, slide thru window w/ TF at 42 R, no problems, tagged btm at 9672' 23:30 - 00:00 0.50 DRILL P PROD1 Difficulty orient TF 45 R below window, not responding to clicks, TF at 36 R w/ reactive torque TF at 15 L 1/23/2006 00:00 -00:30 0.50 DRILL P PROD1 PU above window to 9645' w/ TF at 135 R, orient TF around to 45 R 00:30 -04:20 3.83 DRILL P PROD1 Slacked off thru window to btm, TF changed to 167 L, Dir Drill w/ TF at 42 R reactive torque, 2.2 bpm at 4500 psi, PV 292 bbls 04:20 - 05:20 1.00 DRILL P PROD1 Orient TF to 80 R, getting little respond to clicks in open hole 05:20 - 06:00 0.67 DRILL P PROD1 Dir Drill w/ 2.2 bpm at 4500 psi, PV 292 bbls 06:00 - 07:30 1.50 DRILL P PRODi POH to BHA 07:30 - 08:00 0.50 DRILL P PROD1 OOH. PJSM. UD BHA #2 & inspect motor & bit. Motor is OK & bit looks green. Reset motor bend to ideg & C/O equalizer internal jet size from 13/32" to 15/32". P/U RES tool. 08:00 - 09:45 1.75 DRILL P PROD1 M/U drilling BHA #3 with ldeg X-treme motor, MWD/GR/RES, orienter & same DS49 bit #3. Scribe tools & initialize RES tool. M/U injector. 09:45 - 12:00 2.25 DRILL P PROD1 RIH drilling BHA #3. SHT tools ~ 3000' - OK, with circ pressure of 3750psi ~ 2.4bpm. RIH & park bit above window ~ 9105'. S/D operations as GPB is presently in Phase-3 on all roads & pads. 12:00 -00:00 12.00 DRILL N WAIT PRODi W.O. Phase-3 weather to subside. Meanwhile circ ~ min rate. 1/24/2006 00:00 -06:00 6.00 DRILL N WAIT PROD1 Continue to circ ®min rate with bit ~ 9105' while W.O. Phase-3 weather to subside. Will resume operations as GPB is presently in Phase-2 on all main roads & Level-3 on Well Pads & access roads. 06:00 - 06:30 0.50 DRILL P PROD1 RBIH to below window ~ 9705'. Printed: 1/30/2006 71:20:37 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~, From - To 1__ 1 /24/2006 ~ 06:30 - 08:00 Z-11 Z-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1 /1 /2006 Rig Release: 1/28/2006 Rig Number: Hours Task Code NPT Phase I 1.501 DRILL P (PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 08:55 0.42 DRILL P PROD1 08:55 - 09:15 0.33 DRILL P PRODi 09:15 - 09:40 0.42 DRILL P PROD1 09:40 - 11:40 2.00 DRILL P PROD1 11:40 - 11:50 0.17 DRILL P PROD1 11:50 - 17:45 5.92 DRILL P PRODi 17:45 - 18:30 0.75 DRILL P PROD1 18:30 - 18:45 0.25 DRILL P PRODi 18:45 - 19:00 0.25 DRILL P PROD1 19:00 - 20:40 1.67 DRILL P PROD1 20:40 - 22:30 1.83 DRILL P PROD1 22:30 - 23:00 0.50 DRILL N WAIT PROD1 23:00 - 23:10 0.17 CASE P RUNPRD 23:10 - 00:00 0.83 CASE P RUNPRD 1/25/2006 00:00 - 00:45 0.75 CASE P RUNPRD 00:45 - 01:15 0.50 CASE P RUNPRD 01:15 - 01:30 0.25 CASE P RUNPRD 01:30 - 03:30 2.00 CASE P RUNPRD 03:30 - 04:10 ~ 0.671 CASE P RUNPRD 04:10 - 05:30 1.33 CASE N DPRB RUNPRD 05:30 - 08:00 2.50 CASE N DPRB RUNPRD 08:00 - 08:45 0.75 CONDH N DPRB RUNPRD 08:45 - 10:55 2.17 CONDH N DPRB RUNPRD 10:55 - 11:25 0.50 CONDH N DPRB RUNPRD 11:25 - 12:30 I 1.081 CONDHUN I DPRB I RUNPRD 12:30 - 14:00 1.50 CONDH~N DPRB RUNPRD 14:00 - 14:45 0.75 CONDH N DPRB RUNPRD 14:45 - 15:15 0.50 CONDH N DFAL RUNPRD 15:15 - 15:30 0.25 CONDH N DPRB RUNPRD 15:30 - 16:30 1.00 CONDH N DPRB RUNPRD 16:30-16:45 0.25 CONDHL~N DPRB RUNPRD 16:45 - 17:05 0.33 CONDH N DPRB RUNPRD 17:05 - 17:20 0.25 CONDH N DPRB RUNPRD 17:20 - 17:30 0.17 CONDH N DPRB RUNPRD 17:30 - 19:15 1.75 CONDH N DPRB RUNPRD 19:15 - 20:00 0.75 CONDH N DPRB RUNPRD Page 3 of 6 Spud Date: 6/15/1990 End: Description of Operations Log up GR & capture RA pip tag C 9661'. PUH to 9649' & log up to TSAD at 9596', RIH log dn, TSAD at 9598', RA tag at 9667', TOWS 9657', TOW 9661.6', BOW 9668', tie-in correction +4' RIH to btm Orient TF to 130 R, FS 3500 psi, Up Wt 22 K, Dn Wt 15 K Dir Drill w/ TF at 85 R, 2.2 bpm, 3950 psi Orient TF to 158 L Dir Drill w/ TF at 115 R, 2.2 bpm, 3850 psi Orient TFaround to 90 R Dir Drill w/ TF at 79 - 59 R, 2.25 bpm, 3925 - 4150 psi MAD pass Tie -in +2' correction. RIH at TC at 10102. POH to surface. LD BHA down load MW D. Wait on arrival of BOT. Held up by Doyon 16 rig move. PJSM for picking up liner. Pu liner 16 jts 2-7/8 & 4 jts 3-1/2" 13CR liner. Continue picking up liner and liner running tools. Change coil connector. Pull test 35K and PT to 3500 psi. MU injector and stab on to well. RIH to 9750 No Go. Stacking out log shows one small shale spike. Directional shows a reduction in build rate nothing significant. DL 44 - 46 Attempt to work thru with no progress. tried and various speeds and pump rates. No progress at all. Decide to POH. POH Standback liner. Held PJSM w/ new crew, Finished POH, STDBK Liner, checked OD's on cementralizers, OK, no visual marks on index shoe. MU 3.75" PDC bit, 1 deg mtr, MWD and rest of Cleanout BHA RIH w/ Cleanout BHA to 9710' Tie-in pass to RA tag, FS 3100 psi at 1.9 bpm, Up wt 23.8 K, Dn wt 12 K, correction +10' RIH taking weight at 9768', PU, orient to 90 R, unable to pass thru tight spot after several attempts, PU to orient TF around to 46 R, worked thru tight hole f/ 9768' - 9848' , RIH to btm at 10102' POH w/ TF at 45 R, backream hole to 9700', 2.2 bpm, 3900 psi RIH, worked thru tight spot at 9794', RIH to 9900' Orient TF to 120 R, POH w/ TF at 90, backream hole to 9700', 2.2 bpm, 3900 psi RIH to 9900', slight bobble at 9800' Orient TF to 175 R, POH w/ TF at 150 - 130 R, backream hole to 9700', 2.15 bpm, 3700 psi Orient TF to 80L, RIH to 9900', slight bobble at 9815' POH w/ TF at 151 L, backream hole to 9700', 1.8 bpm, 3300 psi Work thru hole t/ 9700' - 9850', hole looks good, no tight spots RIH to btm, no hole problems POH to BHA, Flagged EOP at 9400' and 9000' LD ceanout BHA Printed: 1/30/2006 11:20:37 AM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To - - ' -- 1/25/2006 20:00 - 20:30 20:30 - 21:45 21:45 - 00:00 1!26/2006 100:00-01:00 Z-11 Z-11 REENTER+COMPLETE Start: 1/1/2006 NORDIC CALISTA Rig Release: 1/28/2006 NORDIC 1 Rig Number: Hours Task I Code I NPT ' Phase 0.50 CASE N 1.25 CASE N 2.25 CASE N 1.001 CASE I N 01:00 - 02:30 1.50 CASE N 02:30 - 03:30 1.00 CASE N 03:30 - 04:30 1.00 CONDH N 04:30 - 06:35 2.08 CONDH N 06:35 - 07:00 0.42 CONDH N 07:00 - 08:00 I 1.001 CONDHU N 08:00 - 08:35 I 0.581 CONDHU N 08:35 - 09:30 0.92 CONDH~ N 09:30 - 09:45 0.25 CONDH N 09:45 - 10:25 0.67 CONDH N 10:25 - 11:00 0.58 CONDH~N 11:00 - 11:30 0.50 CONDH N 11:30 - 11:50 0.33 CONDH N 11:50 - 12:05 I 0.251 CONDHU N 12:05 - 12:20 I 0.251 CONDHU N 12:20 - 12:35 0.25 CONDH N 12:35 - 13:20 0.75 CONDH N 13:20 - 13:25 0.08 CONDH N 13:25 - 13:55 0.50 CONDH N 13:55 - 14:10 0.25 CONDH N 14:10 - 15:10 1.00 CONDH N 15:10 - 15:50 I 0.671 CONDHU N 15:50- 16:45 I 0.921 CONDHUN 16:45 - 18:10 1.42 CONDHL~ N 18:10 - 18:30 0.33 CONDH N 18:30 - 21:30 I 3.001 CONDHU N Spud Date: 6/15/1990 End: Description of Operations DPRB RUNPRD PJSM DPRB RUNPRD MU liner DPRB RUNPRD RIH with liner to flag at 9600. No correction. Continue in hole ~ .2 bpm 1250 psi .Set down at 9735'. Make multipual attempts NO Go. Set and circulate 1 bpm @ 1950 psi. with -2k surface wt. DPRB RUNPRD Conitnue attempting to wash thru tight spot. Circulate 1 bpm C~ 1950 psi with -2K surface wt. Pick up clean. Washed for 50 minutes with no surface wt change. Decide to POH. DPRB RUNPRD POH. DPRB RUNPRD Stand back liner DPRB RUNPRD PU cleanout assembly. DPRB RUNPRD RIH with 2 degree motor cleanout assembly to 9705' DPRB RUNPRD Tie-pass f/ 9705' to RA marker at 9667', FS 3050 psi at 1.95 bpm, Up wt 23 k, Dn wt 11.5 k, +2' correction DPRB RUNPRD RIH tagged at 9737', worked thru tight spot at 9737' - 9740' several times w/ TF @ 45 - 60R, RIH to btm at 10102', tight spots seen thru most of shale stringers at 9780', 9815' and 9840', no real problem working past these intervals. DPRB RUNPRD POH to 9900', backreamed to 9700' w/ TF at 40L, 2.25 bpm w/ 3800 DPRB RUNPRD RIH to 9900', 1.92 bpm w/ 3035 psi DPRB RUNPRD POH to 9680', no problems, orient TF to 150R DPRB RUNPRD RIH to 9900', tagged and worked thru tight spot at 9750', OK, TF fluctuated f/ 135 - 70R DPRB RUNPRD POH to 9680', backreamed tight spot at 9780' DPRB RUNPRD Orient TF to 167 L DPRB RUNPRD RIH to 9900', TF fluctuated between 32 L - 178 L for the most part held steady 133 L, 1.88 bpm, 3350 psi, slight bobbles at 9740' and 9832' DPRB RUNPRD POH to 9680', TF fluctuated between 178 L - 82 L, 1.88 bpm, 3300 psi DPRB RUNPRD RIH, tagged up at 9780', TF at 167 L, attempt to worked thru tight spot, no go DPRB RUNPRD PUH to 9680', orient TF to 45 R DPRB RUNPRD RIH, tagged up at 9793', work thru tight spot after many attempts, TF at 45 R, work pump rate @ 1.88 bpm, 3375 psi DPRB RUNPRD RIH to 9900', OK DPRB RUNPRD Backream to 9680' w/ 2.13 bpm, 3825 psi DPRB RUNPRD RIH, work thru tight spot at 9799', RIH to 9830' DPRB RUNPRD Backream to 9680', TF at 45 R, work pump rate C~ 2.24 bpm, 3900 psi DPRB RUNPRD TF at 45 R, RIH to btm at 10102', slight bobbles at 9780' and 9793', over all the hole looks good, 2.05 bpm, 3575 psi, once past troubled hole started pumping hi-vis sweep followed by 9.4 ppg brine water DPRB RUNPRD POH aboe TOWS inside 7" csg at 9634, displacing well to 9.4 ppg brine water C~ 2.0 bpm w/ 3450 psi, up wt 24 k, tight spot at 9845', 9837' w/ 8 k overpull DPRB RUNPRD Circ 9.4 ppg brine water in/out DPRB RUNPRD RIH and set down at 9796'. PU and work thru. RIH tag TD at 10102'. DPRB RUNPRD POH for liner. Printed: 1/30/2006 11:20:37 AM BP EXPLORATION Operations Summary Report Legal Well Name: Z-11 Common Well Name: Z-11 Event Name: REENTER+COMPLETE Start: 1/1/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/28/2006 Rig Name: NORDIC 1 Rig Number: Date ~ From - To Hours Task ;Code NPT Phase 1/26/2006 21:30 - 22:00 0.50 CONDH N DPRB RUNPRD 22:00 - 22:15 0.25 CONDH N DPRB RUNPRD 22:15 - 23:30 1.25 CONDH N DPRB RUNPRD 23:30 - 00:00 0.50 CONDH N DPRB RUNPRD 1/27/2006 00:00 - 01:00 1.00 CONDH N DPRB RUNPRD 01:00 - 01:15 0.25 CONDH P RUNPRD 01:15 - 02:00 0.75 CEMT P RUNPRD 02:00 - 05:00 3.00 CEMT P RUNPRD 05:00 - 05:15 0.25 CEMT P RUNPRD 05:15 - 05:50 0.58 CEMT P RUNPRD 05:50 - 07:05 1.25 CEMT P RUNPRD Page 5 of 6 Spud Date: 6/15/1990 End:. Description of Operations LD Cleanout assembly #2. PJSM picking up liner in stands. Change out Shoe foe bull nose. PU 2 stands of 2-7/8 13 CR liner and 2 stands of 3-1/2" 13CR liner. Pu injector and stab onto well. RIH with liner. RIH nto window Up Wt 26K RIH set down at 9834. PU RIH to TD 10102'. PU to ball drop position. Lauch 5/8" steel ball and displace to running tool.At 1.8 bpm after 30 bbls displaced slow pump to .6 bpm. Ball on seat C~ 37.6 bbls and shear off 38.1 bbl displacement. PU confirm free of liner. OK. Circulate and swap well back to 8.5ppg 2% KCL. PJSM for cement job. Batch up 11 bbls of 15.8 