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201-228
Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:201-228 6.50-029-22402-01-00 PRUDHOE BAY, NIAKUK 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 12444 12248 9380 9739 none 12248 7166 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1530 520 Surface 4970 10-3/4" 36 - 5006 36 - 4142 5210 2480 Intermediate 9997 7-5/8" 33 - 10030 33 - 7350 8180 5120 Production Perforation Depth: Measured depth: 12214 - 12389 feet True vertical depth:9347 - 9520 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 / L-80 30 - 9949 30 - 7298 9739 7166Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Liner 2504 4-1/2" 9936 - 12440 7290 - 9570 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 75914282605387 5579539 2113 287 1085 623 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: Kirsty Glasheen Kirsty.Glasheen@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5258 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 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 measured9574 Sundry Number or N/A if C.O. Exempt: 321-208 4-1/2" FXE 2182 2129 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Tubing swap Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0034635 NIA NK-22A 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 By Meredith Guhl at 10:47 am, Sep 17, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.17 10:07:19 -08'00' Bo York SFD 9/28/2021RBDMS HEW 9/17/2021 DSR-9/17/21MGR14OCT2021 ACTIVITYDATE SUMMARY 7/6/2021 T/I/O = 690/690/60. Temp = SI. TBG & IA FL (Wie request). No AL or flowline. TBG & IA FL @ near surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:20 7/7/2021 T/I/O = 690/690/80. Temp = SI. CMIT-TxIA to 4000 psi FAILED (Pre Rig). No AL or flowline. TBG & IA FL @ near surface. Max applied pressure = 4000 psi. Used 10.9 bbls Diesel by pumping into the IA to pressure T/IA to 3300/3300 psi. T/IA would not pressure up above 3300 psi. Established T/IA LLR of 10.4 gpm @ 3250 psi. Bled T/IA to 690 psi (5.2 bbls). Hung tags. OA Integrity test to 1200 psi PASSED (Pre Rig). OA FL @ surface. Used 1.4 bbls Diesel to pressure OA to 1200 psi. OAP decreased 21 psi during the 5 min test. No sign of leaks anywhere on the surface kit. Bled OAP to 80 psi (1.4 bbls). Hung tags. Final WHPs = 690/690/80. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:00 7/12/2021 ***WELL S/I ON ARRIVAL***(rwo) RAN SWIVEL, 3.48" DECENT, 3.70" LIB TO TBG STUB @ 9,811' SLM, IMPRESSION OF TBG STUB (arc @ 6:00). PULLED 2.31" PX PLUG FROM NIPPLE REDUCER @ 9916' MD. (PLUG LOOKS GOOD). ATTEMPTED TO SET 2.31" PX PLUG BODY @ 9916' MD, UNABLE TO SHEAR STEEL UPPER PIN IN X-LINE. ***WSR CONTINUED ON 7-13-21*** 7/12/2021 T/I/O= 950/950/100 TFS unit # 1 (Assist SL CMIT-TxIA) Road to location, Rig up and PT ***Job continued on 07/13/2021*** 7/13/2021 ***WSR CONTINUED FROM 7-12-21*** SET 2.31" PX PLUG BODY IN NIPPLE REDUCER @ 9916' MD. ATTEMPTED TO SET EQ PRONG ASS'Y W/ 2.30" BLB BRISTLES. LEFT PRONG IN TBG STUB @ 9826' MD. RECOVERED PRONG ASS'Y FROM 9826' MD. SET EQ PRONG ASS'Y W/ 2.60" BLB BRISTLES IN PX PLUG BODY @ 9916' MD. T-BIRD ATTEMPTS TO CMIT-TxIA, ESTABLISHED A LLR OF 0.5 bpm @ 3,600 psi RAN 3.80" TAPERED LIB THROUGH TBG CUT @ 9,825' MD RAN READ CASED HOLE LDL (S/P/T), (plug is holding, leaks into tbg cut & st#4) ***WELL S/I ON DEPARTURE*** ***in line spinner lost down hole*** 7/13/2021 ***Job continued from 07/12/2021*** TFS unit # 1 (Assist Slickline) Attempted to bring TxIA up to max applied psi of 4000, Not able to pressure up TxIA to 4000 psi, established LLR= 0.5 bpm @ 3600 psi. FWHP=1000/1000/100 Slickline still on well upon departure. Fluid packed annulus sign on well. 7/16/2021 ARCHHER LDL LOG WELL SHUT IN ON ARRIVAL MIRU EL LOG ACOUSTIC LDL FROM 9910 TO SURFACE ACCOUSTIC LEAK SIGNATURE AT TUBING CUT AT 9825' WELL SHUT IN ON DEPARTURE Daily Report of Well Operations PBU NK-22A Daily Report of Well Operations PBU NK-22A 7/16/2021 T/I/O = 1180/1180/100 (Assist E-Line) Pumped 105 bbls crude to assist E-Line with LDL. E-Line still on well upon departure. (This AWGR was recreated due to file corruption) 7/27/2021 T/I/O=922/945/95 (RWO EXPENSE) Pumped 10 BBL's of 60/40 methanol followed by 50 BBL's of 2% Baraklean in fresh water, 450 BBL's of 9.03 ppg brine, and 100 BBL's of diesel. Allow to U-tube for 1 hour. WV/SV/SSV = closed, MV = open, CV's = OTG. FWHP's = 899/921/574 8/2/2021 T/I/O = 480/480/70. Temp = SI. Bleed WHPs and Control line to 0 psi (Pre RWO). No AL, flowline, or wellhouse. TBG, IA & OA FL @ surface. Control line = 480 psi. Bled TP/IAP to BT from 480 psi to 0+ psi in 20 min (Fluid, 0.9 bbls). OAP decreased 10 psi, Control line decreased 200 psi. Bled Control line from 280 psi to 0 psi in 3 min (Mostly gas). Bled OAP to BT from 60 psi to 0+ psi in 45 min (Energized fluid, 1/2 bbl). During OA bleed, TP/IAP increased 90 psi. Bled TP/IAP to 0+ psi (1/4 bbl). Monitored for 30 min. TP/IAP increased 60 psi. Bled TP/IAP to 0+ psi and held open for 1 hr (0.2 bbls). Monitored for 30 min. TP/IAP increased 60 psi. Final WHPs = 60/60/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:40 8/3/2021 T/I/O = 480/480/0. Pre RWO. Bleed Tubing/IA to 0psi. Set 4" 'H' CTS BPV #2 with dryrod. ND 4" Production tree and THA. Wellhead Tech. prepped wellhead. NU BOP's and torqued to API specs. RDMO ***Job Complete*** Final W HP = BPV/0/0. BPV sign hung on wellhead. 8/3/2021 Cost Placeholder Arctic Lift Systems DGLV / Latch Purchase 8/3/2021 T/I/O 480/480/0 Pre RWO. Bleed tubing & IA to 0-psi. Set 4" CTS BPV with dry rod. Tubing hanger void 0+ psi, bled to 0 psi, remove adapter & tree, SBMS stayed in Adapter. Cut CCL and cap, Install CTS plug, MU 4-1/2 NSCT test sub 8 turns, Did not test CTS plug. Function all LDS out = 4-1/2" Adapter Part number 02-047-689, Tubing hanger part number 82-747-698 8/6/2021 T/I/O=BPV/480/0. Pre RWO remove BOP for reworking. ND BOP and NU Shooting flange with 4" temp valve. Torqued flanges to API spec. ***Job Complete*** Final WHP's BPV/480/0. 8/8/2021 T/I/O=BPV/480/0. Pre RWO Install BOP. ND Shooting flange with 4" temp valve and NU BOPwith shooting flange. Torqued flanges to API spec. ***Job Complete*** Final WHP's BPV/480/0. 8/17/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue moving equipment from S-Pad to NK-22. Mobilize rig from NES yard to NK- 22. Spot rig and equipment on location. Rig up operations. Install 2-7/8" x 5-1/2" VBR's & 4.5" fixed ram. 24 hr BOP test notification update given. Matt Herrera waived witness. RU and Test BOPE per Sundry. 24Hr notice and BOP test notification update given to AOGCC. Matt Herrera waived witness. Test BOPE per the sundry. with 2-7/8" & 4-1/2" Test Joints to 250 psi Low/ 4000 psi High. Lower single gate tested to 250 psi Low / 5000psi high. No failures. Test gas alarms. Koomy Drawdown RD Test Equipment. Take on 9.8 ppg NACL/KCL Brine. NU shooting flange. Pull blanking dart on BPV. ...Continue WSR on 8/18/21... 8/18/2021 ***THUNDERBIRD RIG ON WELL*** (rig job) RAN 3.42" DECENTRALIZER, 3.50" LIB TO TBG CUT @ 9,831' SLM. ***WSR CONTINUED ON 8/19/21*** 8/18/2021 RWO: Pulled CTS inner plug using dry rod. Valve shop lubricated out 4" H CTS BPV due to 500 psi on tubing. 8/18/2021 Pulled 4" CTS BPV through BOP stack. RDMO. ***Job Compete*** Daily Report of Well Operations PBU NK-22A 8/18/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion NU shooting flange on top of annular. Vault well head rep pulled test dart on CTS Valve. BOP form 10-424 sent back to AOGCC. 24 hr notice to AOGCC for upcoming ram change. Witness waived by Bob Noble. PU/MU Lubricator. PT lubricator. Shooting flange Leaking. C/O API ring. PT'd lubricator and pulled CTS valve. Rock diesel out of tubing and circulate 475 bbls of 9.8ppg brine into TBG and up IA. Shut down and found TGB and IA still had 50psi of pressure and fluid returns were contaminated with crude. Bleed 10bbls off of TBG/IA and still had 20psi of pressure. Consulted with OE and determined we were most likley circulating around known leak at GLM #3 and getting residual crude from previous LDL. Decision made to RU SL and pull TTP for bullhead L&K. RU Pol wireline, RIH with LIB. ...Continue WSR on 8/19/21... 8/19/2021 ***WSR CONTINUED FROM 8/18/21*** (rig job) MADE 2 ATTEMPTS TO PULL PRONG FROM PX-PLUG @ 9,916' MD. (issues getting into tbg cut) PULLED 2-7/8" PX-PLUG FROM 9,916' MD. T-BIRD RIG RELOADED TBG & IA SET 2 7/8" PX-PLUG IN NIPPLE REDUCER @ 9,916' MD ***RIG IN CONTROL OF WELL ON DEPAERTURE*** 8/19/2021 RWO: Backed out tubing hanger LDS to minimum of clear bowl measurement of 4- 1/2". Pulled tubing hanger to the rig floor. Up weight 98K. Cut and capped 1 each 1/4" control line. Left location. Called back to location. Rig has crude oil in the tubing. Re-landed tubing hanger and ran in 2 each LDS so that rig can reverse circulate crude out of tubing. 8/19/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue with wireline: 300 psi WHP prior to RIH. First run to retrieve the PX plug was unsuccessful. Make up new JD retrieval tool, RIH and Pull PX prong from 9916'. Observe pressure pressure drop to 175 psi and weight gain. Line up down the TBG and IA with 2 pumps. Bullhead 600bbls of 9.8ppg brine down the TBG and IA at 7 BPM. SL RIH and set 2-7/8" PX plug and prong at 9920'. RD slickline and perform flow checks and pressure monitoring. Had crude returns from the IA that would clear after pumping 20bbls down TBG. MU landing joint and backed out LDS. Pulled TBG hanger to floor with 98k. Started circulating across the top and got crude returns. Broke out TBG hanger and had crude in the TBG. Made TBG hanger back up and landed back in well to circ out crude. Reverse crude out of tubing. Change out elevators. Start Decomplete. ...Continue WSR on 8/20/21... 8/20/2021 RWO: Set special modified upper test plug with compression seal so that the rig could change BOP rams. This plug was needed due to known casing leak. Run in LDS to energize compression seal. Rig pressure tested against bottom of test plug to 1000 psi for 10 minutes. Rig changed rams and then shell tested BOPs to 4000 psi for 10 minutes. Backed out LDS, pulled test plug, set bowl protector. Ran in 2 LDS on bowl protector. Daily Report of Well Operations PBU NK-22A 8/20/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue Decomplete. POOH with 4-1/2" IBT completion. All bands in tact and recovered. Install test plugh, RILDS. Test from below to 1000 psi charted. Good test. Install 2-7/8" fixed rams in Lower ram cavity & PT wtih 2-7/8" TJ to 250 low/4000 psi high 5 charted min each. Good test. LD Test joint, Pull test plug, Install wear ring. ick up Baker 7-5/8" TST-3 Service Packer and RIH picking up single joints of 2-7/8" PH6 Drill Pipe. ...Continue WSR on 8/21/21... 8/21/2021 RWO: BOLDS and pull WR. Set modified upper test plug and RILDS in preparation for BOP ram change. LDS torqued 500 ft/lbs. Rig tested casing to 1000 psi and then changed rams. BOP shell test to 4000 psi. BOLDS and pull TP. Standby for 4-1/2¿ completion string to be run. 8/21/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion RIH wtih Baker 7-5/8" TST-3 Service Packer on single joints of 2-7/8" PH6 Drill Pipe. Set packer at ~9,800' COE. Pressure up the TBG to 1K psi. Leaking Head pin. Perform passing MIT on 7-5/8" casing to 4,000psi. Unseat packer and trip OOH. Lay down packer, pull wear bushing. MU test plug, land plug and PT from below to 1,300psi. 24 notice given to AOGCC for Ram change. Witness waived. Change lower rams to 4.5". MU 4.5" test joint and PT lower rams to 300/4000psi.Trouble shoot leaks. C/O TIW. Good test. RU Doyon Casing. MU & RIH with approved 4-1/2" completion. 4-1/2" 12.6# 13Cr VamTop. ...Continue WSR on 8/22/21... 8/22/2021 RWO: MU FMC 13-1/2" x 4-1/2" TC-II tubing hanger (P1000195672) with x/o pup to 233 joints of 4-1/2", 12.6#, L-80, Vam Top tubing. Routed and terminated 1 each ¼" CCL for SSSV. RIH and landed tubing hanger at 14.00 RKB, RILDS, torque LDS and gland nuts to 500 ft/lbs. Standby for rig to spot corrosion inhibitor, set packer, and test. 8/22/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion MU & RIH with approved 4-1/2" completion. 