PPG, G Cement with Latex Press test cement line. Pumped 6.2 bbls of cmt, lost density to cmt, troubleshoot problem for 20 minutes, back online finished pumping 4.2 bbls of cmt, total of 10.6 bbls of CL "G" at 1.2 bpm, 1400 psi, 1.0 bpm returns. Clean cement line. Insert Dart. Displace dart with 25 bbls Biozan water ~ 2.02 bpm, 1.98 bpm returns, 2350 psi, pumped 20.1 bbls of KCL water, pumped 42 bbls when dart engaged liner wiper plug, sheared at 4010 psi, bumped plug w/ 45.1 bbl, pressured up f/ 1600 psi to 2600 psi ,held for 2 minutes, bled of floats held, CIP at 07:00 hrs on 1/27/06 Cement return volume was 1 for 1 bbls, no fluid loss to formation during cement job. Top of FS at 10102' 1st(Btm) FC at 10099' 2nd(Top) FC at 10068' LC at 10067' BOT Liner Deployment Sleeve at 9476' 07:05 - 08:50 1.751 CEMT P 08:50 - 09:15 0.42 CEMT P 09:15 - 09:30 0.25 EVAL P 09:30 - 11:00 1.501 EVAL N 11:00 - 12:30 12:30 - 14:20 14:20 - 14:35 14:35 - 15:30 1.501 EVAL P 1.83 ~ EVAL P 0.25 EVAL P 0.92 EVAL P RUNPRD RUNPRD LOW ER1 HMAN LOWERI LOW ER1 LOW ER1 LOW ER1 LOW ERi 2 7/8" tbg and accessories was drifted to 2.347", Pin Bore 2.377" ID; 3 1/2" tbg and accessories was drifted to 2.867", Pin Bore 2.972" I D Pressured up to 200 psi, unsting f/ deployment sleeve, POH while tilling voidage Std Back Inj., LD Baker Running Tool PJSM -Review procedure, hazards and mitigation for M/U CNL/GR and motor/mill BHA. Attempt to install MCNL tool in carrier, tool was to long for carrier, had to redesign tool and carrier to fit. SLB hand did not check out equipment until ready to use. SLB was on will call for four days, in daily contact with rig. M/U 2.30" mill, 2-1/8" motor, XO, 2 jts CSH, XO and SWS carrier with MCNL/GR. RIH with 10 stds of CSH workstring. Check torque on connections. M/U SWS MHA. OAL = 728.14', Stab Injector RIH w/ Cleanout Assy and MCNL to 9000' Wait on UCA test results on liner cmt job Results in on UCA test w/ 500 psi compressive strength, RIH to Printed: 1/30/2006 11:20:37 AM BP EXPLORATION Operations Summary Report Page 6 of 6 Legal Well Common W Event Nam Contractor Rig Name: ate Name: ell Name: Z e: Name: om - To Z-11 -11 REENTER+COM NORDIC CALIS NORDIC 1 Hours Task PLETE TA Code NPT ~ Spud Date: 6/15/1990 Start: 1/1/2006 End: Rig Release: 1/28/2006 Rig Number: Phase ~ Descri tion of O erations P P = 1/27/2006 - 14:35 - 15:30 0.92 - EVAL P LOWERI - --_ ___ ---- --- - 9100', Log Dn at 30fpm to PBTD at 10067' w/ .88 bpm at 1250 psi, Log Up at 60fpm to 9100' w/ 1.0 bpm at 1400 psi 15:30 - 15:45 0.25 EVAL P LOWERI RIH to 10067' w/ .88 bpm at 1250 psi 15:45 - 17:30 1.75 EVAL P LOWERI POH to BHA, spotting pert pill in liner, circ hole clean at 1.5 bpm w/ 1900 psi, cement in returns. Set back Injector 17:30 - 19:30 2.00 EVAL P LOWERI POH w/ BHA, Std Bk 1 1/4" CSH, LD MCNL tools, LD mtr and mill. 19:30 - 19:45 0.25 EVAL P LOWERI PJSM Break down loggng tools. 19:45 - 20:00 0.25 EVAL P LOW ER1 Break down logging tools. 20:00 - 21:15 1.25 EVAL P LOW ER1 PU nossel and wash stack. 21:15 - 22:00 0.75 EVAL P LOW ER1 Test liner and lap to 2130 psi for 30 minutes. Lost 25 psi in 30 minutes Good Test 22:00 - 00:00 2.00 EVAL P LOW ER1 Wait on processing of logs. Wait on new printer from dead horse for logging unit. New printer didn't fix problem . Electronically send PDS file to Anchorage. 1/28/2006 00:00 - 00:30 0.50 EVAL P LOWERI Wait on Anchorage reviewing log data. OK to shoot as previously planned. 00:30 - 01:30 1.00 PERFO P LOWERI PU 7 guns and 8 stands of 1-1/4 CSH. 01:30 - 03:30 2.00 PERFO P LOWERI RIH with perforating guns. Tag TD and correct +3' "up". PU WT 26K. 03:30 -04:00 0.50 PERFO P LOWERi PU to setting depth and launch 1/2" steel ball with 1300 psi. 5 bbl FloPro ahead and behind ball. Circulat ball to firing head. Ball on seat at 35.3 bbls pressure to 2000 psi at 35.9 bbl. Good indication guns fired. Guns fired on the fly. 04:00 - 06:00 2.00 PERFO P LOWERI POH to BHA 06:00 - 08:30 2.50 PERFO P LOWERI PJSM on present operations, POH w/ BHA, Stdback CSH, UD pert guns, all shots fired 08:30 - 10:45 2.25 WHSUR P POST MU, RIH w/ nozzle to 2500', freeze protect well w/ 22 bbls - 60/40 McOH to surface 10:45 - 12:10 1.42 RIGD P POST PJSM on handling and pickling CT w/ bleach and corrision inhibited pill, Pump 15 bbls of bleach, 60bbls of fresh water, 15bbls of corrosion inhibitor & 5 bbls of McOH. 12:10 - 12:40 0.50 RIGD P POST PR N2 lines ~ OK, Blow down CT with N2. Meanwhile clean out pits & tanks. 12:40 - 14:30 1.83 RIGD P POST PU Injector, prep for pulling coil across and secure, cut CT, pulled cable back to rig floor 14:30 - 16:00 1.50 RIGD P POST C/O packoff rubber and brass(upper& lower), C/O BOP rams to 2 3!8", RD BOP, finished cleaning out pits 16:00 - 16:30 0.50 RIGD P POST P/T tree cap, secured well, released rig at 16:30 hrs on 01 /28/06 Printed: 1/30/2006 11:20:37 AM Halliburton Global Company: BP Amoco Date: 2/10/2006 Time: 16:06:38 P:~ge: 1 ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Z-11, True No rth Site: PB Z Pad Vertical (fVD) Refer ence: 15 :11 6!15/1990 00:00 91.7 Wcll: Z-11 Section (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) ~ Wellpath: Z-11A Survey Calculation M ethod: Mi nimum Curvature Db: Oracle I Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: Z-11 Slot Name: Z-11 Well Position: +N/-S 1894.53 ft Northing: 5959100.04 ft Latitude: 70 17 51.681 N +E/-W -1804.58 ft Easting : 599475.03 ft Longitude: 149 11 39.968 W Position Uncertainty: 0.00 ft Wellpath: Z-11A Drilled From: Z-11 500292205301 Tie-on Depth: 9 563.60 ft Current Datum: 15: 11 6!15/1990 00 :00 Height 91.70 ft Above System Datum: Mean Sea Level Magnetic Data: 2/8/2005. Declination: 24.76 deg Field Strength: 57575 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direc tion ft ft ft deg 3 7.70 0.00 0.00 275.00 Survey Program for Definitive Wellpath Date: 2/8/2005 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 41.05 9630.49 1 : Schlumberger GCT multi shot (41.05- 104~OM8 Schlumbe rger GCT multish ot 9657.00 10102.00 MWD (9657.00-10102.00) MWD MWD -Standard Survey DIp_ Inc! _ Azim fVD Svs ~ 'fVD N/S E/W Map\ MapE 'lbul ~~, ft deg deg ft ft ft ft ft ft 37.70 0.00 0.00 37.70 -54.00 0.00 0.00 5959100.04 599475.03 TIE LINE 41.05 0.27 136.22 41.05 -50.65 -0.01 0.01 5959100.03 599475.04 GCT-MS 57.65 0.13 104.82 57.65 -34.05 -0.04 0.05 5959100.00 599475.08 GCT-MS 74.75 0.10 53.57 74.75 -16.95 -0.03 0.08 5959100.01 599475.11 GCT-MS 91.85 0.08 345.13 91.85 0.15 -0.01 0.09 5959100.03 599475.12 GCT-MS 109.05 0.08 287.34 109.05 17.35 0.00 0.08 5959100.04 599475.11 GCT-MS 126.25 0.12 231.74 126.25 34.55 -0.01 0.05 5959100.03 599475.08 GCT-MS 143.20 0.13 189.37 143.20 51.50 -0.04 0.03 5959100.00 599475.06 GCT-MS 158.80 0.13 147.02 158.80 67.10 -0.07 0.04 5959099.97 599475.07 GCT-MS 175.80 0.10 90.21 175.80 84.10 -0.09 0.07 5959099.96 599475.10 GCT-MS 192.80 0.08 31.03 192.80 101.10 -0.08 0.09 5959099.97 599475.12 GCT-MS 209.80 0.07 323.21 209.80 118.10 -0.06 0.09 5959099.98 599475.12 GCT-MS 226.80 0.08 250.49 226.80 135.10 -0.05 0.07 5959099.99 599475.10 GCT-MS 243.80 0.10 200.30 243.80 152.10 -0.07 0.05 5959099.97 599475.08 GCT-MS 260.90 0.10 172.17 260.90 169.20 -0.10 0.05 5959099.94 599475.08 GCT-MS 278.00 0.08 142.68 278.00 186.30 -0.12 0.06 5959099.92 599475.09 GCT-MS 295.00 0.05 106.02 295.00 203.30 -0.13 0.07 5959099.91 599475.10 GCT-MS 312.10 0.03 44.60 312.10 220.40 -0.13 0.08 5959099.91 599475.11 GCT-MS 329.25 0.05 333.66 329.25 237.55 -0.12 0.08 5959099.92 599475.11 GCT-MS 346.40 0.05 272.70 346.40 254.70 -0.12 0.07 5959099.92 599475.10 GCT-MS 363.50 0.07 227.04 363.50 271.80 -0.12 0.06 5959099.92 599475.09 GCT-MS 380.65 0.10 197.07 380.65 288.95 -0.14 0.05 5959099.90 599475.08 GCT-MS 397.65 0.08 162.49 397.65 305.95 -0.17 0.04 5959099.87 599475.08 GCT-MS 414.70 0.02 103.72 414.70 323.00 -0.18 0.05 5959099.86 599475.08 GCT-MS 431.80 0.02 27.03 431.80 340.10 -0.18 0.06 5959099.86 599475.09 GCT-MS 448.95 0.05 317.11 448.95 357.25 -0.17 0.05 5959099.87 599475.08 GCT-MS 466.10 0.07 254.46 466.10 374.40 -0.17 0.04 5959099.87 599475.07 GCT-MS 483.30 0.10 210.95 483.30 391.60 -0.19 0.02 5959099.85 599475.05 GCT-MS 500.50 0.12 181.31 500.50 408.80 -0.22 0.01 5959099.82 599475.04 GCT-MS Halliburton Global ~ __ Company: BP Amoco llate: 2/10/2006 Tirue: 16:06:38 Page:. 2 i Field: Pru dhoe Bay Co-ord inate(NE) Reference: WeO: Z-11, True North Site: PB Z Pad Vertical (TVD) Reference: 15 :11 6/15/1990 0 0:00 91.7 Well: Z-1 1 Section (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) Wcllpath: Z-1 ~_ _ 1A _ __ _ _ - _ - _ _ __ ___ _ Survey ~ Calcula8on Method: Mi _ __ _- nimum Curvature - _ _ __ Db: Oracle _ _ _. __ I Sw'vcy MD Incl Haim TVD Sys TVD V/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 517.70 0.08 143.38 517.70 426.00 -0.24 0.02 5959099.80 599475.05 GCT-MS 534.95 0.05 88.90 534.95 443.25 -0.25 0.03 5959099.79 599475.06 GCT-MS 552.15 0.05 21.28 552.15 460.45 -0.25 0.04 5959099.79 599475.08 GCT-MS 569.40 0.08 317.19 569.40 477.70 -0.23 0.04 5959099.81 599475.07 GCT-MS 586.60 0.08 258.42 586.60 494.90 -0.22 0.02 5959099.82 599475.05 GCT-MS 603.90 0.10 211.58 603.90 512.20 -0.24 0.00 5959099.80 599475.03 GCT-MS 621.15 0.13 174.18 621.15 529.45 -0.27 -0.01 5959099.77 599475.02 GCT-MS 638.40 0.10 137.21 638.40 546.70 -0.30 0.00 5959099.74 599475.04 GCT-MS 655.70 0.07 97.64 655.70 564.00 -0.31 0.02 5959099.73 599475.06 GCT-MS 672.90 0.03 359.34 672.90 581.20 -0.31 0.03 5959099.73 599475.07 GCT-MS 690.20 0.07 245.24 690.20 598.50 -0.31 0.02 5959099.73 599475.06 GCT-MS 707.50 0.15 195.84 707.50 615.80 -0.34 0.01 5959099.70 599475.04 GCT-MS 724.75 0.22 176.98 724.75 633.05 -0.39 0.00 5959099.65 599475.04 GCT-MS 741.95 0.27 154.86 741.95 650.25 -0.46 0.02 5959099.58 599475.06 GCT-MS 759.10 0.30 136.08 759.10 667.40 -0.53 0.07 5959099.51 599475.11 GCT-MS 775.90 0.27 131.01 775.90 684.20 -0.59 0.13 5959099.45 599475.17 GCT-MS 792.80 0.22 134.49 792.80 701.10 -0.64 0.19 5959099.41 59947522 GCT-MS 809.70 0.23 145.01 809.70 718.00 -0.69 0.23 5959099.36 599475.27 GCT-MS 826.70 0.28 152.36 826.70 735.00 -0.75 0.27 5959099.29 599475.31 GCT-MS 843.65 0.37 153.04 843.65 751.95 -0.84 0.31 5959099.21 599475.35 GCT-MS 860.70 0.43 148.45 860.70 769.00 -0.94 0.37 5959099.10 599475.41 GCT-MS 877.65 0.45 135.60 877.65 785.95 -1.04 0.45 5959099.00 599475.49 GCT-MS 894.65 0.38 130.87 894.65 802.95 -1.13 0.54 5959098.92 599475.58 GCT-MS 911.65 0.35 135.82 911.65 819.95 -1.20 0.62 5959098.85 599475.66 GCT-MS 928.65 0.42 138.20 928.65 836.95 -1.29 0.69 5959098.76 599475.74 GCT-MS 945:65 0.55 140.20 945.65 853.95 -1.40 0.79 5959098.66 599475.84 GCT-MS 962.75 0.65 139.16 962.74 871.04 -1.53 0.90 5959098.52 599475.95 GCT-MS 979.75 0.68 132.42 979.74 888.04 -1.67 1.04 5959098.38 599476.09 GCT-MS 996.75 0.63 126.99 996.74 905.04 -1.80 1.19 5959098.26 599476.24 GCT-MS 1013.75 0.60 126.71 1013.74 922.04 -1.91 1.34 5959098.15 599476.39 GCT-MS 1030.80 0.67 127.84 1030.79 939.09 -2.02 1.49 5959098.04 599476.54 GCT-MS 1047.85 0.73 130.95 1047.84 956.14 -2.15 1.65 5959097.91 599476.71 GCT-MS 1064.85 0.78 131.57 1064.84 973.14 -2.30 1.82 5959097.76 599476.88 GCT-MS 1081.90 0.83 128.89 1081.89 990.19 -2.46 2.00 5959097.61 599477.06 GCT-MS 1098.90 0.87 127.24 1098.88 1007.18 -2.61 2.20 5959097.46 599477.26 GCT-MS 1115.95 0.87 126.71 1115.93 1024.23 -2.77 2.40 5959097.31 599477.47 GCT-MS 1132.90 0.88 125.72 1132.88 1041.18 -2.92 2.61 5959097.16 599477.68 GCT-MS 1149.90 0.85 123.48 1149.88 1058.18 -3.07 2.82 5959097.01 599477.89 GCT-MS 1166.80 0.83 125.05 1166.78 1075.08 -3.20 3.03 5959096.88 599478.10 GCT-MS 1183.80 0.85 127.22 1183.77 1092.07 -3.35 3.23 5959096.73 599478.30 GCT-MS 1200.80 0.90 126.23 1200.77 1109.07 -3.51 3.44 5959096.58 599478.51 GCT-MS 1217.90 0.92 125.39 1217.87 1126.17 -3.67 3.66 5959096.42 599478.74 GCT-MS 1234.95 0.90 124.42 1234.92 1143.22 -3.82 3.88 5959096.27 599478.96 GCT-MS 1252.00 0.92 120.40 1251.97 1160.27 -3.97 4.11 5959096.13 599479.19 GCT-MS 1269.10 0.90 119.96 1269.06 1177.36 -4.10 4.34 5959096.00 599479.43 GCT-MS 1286.25 0.90 124.35 1286.21 1194.51 -4.25 4.57 5959095.86 599479.66 GCT-MS 1303.30 0.92 124.94 1303.26 1211.56 -4.40 4.80 5959095.70 599479.88 GCT-MS 1320.40 0.93 123.84 1320.36 1228.66 -4.56 5.02 5959095.55 599480.11 GCT-MS 1337.50 0.93 122.19 1337.45 1245.75 -4.71 5.26 5959095.40 599480.35 GCT-MS 1354.60 0.97 119.56 1354.55 1262.85 -4.85 5.50 5959095.26 599480.59 GCT-MS 1371.65 0.90 117.28 1371.60 1279.90 -4.98 5.74 5959095.13 599480.84 GCT-MS 1388.75 0.90 119.66 1388.70 1297.00 -5.11 5.98 5959095.01 599481.08 GCT-MS Halliburton Global Company: BP Amoco Field: Prudhoe Bay Sitr. PB Z Pad VI'dL• Z-11 Wel-path: Z-11A Survcv ~~ MD Incl Acim ft deg -- _ _ _ deg 1405.80 0.98 122.52 1422.95 0.98 122.70 1440.05 1.00 121.91 I 1457.20 1.03 120.77 1474.30 1491.45 1508.60 1525.70 1542.60 1559.45 1576.35 1593.25 1610.15 1627.15 1644.05 1661.00 1677.90 1694.85 1711.80 1728.75 1745.70 1762.65 1779.60 1796.60 1813.60 1830.60 1847.60 1864.60 1881.60 1898.65 1915.55 1932.50 1949.50 1966.55 1983.65 2000.65 2017.75 2034.85 2051.90 2069.00 2086.05 2103.20 2120.30 2137.40 2154.50 2171.60 2188.70 2205.90 2223.00 2240.15 2257.30 2274.45 2291.50 1.03 0.98 0.98 1.02 1.02 1.00 0.92 0.80 0.75 0.75 0.75 0.78 0.78 0.75 0.75 0.72 0.72 0.73 0.75 0.73 0.72 0.75 0.77 0.75 0.75 0.77 0.78 0.77 0.77 0.75 0.75 0.75 0.75 0.75 0.75 0.72 0.62 0.55 0.50 0.47 0.42 0.38 0.40 0.47 0.45 0.43 0.45 0.48 0.53 119.41 117.50 118.68 120.79 120.65 120.06 118.01 115.14 114.27 114.54 115.59 117.62 115.98 111.70 110.65 111.11 110.43 109.66 112.99 113.81 109.21 106.86 107.18 107.19 107.40 110.17 110.96 108.83 108.26 107.98 106.60 107.02 105.36 101.95 100.46 100.85 102.49 103.10 103.04 104.71 109.18 114.98 122.73 124.12 121.99 126.71 134.15 142.37 150.34 Dater 2/10/2006 'l'ime: 16:06:38 Nage: 3 Co-ordinate(NEyReference: Well: Z-11, True North Vertical ('I'VD) Reference: 15:11 6/15/1990 00:00 91.7 Section (VS) Keference: Well (O.OON,O.OOE,275.OOAzi) Sure°ey Calculation Method: Minimum Curvature Db: Oracle 'I Vll Sys T~ D N/S ft ft ft 1405.75 1314.05 -5.26 1422.89 1331.19 -5.42 1439.99 1348.29 -5.57 1457.14 1365.44 -5.73 1474.24 1382.54 -5.89 1491.38 1399.68 -6.03 1508.53 1416.83 -6.17 1525.63 1433.93 -6.31 1542.52 1450.82 -6.47 1559.37 1467.67 -6.62 1576.27 1484.57 -6.76 1593.17 1501.47 -6.87 1610.07 1518.37 -6.97 1627.06 1535.36 -7.06 E/W Map{ ft ft 6.22 5959094.87 6.47 5959094.71 6.72 5959094.56 6.98 5959094.40 7.24 5959094.25 7.51 5959094.11 7.76 5959093.98 8.02 5959093.83 8.28 5959093.68 8.54 5959093.54 8.79 5959093.40 9.01 5959093.29 9.22 5959093.20 9.42 5959093.11 9.62 5959093.02 9.83 5959092.92 10.03 5959092.82 10.24 5959092.73 10.44 5959092.65 10.65 5959092.58 10.85 5959092.50 11.05 5959092.43 11.25 5959092.36 11.45 5959092.27 11.65 5959092.20 11.86 5959092.13 12.08 5959092.07 12.29 5959092.00 12.50 5959091.94 12.72 5959091.87 12.93 5959091.79 13.15 5959091.72 13.36 5959091.65 13.58 5959091.58 13.79 5959091.52 14.01 5959091.46 14.22 5959091.40 14.44 5959091.35 14.66 5959091.31 14.87 5959091.27 15.07 5959091.23 15.24 5959091.19 15.39 5959091.16 15.53 5959091.13 15.66 5959091.09 15.77 5959091.05 15.87 5959090.99 15.98 5959090.92 16.10 5959090.85 16.20 5959090.78 16.30 5959090.69 16.40 5959090.59 16.48 5959090.47 MapE ft Tool 1643.96 1552.26 -7.15 1660.91 1569.21 -7.25 1677.81 1586.11 -7.36 1694.76 1603.06 -7.45 1711.71 1620.01 -7.53 1728.66 1636.96 -7.61 1745.60 1653.90 -7.68 1762.55 1670.85 -7.75 1779.50 1687.80 -7.83 1796.50 1704.80 -7.92 1813.50 1721.80 -8.00 1830.50 1738.80 -8.07 1847.50 1755.80 -8.13 1864.49 1772.79 -8.20 1881.49 1789.79 -8.27 1898.54 1806.84 -8.34 1915.44 1823.74 -8.42 1932.39 1840.69 -8.50 1949.39 1857.69 -8.57 1966.44 1874.74 -8.64 1983.53 1891.83 -8.71 2000.53 1908.83 -8.77 2017.63 1925.93 -8.83 2034.73 1943.03 -8.89 2051.78 1960.08 -8.93 2068.88 1977.18 -8.97 2085.93 1994.23 -9.01 2103.07 2011.37 -9.05 2120.17 2028.47 -9.08 2137.27 2045.57 -9.12 2154.37 2062.67 -9.16 2171.47 2079.77 -9.20 2188.57 2096.87 -9.26 2205.77 2114.07 -9.33 2222.87 2131.17 -9.41 2240.02 2148.32 -9.48 2257.17 2165.47 -9.57 2274.32 2182.62 -9.67 2291.37 2199.67 -9.79 599481.32 GCT-MS 599481.57 GCT-MS 599481.82 GCT-MS 599482.08 GCT-MS 599482.35 GCT-MS 599482.61 GCT-MS 599482.87 GCT-MS 599483.14 GCT-MS 599483.40 GCT-MS 599483.65 GCT-MS 599483.90 GCT-MS 599484.13 GCT-MS 599484.34 GCT-MS 599484.54 GCT-MS 599484.75 GCT-MS 599484.95 GCT-MS 599485.16 GCT-MS 599485.36 GCT-MS 599485.57 GCT-MS 599485.78 GCT-MS 599485.98 GCT-MS 599486.18 GCT-MS 599486.38 GCT-MS 599486.59 GCT-MS 599486.79 GCT-MS 599487.00 GCT-MS 599487.21 GCT-MS 599487.43 GCT-MS 599487.64 GCT-MS 599487.86 GCT-MS 599488.07 GCT-MS 599488.29 GCT-MS 599488.51 GCT-MS 599488.72 GCT-MS 599488.94 GCT-MS 599489.15 GCT-MS 599489.37 GCT-MS 599489.58 GCT-MS 599489.80 GCT-MS 599490.02 GCT-MS 599490.21 GCT-MS 599490.39 GCT-MS 599490.54 GCT-MS 599490.68 GCT-MS 599490.81 GCT-MS 599490.92 GCT-MS 599491.02 GCT-MS 599491.13 GCT-MS 599491.25 GCT-MS 599491.36 GCT-MS 599491.46 GCT-MS 599491.55 GCT-MS 599491.64 GCT-MS Halliburton ~ Global Company: BP Amoco Date: 2/10/2006 'l'ime: 16:06:38 - -- Pager 4 Field: Pru dhoe Bay Co-ord inate(~YE} Reference: Well: Z-11, True No rth Site: PB Z Pad Vertica l (TVll) Reference: 15 :11 6/15!1990 0 0:00 91.7 Wcll: Z-1 1 Section (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) Wellpath: Z-1 1A Survey Calculation Method: Minimum Curvature Db: Oracle Surve~~ _ _ -_ - A1D Intl Azim _ TVD -- Sys TVD N/S E/W MapN A~IapE Tool ft deg deg ft ft ft ft ft ft j 2308.55 0.57 156.42 2308.42 -_ 2216.72 _ _ . -9.94 _ 16.55 _ - 5959090.32 599491.71 GCT-MS 2325.35 0.62 161.44 2325.22 2233.52 -10.10 16.61 5959090.16 599491.77 GCT-MS 2342.25 0.73 163.34 2342.12 2250.42 -10.29 16.67 5959089.97 599491.84 GCT-MS 2359.15 0.80 166.81 2359.01 2267.31 -10.51 16.73 5959089.75 599491.90 GCT-MS 2376.05 0.82 171.70 2375.91 2284.21 -10.75 16.78 5959089.52 599491.95 GCT-MS 2392.95 0.88 174.57 2392.81 2301.11 -10.99 16.81 5959089.27 599491.98 GCT-MS 2409.85 0.90 177.24 2409.71 2318.01 -11.26 16.82 5959089.01 599492.00 GCT-MS 2426.75 0.93 179.01 2426.61 2334.91. -11.53 16.83 5959088.74 599492.01 GCT-MS 2443.65 0.95 180.71 2443.50 2351.80 -11.80 16.83 5959088.46 599492.02 GCT-MS 2460.55 1.05 181.07 2460.40 2368.70 -12.10 16.83 5959088.17 599492.02 GCT-MS 2477.50 1.17 181.18 2477.35 2385.65 -12.43 16.82 5959087.84 599492.01 GCT-MS 2494.40 1.22 181.76 2494.25 2402.55 -12.78 16.81 5959087.49 599492.01 GCT-MS 2511.30 1.23 181.11 2511.14 2419.44 -13.14 16.80 5959087.13 599492.01 GCT-MS 2528.25 1.23 180.64 2528.09 2436.39 -13.50 16.80 5959086.76 599492.00 GCT-MS 2545.20 1.25 180.41 2545.03 2453.33 -13.87 16.80 5959086.39 599492.01 GCT-MS 2562.10 1.23 180.94 2561.93 2470.23 -14.24 16.79 5959086.03 599492.01 GCT-MS 2579.10 1.23 182.91 2578.93 2487.23 -14.60 16.78 5959085.66 599492.00 GCT-MS 2596.00 1.23 183.47 2595.82 2504.12 -14.96 16.76 5959085.30 599491.98 GCT-MS 2612.90 1.25 183.32 2612.72 2521.02 -15.33 16.74 5959084.94 599491.97 GCT-MS 2629.90 1.27 183.02 2629.71 2538.01 -15.70 16.72 5959084.56 599491.95 GCT-MS 2646.80 1.27 182.45 2646.61 2554.91 -16.08 16.70 5959084.19 599491.94 GCT-MS 2663.65 1.25 181.95 2663.46 2571.76 -16.45 16.68 5959083.82 599491.93 GCT-MS 2680.40 1.20 180,99 2680.20 2588.50 -16.80 16.68 5959083.46 599491.92 GCT-MS 2697.25 1.18 181.00 2697.05 2605.35 -17.15 16.67 5959083.11 599491.92 GCT-MS 2714.15 1.22 181.64 2713.94 2622.24 -17.51 16.66 5959082:76 599491.92 GCT-MS 2731.05 1.25 181.16 2730.84 2639.14 -17.87 16.65 5959082.39 599491.92 GCT-MS 2747.95 1.32 181.01 2747.74 2656.04 -18.25 16.64 5959082.01 599491.91 GCT-MS 2764.95 1.40 181.61 2764.73 2673.03 -18.65 16.64 5959081.61 599491.91 GCT-MS 2781.85 1.47 181.67 2781.63 2689.93 -19.08 16.62 5959081.19 599491.90 GCT-MS 2798.75 1.57 181.29 2798.52 2706.82 -19.52 16.61 5959080.74 599491.90 GCT-MS 2815.75 2.00 182.04 2815.51 2723.81 -20.05 16.60 5959080.21 599491.89 GCT-MS 2832.65 2.68 182.71 2832.40 2740.70 -20.74 16.57 5959079.52 599491.87 GCT-MS 2849.65 3.30 181.86 2849.37 2757.67 -21.63 16.53 5959078.63 599491.85 GCT-MS 2866.60 3.80 181.01 2866.29 2774.59 -22.68 16.51 5959077.58 599491.83 GCT-MS 2883.55 4.22 181.16 2883.20 2791.50 -23.86 16.48 5959076.40 599491.83 GCT-MS 2900.55 4.62 182.23 2900.15 2808.45 -25.17 16.44 5959075.09 599491.80 GCT-MS 2917.50 5.07 182.24 2917.04 2825.34 -26.60 16.39 5959073.66 599491.77 GCT-MS 2934.50 5.65 181.34 2933.96 2842.26 -28.19 16.34 5959072.07 599491.74 GCT-MS 2951.50 6.15 181.18 2950.87 2859.17 -29.94 16.30 5959070.32 599491.72 GCT-MS 2968.50 6.57 181.21 2967.77 2876.07 -31.82 16.26 5959068.44 599491.71 GCT-MS 2985.50 6.98 180.87 2984.65 2892.95 -33.83 16.23 5959066.43 599491.70 GCT-MS 3003.30 7.47 180.16 3002.31 2910.61 -36.06 16.21 5959064.20 599491.71 GCT-MS 3034.70 8.47 179.67 3033.41 2941.71 -40.42 16.21 5959059.84 599491.78 GCT-MS 3067.10 9.43 179.35 3065.41 2973.71 -45.46 16.26 5959054.80 599491.89 GCT-MS 3098.95 10.33 177.91 3096.79 3005.09 -50.92 16.39 5959049.34 599492.09 GCT-MS 3130.90 11.20 176.81 3128.18 3036.48 -56.88 16.67 5959043.39 599492.45 GCT-MS 3163.25 12.10 176.82 3159.86 3068.16 -63.40 17.03 5959036.87 599492.90 GCT-MS 3195.55 13.08 177.15 3191.38 3099.68 -70.44 17.40 5959029.85 599493.36 GCT-MS 3228.05 14.02 177.76 3222.98 3131.28 -78.04 17.74 5959022.25 599493.80 GCT-MS 3260.55 14.62 179.87 3254.47 3162.77 -86.08 17.90 5959014.21 599494.07 GCT-MS 3293.00 15.13 182.84 3285.83 3194.13 -94.40 17.70 5959005.89 599493.98 GCT-MS 3325.85 15.82 185.16 3317.49 3225.79 -103.14 17.09 5958997.14 599493.48 GCT-MS Halliburton Global Company: BP Amoco Date: 211 012 0 0 6 'Dime: 16:06:38 Pate: 5 field: Pru dhoe Bay Co-ord inate(NE) Re ference: Well: Z-11, True N orth ~~ Site: PB Z Pad Vertical (TVD) Refe rence: 15 :11 6/15/1990 00:00 91.7 i 0 ) ~ 0 0 75.00 ) Wellpath_ Z 1 1 A _ _ _ _. _Surrey Cal u time I1lethod: _ _ M n i m um Cu ure rvat D b: Oracle _ l Surrey __ (v1D -ncl Azim 'TVD SpsTVD N/S E/~V irlapN Mapf Ibol ~~ ft deg deg ft ft ft ft ft ft 3360.60 16.45 185.13 3350.87 3259.17 -112.76 16.22 5958987.51 599492.74 GCT-MS 3395.30 17.03 183.59 3384.10 3292.40 -122.73 15.46 5958977.54 599492.11 GCT-MS 3429.90 17.87 181.81 3417.11 3325.41 -133.09 14.98 5958967.17 599491.77 GCT-MS 3464.70 18.95 179.63 3450.13 3358.43 -144.08 14.84 5958956.18 599491.78 GCT-MS 3499.60 20.03 177.46 3483.03 3391.33 -155.72 15.15 5958944.55 599492.23 GCT-MS 3534.45 21.03 175.63 3515.66 3423.96 -167.91 15.89 5958932.37 599493.14 GCT-MS 3569.30 22.13 174.42 3548.07 3456.37 -180.68 17.00 5958919.61 599494.42 GCT-MS 3604.25 23.33 173.40 3580.31 3488.61 -194.11 18.44 5958906.21 599496.03 GCT-MS 3639.15 24.53 172.86 3612.20 3520.50 -208.16 20.13 5958892.18 599497.91 GCT-MS 3674.15 25.70 172.58 3643.90 3552.20 -222.90 22.02 5958877.47 599499.99 GCT-MS 3709.10 26.83 172.46 3675.24 3583.54 -238.23 24.03 5958862.17 599502.21 GCT-MS 3744.15 27.92 172.49 3706.36 3614.66 -254.21 26.14 5958846.22 599504.53 GCT-MS 3779.15 28.95 172.46 3737.14 3645.44 -270.73 28.32 5958829.73 599506.93 GCT-MS 3814.00 29.60 172.24 3767.54 3675.84 -287.62 30.59 5958812.87 599509.42 GCT-MS 3848.30 29.93 171.82 3797.31 3705.61 -304.49 32.95 5958796.04 599512.01 GCT-MS 3882.85 30.25 171.74 3827.21 3735.51 -321.63 35.43 5958778.94 599514.71 GCT-MS 3917.40 30.48 171.96 3857.02 3765.32 -338.92 37.91 5958761.68 599517.41 GCT-MS 3951.90 30.75 172.27 3886.71 3795.01 -356.32 40.32 5958744.31 599520.05 GCT-MS 3986.50 31.02 172.46 3916.40 3824.70 -373.92 42.67 5958726.75 599522.65 GCT-MS 4021.00 31.27 172.56 3945.93 3854.23 -391.62 45.00 5958709.09 599525.21 GCT-MS 4055.65 31.33 172.67 3975.54 3883.84 -409.47 47.31 5958691.27 599527.76 GCT-MS 4090.25 31.23 172.69 4005.11 3913.41 -427.29 49.60 5958673.48 599530.28 GCT-MS 4124.85 31.27 172.71 4034.69 3942.99 -445.09 51.88 5958655.71 599532.80 GCT-MS 4159.45 31.52 172.83 4064.22 3972.52 -462.97 54.15 5958637.87 599535.30 GCT-MS 4194.05 31.88 172.99 4093.66 4001.96 -481.01 56.40 5958619.86 599537.78 GCT-MS 4228.55 32.28 173.05 4122.89 4031.19 -499.20 58.62 5958601.70 599540.25 GCT-MS 4263.15 32.67 173.11 4152.08 4060.38 -517.64 60.86 5958583.29 599542.73 GCT-MS 4297.70 32.90 173.23 4181.13 4089.43 -536.22 63.09 5958564.75 599545.20 GCT-MS 4332.35 33.13 173.34 4210.18 4118.48 -554.97 65.29 5958546.03 599547.66 GCT-MS 4366.85 33.43 173.42 4239.02 4147.32 -573.77 67.48 5958527.26 599550.09 GCT-MS 4401.50 33.70 173.48 4267.90 4176.20 -592.81 69.66 5958508.26 599552.53 GCT-MS 4436.10 33.77 173.59 4296.67 4204.97 -611.90 71.83 5958489.20 599554.94 GCT-MS 4470.70 33.72 173.68 4325.44 4233.74 -631.00 73.96 .5958470.13 599557.32 GCT-MS 4505.40 33.67 173.64 4354.31 4262.61 -650.13 76.08 5958451.03 599559.70 GCT-MS 4540.30 33.60 173.46 4383.37 4291.67 -669.34 78.25 5958431.85 599562.13 GCT-MS 4574.40 33.53 173.31 4411.78 4320.08 -688.07 80.43 5958413.16 599564.55 GCT-MS 4608.30 33.58 173.26 4440.03 4348.33 -706.68 82.62 5958394.58 599566.98 GCT-MS 4642.50 33.67 173.23 4468.51 4376.81 -725.49 84.84 5958375.80 599569.46 GCT-MS 4676.60 33.58 173.15 4496.90 4405.20 -744.24 87.08 5958357.09 599571.95 GCT-MS 4710.80 33.52 173.05 4525.41 4433.71 -763.00 89.35 5958338.36 599574.47 GCT-MS 4744.95 33.53 172.97 4553.88 4462.18 -781.72 91.65 5958319.67 599577.01 GCT-MS 4779.15 33.47 172.84 4582.39 4490.69 -800.45 93.98 5958300.97 599579.59 GCT-MS 4813.30 33.38 172.77 4610.90 4519.20 -819.12 96.34 5958282.34 599582.19 GCT-MS 4847.50 33.37 172.77 4639.46 4547.76 -837.78 98.70 5958263.71 599584.81 GCT-MS 4881.75 33.32 172.73 4668.07 4576.37 -856.46 101.08 5958245.07 599587.43 GCT-MS 4916.05 33.27 172.69 4696.74 4605.04 -875.13 103.47 5958226.43 599590.06 GCT-MS 4950.30 33.17 172.67 4725.39 4633.69 -893.75 105.86 5958207.85 599592.70 GCT-MS 4984.55 33.02 172.62 4754.08 4662.38 -912.29 108.25 5958189.34 599595.34 GCT-MS 5018.85 32.90 172.58 4782.86 4691.16 -930.80 110.66 5958170.87 599597.99 GCT-MS 5053.15 32.72 172.52 4811.69 4719.99 -949.23 113.07 5958152.48 599600.64 GCT-MS 5087.55 32.58 172.45 4840.66 4748.96 -967.63 115.49 5958134.11 599603.31 GCT-MS 5121.85 32.43 172.51 4869.58 4777.88 -985.90 117.91 5958115.87 599605.96 GCT-MS 5156.15 32.32 172.51 4898.55 4806.85 -1004.11 120.30 5958097.70 599608.60 GCT-MS Halliburton Global Company: BP Amoco llate: 2/10/2006 'Circe: 16:06:38 Page: 6 ~, Ficld: Pru dhoe Bay Co-ord inate(NE) Re ference: Well: Z-11, True N orth Site: PB Z Pad Vertical ('I'VD) Refe rence: 15 :11 6/15/1990 00:00 91.7 ~ ~~ ell: Z-1 1 Section (VS) Keference: Well (0 OON,O.OOE ,275.OOAzi) I ~l'ellpath: Z-1 1A Surce~ Calculation (Method: Min imum Curvatur e Db: Orade $urve~~ --- r lV1D Incl Azim CVll Sys'1'VD ~/S E/W Maps] N1apE "Cool I ft deg deg ft ft ft ft ft ft 1 5190.50 32.20 172.45 4927.60 ___ _ _ 4835.90 _--- -1022.29 122.70 --- - 5958079.56 - -- 599611.24 11 __ - _ GCT-MS I 5224.95 31.98 172.39 4956.78 4865.08 -1040.43 125.11 5958061.45 599613.89 GCT-MS 5259.30 31.92 172.36 4985.93 4894.23 -1058.44 127.53 5958043.47 599616.54 GCT-MS 5293.15- 31.77 172.31 5014.69 4922.99 -1076.15 129.91 5958025.80 599619.16 GCT-MS 5326.85 31.50 172.21 5043.38 4951.68 -1093.66 132.29 5958008.32 599621.77 GCT-MS 5360.60 31.38 172.16 5072.17 4980.47 -1111.10 134.68 5957990.92 599624.39 GCT-MS 5394.45 31.30 172.16 5101.08 5009.38 -1128.54 137.08 5957973.51 599627.03 GCT-MS 5428.25 31.13 172.16 5129.99 5038.29 -1145.90 139.47 5957956.19 599629.65 GCT-MS 5462.10 31.00 172.16 5158.99 5067.29 -1163.20 141.86 5957938.92 599632.26 GCT-MS 5495.90 30.92 172.18 5187.97 5096.27 -1180.42 144.23 5957921.73 599634.85 GCT-MS 5529.80 30.88 172.19 5217.06 5125.36 -1197.67 146.59 5957904.52 599637.45 GCT-MS 5563.65 30.72 172.19 5246.14 5154.44 -1214.84 148.95 5957887.38 599640.03 GCT-MS 5597.50 30.52 172.21 5275.27 5183.57 -1231.93 151.29 5957870.33 599642.60 GCT-MS 5631.40 30.32 172.24 5304.50 5212.80 -1248.93 153.61 5957853.36 599645.14 GCT-MS 5665.30 30.08 172.24 5333.80 5242.10 -1265.83 155.91 5957836.50 599647.67 GCT-MS 5699.20 29.93 172.23 5363.15 5271.45 -1282.63 158.20 5957819.73 599650.18 GCT-MS 5733.10 29.70 172.23 5392.57 5300.87 -1299.33 160.48 5957803.07 599652.68 GCT-MS 5767.00 29.48 172.27 5422.05 5330.35 -1315.91 162.74 5957786.51 599655.16 GCT-MS 5800.90 29.35 172.37 5451.58 5359.88 -1332.41 164.96 5957770.05 599657.60 GCT-MS 5834.90 29.22 172.48 5481.23 5389.53 -1348.90 167.16 5957753.59 599660.01 GCT-MS 5868.80 29.20 172.54 5510.82 5419.12 -1365.30 169.31 5957737.22 599662.38 GCT-MS 5902.80 29.27 172.54 5540.49 5448.79 -1381.77 171.47 5957720.79 599664.76 GCT-MS 5936.80 29.28 172.54 5570.15 5478.45 -1398.25 173.63 5957704.33 599667.13 GCT-MS 5970.80 29.23 172.56 5599.81 5508.11 -1414.73 175.78 5957687.89 599669.51 GCT-MS 6004.30 29.23 172.60 5629.04 5537.34 -1430.95 177.89 5957671.70 599671.83 GCT-MS 6037.65 29.23 172.66 5658.15 5566.45 -1447.10 179.98 5957655.58 599674.13 GCT-MS 6070.95 29.20 172.77 5687.21 5595.51 -1463.22 182.04 5957639.49 599676.41 GCT-MS 6104.35 29.17 172.88 5716.37 5624.67 -1479.38 184.08 5957623.36 599678.66 GCT-MS 6137.80 29.12 173.00 5745.59 5653.89 -1495.55 186.08 5957607.22 599680.87 GCT-MS 6171.20 29.00 173.13 5774.78 5683.08 -1511.65 188.04 5957591.14 599683.04 GCT-MS 6204.75 28.82 173.27 5804.15 5712.45 -1527.76 189.96 5957575.07 599685.18 GCT-MS 6238.20 28.63 173.44 5833.48 5741.78 -1543.73 191.82 5957559.12 599687.25 GCT-MS 6271.75 28.50 173.54 5862.95 5771.25 -1559.66 193.64 5957543.21 599689.28 GCT-MS 6305.20 28.38 173.54 5892.36 5800.66 -1575.49 195.43 5957527.41 599691.28 GCT-MS 6338.75 28.22 173.52 5921.90 5830.20 -1591.30 197.22 5957511.63 599693.28 GCT-MS 6372.30 27.98 173.55 5951.50 5859.80 -1607.00 199.00 5957495.96 599695.27 GCT-MS 6405.85 27.78 173.62 5981.15 5889.45 -1622.59 200.76 5957480.39 599697.23 GCT-MS 6439.45 27.48 173.78 6010.92 5919.22 -1638.08 202.47 5957464.93 599699.14 GCT-MS 6473.05 27.15 174.06 6040.78 5949.08 -1653.41 204.10 5957449.62 599700.98 GCT-MS 6506.65 26.85 174.41 6070.71 5979.01 -1668.59 205.63 5957434.47 599702.71 GCT-MS 6540.25 26.52 174.85 6100.74 6009.04 -1683.61 207.04 5957419.47 599704.32 GCT-MS 6573.85 26.23 175.30 6130.84 6039.14 -1698.48 208.33 5957404.62 599705.80 GCT-MS 6607.55 26.05 175.51 6161.09 6069.39 -1713.28 209.52 5957389.83 599707.18 GCT-MS 6641.15 25.95 175.42 6191.29 6099.59 -1727.96 210.68 5957375.17 599708.54 GCT-MS 6674.75 25.97 175.26 6221.50 6129.80 -1742.62 211.88 5957360.53 599709.93 GCT-MS 6707.95 25.90 175.34 6251.36 6159.66 -1757.09 213.07 5957346.08 599711.31 GCT-MS 6741.05 25.73 175.57 6281.15 6189.45 -1771.46 214.21 5957331.72 599712.65 GCT-MS 6774.05 25.63 175.79 6310.89 6219.19 -1785.72 215.28 5957317.48 599713.91 GCT-MS 6806.95 25.55 176.03 6340.57 6248.87 -1799.90 216.30 5957303.32 599715.11 GCT-MS 6840.15 25.45 176.24 6370.53 6278.83 -1814.16 217.26 5957289.08 599716.26 GCT-MS 6873.25 25.38 176.41 6400.43 6308.73 -1828.33 218.17 5957274.92 599717.36 GCT-MS 6906.35 25.38 176.54 6430.33 6338.63 -1842.49 219.04 5957260.77 599718.42 GCT-MS Halliburton Global Company: BP Amoco Date: 2/10/2006 'time: 16:06:38- Page: 7 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Z-11, True North Site: PB Z Pad Vertical ('I'VD) Reference: 15:11 6/15/1990 00.00 91.7 Well: Z-11 Section (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) Wellpath: Z-11A Surve~~ Calculation !1lethod: Minimum Curvature Db: Oracle -- - - _ - -- _ __ _ _ _-- _ j $ur~cv IVID Incl Azirn 1'VD Sps'I'VD N/S E/~V MapN NIapE Tool '~~ ft deg deg ft ft ft ft ft ft I 6939.35 25.45 176.68 6460.14 6368.44 -1856.63 219.88 5957246.65 599719.45 GCT-MS 6972.55 25.52 176.88 6490.11 6398.41 -1870.89 220.68 5957232.40 599720.44 GCT-MS 7005.65 25.45 177.21 6519.99 6428.29 -1885.12 221.42 5957218.18 599721.36 GCT-MS I 7038.75 25.28 177.52 6549.90 6458.20 -1899.28 222.07 5957204.03 599722.20 GCT-MS 7071.75 25.23 177.83 6579.74 6488.04 -1913.35 