4-1/2" 12.6# 13Cr VamTop. MU SSSV nipple, terminate control line and pressure test. Land overshot on TBG stub and space out. Space out bottom of overshot 4' off of No go. MU TBG hanger, termintated and tested control line. RILDS. Reverse in 55 bbls of Corrosion inhibited brine. 1% Baracor 100 wtih .1% Oxygone. Chased with 205 bbls of 9.8ppg brine. Drop Ball and Rod with Roller stem. (1.375")FN. Pressure up tbg & set packer, see packer set ~2200 psi, MIT-T to 4220 psi.- 15 min-4150 psi, 30 min-4125 psi.- passing Bleed TBG to 2150 psi. Test. MIT-IA to 4250 psi Start. 15 min- 4200 psi, 30 min- 4200 psi.- passing Test. Bleed TBG to Zero & shear GLV at 4969' . Verify circulation both ways thru the shear valve. Reverse in 91 bbls of Freeze protect. U-tube ~2hr. Verify zero Pressure on well. Send BOPE test request to the AOGCC for H-21 ...Continue WSR on 8/23/21... 8/22/2021 RWO: Dry rod in 4" H TWCV for BOP ND. 8/23/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue Reverse in 91 bbls of Freeze protect. U-tube ~2hr. Bleed Pressure from the Control line, cap and coil inside the annular. Set TWC & Test from Below to 3000 psi.- Good test Suck stack out with Vac Truck. Remove VBR's. RDMO from NK-22, Mobilize Rig to H-21. Job Complete final WSR Daily Report of Well Operations PBU NK-22A 8/23/2021 T/I/O=0/0/0. ND YJ 13-5/8" 5M BOP's and set on BOP skid. ND 13-5/8" 5M single gate ram and spool peice, deliver to YJ. (well head tech routed (1) 1/4" CCL through fitting on top flng. of tbg. spool, installed new SBMS seal in hanger neck, clean void & ring groove, install new RX-54, fill void w/ hydraulic oil, inspect 4-1/2" TC-II lift threads, ***LIFT THREADS GALLED BY LANDING JOINT AND NO LONGER FUNCTIONAL*** NU 13-5/8" 5M FMC THA & 4-1/16" 5M CIW production tree w/ Baker C actuator. Wellhead tech pressure tested adapter void 5m/30 min (PASS), bleed off test psi. Install production and AL piping, set wellhead scaffolding and set well shelters on NK-22 and 42. Pressure test production tree to 500 psi low and 5000 psi high (PASS). Pull 4" CIW TWC. RDMO. 8/24/2021 ***WELL S/I ON ARRIVAL (post rig)*** GAUGED TBG 3.84" TO 2182' MD. ***WSR CONTINUED ON 8-25-21*** 8/25/2021 ***WSR CONTINUED FROM 8-24-21*** PULLED 4 1/2" FXE WRSSSV FROM 2182' MD. PULLED BALL & ROD FROM 9814' SLM. PULLED BK-DGLV FROM STA# 5 @ 4967' MD. PULLED BK-DGLV FROM STA# 2 @ 8836' MD. ATTEMPTED TO PULL BK-DGLV FROM STA# 3 @ 7870' MD (DIFFICULTIES NOW S/D IN MANDREL) MADE MULTIPLE LIB RUNS TO STA# 3. ON 3RD ATTEMPT GET PICTURE OF LATCH. PULLED BK-DGLV FROM STA# 3 @ 7870' MD. PULLED BK-DGLV FROM STA# 4 @ 6745' MD. SET BK LGLV IN STA# 5 @ 4967' MD. ***WSR CONTINUED ON 8-25-21*** 8/26/2021 ***WSR CONTINUED FROM 8-25-21*** SET BK-LGLV'S IN ST #4 @ 6,745' MD, & ST #3 @ 7,871' MD SET BK-OGLV IN ST # 2 @ 8,836' MD PULLED RHC BODY FROM X NIP @ 9,813' MD PULLED 2 7/8" PX PLUG FROM NIP REDUCER @ 9,916' MD PULLED 4 1/2" NIPPLE REDUCER FROM X NIP @ 9,916' MD SET 4 1/2" FXE (SER #0004073123-1) IN SSSV NIPPLE @ 2,182' MD(2.120"ID) CHECKSET TO CONFIRM SAFETY VALVE SET (sheared) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** David Dempsey Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/15/2021 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: Please include current contact information if different from above. Received By: 07/15/2021 37' (6HW By Abby Bell at 4:13 pm, Jul 15, 2021 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:201-228 6.API Number:50-029-22402-01-00 PRUDHOE BAY, NIAKUK OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 034635, 034630 Property Designation (Lease Number):10. 8. PBU NK-22A 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 Repair Well 5 Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12444 Effective Depth MD: L-80 11. Commission Representative: 15. Suspended Contact Name: Kirsty Schultz Contact Email: Kirsten.Schultz@hilcorp.com Authorized Name: Bo York 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:Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9574 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9892, 7262 Date: Liner 2504 4-1/2"9936 - 12440 7290 - 9570 8430 7500 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 36 - 5006 36 - 4142 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural 8180 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 12214 - 12389 9347 - 9520 4-1/2" 12.6# L-80 30 - 9949 Production 9916 7278 9916 , 12248 none 36 - 116 520 10-3/4" 7-5/8" Contact Phone:907.564.5258 Date: 4-22-21 5120 80 153020"Conductor 2480 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 4970 5210 Intermediate 9997 33 - 10030 33 - 7350 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 2376 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. No SSSV installed 8/15/2021 By Samantha Carlisle at 6:53 pm, Apr 22, 2021 321-208 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.22 15:46:13 -08'00' Bo York 10-404 SFD 4/23/2021 BOPE test to 4000 psi. Annular to 3500 psi. MGR26APR21 DSR-4/22/21 Yeson Required? Comm. 4/26/21 dts 4/26/2021 JLC 4/26/2021 RBDMS HEW 4/28/2021 RWO NK-22A PTD: 1950660 Well Name:NK-22A API Number:500292240201 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:8/15/2021 Estimated Duration:5 days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:2012280 First Call Engineer:Kirsty Schultz 907-564-5258 907-350-4310 Second Call Engineer:David Bjork 907-564-4672 907-440-0331 Current Bottom Hole Pressure:4,023 psi @ 9,200’ TVD 8.4 PPGE | SBHP Survey - 05/20 Max. Anticipated Surface Pressure:3,103 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1,200 psi (Taken on 05/02/20) Min ID:2.313” 4-1/2” reducing nipple @ 9,916’ MD Max Angle:52 Deg @ 9,693’ Brief Well Summary: NK-22A was sidetracked from NK-22 and placed on production as a gas lifted producer on 01/10/2002. The well has been a mostly full-time producer, except during down periods due to integrity issues. The well had two tubing patches deployed (one in 2006 and one in 2012) to repair during integrity. A negative side effect of the tubing patches was limited gas lift injection depth. Due to the benefits associated with deeper lift, it was decided to move forward with a RWO in 2019. The well was prepped for a RWO, but the RWO never took place. The well is currently sitting idle with a plug in the nipple reducer at 9916’ MD and the tubing cut above. Hilcorp would like to move forward with the RWO and place the well back on production. Objective: Pull the existing 4 ½” L80 tubing and replace with 13 chrome tubing with deep gas lift design. Achieve a passing MIT-IA & MIT-T. Pre RWO work: Wellhead -PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function all LDS. Slickline - Set hold open sleeve in SSSV. Fullbore - CMIT-TxIA to 4000 psi. OA integrity test to 1200 psi. Circ well to 9.8 brine and freeze protect and bleed WHP to 0 psi. Valve Shop - Set and test TWC Nipple Down Tree and tubing head adapter. Inspect lift threads. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross, 2- 7/8” x 5-1/2” VBRs. Tubing cut @ ~9826'MD (4-9-2019) RWO NK-22A PTD: 1950660 Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/4,000psi High, annular to 250psi Low/3,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4-1/2” and 2-7/8” test joints. Test the Annular preventer with a 2-7/8” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. 4. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~124K 5. Pull 4 1/2” tubing to floor, circulate bottoms up. 6. Run 4 ½” 13Cr tubing with stacker packer completion as detailed on proposed schematic. 7. Land Hanger and reverse in corrosion inhibited 9.8 ppg brine. 8. Drop ball and rod and set packer with 3,500psi pump pressure. 9. Perform MIT-T to 4,000 psi and MIT-IA to 4,000 psi for 30 charted minutes. 10. Set TWC 11. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000’ with diesel. Post rig Slickline Work 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer 3. Pull plug from nipple reducer at 9,916’ MD 4. Pull nipple reducer at 9,916’ MD 5. RDMO & POP well Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing RWO NK-22A PTD: 1950660 Wellbore Schematic RWO NK-22A PTD: 1950660 Proposed Wellbore Schematic RWO NK-22A PTD: 1950660 RWO BOPs 2-7/8" x 5-1/2" VBRs Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:201-228 6.50-029-22402-01-00 PRUDHOE BAY, NIAKUK OIL BP Exploration (Alaska), Inc 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 12444 9916 7277 9892 9916 9916, 12248 7262 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1530 520 Surface 4970 10-3/4" 36 - 5006 36 - 4142 5210 2480 Intermediate 9997 7-5/8" 33 - 10030 33 - 7350 8180 5120 Production Perforation Depth: Measured depth: 12214 - 12389 feet True vertical depth:9347 - 9520 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 30 - 9949 30 - 7298 9892 7262Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 2504 4-1/2" 9936 - 12440 7290 - 9570 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 6KXW,Q Shut-In 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: Mclaughlin, Sean M Sean.McLaughlin@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone: Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing 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 measured9574 Sundry Number or N/A if C.O. Exempt: 319-055 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Cut Tubing Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 034630 & 034635 PBU NK-22A 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 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.04.15 16:15:52 -08'00' By Samantha Carlisle at 8:12 am, Apr 16, 2020 MGR24APR20 RBDMS HEW 4/16/2020 DSR-4/16/2020 SFD 4/23/2020 ACTIVITYDATE SUMMARY 3/31/2019 ***WELL S/I ON ARRIVAL*** (Pre RWO) TAG 4-1/2" HES QOS W/ 3.84" NO-GO CENT AT 2,069' SLM / 2,091' MD. ***JOB IN PROGRESS, CONTINUED ON 4/1/19 WSR*** 4/1/2019 ***CONTINUED FROM 3/31/19 WSR*** (Pre RWO) PULL 4-1/2" HES QOS (CP-2 extension, s/n = QOS-35) FROM 2,069' SLM / 2,091' MD. PURGE 3 GALLONS OF HYDRAULIC FLUID DOWN CONTROL LINE PER PROGRAM. RAN TANDEM BP SBHPS GAUGES PER PROGRAM (Good data). SET 4-1/2" WHIDDON CATCHER SUB ON 45KB PATCH AT 6,757' SLM / 6,771' ELM. PULL BK-OGLV (Bad check spring) FROM ST #4 & SET BK-DGLV AT ST #4 (4,816' MD). PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 6,757' SLM / 6,771' MD. BRUSH 4-1/2" x 2-7/8" X-NIPPLE REDUCER W/ 2.30" CENT, 2-7/8" BRUSH (No issues). LRS LOADED TUBING W/ 360 BBLS OF 1% KCL & 38 BBL DIESEL FREEZE PROTECT. SET 2-7/8" PX PLUG BODY IN NIPPLE REDUCER AT 9,905' SLM / 9,916' MD. ***JOB IN PROGRESS, CONTINUED ON 4/2/19 WSR*** 4/1/2019 T/I/O=2400/2411/126 Temp=SI (LRS Unit 70 - Assist Slickline: Load & Test) Load Tubing w/ 2 bbls 60/40 spear followed by 365 bbls of 1% KCl Freeze protect w/ 2 bbls 60/40 spacer, 38 bbls diesel. Bled IAP to NK-21 FL, freeze protect flowline with 4 bbls 60/40. Slickline set plug. ***Continued on 04-02-19 WSR*** 4/2/2019 T/I/O = 880/1900/120. Temp = SI. IA FL (Assist SLB). IA FL @ 4130' (108 bbls). Assist with fluid as needed. SLB & LRS in control of well. IA, OA = OTG. 13:00. 