222.64 5957189.97 599722.96 GCT-MS 7104.85 25.20 178.35 6609.69 6517.99 -1927.44 223.11 5957175.89 599723.61 GCT-MS 7137.95 25.20 178.90 6639.64 6547.94 -1941.53 223.45 5957161.81 599724.14 GCT-MS 7170.95 25.35 179.33 6669.48 6577.78 -1955.62 223.67 5957147.72 599724.54 GCT-MS 7204.05 25.48 179.78 6699.38 6607.68 -1969.83 223.78 5957133.52 599724.84 GCT-MS 7237.15 25.52 180.02 6729.25 6637.55 -1984.08 223.80 5957119.28 599725.05 GCT-MS 7270.25 25.48 180.13 6759.13 6667.43 -1998.33 223.78 5957105.03 599725.22 GCT-MS 7303.35 25.47 180.41 6789.01 6697.31 -2012.56 223.72 5957090.79 599725.34 GCT-MS 7336.55 25.48 180.91 6818.98 6727.28 -2026.84 223.55 5957076.52 599725.37 GCT-MS 7369.55 25.50 181.45 6848.77 6757.07 -2041.04 223.26 5957062.32 599725.26 GCT-MS 7402.10 25.50 181.96 6878.15 6786.45 -2055.05 222.84 5957048.31 599725.03 GCT-MS 7434.65 25.55 182.49 6907.52 6815.82 -2069.06 222.30 5957034.29 599724.67 GCT-MS 7467.15 25.65 182.99 6936.83 6845.13 -2083.09 221.63 5957020.25 599724.19 GCT-MS 7499.60 25.77 183.45 6966.07 6874.37 -2097.14 220.84 5957006.19 599723.58 GCT-MS 7532.05 25.90 183.89 6995.28 6903.58 -2111.26 219.93 5956992.07 599722.87 GCT-MS 7564.60 26.08 184.35 7024.54 6932.84 -2125.48 218.91 5956977.83 599722.03 GCT-MS 7597.20 26.27 184.84 7053.79 6962.09 -2139.82 217.75 5956963.48 599721.07 GCT-MS 7629.75 26.42 185.55 7082.96 6991.26 -2154.20 216.45 5956949.08 599719.95 GCT-MS 7662.30 26.55 186.35 7112.10 7020.40 -2168.64 214.94 5956934.63 599718.64 GCT-MS 7694.90 26.63 187.17 7141.25 7049.55 -2183.13 213.22 5956920.12 599717.11 GCT-MS 7727.50 26.67 188.08 7170.38 7078.68 -2197.62 211.28 5956905.60 599715.36 GCT-MS 7760.10 26.73 188.95 7199.51 7107.81 -2212.11 209.11 5956891.09 599713.38 GCT-MS 7792.70 26.85 189.71 7228.61 7136.91 -2226.61 206.73 5956876.56 599711.19 GCT-MS 7825.30 26.93 190.32 7257.68 7165.98 -2241.13 204.17 5956862.01 599708.82 GCT-MS 7857.90 27.02 190.74 7286.74 7195.04 -2255.66 201.46 5956847.44 599706.31 GCT-MS 7890.60 27.12 191.06 7315.86 7224.16 -2270.28 198.65 5956832.79 599703.69 GCT-MS 7923.20 27.13 191.41 7344.87 7253.17 -2284.86 195.75 5956818.18 599700.99 GCT-MS 7955.80 27.12 191.59 7373.88 7282.18 -2299.42 192.79 5956803.58 599698.22 GCT-MS 7988.40 27.20 191.71 7402.89 7311.19 -2313.99 189.79 5956788.97 599695.41 GCT-MS 8021.10 27.23 191.81 7431.97 7340.27 -2328.64 186.74 5956774.29 599692.56 GCT-MS 8053.60 27.00 192.04 7460.90 7369.20 -2343.13 183.68 5956759.76 599689.69 GCT-MS 8085.70 26.73 192.56 7489.53 7397.83 -2357.30 180.59 5956745.54 599686.79 GCT-MS 8117.80 26.58 192.83 7518.22 7426.52 -2371.35 177.42 5956731.46 599683.81 GCT-MS 8149.90 26.48 192.98 7546.94 7455.24 -2385.33 174.22 5956717.44 599680.79 GCT-MS 8181.90 26.32 193.41 7575.60 7483.90 -2399.18 170.97 5956703.55 599677.73 GCT-MS 8213.90 26.15 194.02 7604.31 7512.61 -2412.92 167.62 5956689.76 599674.56 GCT-MS 8245.85 26.15 194.49 7632.99 7541.29 -2426.57 164.15 5956676.07 599671.27 GCT-MS 8277.95 26.12 194.98 7661.81 7570.11 -2440.24 160.56 5956662.35 599667.86 GCT-MS 8310.04 26.12 195.58 7690.62 7598.92 -2453.87 156.83 5956648.68 599664.31 GCT-MS 8342.04 26.12 196.15 7719.35 7627.65 -2467.42 152.98 5956635.08 599660.64 GCT-MS 8374.15 26.12 196.73 7748.18 7656.48 -2480.98 148.98 5956621.47 599656.82 GCT-MS 8406.25 26.18 197.13 7777.00 7685.30 -2494.51 144.86 5956607.88 599652.88 GCT-MS 8438.25 26.25 197.20 7805.71 7714.01 -2508.02 140.69 5956594.32 599648.89 GCT-MS 8470.35 26.25 197.09 7834.49 7742.79 -2521.59 136.50 5956580.70 599644.88 GCT-MS 8502.45 26.23 197.15 7863.29 7771.59 -2535.15 132.33 5956567.09 599640.89 GCT-MS 8534.45 26.17 197.40 7892.00 7800.30 -2548.64 128.13 5956553.54 599636.87 GCT-MS 8566.45 26.10 197.65 7920.73 7829.03 -2562.08 123.89 5956540.05 599632.81 GCT-MS 8598.50 26.10 197.96 7949.51 7857.81 -2575.51 119.58 5956526.57 599628.67 GCT-MS 8630.60 26.15 198.49 7978.33 7886.63 -2588.93 115.15 5956513.09 599624.43 GCT-MS Halliburton Global Company: BP Amoco Date: 2/10/2006 'l'ime: 16:06:38 Pati e: 8 Field: Pru dhoe Bay _ Co-ordinate(~E) Reference: Welt Z-11, True North Site: PB Z Pad Vertic al (TVD) Reference: 15 :11 6/15/1990 0 0:00 91.7 j Well: Z-1 1 Sectio n (VS) Referen ce: Well (O.OON,O.OOE,275.OOAzi) Wellpath: Z-1 1A Survey Calculation Method: Mi nimum Curvalure Db: Oracie Cur~'ev Mll Incl Aim TVD Sys'I'VD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ', 8662.65 26.13 199.24 8007.10 7915.40 -2602.29 110.59 5956499.67 -- _ 599620.04 _ _ GCT-MS 8694.70 26.10 200.26 8035.88 7944.18 -2615.57 105.82 5956486.33 599615.45 GCT-MS 8726.40 26.10 201.42 8064.35 7972.65 -2628.60 100.86 5956473.23 599610.66 GCT-MS 8757.80 26.08 202.56 8092.55 8000.85 -2641.41 95.69 5956460.36 599605.66 GCT-MS 8789.29 26.12 203.76 8120.83 8029.13 -2654.15 90.24 5956447.56 599600.38 GCT-MS 8820.70 26.23 204.91 8149.02 8057.32 -2666.77 84.53 5956434.86 599594.84 GCT-MS 8852.20 26.33 205.80 8177.26 8085.56 -2679.37 78.56 5956422.18 599589.04 GCT-MS 8883.55 26.43 206.55 8205.35 8113.65 -2691.87 72.42 5956409.60 599583.06 GCT-MS 8914.90 26.48 207.24 8233.41 8141.71 -2704.33 66.10 5956397.06 599576.91 GCT-MS 8946.20 26.43 207.74 8261.44 8169.74 -2716.70 59.66 5956384.61 599570.64 GCT-MS 8977.70 26.35 208.11 8289.65 8197.95 -2729.07 53.10 5956372.16 599564.25 GCT-MS 9009.14 26.32 208.49 8317.83 8226.13 -2741.35 46.49 5956359.79 599557.80 GCT-MS 9040.64 26.27 209.06 8346.07 8254.37 -2753.58 39.78 5956347.47 599551.24 GCT-MS 9070.49 26.18 209.48 8372.85 8281.15 -2765.09 33.33 5956335.88 599544.95 GCT-MS 9089.35 26.20 209.59 8389.77 8298.07 -2772.33 29.22 5956328.59 599540.94 GCT-MS 9101.95 26.23 209.81 8401.08 8309.38 -2777.16 26.47 5956323.72 599538.25 GCT-MS 9114.60 26.18 210.19 8412.43 8320.73 -2782.00 23.67 5956318.84 599535.52 GCT-MS 9127.25 26.18 210.49 8423.78 8332.08 -2786.82 20.85 5956313.99 599532.76 GCT-MS 9139.85 26.33 210.63 8435.08 8343.38 -2791.62 18.02 5956309.15 599529.99 GCT-MS 9152.45 26.45 210.93 8446.37 8354.67 -2796.43 15.15 5956304.31 599527.19 GCT-MS 9165.04 26.33 211.46 8457.64 8365.94 -2801.22 12.25 5956299.48 599524.36 GCT-MS 9177.70 26.28 211.91 8468.99 8377.29 -2805.99 9.31 5956294.67 599521.47 GCT-MS 9190.35 26.25 212.30 8480.34 8388.64 -2810.73 6.33 5956289.89 599518.56 GCT-MS 9202.95 26.17 212.65 8491.64 8399.94 -2815.43 3.34 5956285.15 599515.64 GCT-MS 9215.65 26.10 212.98 8503.04 8411.34 -2820.13 0.31 5956280.41 599512.67 GCT-MS 9228.35 26.02 213.27 8514.45 8422.75 -2824.80 -2.74 5956275.70 599509.68 GCT-MS 9240.95 25.97 213.59 8525.78 8434.08 -2829.41 -5.78 5956271.05 599506.70 GCT-MS 9253.60 25.97 214.03 8537.15 8445.45 -2834.01 -8.86 5956266.41 599503.68 GCT-MS 9266.25 26.03 214.22 8548.52 8456.82 -2838.60 -11.97 5956261.78 599500.63 GCT-MS 9278.74 25.95 214.44 8559.75 8468.05 -2843.12 -15.06 5956257.22 599497.60 GCT-MS 9279.35 25.95 214.45 8560.29 8468.59 -2843.34 -15.21 5956257.00 599497.46 GCT-MS 9296.54 26.15 214.78 8575.74 8484.04 -2849.55 -19.50 5956250.73 599493.25 GCT-MS 9330.00 26.08 215.82 8605.78 8514.08 -2861.57 -28.01 5956238.60 599484.90 GCT-MS 9363.75 26.07 216.76 8636.10 8544.40 -2873.53 -36.79 5956226.53 599476.28 GCT-MS 9396.95 26.38 217.62 8665.88 8574.18 -2885.22 -45.66 5956214.73 599467.57 GCT-MS 9430.20 26.78 218.11 8695.62 8603.92 -2896.96 -54.79 5956202.86 599458.59 GCT-MS 9463.45 26.83 218.31 8725.29 8633.59 -2908.74 -64.06 5956190.96 599449.48 GCT-MS 9496.79 26.53 218.92 8755.08 8663.38 -2920.44 -73.40 5956179.14 599440.29 GCT-MS 9530.14 26.32 219.43 8784.95 8693.25 -2931.95 -82.78 5956167.51 599431.07 GCT-MS 9563.60 26.23 219.51 8814.95 8723.25 -2943.38 -92.20 5956155.96 599421.81 GCT-MS 9630.49 26.35 219.22 8874.92 8783.22 -2966.29 -110.99 5956132.81 599403.32 GCT-MS 9657.00 26.49 218.64 8898.67 8806.97 -2975.45 -118.39 5956123.55 599396.04 MWD 9683.68 33.40 233.67 8921.82 8830.12 -2984.46 -128.03 5956114.41 599386.52 MWD 9710.55 39.46 242.89 8943.44 8851.74 -2992.74 -141.62 5956105.95 599373.05 MWD 9736.48 46.47 249.52 8962.42 8870.72 -2999.80 -157.78 5956098.68 599356.98 MWD 9763.47 50.62 256.60 8980.29 8888.59 -3005.65 -177.12 5956092.58 599337.72 MWD 9795.83 56.78 273.48 8999.53 8907.83 -3007.74 -202.94 5956090.15 599311.93 MWD 9822.73 61.87 286.13 9013.29 8921.59 -3003.74 -225.65 5956093.84 599289.18 MWD 9853.46 61.06 296.46 9028.00 8936.30 -2993.97 -250.76 5956103.28 599263.94 MWD 9895.92 58.68 305.28 9049.35 8957.65 -2975.18 -282.25 5956121.65 599232.21 MWD 9928.36 56.21 308.80 9066.80 8975.10 -2958.73 -304.07 5956137.81 599210.17 MWD 9959.04 56.92 315.14 9083.72 8992.02 -2941.62 -323.09 5956154.67 599190.93 MWD Halliburton Global Company: BP Amoco Date: 2/10/2006 Time: 16:06:38 Page: 9 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Z-11, True North Site: PB Z Pad Vertical (TVD) Reference: 15.11 6/15/1990 00:00 91.7 Well: Z-11 Section (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) Wcllpath: Z-11A Survey Calculation Method: Minimum Curvature Db: Orade Survey _:._... -. r I bID __ Intl __. .4zim 7"~'D __ Sys'fVD _.- ~/S - E/~V' -- MapN _. MapE - -- -_ Tool 'I ft deg deg ft ft ft ft ft ft 9991.13 56.74 316.20 9101.28 9009.58 -2922.40 -341.86 5956173.63 599171.91 MWD i 10022.44 56.74 322.02 9118.46 9026.76 -2902.62 -358.98 5956193.18 599154.53 MWD 10050.07 56.83 325.19 9133.60 9041.90 -2884.02 -372.70 5956211.60 599140.57 MWD 10079.37 57.53 329.42 9149.48 9057.78 -2863.30 -385.99 5956232.13 599127.01 MWD 10102.00 57.53 329.42 9161.63 9069.93 -2846.87 -395.70 5956248.44 599117.08 MWD • TREE _ , 4-1/16" CM! WELLHEAD= FMC ACTUATOR= KB. ELEV = OTIS 91.7' BF. ELEV = 55.3' KOP = 9661 Max Angle = 61 @9822 Datum MD = 9649' Datum TVD = 8800' SS I 13-3/8" CSG, 68#, L-80, ID =12.415" I • ~ -11 A SAFET ES: COLIAPS® LINB2 @ 9792' - *" IA x Present CTD Sidetrack OA COMM. OPERATING PRESSURE OF THE 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (02/08/03 WAIVER) *** 4-1 /2" OTIS XN NIPP_LE (milled to 3.8") O 1 /2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2964 2875 7 OTIS DMY RA 5 6083 5604 29 OTIS DMY RA 4 7127 6540 25 OTIS DMY RA 3 8093 7403 27 OTIS DMY RA 2 8649 7902 26 OTIS DMY RA 1 9054 8265 26 OTIS DMY RA 90s4' 1.~4-1/2" PARKER SWS NIP, ID = 3.813" 9092' 9-5/8" X 4-1/2" BKR SB-3 PKR TOP OF 7" LNR ~ 9142' 9-5/8" CSG, 47#, NT-80S, ID = 8.681" 9396' Top of 3-1/2" Chrome Ln - 9476' 3.5" X Nip 2.813" ID 9494 ~4-1/2" TBG, 12.6#, L-80, TDS, 0.0152 bpf, ID = 3.958" ~--~ 9621' REF LOG: BRCS ON 06/28/90 ANGLE AT TOP PERF: 49 at 9750' Note: Refer to Production DB for historical perf data SIZE SPF NVTERVAL Opn/Sqz DATE 2" 6 9750 - 9778 Opn 01/28/06 2" 6 9794 - 9804 Opn 01/28/06 2" 6 9822 - 9844 Opn 01/28/06 2" 6 9870 - 9888 Opn 01/28/06 1 7" LNR, 26#, L-80, .0383 bpf, O = 6.276" I-~ 10306' 9476' Top of Cement 9595' _ 4-1/2" PARKER SWS NIP, ID = 3.813" 9616' 4-1/2" OTIS XN NIP, ID = 3.725" (milled to 3.8") 9623' 4-1/2" TBG TAIL ID = 3.958" 9621' ELMD TT LOGGED 10/06/98 9495' 3.5 X Nipple ID 2.813 9661' Mechanical Whipstock 9792' COLLAPSED LNR (10/29/01) PBTD at Landing Collar 10067' 3-1/2" x 2-7/8" chrome Inr 10102' 10230' I~ TBG CONVEYED PFRF ASSY DATE REV BY COMMEM'S DATE REV BY COMMENTS 06/18/90 PGS ORIGINAL COMPLETION 02/08/03 ?/KAK WANER SAFETY NOTE REV. 03/14/01 SIS-MD FINAL 04/06/05 MSE PROPOSED CTD SIDETRACK 05/17/01 RN/TP CORRECTIONS 01/28/06 R.Bordes PRESENT CTD SIDETRACK 10/29/01 CJS/KAK COLLAPSED LAVER 08/29/02 DTR/TP GLV C/O 09!26/02 BM/TP WANER SAFETY ~~ti'O'i PRUDHOE BAY UNrr WELL: Z-11A PERMrf No: 205-031 API No: 50-029-22053-01 SEC 19,T11N,R12E, 980' FNL 8~ 3198' FEL BP 6cploration (Alaska) r: 13-Feb-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Z-11A Dear Dear SirlMadam: Enclosed is one disk with the *.PTT and ~.PDF files. Tie-on Survey 9,563.60' MD ~~5 - C~31 Window /Kickoff Survey: 10,079.37' MD (if applicable) Projected Survey: 10,102.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date (~~~ i ~7/~~, S Please call me at 273-3545 if Regards, Carl Ulrich Survey Manager ~!'°'~-, Ine J ) _ ) you a any questions or concerns. Attachment(s) ~ # ~ ~ ~~ ,~ ( ) '°t~'~ ~ ~: s FRANK H. MURKOWSKI, GOVERNOR ~~~~ ~~~~ ~~~~++ ~ta~ ~~~+ ~4[aa7~~ OIL ~ ~ ~ 333 W. 7`" AVENUE, SUITE 100 COI~TSFiRQATI0IIT CO1rI11'IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Z-11 A BP Exploration (Alaska) Inc. Permit No: 205-031 Surface Location: 980' SNL, 3202' WEL, SEC. 19, T11N, R12E, UM Bottomhole Location: 3803' SNL, 3594' WEL, SEC. 19, Tl 1N, R12E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please rovide at least twenty-four (24) hours notice for a representative of the Commission to ss any required test. Contact the Commission's petroleum field inspector at (907) 659-36 (p er). DATED this day of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. I ~:lG~ z%ts~t~as STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL = - ~n aat^ ~~ nn~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zonis 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU Z-11A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10100 TVD 9062 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surtace: 980' SNL, 3202' WEL SEC. 19 T11N R12E UM 7. Property Designation: ADL 028262 Pool , , , , Top of Productive Horizon: 3937' SNL, 3317' WEL, SEC. 19, T11N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: March 22, 2005 Total Depth: 3803' SNL, 3594' WEL, SEC. 19, T11N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 1290' 4b. Location of Well (State Base Plane Coordinates): Surtace: x-599475 y-5959100 Zone-ASP4 10. KB Elevation (Height above GL): g1.7' feet 15. Distance to Nearest Well Within Pool 1650' 16. Deviated Wells: Kickoff Depth: 9655 feet Maximum Hole Angle: 60 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3640 Surface: 2760 ~ 18. as rig rogram: Size Specifications Setting !)epth To Bottom uantrty o merit c.f. or sacks Hole Gasin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 3-3/16" 6.2# L-80 TCII 625' 9475' 8644' 10100' 9062' 6 cu ft Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redritl AND Re-entry Operations) Total Depth MD (ft): 10306 Total Depth TVD (ft): 9478 Plugs (measured): None Effective Depth MD (ft): 10230 Effective Depth TVD (ft): 9411 Junk (measured): 10230 Casin Len th Size Cement Volume MD TVD r n r 110' 20" 110' 110' 2660' 13-318" 3723 cu ft Permafrost 2660' 2660' I 9396' 9-5/8" 1979 cu ft Permafrost 9396' 8665' P n 1164' 7" 363 cu ft Class 'G' 9142' - 10306' 8437' - 9478' Perforation Depth MD (ft): 9686' - 9860' Perforation Depth TVD (ft): 8925' - 9081' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Preparetl By Name/Number: Si nature ~~ ~ ~ ~~ f~- Phone 564-4387 Date Z ~ ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number:.~3 - d API Number: 50- 029-22053-01.00 Permit Approval Date: ~- b See cover letter for other requirements Conditions of Approval: Samples Required ~ Yes ~No Mud Log Required ~ ~ Yes ~'No H en Sulfide Measures `Yes ~'~ No Directional Survey Required ~5'es ^ No Other: ~ ~P S"E O {~ ~~O D ~s r . APPROVED BY ~ [) A roved - ~ . -< THE C~MMISSI~N Date !!//~~ Form 10-401 Revise 06/20 4 /Subrrrft In Duplicate BP Z-11A Sidetrack CTD Sidetrack Summary 1) Mill window off whipstock 2) Drill sidetrack 3) Run liner, cement Mud Program: • Well kill: 8.4 - 8.9 ppgj ~e • Milling/drilling: 8S -r$.9~pg used Flo Pro or biozan for milling, new Flo Pro for drilling. e Disposal: (__~. • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • -All Class I wastes will go to Pad 3 for disposal. Casing Program: • 3 3/16" cemented liner completion o Solid liner 9475' - 10100' ,,--~. ~ • The liner cement volume is planned to b 6.5 bbls of 15.8 ppg class G. ~c-i, Casing/Liner Information 13 3/8", L-80, 68#, Burst 5020 psi; collapse 2260 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 7", L-80, 26#, Burst 7240 psi; collapse 5410 psi 4'h" L-80, 12.6#, Burst 8430 psi; collapse 7500 psi planned 3 3/16" L-80 TCII, 6.2#, Burst 8520 psi; collapse 7660 psi (hole size 4.125") ,i Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. ~ • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 60deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property is 1290' ft. / • Distance to nearest well within pool: 1650' NE of Z-O1 Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • MCNL will be run cased hole. Hazards • Z pad is n~designated as an HZS pad. Typically 10-20 ppm H2S on Z pad • Lost circulation risk is considered "low". Reservoir Pressure - • Res. press. is estimated to be 3640 psi at 8800'ss (8.0 p g EMS). Max. surface pressure with gas (0.10 psi/ft) to surface i 7fj0`psi. TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV - 91.T BF. ELEV = 55.3' KOP = 3102' Max Angle = 34 @ 4426' Datum MD = 9649' Datum TV D = 8800' SS • 13-3/8" CSG, 68#, L-80, ID =12.415" ~~ 2660' Minimum ID = 3.725" @ 9616' 4-1/2" OTIS XN NIPPLE Z ~ 11 Y NOTES: COLLAPSED LINER @ 9792' - "*" IA x OA COMM. OPERATING PRESSURE OF THE 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (02/08/03 WAIVER) *"* 2076' 4-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2964 2875 7 OTIS DMY RA 5 6083 5604 29 OTIS DMY RA 4 7127 6540 25 OTIS DMY RA 3 8093 7403 27 OTIS DMY RA 2 8649 7902 26 OTIS DMY RA 1 9054 8265 26 OTIS DMY RA 9084' ~4-1/2" PARKER SWS NIP, ID = 3.813" 9092' 9-5l8" X 4-1/2" BKR SB-3 PKR TOP OF 7" LNR I 9142' 9-5/8" CSG, 47#, NT-80S, ID = 8.681" 9396' ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 9621' PERFORATION SUMMARY REF LOG: BHCS ON 06/28/90 ANGLE AT TOP PERF: 26 @ 9686' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 4-1/2" 4 9686 - 9698 O 07/12/93 4-1/2" 4 9706 - 9736 O 07/12/93 4-1/2" 4 9746 - 9756 O 07/12/93 4-1l2" 4 9788 - 9812 O 07/12/93 4-1/2" 4 9820 - 9830 O 07/12/93 4-1/2" 4 9840 - 9848 O 07/12/93 3-3/8" 4 9848 - 9860 O 07/12/93 9595' ~4-1/2" PARKER SWS NIP, ID = 3.813" 9616' 4-1/2" OTIS XN NIP, ID = 3:725" 9623' 4-1/2" TBG TAIL ID = 3.958" 9621' ~ELMD TT LOGGED 10/06/98 9792' ~~ COLLAPSED LNR (10/29/01) 10230' I-i TBG CONVEYED PERF ASSY PBTD 10230' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10306' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/18/90 PGS . ORIGINAL COMPLETION 02/08/03 ?/KAK WANER SAFETY NOTE REV. 03!14/01 SIS-MD FINAL 05/17/01 RN/TP CORRECTIONS 10/29/01 CJS/KAK COLLAPSED LINER 08/29/02 DTR/TP GLV C/O 09/26/02 BM/TP WANER SAFETY NOTE PRUDHOE BAY UNff WELL: Z-11 PERMIT No: 1900720 API No: 50-029-22053-00 SEC 19,T11N,R12E, 980' FNL & 3198' FEL BP Exploration (Alaska) TREE = 4-1 /, 6" CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 91.7' BF. ELEV = 55.3' KOP = 3102' Max Angle = 34 @_4426' Datum MD = ~^ 9649' Datum TVD = 8800' SS I 13-3/8" CSG, 68#, L-80, ID =12.415" ~ Minimum ID = 3.725" @ 9616' 4-1/2" OTIS XN NIPPLE (milled to 3.8") SAF~TS( NOTES: COLLAPSED LINER @ 9792' - "' IA x OA COMM. OPERATING PRESSURE OF THE 13-318" ANNULUS MUST NOT EXCEED 2000 PSI (02/08/03 WAIVER) "" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2964 2875 7 OTIS DMY RA 5 6083 5604 29 OT1S DMY RA 4 7127 6540 25 OTIS DMY RA 3 8093 7403 27 OTIS DMY RA 2 8649 7902 26 OTIS DMY RA 1 9054 8265 26 OTIS DMY RA 90$4' ~~4-1/2" PARKER SWS NIP, ID = 3.813" 9092' ~ 9-5/8" X 4-1/2" BKR SB-3 PKR TOP OF 7" LNR _ _ 9142' 9-5/8" CSG, 47#, NT-80S, ID = 8.681" 9396' % __ TOP OF 3-3116" LN 9475' 9475' --Top of Cement 3.5" X Nip 2.813" ID 9475' ...~g595~ ~~-== 4-1/2" PARKER SWS NIP, ID = 3.813" 9616' 4-1/2" OTIS XN NIP, ID = 3.725" n, iT'de ' o~3~"r- 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9621' 9623' 4-1/2" TBG TAIL ID = 3.958" 9~ 621 ELMD TT LOGGED 10/06/98 PERFORATION SUMMARY REF LOG: BRCS ON 06/28/90 ANGLE AT TOP PERF: 26 @ 9686' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-112" 4 9686 - 9698 O 07/12/93 4-1/2" 4 9706 - 9736 O 07/12/93 4-1/2" 4 9746 - 9756 O 07/12/93 4-1/2" 4 9788 - 9812 O 07/12/93 4-1/2" 4 9820 - 9830 O 07/12/93 4-1/2" 4 9840 - 9848 O 07/12/93 3-318" 4 9848 - 9860 O 07/12/93 PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9792' I-{ COLLAPSED 3-3/16" cmt'ed and perfed 10100' I~ TBG CONVEYED PERF ASSY DATE REV BY COMMENTS DATE REV BY COMMENTS 06/18/90 PGS ORIGINAL COMPLETION 02/08/03 ?/KAK WANERSAFETYNOTEREV. 03/14/01 SIS-MD FINAL 05/17/01 RN/TP CORRECTIONS 10/29/01 CJSIKAK COLLAPSED LINER 0829/02 DTR/TP GLV C/O - ~ ! I , PRUDHOE BAY UNrf WELL: Z-11 PERMrf No: 1900720 API No: 50-029-22053-00 SEC 19,T11N,R12E, 980' FNL 8~ 3198' FEL BP Exploration (Alaska) Z-11A Proposed CTD Sidetr~ O C. C7 ~~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~r INTEQ Company: BP Amoco Date:.- 2/18/2005. Time: 13:29:49- Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well:. Z-11, True North Site: PB Z Pad Vertical (TVD)Refereace: 15:11 6/15/1990 00:00 91.7 Well: Z-11 Section (VS) Reference: Well (O.OON,O.~E,275. OOAzi) Weppath: Plan#3, Z-41A Survey Caicaistion Method: Minimum Curvature Db: Orate ~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Msp Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well CenVe Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: PB Z Pad TR-11-12 UNITED STATES :North Slope Site Position: Northing: 5957230. 17 ft Latitude: 70 17 33.051 N From: Map EasHng: 601304. 82 ft Longitude: 149 10 47.365 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.77 deg Well: Z-11 Slot Name: 11 Z-11 Well Position: +N/-S 1894.47 ft Northing: 5959099. 