4/2/2019 ***Continued from 04-01-19 WSR*** (LRS Unit 70 - Assist Slickline:Circ Out/Mit's,RWO Expense) Pumped 25 bbls 20* diesel down TBG to verify prong set, IA tracking (trouble shoot) Grease crew service companion valves wing & AL casing. Bleed IAP down NK-21 for trouble shooting, S-line reset prong in plug. Pumped 52.6 bbls of 20* diesel down TBG up IA to NK-22 to fluid pack IA. CMIT-TxIA Passed to 1668/1678 psi (Max =1750 psi, Target = 1500 psi ) Pumped 2.4 bbls of diesel down TBG to reach 1740/1740 for TxIA psi test. 1st 15 min T/IA lost 62/51 psi. 2nd 15 min T/IA lost 10/11 for a total of 72/62 psi in 30 min. F-protect hard line & F-line NK-21 with 7 bbls of 60/40. Pumped 3 bbls of 60/40 down IA. Pumped 2 bbls of diesel to assist S-line with catcher. Called off job for freeze protect on pad. Slickline in control of well upon departure. IA OA= OTG Final Whp's=700/700/120 Daily Report of Well Operations PBU NK-22A Daily Report of Well Operations PBU NK-22A 4/2/2019 ***CONTINUED FROM 4/1/19 WSR*** (Pre RWO) SET EQUALIZING PRONG IN 2-7/8" PX PLUG BODY AT 9,905' SLM / 9,916' MD. LRS ATTEMPTED PRESSURE TEST ON TBG (tbg x ia comm & plug may be leaking). PULL EQUALIZING PRONG FROM 2-7/8" PX PLUG BODY AT 9,916' MD (Packing torn). SET EQUALIZING PRONG IN 2-7/8" PX PLUG BODY AT 9,905' SLM / 9,916' MD. LRS PERFORMED SUCCESSFUL PRESSURE TEST ON TBG & IA TO 1650 PSI. MADE ONE ATTEMPT TO PULL BK-DGLV FROM ST #1 (9,803' MD). ***JOB IN PROGRESS, CONTINUED ON 4/3/19 WSR*** 4/3/2019 ***CONTINUED FROM 4/2/19 WSR*** (Pre RWO) MADE THREE ATTEMPTS TO PULL BK-DGLV FROM ST #1 (9,803' MD). DRIFT TO EQUALIZING PRONG AT 9,901' SLM / 9,916' MD W/ 2.30" CENT. PUNCH TBG FROM 9,811' TO 9,816' MD W/ SLB E-FIRE & 5' x 1.56" TBG PUNCH. LRS CIRCULATED 508 BBLS OF 9.8 BRINE DOWN TBG & UP IA TO NK-21 FLOWLINE. LRS FREEZE PROTECTED TBG & IA W/ 20 BBLS OF DIESEL & NK-21 FLOWLINE. LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 3129 PSI. ***LRS IN CONTROL OF WELL ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 4/3/2019 T/I/O=700/700/120 Temp=S/I (LRS Unit 70-Assist Slickline: Circ Wellbore/CMIT- TxIA-RWO Expense) Pumped down TBG up IA through hardline to NK-21 F-line. Spear in w/5 bbls of 0* meth followed by 508 bbls of 70* 9.8 brine 20 bbls of 0* diesel. F-protect hard line & NK-21 F-line w/5 bbls of meth , U-tube TxIA for 30 min. Bled OAP down for CMIT Tx IA CMIT TxIA PASSED @ 3158/3129 psi. Target psi 3000 psi MAX applied 3250 psi .Pumped 2.4 bbls of 0* diesel down TBG to reach test psi for CMIT Tx IA 1st test 1st 15 min TxIA lost 22/24 psi 2nd 15 min 20/20 3rd 15 min lost 16/16 psi for a total of 58/61 psi in 45 min. Bleed TxIAP down bleed back ~aprox 3 bbls. OA integrity test passed to 1108 psi. Pressured up OA to 1122 psi with 7.6 bbls diesel. OA lost 14 psi in 5 min and no visible fluid to surface. bled back~ 3 bbls. Tags hung, **AFE** sign hung on well. SV WV SSV= closed. MV IA OA= open. Final Whp's=240/260/50 4/4/2019 ***WELL S/I ON ARRIVAL*** (Pre RWO) PULL BKR 45KB x 22.81' STRADDLE PATCH (Missing two elements) FROM 6,771' MD. RAN 3.50" WIRE GRAB TO 45KB PACKER AT 8,056' MD (Recovered one element). RE-RAN 3.50" WIRE GRAB TO 45KB PACKER AT 8,056' MD (No recovery). CURRENTLY IN HOLE JARRING ON 45KB PACKER AT 8,056' MD. ***JOB IN PROGRESS, CONTINUED ON 4/5/19 WSR*** Daily Report of Well Operations PBU NK-22A 4/5/2019 ***CONTINUED FROM 4/4/19 WSR*** (Pre RWO) PULL UPPER 45KB x 35.82' SPACER, SNAP LATCH ASSEMBLY FROM 8,056' ELM (Missing one element). RAN 3.50" WIRE GRAB TO MIDDLE SPACER, SNAP LATCH ASSEMBLY (No recovery). PULL BAKER SPACER, SNAP LATCH ASSEMBLY (Complete) FROM 8,077' SLM. PULL BAKER SPACER, LOWER ANCHOR PACKER (Missing one element) FROM 8,101' SLM. UNABLE TO PASS ST #1 (9,803' MD) W/ 3.50" WIRE GRAB (No recovery). ***JOB IN PROGRESS, CONTINUED ON 4/6/19 WSR*** NOTE: THREE ELEMENTS LEFT IN HOLE FROM 45KB PACKERS PULLED 4/4 & 4/5/19. 4/6/2019 ***CONTINUED FROM 4/5/19 WSR*** (Pre RWO) RAN 3.50" WIRE GRAB TO 9,860' SLM (No recovery - ~37' above Eq. prong). RAN 3.70" CENT, 3.25" L.I.B. TO 9,895' SLM (No impression - possible elements). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** NOTE: THREE ELEMENTS LEFT IN HOLE FROM 45KB PACKERS PULLED 4/4 & 4/5/19. 4/8/2019 T/I/O=SSV/100/0, Temp=SI. PPPOT-T (PASS), PPPOT-IC (PASS). Pre pulling unit. PPPOT-T: Stung into test port (2200 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (650 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 4/9/2019 ***JOB STARTED 09-APR-2019*** (Pre-RWO) CUT 4-1/2" TBG AT 9825' MD W/ 2.5" POLLARD RCT CUTTER. ALL LOGS TIED INTO TBG TALLY DATED 23-DEC-2001 WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 100/100/0. ***JOB COMPLETE ON 09-APR-2019*** 4/13/2019 T/I/O=22/44/24 temp=SI LRS unit 70 CMIT-TXIA (RWO EXPENSE) CMIT-TxIA FAILED to 2417/2346 psi Max Applied Pressure= 3250 psi Target Pressure= 3000 psi. Pressured T/IA to 3215/3144 psi with 15.68 bbls of Diesel. CMIT-TxIA lost 431/430 psi in the 1st 15 min and 367/368 psi in the 2nd 15 min for a total of 798/798 psi during a 30 min test. Established a LLR of .04 bpm. See log for details. Bled T/IA to 44/49 psi recovering ~ 3 bbls . Freeze protected FL w/ 4 bbls crude MW. SV/WV/SSV= closed MV=open CV's= OTG. Tags Hung DSO notified of well status upon LRS departure. FWHP's 44/49/3. 4/14/2019 T/I/O = VAC/30/20. Temp = SI. TBG & IA FL (WIE Request). ALP = 2400 psi, SI @ CV. TBG FL @ near surface. IA FL @ near surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:30 Daily Report of Well Operations PBU NK-22A 8/15/2019 ***WELL S/I ON ARRIVAL***(pre rwo) DRIFTED W/ 2.5" CENTRALIZER, 2.25" LIB TO PX PLUG @ 9,916' MD. (picture of prong) PULLED PRONG FROM PLUG BODY @ 9,916' MD. RAN SBHPS PER PROGRAM (Good Data) SET PRONG IN PLUG BODY @ 9,916' MD. ***JOB COMPLETE, WELL LEFT S/I*** 3/23/2020 T/I/O = 1180/1360/100. Temp = SI. T & IA FL (eval secure). Flowline & AL disconnected. T FL @ 1500' (23 bbls). IA FL @ 1940' (51 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 Failed CMIT Tx IA after Tubing Cut. mgr THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Niakuk Oil Pool, PBU NK -22A Permit to Drill Number: 201-228 Sundry Number: 319-055 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907279.1433 Fax: 907.276.7542 w .aogcc.olosko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this of February, 2019. RBDMSkAkB 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 NtULIVED FFR 0 h 2010 1, Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Operations shuWghly r] / Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ® Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Soap Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 201-228 3, Address: P.O. Box 196612 Anchorage, AK 99519-8612 Stretigrephic ❑ Service ❑ 6. API Number: 50-029-22402-01-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No RI PBU NK -22A - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 034630& 034635 PRUDHOE BAY. NIAKUK OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(8): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12444 9574 12248 9380 2990 12248 None Casing Length Sin MD TVD Burst Collapse Structural Conductor 80 20" 36-116 36-116 1530 520 Surface 4970 10-3/4" 36-5006 36-4142 5210 2480 Intermediate 9997 7-518" 33-10030 33-7350 8180 5120 Pmduction Liner 2504 4-112" 9936-12440 7290-9570 8430 1 7500 Perforation Depth MD (ft): Per omtion Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 12214 - 12389 9347-9520 4-112" 12.6# L 30-9949 Packers and SSSV Type: 4-112" Baker S-3 prod Packer Packers and SSSV MD (ft) and TVD (ft): 9892/7262 4-112. OOS SSV 2091 12047 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development 10 Service ❑ 14. Estimated Date for Commencing Operations: Febwary 15, 2019 15. Well Status after proposed work: Oil IZ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval. Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Ciolkoez, Ryan R be deviated from without prior written approval. Contact Email: Ryan.CioIkoszC1%bp.corn Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 5977 Authorized Title: Engi ear Team Lead -CTD Authorized Signature: Date: �\ZIA /� COMMISSION USE ONLY Conditions of approval: Notify Commission so that aarrepresentative may witness Sundry Number: �� Plug Integri�tyl ❑ BOP Test 01 Mechanical Integrity Test ❑ Location Clearance ❑ '� Other: d< 6 �� —�rJ T -%� .'Q ©IP S / Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Id Subsequent Form Required.APPROVED Approved b COMMISSIONER COMMISSION Date: Date: Form 10-403 Revised 04/2017 ORIGINAL RBDW6FEB 192019 /2'r&Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission e4#0 From: Ryan Ciolkosz i bp RWO/CTD Engineer �1k �" Date: February 4, 2019 Re: NK -22A Sundry Approval Sundry approval is requested to perform a tubing swap on NK -22A to restore gas lift to the tubing. History and current status: NK -22A has suffered from significant tubing corrosion that has required the deployment of two tubing patches (2006 & 2012) in order to maintain well integrity. A side effect of this patch usage is a limit on the depth that gas lift can be deployed in the tubing. Currently the deepest lifting station possible in NK -22A in the top GLM @ 4816' MD. Given the need for deep gas -lift to realize the full producing potential of the well there is benefit to shifting gas lift to a deeper station and improving drawdown. Proposed plan: All American Oilfield 111 pulling unit will pull tubing and re -run a new tubing and packer on or around July 1 st. 2019. The MASP is 2990 psi. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed tubing swap is attached for reference. Scope of Work. The primary objective of this RWO is to restore well integrity and return the well to operable status. Pre -Rig Prep Work: 1. S: Set plug in reducer nipple @ 9916' MD. Recover tubing patches @ 6771' MD and 8056' MD. SHP 2. V: PPPPOT-T/IC, function LDS, service tree valves 3. F: CMIT-TAA 3500 psi. MIT -OA 1200psi 4. E: Cut 4-1/2" tubing —9825' MD 5. F: Circ well to 8.6 ppg brine & Freeze Protect 6. S: Set hold open sleeve in SSSV. 7. V: Set BPV. Pre RWO Tree Work. Proposed RWO Procedure: L^/ 1. MIRU. Pull BPV. Circulate KWF. Set TWC. / Z y�cer+' /(fg J�i Gc � /i4o(! c 2. ND tree. NU and test ROPE. Test to 3500 psi and the annular to 3500 psi. Pull TWC. Perform RTTS packer run and pressure test tubing above leak. 3. Run new 4%' 13Cr completion with 7-5/8" x 4.5" packer. MIT -T & MIT -IA to 3500 DSL 4. Set TWC. ND BOPE. NU and test tree. RDMO. 3m r a �a� ✓ Post rig Work 1. Pull ball and rod 2. Set generic GLV 3. Pull plug in reducer nipple. Pull reducer nipple Ryan Ciolkosz RWO/CTD Engineer 564-5977 CC: Well File Joe Lastufka TREE= 4-1116" SM CJW VVEL.LFEAD = 1358' - 5M FMC ACTUATOR= BAKER OKB. ELEV = 60' REF ELBf = 53A1' BF. ELEV = -— 19' KOP= 1200' M9x Angle = 52- @ 9693 - Dalian MD= 12120' Datura TVD= 92D0'SS LE 1/2- BKR PATC7-L D = 2.45-—( 677T - 6794' t ili0li2) Minimum ID = 2.313"@ 9916' 4412" REDUCING X NIPPLE TBG, 12.61, PERFORATION SUMMARY REF LOG: SCMT ON 01/0&02 ANGLE AT TOP F EF F: 9' @ 12214' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-12' 6 12214-12224 O 11/19103 PORT 2-12' 6 12258-12268 C 02103/03 06(01/16 JNIJJMD UPDATE) 0KB/A008? RE= B -EV 2-12' 6 12328-12348 S 11/0910212101/02 4016 3-318" 6 12349- 12369 S 01/09/02 12101102 2-12' 6 12354-12389 C 1220102 3318' 6 12369-12389 S 01/08/0212/01/02 5288 D = 6.875" H 12720' =6.875' H 13516' NK -22A SAY NOTES: WELL REQUIRES A SSSV. '^CHROME CASING"' O 2091' 4-1/2' F£S CFL2 TRSSSV, D = 3.813' FLAPPER MLLED OUT (02122112) GAS LIFT MANDRELS J DATE RLa/ BY COMMENTS 10/31193 POOL 7 INITIAL COMPLETION 06/06112 TBD/JM1 GLV C/0 (06102112) ST MD TVD DEV TYPE VLV LATCH PORT LATE 07110/14 PJC LEGEN Y PE RFI FALLOUT VNFDOW 05/09112 GIFIJMD GLV C/O (05/04/12) 06(01/16 JNIJJMD UPDATE) 0KB/A008? RE= B -EV 4 4816 4016 48 KBMGM SO BK 20 10105/12 '3 6778 5288 50 KBMGM 'DMY BK 0 06/02112 2 8361 6284 51 KBMGM DW BK 0 06123/03 1 9803 7206 51 KBMGM DFM BK 0 06123/03 'STA I3 = HAS EXTENDED HCR & IS BEHIND PATCH 9871' —14-1/2'HES X NP, D=3.813' 8892' 7-S18' X 4-1/2' BKR S3 PUO; D = 3.874' 9918' 4-112- HM W. D=3.813' 9918' H4-12' RE JCM X NP. D = 2.313 (06123 9936' H4-12' HES XN FP, D = 3.725' 9936' H7-5/8'X5-1/2-8KRZXPPRL 9949' 4-112- VVLEG, D 3.958' RAUTT LOGGED 01109/02 9968' 5-12' X 4-12' XO, D = 3.958' 1 12044' 1 DATE REV BY 00Mo64TS DATE RLa/ BY COMMENTS 10/31193 POOL 7 INITIAL COMPLETION 06/06112 TBD/JM1 GLV C/0 (06102112) 12/29101 DACIKA14 SIDETRACK(W22A) 09/11/12 SET/JM) SET TBG PATCH (09/10/12) 06104/10 SEWIPJC SET XX PLUG (06/03110) 10/24/12 TI+VM GLV 00 (10/05/12) 02118111 M3IJLD ADDED SSSV SAFETY NOTE 11119/12 SJWJM1 PULL 2-718' XX PLUG (11115/12) 04126/12 SET/JM) MILE) FLAPPER (0222112) 07110/14 PJC LEGEN Y PE RFI FALLOUT VNFDOW 05/09112 GIFIJMD GLV C/O (05/04/12) 06(01/16 JNIJJMD UPDATE) 0KB/A008? RE= B -EV 1 1224V 1 D=3.918' H 1244W NIAKUK LINT WELL: W -22A PERMIT No: 2012280 AH No: 50-029-22402-01 SEC 36, T12K RISE, 1435' FSL & 694' FEL BP Btploration (Alaska) TREE= 4-1116" SM CNV MLLEAD= 13518'-5MFMC \CTl1ATOR= BAKER )KB BEV =_ --. ... 