98 ft Latitude: 70 17 51.681 N +E/-W -1804.73 ft EasHng : 599474. 89 ft Longitude: 149 11 39.972 W Position Uncertainty: 0.00 ft Wellpath: Plan#3, Z-11A Drilled From: Z-11 500292205301 Tie-on Depth: 9597.00 ft Current Datum: 15:11 6/15/1990 00:00 Height 91. 70 ft Above System Datum: Mean Sea Level Magnetic Data: 2/8/2005 Declination: 24.63 deg Field Strength: 57606 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.70 0.00 0.00 275.00 Plan: Plan #3 Date Composed: 2/18/2005 Copy Lamar's Plan#3 Version: 1 Principal: No Tied-to: From: Definitive Path Targets - Map Map.. G-- Latitude -> <- Longitude -> ~ ~ Name Description TVD +N/-S +E/-W Northing EasHng Deg Min Sec Deg Min Sec L Dip. Dir. $ ft ft - $ ft Z-11A Polygon 91.70 -2878.94 -117.01 5956220.00 599396.00 70 17 23.366 N 149 11 43.382 W -Polygon 1 91.70 -2878.94 -117.01 5956220.00 599396.00 70 17 23.366 N 149 11 43.382 W -Polygon 2 91.70 -2932.07 -258.74 5956165.00 599255.00 70 17 22.844 N 149 11 47.512 W -Polygon 3 91.70 -2855.22 -397.75 5956240.00 599115.00 70 17 23.600 N 149 11 51.562 W -Polygon 4 91.70 -3034.49 -455.13 5956060.00 599060.00 70 17 21.836 N 149 11 53.234 W -Polygon 5 91.70 -3126.54 -301.32 5955970.00 599215.00 70 17 20.931 N 149 11 48.752 W -Polygon 6 91.70 -3079.39 -85.66 5956020.00 599430.00 70 17 21.395 N 149 11 42.468 W Z-11A Hardline Circle 9031.70 -2025.59 -207.73 5957072.00 599294.00 70 17 31.759 N 149 11 46.026 W -Circle (Radius: 100) -Plan out by 960.42 at 9031.70 -2985.18 -247.51 5956112.05 599266.93 70 17 22.321 N 149 11 47.185 W Z-11A Target-TD 9150.70 -2954.26 -396.06 5956141.00 599118.00 70 17 22.626 N 149 11 51.513 W -Plan out by 127.58 at 9150.70 -2827.93 -378.19 5956267.54 599134.20 70 17 23.868 N 149 11 50.992 W Annotation MD TVD ft ft' 9597.00 8844.91 TIP 9655.00 8896.89 KOP 9675.00 8914.68 3 -End 9/100DLS 9715.00 8948.28 4 9795.36 9001.32 5 9856.36 9032.31 6 9956.36 9082.02 7 10100.00 9153.61 TD • ~,~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report 11~.1i1• s ILVTEQ Company: B P Amoco Date: 2/18/2005 Time: 13:29:49 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Z-11, True North Site: P B Z Pad Verti cal (TVD) Re ference: 1 5:11 6/15/ 1990 00:00 91.7 Well: Z -11 Section (VS) Reference: Wetl (O.OON, O.OOE,275.OOAzi) Wellpath: P lan#3, Z-11A Survey Calculation Method: Minimum Cu rvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E(-W DLS Builtl ' Turu TFO Target ft deg. deg ft ft ft deg/100ft deg1100ft deg/100ft deg 9563.60 26.23 219.51 8814.95 -2943.38 -92.20 0.00 0.00 0.00 0.00 9597.00 26.27 219.50 8844.91 -2954.78 -101.59 0.12 0.12 -0.03 353.68 9630.49 26.35 219.22 8874.93 -2966.26 -111.01 0.44 0.24 -0.84 302.68 9655.00 26.40 218.68 8896.89 -2974.72 -117.85 1.00 0.20 -2.20 281.53 9675.00 27.89 220.89 8914.68 -2981.73 -123.69 9.00 7.46 11.04 35.00 9715.00 38.27 243.56 8948.28 -2994.40 -141.02 40.00 25.94 56.67 60.00 9795.36 60.00 275.70 9001.32 -3002.24 -199.47 40.00 27.04 40.00 60.00 9856.36 59.95 303.96 9032.31 -2984.60 -248.39 40.00 -0.09 46.32 97.30 9956.36 60.67 317.75 9082.03 -2927.95 -313.84 12.00 0.72 13.80 90.00 10100.00 60.04 337.60 9153.61 -2823.28 -380.15 12.00 -0.44 13.82 97.00 Survey MD Iacl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/1'OOft ft deg.... 9563.60 26.23 219.51 8723.25 -2943.38 -92.20 5956155.90 599421.67 0.00 -164.69 0.00 MWD 9575.00 26.24 219.51 8733.48 -2947.27 -95.40 5956151.97 599418.51 0.12 -161.83 353.68 MWD 9597.00 26.27 219.50 8753.21 -2954.78 -101.59 5956144.38 599412.42 0.12 -156.32 353.69 MWD 9600.00 26.28 219.47 8755.90 -2955.80 -102.44 5956143.34 599411.59 0.44 -155.57 302.68 MWD 9625.00 26.34 219.27 8778.31 -2964.37 -109.47 5956134.68 599404.68 0.44 -149.31 302.70 MWD 9630.49 26.35 219.22 8783.23 -2966.26 -111.01 5956132.78 599403.16 0.44 -147.94 302.89 MWD 9650.00 26.39 218.79 8800.71 -2972.99 -116.46 5956125.97 599397.80 1.00 -143.10 281.53 MWD 9655.00 26.40 218.68 8805.19 -2974.72 -117.85 5956124.22 599396.43 1.00 -141.86 281.92 MWD 9675.00 27.89 220.89 8822.98 -2981.73 -123.69 5956117.14 599390.68 9.00 -136.65 35.00 MWD 9700.00 33.92 236.52 8844.46 -2990.02 -133.36 5956108.72 599381.12 40.00 -127.74 60.00 MWD 9715.00 38.27 243.56 8856.58 -2994.40 -141.02 5956104.24 599373.53 40.00 -120.50 46.55 MWD 9725.00 40.39 248.91 8864.32 -2996.95 -146.82 5956101.61 599367.76 40.00 -114.94 60.00 MWD 9750.00 46.62 260.31 8882.47 -3001.41 -163.37 5956096.94 599351.27 40.00 -98.84 55.86 MWD 9775.00 53.75 269.46 8898.49 -3003.03 -182.46 5956095.06 599332.21 40.00 -79.97 47.56 MWD 9795.36 60.00 275.70 8909.62 -3002.24 -199.47 5956095.63 599315.19 40.00 -62.95 41.69 MWD 9800.00 59.78 277.83 8911.94 -3001.76 -203.45 5956096.05 599311.20 40.00 -58.94 97.30 MWD 9825.00 59.21 289.42 8924.67 -2996.71 -224.33 5956100.83 599290.26 40.00 -37.70 96.23 MWD 9850.00 59.67 301.03 8937.41 -2987.55 -243.75 5956109.73 599270.72 40.00 -17.55 90.33 MWD 9855.14 59.89 303.40 8940.00 -2985.18 -247.51 5956112.05 599266.93 40.00 -13.60 84.42 Z-11A H 9856.36 59.95 303.96 8940.61 -2984.60 -248.39 5956112.62 599266.04 40.00 -12.68 83.22 MWD 9875.00 59.97 306.54 8949.94 -2975.29 -261.57 5956121.75 599252.75 12.00 1.26 90.00 MWD 9900.00 60.09 310.00 8962.43 -2961.88 -278.57 5956134.94 599235.58 12.00 19.36 88.71 MWD 9925.00 60.29 313.45 8974.87 -2947.44 -294.75 5956149.16 599219.20 12.00 36.74 86.98 MWD 9950.00 60.58 316.88 8987.20 -2932.02 -310.08 5956164.37 599203.67 12.00 53.35 85.26 MWD 9956.36 60.67 317.75 8990.33 -2927.95 -313.84 5956168.39 599199.86 12.00 57.45 83.57 MWD 9975.00 60.42 320.31 8999.49 -2915.70 -324.47 5956180.50 599189.06 12.00 69.12 97.00 MWD 10000.00 60.16 323.75 9011.88 -2898.58 -337.83 5956197.44 599175.48 12.00 83.92 95.74 MWD 10025.00 60.00 327.20 9024.36 -2880.74 -350.11 5956215.12 599162.97 12.00 97.71 94.04 MWD 10050.00 59.92 330.67 9036.87 -2862.20 -361.28 5956233.50 599151.56 12.00 110.44 92.31 MWD 10075.00 59.94 334.14 9049.40 -2843.03 -371.30 5956252.53 599141.29 12.00 122.10 .90.58 MWD 10094.18 60.01 336.79 9059.00 -2827.93 -378.19 5956267.54 599134.20 12.00 130.28 88.84 Z-11A T 10100.00 60.04 337.60 9061.91 -2823.28 -380.15 5956272.17 599132.18 12.00 132.63 87.51 MWD BP Amoco fr•us~nr na>fuf w.fs, zwu ssfafamsaw ~.r.er rf.ff.ar an >r..-r. fsufo tttn ^a.are / w. o.r.r ~s r ~~ wwfw aamo n.>fn ~ ~ ~ .~i w inw~ i~ro REFERENCE INFORMATION Co-oNinate (N/E) Relsrsnce: Well Centre: Z-71, True NorN Vertlcal ( D) Refeence: Syysstem: Mean Sea LevN Sectlon (VS) Reference: Sbt - 71 (O.OON,O.OOE) Measured Depth Reference: 15:11 &15/799000:00 97.70 CaloAaticn Method: Mnimum Curvature ne>ew anfu f.. .f fy n.. r.fw f,or aaa a fmii °a uio iiuf i n:a.ef anaar > _ ~f rnaom fw aarr fefrr :ms :.~~ naa rrm .ao 7w ~ f.reerrrn ,.. -s .., ... . f>f1.H fee>.00 ~ ~.,~••-• ~ r-m a-~w -a..r ... ffOf.lf ffff.00 RM ffa1M M)l.00 )-1M woeou ffff.0f f>10.00 ~ ffOf.fa flff.af f ffff.f7 M!t% f fNO.ax ff%.M > fON.f110100.00 TO 8780 ~ ~~~ii 8780 'ii;; li 8800 _ i_;-_ 8820 rl C 8840 :, N 8860 I-+- ~ 8880 d is CI 8900 j viii ~~ ''I.~ ~ ~ 8920 ~ I '. ' ~- ~'r. j: ~; 8940 - . ~ 8960 _^ ~r ~ 8980 i. : i-° , T Y f::~ 9000 9020 : `!.~. 't- 1 ll r i f l u ; ~ I ~^ 3-Fs01N7000L5 ~ i - i i::. s + ._ }-; ..-! West(-)/East(+) [20ft/in] ++ - ~ il; i :!t.~: '. i i; ii +a-.- ii l: ',-~~ b LEGEND __ Z3-}~;7A - A.n#3 T Azimuths to True North M Magnetic North: 24.63° Magnetic Field Streit9lh: 57606nT Dip Angle: 80.79° Date:2/8l2005 ~n~ Plen #3 (Z-11/Pler#F3, Z-11A) Createtl By: eYl Miotlaelson Date: 2/782005 -- - - Contact m/o~malron ,lames Onlinger Direcl: (907 267E670 cell. (907)50-7375 Model: bggm2004 E-mail: james.ohlinger®Inteq.com (I!i :.:f;;, ._-_7_ff. i~l ~, i ~'. :': 'i) -~( IT I . .. I :. ... it ii'... -~~ '- +;- n I th~ I~ +'. .r -20 0 20 PM • Vertical Section at 275.00' [20ft/in] • • ments are from r i ~_ of bag Z-11 A BAG 7 1/16" 5000 psi. bttm of bag middle of slips of of flow cross Blind/Shears 2 3/8" combi ram/slips Mud Cross of blind/shears variable bore pipe 3 1/2"-2 7/8" of pipe/slips 2 3/8" combi ram/slips TOTs ~ 7 1/16" 5000psi Mud Cross 7 1/16" 5000psi TOTs 7 1/16" 5000psi Flow Tee 7ERRIE L RUBBLE BP` EXPLORATION AK INC „ PO BOX 196612 ' MB 7-5 ss-si~252 182 ANCHORAGE, qK 99.519_ Mastercard Check" 6612 c PAY TO THE DATE ~V - ORDER.OF nn -----~ First National ank Alaska ~ V(J Anchora8e, AK' 99501.. DOLL S MEMO ~ ' ~ 1 ~~~~ ~: i 2 5 2000 60~: 9,9 1 t,~.~ ~ • 6227~.~1556~~, 0Lg2 ~ • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~z?--`/~ PTD# 2c>,S ©~ j Development Service Exploration Stratigraphic CHECK WAAT ADD-OHS "CLiTE"~ APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well Permit No, ~~ A.PI No. (If API number Production. should continue to be reported as Iasi two. (2) digits a function~of the original API number. stated are between 60-69) above. PILOT IlOLE In accordance with 20 AAC 25.0050, all (PIS records, data and logs acquired, for the pilot bole must be clearly differentiated ~in both name (name on permit plus P~ and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject •to fuU EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ eaception. _ iComuany Name) assumes the liability of any protest to the spacing .eaception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost . ~ or from where samples are first caught and . ] 0' sample intervals through target zones. ELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT Z-11A Program DEV Well bore seg ^ PTD#:2050310 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV / 1-OIL GeoArea 890 Unit 11650 ONOff Shore On Annular Disposal ^ Administration 1 Pe[mitfee attached_ _ - - - -- Yes - - - - - - 2 Lease number appropriate____________________________ _____________Yes-__-_. _ 3 Uniquewell-name andnumbe[--------- ------- --- -- --------- --Yes- --- -- ----- ------ --------- -- - ------- - --- ---------------- 4 Well located in a-definedpool__________________________ -------.-_- -Yes_____-- ___-_ -- - 5 Well located proper distance from drilling unitboundary_--_____- -------------Yes._-- _- __________-----__ ---._-__-___-_----.-_--___ - - _-_ 6 Well locatedpr_operdistancefromotherwells-____- --------- -------------Yes_____ ___. ----- - - - 7 Sufficient acreageayail_ablein_drillinqunit___________________ ____________Yes-__--__ ______--__ ---------------------------- ------------------------------ 8 Ifdeviated,is-wellboreplat_inc_luded____-___--_____--___ ----___-----Yes_______ __________-__-__ 9 Ope[ator only affected party - - - - - - Yes - - - - - - 10 Operatorhas-appropriate.bondinforce____________________ _____________ Yes_____._ 1 t Pe[mitcan be issued without conservation order- . , -- Yes - - Appr Date 12 Permit can be issued without administrative_approval------------ -------------Yes_____-- _--_--_--__--_--____-____------,-__- - -- RPC 2/2812005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata ar~thprized by_ Injection OMe[ ff (put1O# in_comments)-(FOr_ NA- - . - ... - - .. - . . 