60' MF ELEV = 5141' —_-'_. TF. BEV = 19' COP=--_--_- _ 1200' Mx Angle = 5T(69693' Atli ND = 1212Q )alum TVD= _------9200'SS N K 2 2 A P R O P O S E D -SAFETY C RD AC SQL REQUIRES A SSSV. O 06/06112 TBIYJNU 2091' 4-12' TRSSSV, ID= 3.813' GAS LIFT MANDRELS 1212991 13ACIKAY SIDETRACK(NK-22A) 09/11/12 SETIJND SET TBG PATCH (09/10/12) ST MD TVD DEV TYPE VLV LATCN PORT DATE 02/18/11 IYB/JND ADDED SSSV SAFETY NOTE 5 K8MG-M DMY BK 0 07/10/14 PJC 4 KBMG-M DMY SK 0 3 KBMG-M DMY BK 0 R KBMG-M DMY BK 0 10-314- CSG, 45.i#, NT -805, D = 9.953' 5011' TBG, 12.6ri, L-80, .0152 bpf, D = 3.958' 9841' DATE REV BY CON ENTS 1013193 POOL 7 INITIAL COMPLETION 06/06112 TBIYJNU 1 1212991 13ACIKAY SIDETRACK(NK-22A) 09/11/12 SETIJND SET TBG PATCH (09/10/12) KBMG-M DMY BK 0 02/18/11 IYB/JND ADDED SSSV SAFETY NOTE 11/19/12 SIW/J 9766' 412' FES X NP, ID = 3.813' 9796' 7-518' X 4-12' FES TNT MR, D = 3.858' 9826' 4-12' FES X NP, D = 3.813' 9861' 7-5/8' X 4-12' UNKRE OV EFi.SHOT 9871' —14-1/2' FES X NP, D = 3.813' 9892' 7-5/8' X 4-112' BKR S-3 RKR D = 3.874' 9916' 4-1/2' FES X IMP. D = 3.813' 04/2612 SET/JW MILLED FLAPPER (02J22/12) 07/10/14 PJC LEGENY F$iF/MLLOUT WINDOW 05109/12 GJF/JMO GLV C/O(05104112) 0601/16 JNJJND UPDATED OMADDEDR FBEV 114-12' TBG, 12.611, L-80, .0152 bpf, D= 3.958' I 1 9936' —14-112- FES XN NP, D = 3.725' 9936' 7-818' X 5-12- BKR Z)CP R<R D = 4.940' ® 4-12' WWtEG, D 3.958' BkD TT LOGGED 01/09/02 9968' 872' X 4-12' XO. D = 3.958' PERFORATION SLPAWARY Fill LOG: SCMT ON 01/08/02 12044' ANGLE AT TOP F$7F: 9' @ 12214' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OprVSgz SHOT SOZ 2-12' 6 12214 - 12224 O 11/19103 2-12' 6 12258 - 12268 C 02/03103 2-12' 6 12328-12348 S 11/0910212/01/02 3-3/8' 6 12349 - 12369 S 01/09/02 12/01102 2-12' 6 12354 - 12389 C 1220102 3-3/8' 6 12369 - 12389 S 01/08/02 12/01/02 1 1 1 1 F1 =&875' H 12720' MM:=1Fi= DATE REV BY CONWENTS DATE REV BY CON ENTS 1013193 POOL 7 INITIAL COMPLETION 06/06112 TBIYJNU GLV d0 (06/02/12) 1212991 13ACIKAY SIDETRACK(NK-22A) 09/11/12 SETIJND SET TBG PATCH (09/10/12) 06/04/10 SEWPJC SET XX R-UG(0603/10) 1024/12 TMJrvU GLV CIO (10t05/12) 02/18/11 IYB/JND ADDED SSSV SAFETY NOTE 11/19/12 SIW/J PUL -L 2-718")0( R -UG (11115/12) 04/2612 SET/JW MILLED FLAPPER (02J22/12) 07/10/14 PJC LEGENY F$iF/MLLOUT WINDOW 05109/12 GJF/JMO GLV C/O(05104112) 0601/16 JNJJND UPDATED OMADDEDR FBEV 1 12248' 1 NAKIIK UNIT WELL W -22A PEF MT No: 2012280 AH No: 50-029-22402-01 SEC 36, T12K R15E. 1435' FSL 8 694' BP Exploration (Alaska) 2 3 4 ._ 4�_Z° o 0 0 0 A 3'-815/1g„ A SHENKAI SL 13-51M ANNULAR 5' 103/LETg SHENKAI SL 13-5M DOUBLE RAM B B 8._5„ 4��. 11�gn 1 -41/1gn r 3_25/° 5_1/x' C _93� G o. o C) O T-41/" o 5--31/2' CLOSING OPEN ING VOLUME (GAL MIN OPEN 30° ITEMS CLOSING VOL OPENNING VOL ANNULAR 23.59 17.41 D RAM 4.39 3.91 D HCR 1 0.40 0.40 NOTES INFOR TIONINTHS TNEC TENTS FTMSMANN6 TH aHERGVYE�cEs OF µS sEWCGF VRgIER TI'L^ BOP 13-5M BOP STACK ORANINGISFOR REFERENCE ONLY aEPRoo TNS A R A-000-15-002 ORATYV Mre ACNE TV 2S/FeW201B N.T.S. ANDS NJT FOii CONSTRLCTON. oaNMNGVai mlmEEAP�EY4 PEaW93�ON Q-'AEYTFld Nexvr+�a. o NnK flE.e TV N1F MIMrt/101E ENERGY 5@MCESCORPIS sTRcn.r PRaniaiTEo. R:Y oEscamnGN BY APPo GAiE AiFROVEO MJP �re011Metl201S wn A zr1EaT 1 OF1 O 1 2 3 4 1 DAT €. 5 -Nov 12 Stephanie Pacillo TRANS#: 6192 Data Delivery Services Technician . ; p7IVlakana K Bender Schlumherger Oilfield Services -I. -' Natural Resources Technician II WIRELINE SCANNED ' , Alaska Oil & Gas Conservation Commission 2525 Gambell St, Ste. 400 \t �' 333 Ave, Anchorage, AID 99503 ° : ;' 7 Suite 100 r nC)' =.G =.C;e AK ?97'20 :0 ice: 907) 273-1770 k�7 ; INEI ,;= SER,VtCE aH RESEI V GI"yL MECH. LO6 PESCRIPTION; DATE B/W COLOR CO `s NAME. ORDER if DIST : DIST , Dt fi 5 aI .: -: _. , _ .. .. - k. ° = PRIG ' .. PRMa _ :: _ Z -34 BTJO -00034 X USIT MSIP 8- Sep -12 1 1 CD H -02B C4W7 -00035 X PPROF 24- Aug -12 1 1 CD • G -29B C1 UB -00030 X LEAK DETECTION LOG 13- Sep -12 1 1 CD D -27A C2JC -00056 X LDL W/ WATERFLOW 5- Sep -12 1 1 CD L -100 C3NA -00041 X SFRT CH FORMATION RESIST') 15- Oct -12 1 1 CD 06 -03A C4W7 -00036 X CEMENT BOND LOG 15- Sep -12 1 1 CD ` MPL -08 C600 -00036 X MEMORY INJECTION PROFILE 10- Aug -12 1 1 CD 15-04B C600-00045 X MEMORY PPROF 7- Sep -12 1 1 CD F -06A C3NA -00038 X PPROF W DEFT & GHOST 16- Sep -12 1 1 CD C -20C BCRC -00212 X MEMORY PPROF 1- Oct -12 1 1 CD 14 -27 C3NA -00039 X LEAK DETECTION LOG 17- Sep -12 1 1 CD V -221 BBSK -00135 X IPROF W/ WFL 22- Aug -12 1 1 CD MPC-42 C600-00057 X MEMORY IPROF 9- Oct -12 1 1 CD MPC -28A C600-00056 X MEMORY IPROF 9- Oct -12 1 1 CD MPL -16A C5XI.00033 X MEMORY IPROF 13- Sep -12 1 1 CD C -18B C600 -00053 X MEMORY PPROF 3- Oct -12 1 1 CD NK -22A BYS4 -00052 X LEAK DETECTION LOG 4-Sep-12 1 1 CD MPG -01 C2JC -00054 X RST WATERFLOW LOG 31- Aug -12 1 1 CD 13-36 BYS4 -00053 X LEAK DETECTION LOG 12-Sep-12 1 1 CD I X X Pief-e--- ,*("folt-k— Please return a signed copy to: Please return a signed c y to: BP PDC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 N � 0 Ong. iihCEIVIED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMMON O C T 0 9 2012 • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Ej *-1 rr44d ll p k v Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WAD 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number:, Name: BP Exploration (Alaska), Inc Development Ei Exploratory ❑ 201 -228 -0 3. Address: P.O. Box 196612 Stratigraphk❑ Service ❑ '6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22402 -01 -00 7. Property Designation (Lease Number): ' ■ 8. Well Name and Number: ADL0034635 ` 34 10 1 j a - NIA NK -22A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): j 10. Field /Pool(s): _ To Be Submitted PRUDHOE BAY, NIAKUK OIL 11. Present Well Condition Summary: Total Depth measured 12444 feet Plugs measured 9916, 12248 feet true vertical 9574.18 feet Junk measured None feet Effective Depth measured 9916 feet Packer measured See Attachment feet true vertical 7277.79 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 36 - 116 36 - 116 1530 520 Surface 4976 10 -3/4" 45.5# NT -80S 35 - 5011 35 - 4145.42 5210 2480 Intermediate None None None None None None Production 9996 7 -5/8" 29.7# NT -95HS 34 - 10030 34 - 7349.67 8180 5120 Liner 2504 4 -1/2" 12.6# L -80 9936 -12440 7290.4 - 9570.22 8430 7500 Perforation depth Measured depth 12214 - 12224 feet 12258 - 12268 feet 12328 - 12330 feet 12330 - 12338 feet 12338 - 12348 feet 12349 - 12354 feet 12354 - 12369 feet 12369 - 12389 feet True Vertical depth 9346.57 - 9356.46 feet 9390.09 - 9399.98 feet 9459.35 - 9461.33 feet 9461.33 - 9469.25 feet 9469.25 - 9479.14 feet 9480.13 - 9485.08 feet 9485.08 - 9499.93 feet 9499.93 - 9519.73 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 33 - 9949 33 - 7298.6 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 10 2013. 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: SI SI SI SI Subsequent to operation: SI SI SI SI 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratorl❑ Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ Wf3SPtJ 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 Email Nita.Summe BP.c Printed Name Nita mmerhay , Titl Petrotechnical Data Technician ���� 47 Phone 564 -4035 Date 10/8/2012 RBDMS OCT 1 0 2012 4601 r Form 10-404 Revised 10/2012 /l 1 ( - Submit Original Only Daily Report of Well Operations ADL0034635 I .:. 1 DATE,, : .... ,, :, } w SUMMARY n ��...�. ■. ■ INITIAL T /IA/OA= 1100 /1000/0 SWAB,SSV= CLOSED RIH WITH HEAD /CCL /BAKER 45 "Flo- guard" STRADDLE PACKER, TOP TO BOTTOM ELEMENT 17', OVERALL LENGTH =31', OVERALL WEIGHT =380# CCL TO TOP ELEMENT =8.1', CCL TO BOTTOM ELEMENT = 25.6', CCL STOP DEPTH = 6764.9', TOP ELEMENT OF PATCH SETTING DEPTH =6673' PATCH TE SET AT 6773' SWAB SSV= CLOSED, • FINAL T /IA/OA= 1100 /1000/0 LEAVE LOCATION,DSO NOTIFIED OF DEPARTURE 9/10/2012 ***JOB COMPLETE, WELL SI ON DEPARTURE*** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL • Perforation Attachment ADL0034635 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base NK -22A 6/6/2010 BPS 12214 12224 9346.57 9356.46 NK -22A 6/6/2010 BPS 12258 12268 9390.09 9399.98 NK -22A 6/6/2010 BPS 12328 12330 9459.35 9461.33 NK -22A 6/6/2010 BPS 12330 12338 9461.33 9469.25 NK -22A 6/6/2010 BPS 12338 12348 9469.25 9479.14 NK -22A 6/6/2010 BPS 12349 12354 9480.13 9485.08 NK -22A 6/6/2010 BPS 12354 12369 9485.08 9499.93 • NK -22A 6/6/2010 BPS 12369 12389 9499.93 9519.73 BPS BRIDGE PLUG SET OH OPEN 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 • • • Packers and SSV's Attachment ADL0034635 SW Name Type MD TVD Depscription NK -22A PACKER 9892 7209.24 4 -1/2" Baker S -3 Perm Packer NK -22A PACKER 9936 7236.99 5 -1/2" BAKER ZXP PACKER I TRH= 41/16" SMCNV '- SA NOTES: WELL REQUIRES A SSSV. TO R = BAKER ='3 - 5M F ACTUATOR R N K 22A _m.._.._._. "'CHROME CASING*" KB. ELEV = 30.49' ELEV 19' 1 2091' 4 2 1/2" HES CP-2 TRSSSV, I)= 3.813" KOP __ 1200' 1 FLAPPER M.L® OUT (02/22/12) Max Angle = 52° @ 9693' Datum MD = _.. _ 12120' GAS LFT MANDRELS DatumTVD = 9200' SS 1ST M3 IV D DEV TY FE VLV LATCH PORT DATE L 4 4816 4016 48 KBMGM DMY BK 0 05/04/12 3 6778 5288 50 KBMG -M 'DMY BK 0 06/02/12 10 3/4^ CSG, 45.5#, NT -80S, D = 9.953" H b011' ' • 2 8361 6284 51 KBMGM DMY BK 0 06/23/03 1 9803 7206 51 KBMGM DMY BK 0 06/23/03 'STA #3 = DMY VALVE HAS EXTENDED PACKING =' = 8056'-8146' ELM 4 -1/2" BKR TBG PATCH I (08/22/06), D = 2.37" 9871' H4 -1/2" HES X LANDING NP, D = 3.813" I 7 \--1 9892' I- 17 -5/8" X 4-1/2" BKR S-3 PKR D = 3.874' I Minimum ID = 2.313" a@ 9916' 8 iv —I 9916' H -1/2"FESX NP, D= 3.813" 4 -1/2" REDUCINGX NIPPLE \ 9916' I--I4-1 REDUCING X MP, D= 2.313(06/23/06) I 9916' H2 -7/8" XX PLUG (06/06/10) r -- I 9936' 1 - I4 -1/2' FES XN NIP, D = 3.725" I ►li C I 9936' 1 17 -5/8" X 5-1/2" BKR ZXP PKR, D = 4.940" I 14-1/2" TBG, 12.6#, L -80, .0152 bpf, D= 3.958" . -1 9949' I ` I 9949' H4-1/2" WLEG, D 3.958" TT LOGGED 01 /09/02 MD I TOP OF WFPSTOCK —{ 10030' ( 9954' (� EL I 9968' H 5 -1/2" X 4-1/2" X0, D = 3.958" 1 PERFORATION SUMMARY ii tel: REF LOG: SCMT ON 01 /08/02 ` ' 12044` —I MARKER JOINT ANGLE AT TOP PERF: 9° @ 12214' Note: Refer to Production DB for historical perf data ` SIZE SFF INTERVAL Opn/Sqz DATE 2 -112" 12214- 17224 0 11/19/03 I 12248' IH BKR CEP (11 /18/03) I 2 -1/2" 6 12258 - 12268 C 02/03/03 id, 2 -1/2" 6 12328 - 12348 S 12/03/02 \/6 3-3/8" 6 12349 - 12369 S 12/03/02 \ 2 -1/2" 6 12354 - 12389 C 12/21/02 • 3-3/8" 6 12369 - 12389 S 12/03/02 I FWD 12404' 11111 X 17 -5/8" CSG, 29.7 #, NT-95-HS, D = 6.875" —I 12720' 1 11111 ��\ 1 �Al``l` . 17516"x4vrPKR 0= 3.941" 1 12975' �111111111j�Z 1 • ff 1 1 1 1 1 1 1 1 1 1 1 1 1 • 1 / •••••••••••••••• 1 • 1 • 1111111111 011111111111111111111 41/2" LNR,12.6#, L -80, .0152 bpf, ID = 3.918" I 12440' • •••••••••• •••••••••• •••••••••• 1 1 •1 •1 1 1 1 1 1 1 1 1 1 1 1 1 17 - 5/8" CSG, 29.7 #, NT13 - CR 80, 83= 6.875' H 13516' 1 1 ••• • • • •1 • •1 • •1. •1 • 1. •1 ∎ • 1, DATE REV BY COMMENTS DATE REV BY COMMENTS MAKUK UNIT 10/31/93 ORIG COMPLETION, (POOL 7) 02/22/12 TTW! RIG FISH BROKEN FLAPPER WELL: NK22A 12/31/01 DAC/KAK RIG SIDETRACK (PE -22A) 04/26/12 SET /JMD &VIED FLAPPER (02/22/12) PERMIT No: " _06/04/10 SEW/PJC SET XX RUG (06/03/10) 05/09/12 G1F /JMD GLV C/O (05/04/12) AR No: 50- 029 - 22402 -01 10/26/10 RCT /PJC FISH/ FLAPPB2 (10/10/10) 06/06/12 TBO/JMD GLV C/O (06/02/12) SEC 36, T12N, R15E, 1435' NSL & 694' WEL 02/18/11 MEMO ADDED SSSV SAFETY NOTE 08/15/12 BS/JMD FISH PULLED (05/02- 03/12) 05/02/11 SWJ PJC FISH (04/28/11) BP Exploration (Alaska) • 0!:) BP Exploration (Alaska) Inc. . Y,,r Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 July 6, 2011 >,;,, ,ii I V't Mr. Tom Maunder 1,' a -� Alaska Oil and Gas Conservation Commission �� 333 West 7 Avenue ' t� Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk 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, Mehreen Vazir, at 659 -5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Niakuk Date: 05/15/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1780280 500292015801 P&A 3/9/91 NA NA NA NA NA NK -02A 1760790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 PM 4/14/80 NA NA NA NA NA NK-04 1842000 500292121700 PM 4/14/96 NA NA NA NA NA NK-05 1850270 500292129000 PM 4/15/98 NA NA NA NA NA NK-06 1852760 800292148800 PM 4/15/98 NA NA NA NA NA NK -07A 2010830 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 600292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 500292242500 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 500292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030550 600292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1981340 500292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2060310 500292286801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -16 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1981850 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/8/2011 NK -19A 2010700 500292250701 1.8 NA 1.8 NA 15.3 5/8/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940860 500292248700 2 NA 2 NA 22.1 5/15/2011 NK -22A 2012280 500292240201 1.5 NA 1.5 NA 11.9 5/11/2011 ° NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970880 500292278000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -26 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1960930 500292287800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1981900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 5/8/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.6 5/9/2011 NK-43 2010010 500292299800 1 NA 1 NA 5.1 5/9/2011 NK-61A 2080350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK-82A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-65A 2050830 500292288901 1 NA 1 NA 8.5 5/8/2011 11 /05/07 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall _Inh it ~,±f~-~~~, f~1~v ~ ~ ~~Q7 Inn I]pscrintinn ^att± NO. 4360 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Niakuk, Milne Pt., Pt. Mac, Prince C 6L Cnlnr CD S-400A 11855508 USIT (REVISED) C 09/18/07 1 C-30 11695080 LDL a 10/16/07 Z-22B 11594525 SBHP SURVEY 10/06/07 1 14-31 11890316 LDL 10118/07 1 NK-22A 11855822 DRIFT TDILDL (- 10/25/07 1 MPG-07 N/A CORRELATION/DDL C. 09/08/07 1 MPG-07 11628799 MEM INJ PROFILE C - 10/20/07 1 MPF-10 11767140 MEM INJ PROFILE U= - 09/15/07 1 MPS-05 11745237 MEM PPROF SUPPLEMENT LOG - _ 3'~. 10/09/07 1 P2-19A 11649963 MCNL '~} ~ ~~ - 04/22/07 1 1 OWDW-SW 11221548 RST ~ 03/05/06 1 1 W-17A 11588701 MCNL _ 1 'tt 12/26/06 1 1 14-30A 11485775 MCNL --6 (p0 11/22/06 1 1 L-51 40013624 OH MWD/LWD EDIT 06/26/06 2 1 PLtASt AGKNUWLEUGt KtGtIF' 1 t3Y SIGNING ANU Kt I UKNING UNt I:UYY tAGr1 1 U: BP Exploration (Alaska) Inc. - -~ ~~ ~` ~ r1 ~~jl Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchors e, Alaska 99508 g I~.~~ %g ', 2(10! Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: • • ~Y . RECEIVED STATE OF ALASKA. ( , ALASKA OIL AND GAS CONSERVATION COMMISSION (JLT 0 4 2006 REPORT OF SUNDRY WELL OPERA TIØN8il & Gas Cons. Commission A 1. Operations Performed: v Abandon 0 Repair WellŒJ PluQ PerforationsD Stimulate 0 OtherD Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒI ExploratoryD 201·2280 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-22402-01-00 7. KB Elevation (ft): 9. Well Name and Number: 53.00 NK-22A 8. Property Designation: 10. Field/Pool(s): ADL-0034635 Prudhoe Bay Field 1 Niakuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12444 feet true vertical 9574.0 feet Plugs (measured) Baker CIBP @ 12248 (11/18/2003) Effective Depth measured 12398 feet Junk (measured) true vertical 9529.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 36 - 116 42.0 - 122.0 1490 470 SURFACE 4976 10-314" 45.5# NT·80S 35 · 5011 41.0 - 4145.0 5210 2480 PRODUCTION 9998 7·518" 29.7# NT-13CR-80 32 · 10030 40.0 - 7350.0 6890 4790 LINER 2504 4·112" 12.6# L-80 9936 · 12440 7290.0 - 9570.0 8430 7500 Perforation depth: <'f~ it~~N~;';J ù ..~ ¡: '·';)\v·,r\~ '-:, ..'; .~t.~.~;, ;;. ,., Measured depth: 12214-12224,12258-12268,12354-12389 True vertical depth: 9347-9356,9390-9400,9485-9520 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-BO @ 37 - 9949 .' Packers & SSSV (type & measured depth): 4-112" BKR KB Patch @ 8056 - 8146 7·5/8" Baker SABL-3 Packer @ 9892 7 ·5/S" Baker ZXP Liner PKR @ 9936 4-1/2" HES CP·2 TRSSSV @ 2091 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft OCì () 4: 2DD6 Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaae Production or Injection Data Oìl-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: SI 0 0 --- 505 Subsequent to operation: 1210 1422 5,036 --- S07 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡Sundry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr NIA Printed Name DeWayne R. Schnorr . Title Petroleum Engineer Signature A.~-. .,~Æ.Jl ----"" Phone 564-5174 Date 1 0/2/06 u I Form 10-404 Revised 4/2004 X¡ AL ¡ uR\G\N . . NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/25/2006 TestElement --- BOPD: 452 BWPD: 5,194 MCFPD: 4,357 AL Rate: 3,653 08/25/2006 TIO = 550/2250/300. Temp = 140 deg. WHPs (post TIFL). Well is on line. 08/24/2006 TIIIO = 520/2180/210. Temp = 140*. ALP = 2300. TIFL ***PASSED*** (post-patch). InitiallA FL @ 6778' (STA#3 SIO GLV). S/I well upon arrival. SII AL at casing valve and in skid. Bled ALP to 520 psi. TBGP stacked to 1460 psi. Continued to stack TBG wllAP to 1690 psi in 10 min. Bled lAP to 540 psi in 1 hr 25 min. During monitor WHPs and IA FL unchanged. Operator informed to return well to production. Final WHPs 1670/540/100. 08/22/2006 (set slickstick/patch w/efjre) SET SLlCKSTICK(27' OAL , 4.5 G FN) IN LOWER PACKER ASSEMBLY @ 8116'SLM . SET SLlCKSTICK (38' OAL, ) WI E-FIRE, @ 8091 SLM. AS PER WELL PROGRAM.RDMO. **** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER.**** 08/21/2006 **"'VVELL SII ON ARRIVAL*** (slickstick/patch w/efire) RIG UP SLlCKLlNE EQUIPMENT W/40' EXTRA RISER AND THIRD PARTY CRANE. UNLOAD AND SECURE SLICK STICKS. 08/17/2006 SET LOWER THIRD OF 4-1/2" BAKER STRADDLE PATCH FROM 8151'-8115' (LOWER KB PACKER MID ELEMENT AT 8146'). TOP OF PATCH SECTION AT 8115' HAS 4" GS PROFILE DEPLOYMENT SLEEVE READY TO ACCEPT SNAP LATCH FROM SLICK STICK. NOTE: WITH PERMISSION FROM TOWN ENGINEER, THE SETTING DEPTH FOR THIS LOWER PATCH SECTION WAS MOVED 6' DEEPER THAN PROCEDURE TO AVOID SETTING UPPER KB PACKER (TO BE RUN IN FUTURE) IN THE COLLAR AT 8150'. ***JOB COMPLETE*** 08/12/2006 RIG UP AND ATTEMPT TO SET BAKER PATCH. JOB CANCELLED DUE TO WINDS GUSTING ABOVE 28 MPH. LUBRICATOR SWINGING, DECIDED UNSAFE TO CONTINUE. RIG DOWN. ** JOB NOT COMPLETE** 06/24/2006 T/I/O=990/1050/40. Temp=SI. TBG & IA FL (CMIT). TBG FL near surface. IA FL @ 72'. 06/22/2006 T/I/O= 1050/110010 Assist Slickline wI Brush-N-Flush- Pumped 100 bbls diesel @ 190* down tubing. 06/22/2006 (patch tbg/liner) PULLED 4.5" PXN PLUG BODY @ 9914' SLM...BRUSH/FLUSH TBG WI 41/2" BLB & 3.70 G-RING WHILE LRS PUMPED 100 BBLS DIESEL, SET 4.5" PX PLUG BODY & PRONG @ 9894' SLM...CMIT TxlA TO 3000#...PASSED...PULLED PX PLUG BODY & PRONG. SET 2.313 X NIPPLE REDUCER (37" OAL) IN X-NIP @ 9894' SLM, CK SET INDICATED GOOD SET. *** NOTIFY DSO, WELL LEFT SI *** 06/21/2006 *** WELL S/I ON ARRIVAL *** (patch tbg/liner) PULLED PRONG FROM PXN PLUG BODY @ 9909' SLM. RIH TO PULL PLUG BODY. *** JOB IN PROGRESS *** 06/10/2006 T/I/O=540/88010 Temp=S/f T & IA FLs (eval failed CMIT). TBG FL near surface. fA FL @ surface. TBGP decreased 160 psi and the lAP decreased 20 psi since CMIT on 06/07. Page 1 . . NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/07/2006 T/I/O= 550/490/0 Temp = 51 CMIT Tx IA FAILED to 3000 psi (Patch tubing) Loaded tbg w/ 125 bbls of crude, RD from tbg--RU to lA, Loaded & pressured up IA to 3000 psi w/107.8 bbls of crude. TP increased w/IA to 2900 psi. CMIT Failed on 3 attempts. Bled 19 bbls of crude. RDMO Final WHP's 700/900/0 06/04/2006 T/I/O=500/500/20 Temp=5/1. WHP's & IA FL (for FB CMIT). TP climbed 20psi overnight, lAP and OAP unchanged. IA FL fell from 6235' (6-3-06) to 6400' (168 bbls). FLUIDS PUMPED BBLS 2.5 PT Surface Equipment 100 Diesel 235 Crude 337.5 TOTAL Page 2 TREE = 4-1/16" 5M CWV . SAFETY NOTES: ***CHROME WELLHEAD = 13-5/8" - 5M FMC N K-22A CASING*** A CTUA TOR = BAKER KB. ELEV = 30.49' BF, ELEV = 19' KOP= 1200' 2091' 1"i4-1/2" HES CP-2 TRSSSV, ID = 3,813" I Max Angle = 52 @ 9693' . Datum MD = 12120' Datum TVD = 9200' SS GAS LIFT MANDRELS ~ ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 4 4816 4016 48 KBMG-M DOME BK 16 12/13/02 J ~ 3 6778 5288 50 KBMG-M SO BK 22 01/16/06 I 10-3/4" CSG, 45,5#, NT-80S, 10 = 9.953" I 5011' I 2 8360 6284 51 KBMG-M DMY BK 0 06/23/03 1 9802 7206 51 KBMG-M DMY BK 0 06123/03 Minimum ID = 2.313" @ 9916' ~ ~ "- M 8056'-8146' ELM 4-1/2" BKR TBG PATCH (08/22/06),10 = 2.37" 4-1/2" REDUCING X NIPPLE . 9871' 1-14-1/2" HESX LANDING NIP, ID= 3.813" I 8: ~ I 9892' 1'17-5/8" x 4-1/2" PKR, ID = 3,874" I ~ .. . 9916' !-i4-1/2" HES x LANDING NIP, ID = 3,813" I ;; ! -- 1-1 9916' 1-14-1/2" REDUCING X NIP, ID = 2.313 (06/23/06) I . I - H 9936' 1-14-1/2" HES XN NIP, ID = 3.725" I 14-1/2" TBG, 12,6#, L-80, 0.152 bpf, ID = 3,958" ~ ~ H 9936' 1-17-5/8" x 5-112" BKRZXP PKR, ID = 4,940" I I 9949' 9949' H4-1/2" WLEG, 103.958" I I - N 9954' H ELMD TT LOGGED 01/09/02 I I TOP OF WHIPSTOCK H 10030' , I 9968' H5-1/2" x 4-1/2" XO, ID = 3,958" I ÆRFORA TION SUMMARY H MARKER JOINT I REF LOG: SCMT ON 01/08/02 12044' ANGLE AT TOP PERF: 9 @ 12214' Note: Refer to Production DB for historical perf data 12248'H BKR CIBP (11/18/03) I SIZE SPF INTERVAL Opn/Sqz DATE I 2-1/2" 12214 - 12224 0 11/19/03 2-1/2" 6 12258 - 12268 C 02/03/03 ~ NIv 2-1/2" 6 12328 - 12348 S 12/03/02 3-3/8" 6 12349 - 12369 S 12/03/02 2-1/2" 6 12354 - 12389 C 12/21/02 3-3/8" 6 12369 - 12389 S 12/03/02 I PBTD I 12404' I I 7-5/8" CSG, 29.7#, NT-95-HS, 10 = 6.875" I 12720' " ~ ~ ~ I 7-5/8" X 4-1/2" PKR, 10 = 3,941" I 12975' "(l-'" IY' I ~ ", ~ 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.918" I 12440' I 17-5/8" CSG, 29,7#, NT-13-CR-80, ID = 6,875" I 13516' DATE REV BY COMMENTS DATE REV BY COMMENTS NIAKUK UNIT 10131193 ORlG COMPLETION, (POOL 7) 08/18/06 OFR/TLH BTM PKR FOR PA TCH SET WELL: NK-22A 12/31101 DAC/KA~ RIG SIDETRACK (NK-22A) 08/22/06 GJF/TLH TBG PATCH SET ÆRMIT No: "2012280 01/21/06 RCc/PAG GLV C/O (01/16/06) 08/28/06 ITLH PERF CORRECTION (OÆN) API No: 50-029-22402-01 06/23/06 BSEJPJC PULL PXN PLUGI SET RED NIP 09/08/06 CS/PJC TVO/ MD DA TUM CORRECTION SEC 36, T12N, R15E, 1435' NSL & 694' WEL 06/25/06 PJC 4-1/2" TBG CORRECTION 08/17/06 JLJ/TLH NIPPLE DESCR CORRECTION BP Exploration (Alaska) R~ ~ ~:... \I L- U AUG 0 S 2006 08/01/06 Schlumkerger ~ Oil & Gas Cons, Co~ NO. 3883 Anchorage Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,n;;..". "_ ""'1 r'",\9' c/(J CI c:Ju 1" (" ~.. i.lii: 2GÜ() 'SCÞ"NNEJ} ;'\ J \.:~ '0 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII J b# L D D BL CI CD e 0 09 eScrlptlon ate o or NK-43 11211388 PROD /ur:.r 04/02/06 1 NIVlZA 10568415 PROD P,,~. 1__ n/ur:.r I 02/26/03 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17 -21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 sBHP 12102/05 1 X-15A 11212877 UslT 07/18/06 1 J-01 B 11511430 US IT 07/24/06 1 15-12A 11221595 US IT 07/25/06 1 Z-14B 11217268 UslT 07/29/06 1 5-400 10987564 CH EDIT PDC-GR OF UslT 01/26/06 1 D-03A 11217269 UslT 07/31/06 1 05-28A 11217267 UslT 07/28/06 1 . . Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc t7<~/-' 2Z.?' 01/31/05 Schlumberger NO. 3320 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED jUN 1 ~t 2005 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay , tJ0. Ç:; Color Well Job# Log Description Date Blueline Prints CD ~ ~(j -C"z-01 10662999 RST -SIGMA 02/25/04 1 1 )3-{24 DS 15-28A 10715362 MCNL 11/22/03 1 1 1- 21..'i NK-22A 10568415 RST -SIGMA/BORAX 02/26/03 1 1 'Í- )/1 E-35A 10715373 MCNL 12/27/03 1 1 J-l2:'!J 'DS 03-22 10687697 RST-SIGMA 07/24/04 1 1 ~. Ût~C-17A 10687693 USIT 07/05/04 1 -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: c2/3'þ5 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950..3-2,.83-á . /1 ATTN: Beth "'\ 1/ ¡J ! ReceiVCì/o' l ¡~ ffL~~ f STATE OF ALASKA l ALASKA ùlL AND GAS CONSERVATION co~,....SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator SuspendD Repair WellO Pull Tubing 0 Operation Shutdown D Plug Perforations ]] Perforate New Pool D 4. Current Well Class: Perforate ŒJ WaiverD Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 201-2280 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 53.41 8. Property Designation: ADL-0034635 11. Present Well Condition Summary: Development ]] Stratigraphic D 9. Well Name and Number: NK-22A 10. Field/Pool(s): Niakuk Field / Niakuk Oil Pool Exploratory 0 ServiceO 6. API Number 50-029-22402-01-00 Total Depth measured 12444 feet Plugs (measured) Junk (measured) 12248 true vertical 9574.2 feet Effective Depth measured 12248 feet true vertical 9380.2 feet None Casing Conductor Liner Production Surface Length 80 2504 9998 4969 Size 20" 94# H-40 4-1/2" 12.6# L-80 7-5/8" 29.7# NT-95HS 10-3/4" 45.5# NT-80LHE MD TVD Burst Collapse 36 116 36.0 - 116.0 1530 520 9936 - 12440 7290.4 - 9570.2 8430 7500 32 - 10030 32.0 - 7349.7 8180 5120 35 - 5004 35.0 - 4140.8 5210 2480 Perforation deDth: Measured depth: 12214 -12224 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 30 F{ECEfVEJJ FEB 2 4 2004 : :~ska Oil & Gas Cons. ComHlIssion 9949 True vertical depth: 9346.57 - 9356.46 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 5-112" Baker ZXP Hydro Set Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure 1079 0 4448 1500 943 1936 1.47 0 1500 1650 ReDresentative Dailv Averaae Production or Iniection Data 14. Attachments: 15. Well Class after proposed work: Exploratory D Development ŒI ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil ]] GasO WAG D GINJO WINJD WDSPLO Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron 73 Title Production Technical Assistant Signature C. 8CA\~NE[) MAR 1 ~ iDD4 Phone 564-4657 Date 2/18/04 -( Form 10-404 Revised 12/2003 0 RIG I N ÄIIDts BFt. FEB 2i''"lßD~ ( ( NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/18/03 RU SLlCKLlNE WI EXTRA RISER & PT. ***CONT ON 11-19-03 W SR*** 11/18/03 SET CIBP @ 12248' 11/19/03 12214'-12224' PERFORATED USING 2.5" HSD GUN LOADED WITH POWERJET PJ2506 CHARGES, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. TIE-IN TO SCHLUMBERGER SCMT LOG DATED 8-JANUARY-2002., CIBP TAGGED @ 12247'. FLUIDS PUMPED BBLS :TOTAL No Fluids Pumped 0 Page 1 1RŒ= 4-1/16" 5M em WELLt-EA D = 13-518" - 5M FMC AC1UATOR= SA KER KB. ELBI ::: 30.49' BF. ELBI = 19' KOP= 1200' Wax Angle::: 52 @ 9693' D3tum ~ ::: 11711' D3tum lV D = 8800' SS 10-314" CSG, 45.5#, NT-80S, 10 = 9.953" 5011' Minimu m ID = 3.725" @ 9936' 4-1/2" HES XN NIPPLE NO-GO 1 TOP OF WHIPSTOCK 1--1 10030' I PERFORATION SUfvYv1ARY REF LOG: SCMf ON 01/08/02 ANGLEATTOPÆRF: 9@ 12214' f\bte: Reter to Produetion DB tor historieal Jert data SIZE SPF INTER\! AL . OpnlSqz DATE 2-112" 12214 - 12224 S 11/19/03 2-112" 6 12258 - 12268 0 02/03103 2-112" 6 12328 - 12348 S 12/03/02 3-318" 6 12349 - 12369 S 12/03/02 2-112" 6 12354 - 12389 0 12/21/02 3-318" 6 12369 - 12389 S 12/03102 7-5/8" CSG, 29.7#, NT-95-HS, ID = 6.875" 7-5/8" X 4-1/2" PKR,ID = 3.941" 17-5/8" CSG, 29.7#, NT-13-CR-80, 10 = 6.875" I 13516' NK-22A - ST MD TVO 4 4816 4018 3 6778 5290 2 8361 6287 1 9803 7209 9936' 9949' 9954' 9968' ( I SAFETY NOTES: CHROME CASING. 4-1/2" I-ES CP-2 TRSSSV, 10= 3.813" GAS LIFT M6.NDRB..S DBI 1YPE VLV LATCH 48 KBMG-M DOME BK 50 KBMG-M SO BK 51 KBMG-M DMY BK 51 KBMG-M OMY BK FORT DATE 16 12/13/02 22 06/23/03 0 06/23/03 0 06/23/03 7-5/8" X 4-1/2" PKR, ID = 3.874" 1 4-1/2" res X LA NDlNG NP, 10 = 3.813" I 4-1/2" I-ES XN NIP NO-GO W/ RI-C, ID = 3.725" 7-5/8" X 5-1/2" BKR ZXP A<R, ID = 4.940" 4-1/2" WLEG, 103.958" -1 B..MOTTLOGGED01109/02 I 1-1 5-1/2" X 4-1/2" XO, 10 = 3.958" I MARKER JOINT BAKER CBP MP ELBv1ENT, 11/18103 4-112" LNR, 12.6#, L-80, .0152 bpt, D = 3.918" DATE REV BY COMrvENTS DATE REV BY CO MrvENTS 10/31/93 ORlG COM PLETION, (POOL 7) 12/21/02 PWEltlh SOZ CHNL & REPERF 12/31/01 DAC/KA~ RIG SIDETRACK (NK-22A) 02/03/03 KSBltlh AOPERFS 01/09/02 TMNIKK IPERFS 06/24/03 JMrrLH GL V C/O 11/09/02 CAOIKK A [PERFS 11/19/03 M6./CO/lF ÆRF, CBP 11/28/02 JGlDfvVTP PBTD CO RRECTON 12/13/02 M-J/KA K GLV C/O N \A. K LK l1'J IT WELL: NK-22A ÆRMT f\b: 2012280 API f\b: 50-029-22402-01 SEC36, T12N, R15E, 1435' NSL& 694'WB.. BP Exploration (Alaska) Cf ~t1 À.~ t~ DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2012280 /'" Operator BP EXPLORATION (ALASKA) INC s~ ;{tö~~~ API No. 50-029-22402-01-00 MD Well Name/No. PRUDHOE BAY UN NIA NK-22A 12444 '---' 9574 - Completion Date 1/9/2002 Completion Status _.-- ------ ------ --~---------- --- --------------. ----- ------ ----.---- -------'-- ..--.--------- ---- TVD 1-01L Current Status 1-01L UIC N ----.-------- ----------.--- - ------ -------- -- -- - .-------- ..~------------------------------- ~-- ----------~----- ---- ------------------ ----- ---- ---- --------------- ----- ------------ REQUIRED INFORMATION -- --------- Mud Log No Samples No ----- ------------------------~---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Frmt C C Log ~. C ~. D Well Cores/Samples Information: ------- Electr Dataset Number -m623 '-11Õ 9 2 Log Log Run Scale Media No 1 1 Name <3aml'11ï:!R~y ..." '*øsðrVoir:SâtÚfáflo'rr .. ".. ..' . . . ... - . . . . ProdÜe:tiQri, .. '-41559Så~NÓt~$ Blu 1 1 1 5 .'.."'..'.".' '. .... ... '.'. ~1$v~dfic~tiqr1.... ..~~.~.~..~R,.r.....~.~t~r~~iÞh'..... ~ 1154Þ¡$Védf¡¿~t¡Þñ'. Blu 1 1 5 Name Interval Start Stop Sent ADDITIONAL INFORMATION Well Cored? Y t;;) Chips Received? - Y / N Analysis Received? Daily History Received? Formation Tops )7/ N ~::~ent~-:-=-([j ù i=-'-~ ___~_)ð _M ( ~~---------------------------- ~.s:1 ~ LAIP4 1(; ~ ,~ IMuu-I;t1?"!' ~ ,--' ~; - ---~LI".' l~ "1 -.--'Q Directional Survey No ------ -~-----------,_._-----,,-'-'--'- (data taken from Logs Portion of Master Well Data Maint) \ Interval OH / Start Stop CH Received 9600 12337 Case 3/5/2002 12000 12379 Case 8/16/2002 12000 12396 Case 4/15/2003 9669 12444 Case 2/11/2003 Comments --------_.------ Digital Well Logging Data 9673 12000 9673 12403 Open 1 0/9/2002 12379 Case 8/16/2002 12403 Open 10/9/2002 Received Sample Set Number Comments { ~N (?yN -.- _..._-,------~----- ---,--------- ----, ..-- .-.".,. ""-- ------'--'------ ~::;-I~::::.;~:;::d ~-;~--~=~~--- ~_._---:-~_.~ -~--- - -==- ~-~~ -=-~=-~==:--~~=--===---============~:~~~~-~:=-Date~-=___-~]~~~-~~~~-~~_:=-~==::=:=:~:_- SfuL'c. ýlV'~.H/f'~ C¡J~À~~ I~ ,t)...0[ -IÀ~~ ~ SH",-l~ ~ ~ K J~À~~ 1- ) ^ 11 ~ -.A 1 ~ l.{Q~ c..uJ ¿ Schlumbel'ger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well A-07 J 7_~-O4 NK-22A ~1" /~;:J'::;) 'l' PWDW2-1 T -¡ w- 0 ø ~ PWDW2-1 ~ R-06A 1l.fX' - J.:::J-¡ Job# Log Description Date PRODUCTION PROFILE PROD PROFILE/DEFT LDL TEMPERATURE LOG LOL 02/04/03 02/26/03 03/01/03 02115/03 02/28/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: t., ~7" ,f"'~ E" '~'~/" Î"'" .-'to. \f~::"-"";I. ,~~,,¡, ."::>"-'"".'J '~ ~. "\ :,=-,.. ~~,~ :_""",:. <!, ,~- ~ ~r"D ",1 ..~"""".'" ! ,:\ , I LIJ~,iv ,;:.\1':1:1:1;""" ,"\~\ i' """ (~,,~ '< " "'~""".,if,\.\ )~¡ì.l Cí ~.;;:dS \....{'! if,~ [:"'î",'"t"..m!!1~n ',."". ."'--li. ¡"N/V Anch{}~t1e ' .., Blueline NO. 2728 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott,Milne Pt. Color Prints CD 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received 4¿1. ~J 04/02/03 ( ( ~ ' (,I' I' (' t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 3845' FNL, 694'FEL, Sec. 36, T12N, R15E, UM At top of productive interval 854'FNL,466~FEL,Sec.32,T12N, R16E, UM At effective depth 852' FNL, 4653' FEL, Sec. 32, T12N, R16E, UM At total depth 852'FNL,4646'FEL,Sec.32,T12N, R16E,UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Intermediate Liner Size 20" Length 80' 3969' 9991' 2504' 10-3/4" 7-5/8" 4-1/2" Stimulate - Alter casing - 5. Type of Well: Development _X Exploratory- Stratigraphic- Serviee- (asp's 721865, 5979979) (asp's 727949, 5983154) (asp's 727960, 5983156) (asp's 727966, 5983157) Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 53 feet 7. Unit or Property name Naikuk Unit 8. Well number NK-22A 9. Permit number / approval number 201-228 10. API number 50-029-22402-01 11. Field / Pool Niakuk Oil Pool 12444 feet 9574 feet Plugs (measured) Tagged TO @ 12398' (02/03/2003) 12398 feet 9529 feet Junk (measured) Measured Depth 122' 5011' 1 0030' 9936' - 12440' True Vertical Depth 122' 4145' 7350' 7290' - 9570' Cemented 280 CF AS (Approx) 3267 cf 'E', 435 cf 'G' 720 cf Class 'G' 303 cf Class 'G' Perforation depth: measured Open Perfs 12258' - 12268', 12354' - 12389'. Sqzd Perfs 12349' - 12354' 'I~'<II\ \f"':""'" fr,,;, ;,M,!"","I'" ,'~,~,'~,', '~, '," I'"", h\;~, :,:", '(",,' true vertical Open Perfs 9485' - 9520'. Sqzd Perfs 9480' - 9485'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 9949'. Packers & SSSV (type & measured depth) 7-5/8"x4-1/2" BKR SABL-3 PKR @ 9892' MD. 4-1/2" HES CP-2 TRSSSV @ 2091' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl 127 77 1278 Prior to well operation 01/22/2003 Subsequent to operation 02/05/2003 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations Oil X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 4--- ~~ ~ Hie: T e;n;cal Assistant DeWayne R. Schnorr 5662 RBDMS 8Fl Form 10-404 Rev 06/15/88 . i::~;F; L ?nOJ7 \ L.n l.... '- J '" ,..., I,' ":"J'""":"\\I,'\,,~it)ln A\as1<a On & " t'\,JI¡ill¡UI,d;;,,~\I'J, , ' 7-5/8"x5-1/2" BKR ZXP ip~À~í@cJ.9§36' MD. Casing Pressure Tubing Pressure 559 1158 4606 737 16. Status of well classification as: 'i, I"~'" , I' I', it; Suspended Service Date February 06, 2003 Prepared by DeWayne R. Schnorr 564-5174 ,.'! ,,' SUBMIT IN DUPLICATE~ (" ( NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/11/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL 01/24/2003 PERFORATING: DRIFT/TAG 02/03/2003 PERFORATING: PERFORATING EVENT SUMMARY 01/11/03 T/I/O=600/2080/500 ( WL) IA FL @ 98031 (STATION #1). 01/24/03 TAGGED SOFT BOTTOM W/ 2.50 X 111 DUMMY GUN @ 12,3581 WLM 02/03/03 PERFORATED: 122581 - 122681. RIH W/2-1/211 GUNS. 6 SPF PJ. TAGGED TD AT 123981. SHOT PERFS FROM 12258'-12268'. POOH. RDMO ***WELL TURNED OVER TO DSO TO POP*** FLUIDS PUMPED BBLS 1 DIESEL FOR PRESSURE TESTING SURFACE EQUIPMENT (ONE TEST) 6 METHANOL 7 TOTAL ADD PERFS 02/03/2003 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-1/211 PJ2506 HMX CHARGE, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. "122581 - 122681 Page 1 ¡ê' ~' \, 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: NK-22A, February 10, 2003 AK-lV[M-11211 aD I-ad. ?f 1/55'1 NK-22A: Digital Log Images 50-029- 22402-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signe : RE CE IVED FEB 1 1 2003 AJaaka Q1 & Gøs Cons. Cornrnitllion Ancf1CQge " ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: CEMENT SQUEEZE 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 3845'FNL,694'FEL,Sec.36,T12N, R15E,UM At top of productive interval 854'FNL,4664'FEL,Sec.32, T12N, R16E,UM At effective depth 852' FNL, 4652' FEL, Sec. 32, T12N, R16E, UM At total depth 852'FNL,4646'FEL,Sec.32,T12N, R16E,UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Intermediate Liner Length 80' 3969' 9991' 2504' Size 20" 10-3/4" 7-5/8" 4-1/2" Stimulate - Alter casing - 5. Type of Well: Development _X Exploratory- Stratigraphic- Service (asp's 721865, 5979979) Plugging - Perforate - Repair well _X Other - 6. Datum elevation (DF or KB feet) RKB 53 feet 7. Unit or Property name ~ik'lk UI"rit P&3lA. 8. Well number NK-22A 9. Permit number / approval number (asp's 727949, 5983154)' J 201-228 \ 10. API number (asp's 727961, 5983156) ~ 50-029-22402-01 11. Field / Pool Niakuk Oil Pool (asp's 727966, 5983157) 12444 feet 9574 feet Plugs (measured) Tagged TO @ 12404' (12/20/2002) 12404 feet 9535 feet Junk (measured) Measured Depth 122' 5011' 1 0030' 9936' - 12440' True Vertical Depth 122' 4145' 7350' 7290' - 9570' Cemented 280 CF AS (Approx) 3267 cf 'E', 435 cf 'G' 720 cf Class 'G' 303 cf Class 'G' . ,~' ~D!<ij "i!Cr' Q f ~C, r, \ \1 t\ mØ\.Þ i~f\. Jk" . '7 1{'cN .-\ "\ 200,) J r\ ~ '...J II'" ,."r~r\:ìli\ssion it &. Gas C((H1S. I¡,,¡¡O~'iuW þ,.