15 All wells-within1l4_milear@a_ofreyiewidentified(Forsen!ieewellgnly)__ ____________ NA______-, ._.______-______,.----_--.-___-.---_- _ _ _ _ _ 16 Pre-produced injector_ duration of pre p[odtrction less than_ 3 months-(For service well only) - - NA- . _ - - - ------------------------------- 17 ACMP_FindingofConsistency_hasbeenissued-forthisproject_______ _____________ NA._--__ ____,____-_--._- -_.-____- Engineering 18 Conductor string-provided--------------------------- - _--. NA,------- -- -------------,--- ---.------ - - 19 Surface-casing-protects all knownUSDWs----- ----- ------ ------- - NA-----___ _____--__-___ 20 CMT-voladeguate_tocircul_ate-o-n conductor&surf_csg___.---.-- -_ NA________ ______________ ______________________ 21 CMT.voladequate_totie-in long string to surfcsg--____________ _____________NA-.--,___ 22 CMT_willcoverallknownproductiyehorizons__ ______________ ___________ _Yes____-_ .--.-_____ - - 23 Casing designs adequate for C,T,B&_permafrost-------------- --------- Yes------- ------------- ------------------ _.-------- 24 Adequatetankage_orreseryepit______________-.-.-_,__ _______.---.Yes_____.. CTgU.---_______-_-_. __--_.-__-__.__- 25 If a-re-drill, has_a_ 10-405 for abandonment been approved _ - - Yes - _ 26 Adgquatewellboreseparationproposed.--._-_____________ _____________Yes_____-. 27 Ifdiverterrequired,daesitmeetregulations------------------ ------------ NA_--_--__ Sidetrack.___-____ -_----________-_---- Appr Date 28 Drilling fluid. program schematic_& equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes .. _ - _ _ Max MW 8,9 ppg, - _ _ _ _ - - . - - _ - - _ _ _ _ _ - - - , - - WGA 2/28/2005 29 BOPEs,dotheymeetregulaiion___________------------ ----_----_-Yes____-._ - --- -- - - 30 BOPS-press rating appropriate; test to_(put prig in comments)- - . - ... . - Yes . Test to 3500 psi. _MSP 2760 psi.... - _ _ - _ - . ------------------------------- 31 Choke,manifoldcomplieswlAPI-RP-53(May84)_____-________ _______--_-_Yes____-._ _--________-___. - - - - 32 Work will occur without operation shutdown__________________ _____________Yes_--__._ _._-.__-___-- -- -- 33 Is presence-ofH2S gas probable--------------------- N°-------- Not anH2Spad..- --- --- ------------ --------------_---------- 34 Mechanical-cond_itionof wells withinAORyerifed(Forservicewellonly)- -------------NA___-__-_ _-----.--__-_--.-_____-__-----_-_ - -- - -- Geology 35 Permit_can be issued wlchydmgen-sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ - - - - - _ , - ---- 36 _D_ata.presentedon-potential overpressure zones--------------- _-__-__--_--NA__-_-._ _____-_--__--_-- -- Appr Date 37 Seismic analysis of shallowgas-zones-____-____-,_-.-__- _______---_-NA_-___-- -- - --------------- RPC 2!28!2005 8 eabed conditionsurvey_(ifoffshore)------------ -------- ----------_NA_-.____ __ - - _--__._ - - - -- 39 Contact nom-a/phone.for weekly progress_reports [exploratory only)_ _ _ - _ _ - - _ - - tJA- _ _ - Geologic Engineering Pu ~ Commissioner: Date Date ~ Commissioner: o Date er z a~~~ s z~ °~ • • • 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 1~inding 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. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 06 16:12:02 2006 • ~~ Reel Header Service name .............LISTPE Date .....................06/03/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/03/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DA'.CE JOB DATA JOB NUMBER: LOGGING ENGINI3ER: OPERATOR WITNESS: Z -1 lA 500292205301 BP Exploration (Alaska) Inc. Sperry Drilling Services 06-MAR-06 MWD RUN 2 MW0004173216 S. LATZ J. EGBEJIMBA MWD RUN 1 MW0004173216 S. LATZ J. EGBEJIMBA SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 12E 980 3202 91.69 ~,~~ ~. C~,3 1 • WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9657.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9657'MD/8807'TVDSS IN THE Z-11 WELLBORE. 4. MWD RUN 1 INCORPORATED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING A SCINTILLATION DETECTOR. 5. MWD RUN 2 INCORPORATED DIRECTIONAL, GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MAD DATA OVER THE RUN 1 INTERVAL WERE ACQUIRED WHILE POOH AFTER REACHING FINAL TD. THESE DATA WERE MERGED WITH MWD RUN 2 DATA - NO SEPARATE MAD PASS PRESENTATION IS INCLUDED. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN THE Z-11A WELLBORE ON 27 JANUARY 2006. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 6 MARCH 2006. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 & 2 REPRESENT WELL Z-11A WITH API #: 50-029-22053-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10,102'MD/9,070'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). • • SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9592.0 10058.5 ROP 9656.5 10102.5 RPS 9658.0 10072.0 RPM 9658.0 10072.0 FET 9658.0 10072.0 RPD 9658.0 10072.0 RPX 9658.0 10072.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9592.0 9592.0 9595.0 9595.0 9597.0 9596.5 9597.5 9597.5 9602.0 9602.5 9604.5 9605.0 9607.0 9607.0 9650.5 9652.5 9656.0 9656.5 9658.0 9660.5 9659.5 9662.5 9663.5 9665.0 9666.5 9666.5 9668.0 9668.5 9672.0 9673.5 9676.5 9676.5 9680.0 9679.5 9681.5 9681.0 9684.0 9683.5 9685.5 9685.0 9687.5 9687.5 9690.0 9690.0 9698.5 9699.0 9701.5 9701.5 9706.5 9706.0 9710.5 9710.5 • 9726.0 9733.0 9736.0 9739.0 9744.0 9749.5 9759.0 9770.5 9773.0 9777.0 9782.5 9792.0 9794.0 9795.5 9797.0 9798.5 9808.0 9811.0 9817.0 9826.5 9838.5 9842.0 9847.5 9851.5 9857.0 9864.0 9867.0 9870.0 9873.0 9875.0 9876.5 9880.5 9884.5 9885.5 9890.0 9896.0 9897.5 9901.5 9907.5 9914.0 9920.0 9925.5 9929.5 9932.0 9936.5 9945.0 9951.0 9956.5 9963.0 9966.0 9968.5 10102.5 MERGED DATA SOURCE 9726.5 9734.0 9737.5 9740.0 9745.0 9751.0 9760.5 9773.5 9777.0 9780.5 9784.0 9792.0 9794.5 9796.0 9797.5 9798.5 9808.5 9811.5 9820.0 9829.5 9840.5 9843.5 9849.0 9852.5 9858.0 9864.0 9866.5 9868.5 9871.5 9873.0 9875.0 9878.0 9881.0 9882.5 9887.0 9895.0 9897.0 9901.0 9906.0 9910.5 9916.5 9922.0 9930.0 9932.5 9935.0 9944.5 9949.5 9956.5 9963.0 9966.0 9968.0 10102.0 PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9592.0 9857.0 MWD 2 9857.0 10102.5 REMARKS: MERGED MAIN PASS. • • Data Format Specification Record Data Record Type ....... ...... .....0 Data Specification Bloc k Type .....0 Logging Direction ...... ...... .....Down Optical log depth units ...... .....Feet Data Reference Point ... ...... .....Undefined Frame Spacing .......... ...... .....60 .lIN Max frames per record .. ...... .....Undefined Absent value ........... ...... .....-999 Depth Units ............ ...... ..... Datum Specification Blo ck sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9592 10102.5 9847.25 1022 9592 10102.5 RPD MWD OHMM 0.09 2000 31.1821 829 9658 10072 RPM MWD OHMM 0.1 1620.85 16.2507 829 9658 10072 RPS MWD OHMM 0.97 2000 27.2949 829 9658 10072 RPX MWD OHMM 1.61 2000 38.7371 829 9658 10072 FET MWD HOUR 0.29 43.4 19.063 829 9658 10072 GR MWD API 18.78 624.31 53.9156 858 9592 10058.5 ROP MWD FT/H 1.15 140.54 54.5165 893 9656.5 10102.5 First Reading For Entire File..........9592 Last Reading For Entire File...........10102.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 • • Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9592.0 9827.0 ROP 9657.5 9857.0 LOG HEADER DATA DATE LOGGED: 23-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9857.0 TOP LOG INTERVAL (FT) 9657.0 BOTTOM LOG INTERVAL (FT) 9857.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.4 MAXIMUM ANGLE: 61.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.750 DRILLER'S CASING DEPTH (FT) 9621.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 158.0 MUD FILTRATE AT MT: .000 .0 • MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • 000 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ........................ Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9592 9857 9724.5 531 9592 9857 GR MWDO10 API 18.78 624.31 70.1614 391 9592 9827 ROP MWDO10 FT/H 1.15 112.57 48.4245 400 9657.5 9857 First Reading For Entire File..........9592 Last Reading For Entire File...........9857 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF • • File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9660.5 10071.5 FET 9660.5 10071.5 RPD 9660.5 10071.5 RPS 9660.5 10071.5 RPM 9660.5 10071.5 GR 9827.5 10058.0 ROP 9857.5 10102.5 LOG HEADER DATA DATE LOGGED: 24-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10102.0 TOP LOG INTERVAL (FT) 9857.0 BOTTOM LOG INTERVAL (FT) 10102.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 56.2 MAXIMUM ANGLE: 61.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.750 DRILLER'S CASING DEPTH (FT) 9621.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.300 68.0 • • MUD AT MAX CIRCULATING TERMPERATURE: .600 MUD FILTRATE AT MT: 1.600 MUD CAKE AT MT: 1.900 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ....... ........... 0 Data Specification Bloc k Type..... 0 Logging Direction ...... ........... Down Optical log depth units ........... Feet Data Reference Point ... ........... Undefined Frame Spacing .......... ........... 60 .lIN Max frames per record .. ........... Undefined Absent value ........... ........... -999 Depth Units ............ ........... Datum Specification Block sub-type ...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD20 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 155.9 68.0 68.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9660.5 10102.5 9881.5 885 9660.5 10102.5 RPD MWD020 OHMM 0.09 2000 31.5285 823 9660.5 10071.5 RPM MWD20 OHMM 0.1 1620.85 18.0999 823 9660.5 10071.5 RPS MWD020 OHMM 0.97 2000 24.1174 823 9660.5 10071.5 RPX MWD020 OHMM 1.61 2000 34.1889 823 9660.5 10071.5 FET MWD020 HOUR 0.29 43.4 19.0771 823 9660.5 10071.5 GR MWD020 API 20.67 165.15 35.6433 462 9827.5 10058 ROP MWD020 FT/H 13.71 140.54 59.8468 491 9857.5 10102.5 First Reading For Entire File..........9660.5 Last Reading For Entire File...........10102.5 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/06 Origin ...................STS Tape Name ................I7NKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/03/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Technical Services Physical EOF Physical EOF Writing Library. Scientific End Of LIS File