\aska 0 ~nch~r.wa~!t' Perforation depth: measured Open Perfs 12354' - 12389'. Sqzd Perfs 12349' - 12354' true vertical Open Perfs 9485' - 9520'. Sqzd Perfs 9480' - 9485'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 9949'. Packers & SSSV (type & measured depth) 7-5/8"x4-1/2" BKR SABL-3 PKR @ 9892' MD. 7-5/8"x5-1/2" BKR ZXP PKR @ 9936' MD. 4-1/2" HES CP-2 TRSSSV @ 2091' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/22/2002 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl 706 323 3508 TubinÇ) Pressure 1048 566 Subsequent to operation 12/31/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations Oil X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledg~. ~~~~~ 388 "H~ '1 S B F l Form 10-404 Rev 06/15/88 . CasinÇ) Pressure 2592 1531 16. Status of well classification as: Title: Technical Assistant Suspended Service Date January 03, 2003 Prepared by DeWayne R. Schnorr 564-5174 ÆB ~ 3 20m SUBMIT IN DUPLICATE 11/09/2002 11/16/2002 11/23/2002 11/24/2002 11/25/2002 11/26/2002 11/28/2002 11/29/2002 11/29/2002 11 /30/2002 11/30/2002 12/01/2002 12/03/2002 12/04/2002 12/12/2002 12/13/2002 12/14/2002 12/20/2002 12/22/2002 12/31/2002 11/09/02 11/16/02 11/23/02 11/24/02 (' (' NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS CEMENT SQUEEZE: PERFORATING BOPD: 751, BWPD: 3,545, MCFPD: 1,340, AL Rate: 1,001 SBHP/FBHP SURVEY: STATIC BOTTOM HOLE PRESSURE SURVEY SBHP/FBHP SURVEY: GAS LIFT--TO DUMMY VALVES; MIT-IA; STATIC BOTTOM HOLE PRESSURE SURVEY SBHP/FBHP SURVEY: DRIFT/TAG; GAS LIFT--TO DUMMY VALVES; STATIC BOTTOM HOLE PRESSURE SURVEY CEMENT SQUEEZE: AC-BLEED; AC-FLUID LEVEL CEMENT SQUEEZE: FLUID SWAP; MIT-IA CEMENT SQUEEZE: AC-MONITOR CEMENT SQUEEZE: AC-MONITOR CEMENT SQUEEZE: AC-MONITOR CEMENT SQUEEZE: CEMENT SQUEEZE CEMENT SQUEEZE: CEMENT SQUEEZE CEMENT SQUEEZE: MILL CEMENT SQUEEZE: FILL CLEAN OUT; FLUID SWAP; MILL CEMENT SQUEEZE: GAS LIFT--FOR RATE CEMENT SQUEEZE: DRIFT/TAG; GAS LIFT--FOR RATE CEMENT SQUEEZE: GAS LIFT--FOR RATE CEMENT SQUEEZE: PERFORATING CEMENT SQUEEZE: AC-FLUID LEVEL WELLEVENT --- BOPD: 388, BWPD: 1,531, MCFPD: 2,592, AL Rate: 2,450 EVENT SUMMARY SQUEEZE PERFS / PERFORATED 123281-123481 WITH 2.511 2506 HJ 6 SPF. CHARGE DATA: 13.111 PENETRATION, 0.4311 ENTRANCE HOLE, 10.5 GRAMS. DEPTHS CORRELATED TO SWS SCMT LOG DATED 8-JAN-2002. NO TAG. «< WELL TURNED OVER TO PAD OP TO POP »> TESTEVENT --- BOPD: 751, BWPD: 3,545, MCFPD: 1,340, AL Rate: 1,001 FREEZE PROTECT TBG WITH 50 BBLS OF 60/40 METHANOL WATER & FLOWLINE WITH 5 BBLS OF 60/40 METHANOL WATER. (WELL SHUT IN ON ARRIVAL) TAG TD WI 3.25 CENT @ 123731 SLM + 111 = 123841 CORR TO RKB - RUN SBHPS - SET 4-1/2" WIDDON C-SUB - PULL OGLV FROM ST A# 1 @ 97781 SLM -- TIME MD SS LUB 15MIN 15MIN 15MIN 40MIN 12,018 12,120 12,220 12,120 9100 9200 9300 9200 PRESS(PSI) 1412 4503.5 4547.3 4590.6 4547.3 TEMP 187.9 189.6 191.0 189.7 Page 1 11/25/02 11/26/02 11/28/02 11/29/02 11/29/02 11/30102 11/30102 12101/02 12/03/02 ( f NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PULL LGLV (BK LATCH, 16/64 PORT, 2467 TRO) FROM STA# 2 @ 8337' SLM- PULL LGLV (BK LATCH, 16/64 PORT, 2483 TRO) FROM STA# 4 @ 4797' SLM- SET DGLV STA# 4 @ 47971 SLM - SET 1" BK DGLV STA 2 - SET 1" BK DGLV STA 1 PULL CS RDMO. (WELL SHUT IN ) ( PRE SQUEEZE) T/I/O=S1/2180/150 BLEED IA (PREP FOR IA LOAD & MIT); INITIAL IA FL @ 57801 (151 BBLS/BETWEEN ST #3 & ST #4). BLED IA FROM 2180 PSI TO 700 PSI IN 2 HOURS. IA FL REMAINED UNCHANGED. SHUT-IN BLEED AND MONITORED FOR 30 MINUTES WITH NO INCREASE IN PRESSURE. FINAL WHpis = S1/70010. LOAD IA WITH BBLS CRUDE, MIT IA TO 1500 PSI. PASSED. BLEED PRESSURE DOWN TO 700 PSI. T/I/O= 2100/850/160 MONITOR WHpls. (POST IA BLEED). T/I/O=S1/920/150 (POST IA BLEED) MONITOR WHpls. TIIIO = S1/850/125. MONITOR WHpls. (POST IA BLEED). MIRU CT #5. DRIFT NEW COIL, BOP TEST. PT ISOLATION VALVES ON SQUEEZE SKID. KILL WELL WI FILTERED 1% KCL. WELL WON'T KILL BULLHEAD, PRESSURED UP. BLEED DOWN WHP TO FLOWLINE. RIH WI 3" JOUST NOZZLE. TAG BTM @ 123921. FLAG COIL @ 123821. CIRC KILL DOWN CT WI FILTERED 1 % KCL, TAKING RETURNS TO THE FLOWLINE. CONTINUE TO LIQUID PACK, TAKING RETURNS TO THE OPEN TOP. INITIAL INJECTIVITY 1.5 BPM AT 1050 PSI. SQUEEZE WITH 27 BBLS OF 15.8 PPG LARC CEMENT. SQUEEZE TO 3500 PSI. PUT APPROX 5 BBLS BEHIND PIPE. CONTAMINATE AND CLEAN OUT TO 122001 CTMD. CHASE OUT AT 80%, WASHING JEWELRY AND MANDRELS. FREEZE PROTECT TUBING AND FLOWLINE WITH 60140 MEOH. LEFT WELL WITH 500 PSI TRAPPED UNDER SWAB. RD. MIRU CTU#5. PU 2-7/8" MOTOR AND 3.70" 3 BLADE MILL. TAG CEMENT AT 121951. REAM FROM 121001 TO CEMENT TOP AT 121951. DRILL CEMENT FROM 121951 TO 124011 CTMD. SWEEP WITH FLO-PRO PILLS WHILE MILLING. SHORT TRIP 124011 TO 122001, ATTEMPT TO OPEN CIRC SUB, PUMP FLO-PRO PILL. CIRC SUB WOULDN'T OPEN, BURST DISK WOULDN'T RUPTURE. POH. DISPLACE COIL WITH MEOH. PU 2.5" JSN AND DCVIS. OPEN WELL. WHP HAD BUILT TO 500 PSI. ALL FLUID. RIH. TAG TD @ 12400' DOWNI 123921 UP. JET TO 122001. PUMP 5 BBL FLOPRO SWEEP ON BTM CHASE OUT. PUMP 5 BBL FLOPRO SWEEP @ 100001, CHASE OUT. Page 2 , 12/04/02 12/12/02 12/13/02 12/14/02 12/20/02 12/22/02 12/31/02 ( ( NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PUMP FLOPRO SWEEPS @ 8000',6000',40001,2700' AND 21001. CHASE TO 21001. CIRC TO SURFACE. RIH TO 12100., CIRC BACKSIDE/LAY IN CRUDE TO SURFACE. FP COIL. RDMO. ** JOB COMPLETE** RIG UP, ATTEMPTING TO UNFREEZE MASTER & SWAB. PULL DGLV1S FROM STA # 1,2,4. PULL RP FROM STA #3. SET S/O IN STA #1. SET LGLV1S IN STA #2,4. SET DGLV IN STA #3. PULL CATCHER. DRIFT W/2.5" DUMMY GUN TAG FILL @ 12,384ISLM. (12,3801 CORR. DEPTH) (TARGET DEPTH 12389l DRIFT W/ XN LOCATOR- LOCATE XN NIPPLE @ 99401 SLM (-41 corr.factor). FINISH RIGGING DOWN. TURN WELL OVER TO DSO,WELL TO BE POP. PERFORATED FROM 123541_123891 MD W / 2.511 HSD - 6 SPF - 2506 PJ - HMX GUNS. THREE RUNS MADE. RUN 1 - TAGGED TD @ 12383.51 MD. FIRST SHOT INTERVAL = 12383-12363. RUN 2 - TAGGED TD @ 124041 MD. SECOND SHOT INTERVAL = 12354-12363. RUN 3 - TAGGED TD @ 124041 MD. SHOT INTERVAL = 123831_123891. THIRD RUN REQUESTED BY APE AFTER DEEPER TD TAG ON RUN 2. GOAL WAS TO PERF INTERVAL PREVIOUSLY THOUGHT UNREACHABLE DUE TO FIRST TAG. NO PROBLEMS RIH OR POOH. LEFT WELL SHUT IN. NOTIFIED DSO OF WELL STATUS. T /1/0 = 700/1650/300. IA FL for DSO @ 98031. WELLEVENT --- BOPO: 388, BWPD: 1,531, MCFPO: 2,592, AL Rate: 2,450 FLUIDS PUMPED BBLS 2 DIESEL FOR PRESSURE TESTING SURFACE EQUIPMENT (ONE TEST) 236 60/40 METHANOL WATER 669 1% KCL WATER 1260 1 % KCL EXTRA SLICK WATER 337 CRUDE 65 FRESH WATER 112 FLOPRO 150,000 LSRV 78 1.5# BIO 27 15.8 PPG LARC CEMENT 2786 TOTAL Page 3 ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ." 1. Operations performed: FCC I ACIDIZE 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 3845'FNL,694'FEL,Sec.36,T12N, R15E,UM At top of productive interval 854'FNL,4664'FEL,Sec.32,T12N, R16E, UM At effective depth 853'FNL,4659'FEL, Sec. 32,T12N, R16E, UM At total depth 852'FNL,4646'FEL,Sec.32,T12N, R16E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Intermediate Liner Size 20" Length 80' 3969' 9991' 2504' 10-3/4" 7-5/8" 4-1/2" Naikuk Unit 8. Well number NK-22A \ 9. Permit number / approval number (asp's 727949, 5983154)~' 201-228 \. 10. API number (asp's 727954, 5983155)"~ 50-029-22402-01 11. Field / Pool Niakuk Oil Pool Stimulate _X Alter casing - 5. Type of Well: '\ Development _X Exploratory- Stratigraphic- Service (asp's 721865, 5979979) (asp's 727966, 5983157) 12444 feet 9574 feet Plugs (measured) 12357 feet 9488 feet Junk (measured) Cemented 280 CF AS (Approx) 3267 cf 'E', 435 cf 'G' 720 cf Class 'G' 303 cf Class 'G' Perforation depth: measured Open Perfs 12349' - 12389' true vertical Open Perfs 9480' - 9520' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 9949'. Packers & SSSV (type & measured depth) 7-5/8"x4-1/2" BKR SABL-3 PKR @ 9892' MD. 4-1/2" HES CP-2 TRSSSV @ 2091' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaae Production or Injection Data Oil.Bbl Gas-Mct Water-Bbl 315 356 2751 Subsequent to operation 03/31/2002 730 1068 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run - ~, Daily Report of Well Operations Oil X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~Þß!~ Prior to well operation 10/15/2002 Form 10-404 Rev 06/15/88 . Title: Technical Assistant ,("'\ ;11 '\..,.,j' I ,', Plugging - Perforate - Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 53 feet 7. Unit or Property name Measured Depth 122' 5011' 1 0030' 9936' - 12440' True Vertical Depth 122' 4145' 7350' 7290' - 9570' RECEIVED OCT 3 1 2002 AtasKaOJ~& G~ ~ns. Commission 7-5/8"x5-1/2" BKR zXP MtgaSB36 , MD. Casing Pressure Tubing Pressure 779 583 6689 Suspended Service Date October 28. 2002 Prepared by DeWayne R. Schnorr 564-5174 1 r \ 'l ~ SUBMIT IN DUPLICATE 10/09/2002 10/11/2002 1 0/22/2002 1 0/23/2002 1 0/26/2002 1 0/09/02 10/11/02 1 0/22/02 1 0/23/02 1 0/26/02 (' (" NK-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS CEMENT SQUEEZE: AC-TIFL TESTEVENT --- BOPD: 346, BWPD: 2,745, MCFPD: 1,337, AL Rate: 961 CEMENT SQUEEZE: ACID TREATMENT; FILL CLEAN OUT CEMENT SQUEEZE: ACID TREATMENT TESTEVENT --- BOPD: 730, BWPD: 6,689, MCFPD: 4,567, AL Rate: 3,499 EVENT SUMMARY T/I/0=1300/2400/100 TIFL PASSED (PRE ACID STIMULATION); BLED IA FROM 2330 PSI IN 2 HOURS. IA FL STARTED AT 98031 (ST #1) AND REMAINED UNCHANGED. SHUT-IN BLEED AND MONITORED THE IA PRESSURE FOR 30 MINUTES WITH NO INCREASE. WELL IS BOL. FINAL WHpis = 1400/750/50. TESTEVENT --- BOPD: 346, BWPD: 2,745, MCFPD: 1,337, AL Rate: 961 MIRU DS CTU #9. RIH WITH 2.2511 JSN. TAGGED UP AT 123791 (UP) CTMD. CLEANED OUT TO 123811 (UP) CTMD. HARD BOTTOM AT THIS POINT AND UNABLE TO MAKE ANY HEADWAY. AS POH JET WITH 2 BIO SWEEPS ACROSS DOGLEG FROM 104201 -106201. POH AT 800/0 WITH WELL FLOWING. JOB IN PROGRESS. FLUID PACK WELL AND RIH WITH 2.25 JS. INJECTIVITY TEST WITH CH20 PRIOR TO ACID IS 1 BPM AT 1622 PSI. TAKE RETURNS THROUGH OUT INITIAL PORTION OF HCL TO MAINTAIN WHP AT 1800 PSI. (ESTIMATE 2 BBLS RETURNS). NO GOOD BREAK BACK SEEN. FINAL INJECTIVITY WITH HCL IS 1 BPM AT 1622 PSI. PUMPED 5 BBLS XYLENE FOLLOWED WITH 25 BBLS OF 50/0 HCL. POH DISPLACING COIL AT 0.5 BPM WITH MEOH. RDMO. NOTIFY DSO TO POP WELL. TESTEVENT --- BOPD: 730, BWPD: 6,689, MCFPD: 4,567, AL Rate: 3,499 FLUIDS PUMPED BBLS 84 METHANOL 10 60/40 METHANOL WATER 356 EXTRA SLICK SEAWATER 34 3# BIOZAN 147 CH20 5 XYLENE 25 50/0 HCL (FIELD TITRATION IS 5.10/0 FE L T 22 PPM. ACID AS PER PROGRAM. 661 TOTAL Page 1 (' r ( TREE = 4-1/16" 5M CIW WELLHEAD = 13-5/8" - 5M FMC ACTUA TOR = BAKER KB. ELEV = 30.49' BF. ELEV = 19' KOP= 1200' Max Angle = 52 @ 9693' Datum MD = 11711' Datum TV D = 8800' SS NK-22A (6) I 10-3/4" CSG, 45.5#, NT-80S, ID = 9.953" I 5011' Minimum ID = 3.725" @ 9936' 4-1/2" HES XN NIPPLE NO-GO PERFORATION SUMMARY REF LOG: SCMT 01/08/02 A NGLE AT TOP ÆRF: 8 @ 12349' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 12349 - 12369 0 01/09/02 3-3/8" 6 12369 - 12389 0 01/09/02 I 7-5/8" CSG, 29.7#, NT95HS, ID = 6.875" I 7-5/8" X 4-1/2" PKR, ID = 3.941" 1 12720' 12975' 7-5/8" CSG, 29.7#, NT13CR-80, ID = 6.875" I 13516' I SAFETY NOTES: CHROME CASING. 2091' -i 4-1/2" HES CP-2 TRSSSV, ID = 3.813" I ST MD 4 4816 3 6778 2 8361 1 9803 GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH 4018 48 KBMG-M DMY BK 5290 50 KBMG-M RP BK 6287 51 KBMG-M DMY BK 7209 51 KBMG-M DMY BK PORT DATE 0 12/29/01 12/29/01 0 12/29/01 0 12/29/01 9871' -1 4-1/2"HESXLANDINGNIP,ID=3.813" 1 9892' -i 7-5/8" X 4-1/2" PKR, ID = 3.874" I 9916' -1 4-1/2" HES X LANDING NIP, ID = 3.813" 1 -i -i -i -i I 10030' l-i TOP OF WHIPSTOCK 1 9954~-I ELMD TT LOGGED 01/09/02 I 9936' 9936' 9949' 9968' 4-1/2" HES XN NIP NO-GO W/ RHC, 10 = 3.725" 1 7-5/8" X 5-1/2" BKR ZXP PKR, ID = 4.940" I 4-1/2" WLEG, ID 3.958" I 5-1/2" X 4-1/2" XC, ID = 3.958" I I 12044' l-i MARKER JOINT 1 I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.918" I DATE REV BY COMMENTS DATE REV BY COMMENTS 10/31/93 ORIG COMPLETION, (POOL 7) 12/31/01 DAC/KAK RIG SIDETRACK 01/09/02 TMN/KK IPERFS NIAKUK UNIT WELL: NK-22A PERMIT No: 201-228 API No: 50-029-22402-01 Sec. 36, T12N, R15E, 1435 NSL, 694 WEL BP Exploration (Alaska) ~' ( aDJ-da ~ J 11 54 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage,Alaska October 2, 2002 RE: MWD Formation Evaluation Logs NK - 22A, AK-MM-11211 1 LDWG formatted Disc with verification listing. lùPI#: 50-029-22402-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~chorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. ~chorage, Alaska 99508 Si~cJ10r-J Date: RECE\VED OCT 09 2002. Hilke on &. Gas Cons. eomm188km AndØIge Scblumbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AnN: Beth Well H-30 ~-~ 5 D.S. 7-36 -¡c; '7- 7 [,., q P2-53 -rq ,,-{)t.J NK-22A ;}"J,'~'::J ~ BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# Log Description Date 22300 RST -SIGMA 22299 MCNL 22311 RST-SIGMA 22284 RST -SIGMA 06/13/02 06/12/02 05/18/02 05/19/02 - RECEIVED AUG 7 6 2002 Alaska Oif a Gas Cons.' . AnchDIIge Comll1i18ion Blueline NO. 2311 Company: 08/15/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia 1 1 1 1 Color Prints eM CD 1 1 1 1 .( '- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 02/2' /02 Scblllllbepgep NO. 1836 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: LIsa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ( 11 \ Well Job # Log Description Date Bluellne Sepia Color Prints CD / B-07 J ï '1- ()O::J. PRODUCTION PROFILE 02/09/02 1 1 MPF-33A ~lDT~DtPw\ STATIC PRESSURE SURVEY 02/14/02 1 1 NK-19A ,.4,/., 1-0 ID STATIC PRESSURE SURVEY 02/10/02 1 1 K-02C aD/-;:::)., (r¡ 22064 MCNL (PDC) 01121/02 1 1 1 D.S. 5-26A 20)-d.;.),1 22048 MCNL (PDC) 01114/02 1 1 1 NK-22A ~Ol-dd. S? 22060 SCMT (PDC) 01/08/02 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-571' AlTN: Sherrle Date Delivered: r'1AR 0 5 2002 Alaska Oil & Gæ.Cons.comm- Anchorage Recelv6.-~.<)a' ("'- OQ(lp. ) ,,'I c, (' STATE OF ALASKA ;,' ALASKA UIL AND GAS CONSERVATION COMM("JION WELL COMPLETION OR RECOMPLETION REPORT AN D LOG 1. Status of Well Classification of Service Well 181 Oil 0 Gas 0 Suspended Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-228 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22402-01 4. Location of well at surface ,~->",,',:, ¡~ ,'.¡ r ¡;;'::'A '!¥.:, ~" ~ 9. Unit or Lease Name 1435' NSL, 694' WEL, SEC. 36, T12N, R15E, UM ¡ . ,>\, ; '\f;~'c:. ~~, Niakuk f ~"?[_~,~2 .~, " ;'dU~W:, . ',' At top of productive interval ~~'Þ7.J '< 4426' NSL, 4664' WEL, SEC. 32, T12N, R16E, UM ,; ~fE'( \:;,"': ;' " li1> - -" ~,.'.,:. 10. Well Number At total depth ',", ~ ,~i' l:;.::-:..;::--:::::,:::::=.-; :"" . '. JI " ...", NK-22A ',' "-" . it 4428' NSL, 4646' WEL, SEC. 32, T12N, R16E, UM .' " .. - , ) tr 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Niakuk Oil Pool RKB = 53.41' ADL 034635 12. Date Spudded 13. Date T.D. Reached 14. Date com~ Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 12-20-2001 12-26-2001 1,~'2002 ,~/) N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 12444 9574 FT 12357 9488 FT 181 Yes ONo (Nipple) 2091' MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DEN, NEU 23. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 80' 30" 1280 cu ft Arctic Set (Aoorox.) 10-3/4" 45.5# NT80LHE 42" 5011' 13-1/2" ß267 cu ft 'E' 435 cu ft 'G' 7-518" 29.7# NT95HS/13CR 39' 10030' 9-7/8" 1720 cu ft Class 'G' 4-1/2" 12.6# L-80 9936' 12440' 6-3/4" 303 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9949' 9892' MD TVD MD TVD 12349' - 12389' 9480' - 9520' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 204 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 10, 2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. RECEIVED FEB 2 5 2002 Alaska Oil & Gas Coos. Commissio 11 & w Form 10-407 Rev. 07-01-80 If'''') r', J r\. ~ ~, ~' t'~ ~ ",~,\"-1(,:. ',~"ët!~"\",'I,,,"\l!' , I t \ ;"" I ¡M\. ' , , ""...' , \i. \,' ,,~ Submit In Duplicate ( 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Top Shale Wall (TSHW) 11400' 8546' HRZ 11988' 9124' Kuparuk 12206' 9339' Zone 1 A 12206' 9339' Zone 2A 12244' 9376' Zone 28 12261' 9393' Zone 2C 12275' 9407' Zone 2D 12297' 9429' Zone 2E 12311' 9443' Zone 3A 12317' 9448' Zone 38 12359' 9490' Zone 3C 12380' 9511' 31. List of Attachments: ( 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECEIVED FEB 2 5 2002 Alaska Oil & Gas Cons. Commission Anchorage Summary of Daily Drilling Reports, Surveys, Pre / Post Rig Summary Report and a Leak Off Integrity Summary. 32. I hereby certify that the fore oing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant NK-22A Well Number 201-228 Permit No. / A roval No. INSTRUCTIONS Date Prepared By Name/Number: Sandra Stewman, 564-4750 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 (~) \, " 1',,'" ~,' ~',,:-""<;;, ~" r,".'\" , ~, [\ , , l;, I ~, ,!~ '\' \ I ".-¡<' ,m"'l" ,", , , >,,! . ,:: r~~ : L,¡I\',\"'",}¡,\¡<:¡\:"." BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: NK-22 Common Name: NK-22A Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Suñace Pressure Leak Off Pressure (BHP) EMW 12/19/2001 LOT 10,058.0 (ft) 7,367.3 (ft) 9.50 (ppg) 2,100 (psi) 5,736 (psi) 14.99 (ppg) r ( Printed: 12/31/2001 10:06:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/14/2001 12/15/2001 12/16/2001 12/17/2001 12/18/2001 ( . Î "" . NK-22 NK-22A REENTER+COMPLETE DOYON DOYON 14 BP EXPLORATION Operations Summary Report 03:00 - 00:00 From - To Hours Activity Code NPT PRE 00:00 - 00:00 00:00 - 12:00 12:00 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 17:30 17:30 - 18:00 18:00 - 20:00 20:00 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 13:00 13:00 - 14:00 14:00 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:00 02:00 - 02:30 02:30 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 12:00 12:00 - 12:30 12:30 - 16:30 16:30 - 18:00 21.00 MOB 24.00 RIGU 12.00 RIGU 1.50 PULL 2.00 PULL 0.50 PULL 1.50 PULL 0.50 PULL 2.00 PULL 2.50 PULL 1.50 PULL 0.50 PULL 5.00 PULL 0.50 PULL 1.00 PULL 1.00 PULL 0.50 PULL 0.50 PULL 4.00 PULL 1.00 PULL 9.00 PULL 1.00 PULL 1.00 BOPSUR P 0.50 BOPSUR P 0.50 STWHIP P 0.50 STWHIP P 2.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 2.00 STWHIP P 3.50 STWHIP P 0.50 STWHIP P 4.00 STWHIP P 1.50 STWHIP P P P P P P P P P P P P P P P P P P P P P P P Phase PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 1 of 5 Start: 12/14/2001 Rig Release: 12/29/2001 Rig Number: Spud Date: 10/5/1993 End: 12/29/2001 Description of Operations PREPARE RIG FOR MOVE TO NK-22. LOWER DERRICK LEFT LOCATION WITH SUB AT 18:00 HRS. Move rig and camp to Niakuk 22A. Set camp and R/U same. Raise derrick and spot over well. (Shut in NK-42 prior to move over) Skid floor and R/U to perform well work. Rig up wind walls, top drive, standpipe, cement lines, rig floor Rig accepted at 12:00 hrs, Dec 16, 2001 Check well pressure, RU Drill Site Maintenance, pull TWC, RD DSM RU to circulate out freeze protect, take on seawater, test lines, flanges and choke Circulate down annlus, displace diesel out of tubing at 4 bpm at 650 psi change lines from ann Ius to tubing Circulate down tubing, displace diesel out of annlus, circulate surface to surface at 6.5 bpm at 1140 psi, ckeck well, dead Install TWC with DSM, pressure test from below to 1000 psi, OK PJSM, RD circulating lines, ND tree, FMC attempted to remove adapter seal, 1/2 hr NU bope, measure RKBs, inspect tubing hanger threads, varify threads with screwing in XIO to hanger RU to pressure test BOPE, install mouse hloe, Rig up to pressure test BOPE PRESSURE TEST bope as per AOGCC regulations, 250, 5000 psi Pull TWC with Drill Site Maintenance Back out lock downs, pull tubing hanger to rig floor Circulate bottoms up, 470 psi at 8 bpm Lay down DP, X/Os, tubing hanger. Norm inspect all related wellbore equipment and tubing. Rig up to lay down tubing PJSM, lay down 41/2" tubing, spool control lines Rig down spool unit, layout unit, clean rig floor Lay down tubing Rig down tubing equipment, layout, change bales, clean rig floor Rig up to pressure test BOPE Pressure test lower pipe rams as per AOGCC reulations, 250 psi, 5000 psi, OK Set wear bushing Rig up to pick up drillpipe Pick up, rabbit, make up drillpipe, trip in 1 x 1, 75 jts Slip and cut drilling line, service top drive Rack 25 stands of drillpipe in derrick Make up mill run BHA Pick up, rabbit, make up drillpipe, trip in 1 x 1 Rig service Pick up, rabbit, make up drillpipe, trip in 1 x 1, tag up at 10,497' Circulate bottoms up, ROT WT 165, PU WT 185, SOW Printed: 12/31/2001 10:07:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/18/2001 12/19/2001 12/20/2001 12/21/2001 ( c- . BP EXPLORATION Operations Summary Report NK-22 NK-22A REENTER+COMPLETE DOYON DOYON 14 16:30 - 18:00 From - To Hours Activity Code NPT PROD1 18:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 03:30 03:30 - 04:00 04:00 - 05:30 05:30 - 10:00 10:00 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 21:00 21 :00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 11 :00 11:00 -14:30 14:30 - 16:30 16:30 - 18:30 18:30 - 19:00 19:00 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 06:30 06:30 - 08:00 08:00 - 09:00 09:00 - 14:00 14:00 - 14:30 14:30 - 00:00 1.50 STWHIP P 4.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 3.00 STWHIP P 0.50 STWHIP P 1.50 STWHIP P 4.50 STWHIP P 5.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 4.00 STWHIP P 1.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 3.50 STWHIP P 2.50 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 4.00 DRILL P 3.50 DRILL 2.00 DRILL 2.00 DRILL P P P 0.50 DRILL 5.00 DRILL P P 2.50 DRILL P 0.50 DRILL 3.50 DRILL 1.50 DRILL 1.00 DRILL P P P P 5.00 DRILL 0.50 DRILL 9.50 DRILL P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 2 of 5 Start: 12/14/2001 Rig Release: 12/29/2001 Rig Number: Spud Date: 10/5/1993 End: 12/29/2001 Description of Operations 140 Torque 7000, Flow check, pump dry job Trip out, strap out, SLM no correction Change elevators, Lay down jars, mill BHA Clean up rig floor Rig up Schlumberger wireline unit Log bridge plug into position, set at 10,051' RKB Rig down Schlumberger wireline unit Pressure test 7 5/8" casing to 4500 psi, OK Make up whipstock BHA, mills, MWD, upload MWD, trip in DC, HWDP and surface test MWD Trip in w/ whipstock BHA, controlled running speed, fill pipe every 2000' Break circulation, orient wI MWD, set whipstock at 87 degrees left hi-side, set at 10,042' (btm of slide) Displace seawater in wellbore to 9.6 ppg LSND mud, take slow pump rates, displace at 330 gpm Mill window from 10,030' to 10,042', open hole to 10,058' Circulate sweep, increase in metal cuttings at shaker Perform LOT, flow cheek, pump dry job Blow down mud lines, ready to POOH Trip out with mill BHA Stand back 4 stands HWDP, PU MU jars, stand back, LD 8 HWDP, 8 DCs, download MWD, LD bumper sub, FL T sub, change probe, LD mills, Clear rig floor Jet BOP stack PU MU motor, set at 1.22 degrees, bit, DS69, MWD tools, upload MWD, PJSM, install nuclear sources, PU flex DCs, RIH jars, HWDP, surface test MWD Trip in filling pipe every 30 stands Rig service, slip and cut drilling line, service top drive Trip in, from 9,714', make MAD pass to 10,032' at 200' I hr Orient tools through whipstock window Directional drill from 10,058' to 10,268' AST 2.32, ART .25, ADT 2.57 Directional drill 6 3/4" production wellbore from 10,268' to 10,359', Wellbore following old wellbore down along side casing AST 4.30, ART 0.25, ADT 4.55, Flow check, pump dry job Trip out to change BHA Handle BHA, remove nuclear sources, change bit, Adjust motor setting to 1.5 degrees, orient, run in BHA, shallow test MWD Trip in filling pipe every 30 stands Break circulation, orient through window, good entry Time drill, 10,74' to 10,080' @ 2 min I inch, 10,080' to 10,111' @ 1 min /inch 10,111' to 10,130' @ 10'/hour, 10,130' to 10,140' @ 20' I hour Printed: 12/31/2001 10:07:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/22/2001 12/23/2001 12/24/2001 12/25/2001 12/26/2001 ( { Page 30f 5 BP EXPLORATION Operations Summary Report NK-22 NK-22A REENTER+COMPLETE DOYON DOYON 14 00:00 - 07:00 From - To Hours Activity Code NPT PROD1 07:00 - 12:00 12:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 06:00 06:00 - 07:00 07:00 - 10:30 10:30 - 13:00 13:00 - 15:00 15:00 - 18:00 18:00 -19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 04:30 04:30 - 06:00 06:00 - 12:00 12:00 - 00:00 00:00 - 06:00 06:00 - 07:00 07:00 - 12:00 12:00 - 00:00 00:00 - 02:00 02:00 - 04:00 04:00 - 06:00 06:00 - 09:00 09:00 - 15:00 7.00 DRILL 5.00 DRILL 8.50 DRILL 0.50 DRILL 3.00 DRILL 6.00 DRILL 1.00 DRILL 3.50 DRILL 2.50 DRILL 2.00 DRILL 3.00 DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 2.00 DRILL 2.50 DRILL 0.50 DRILL 1.50 DRILL 1.50 DRILL 6.00 DRILL 12.00 DRILL 6.00 DRILL 1.00 DRILL 5.00 DRILL 12.00 DRILL 2.00 DRILL 2.00 DRILL 2.00 DRILL 3.00 DRILL 6.00 DRILL Phase P P PROD1 P P P PROD1 PROD1 PROD1 P P PROD1 PROD1 P P PROD1 PROD1 P PROD1 P P N P P P P P P P P PROD1 PROD1 HMAN PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 HMAN PROD1 PROD1 PROD1 P PROD1 P PROD1 N RREP PROD1 P PROD1 P PROD1 P P PROD1 PROD1 P PROD1 P PROD1 P PROD1 Start: 12/14/2001 Rig Release: 12/29/2001 Rig Number: Spud Date: 10/5/1993 End: 12/29/2001 Description, of Operations Time drill, trench from 10,133 to 10,163', check ledge wI 5000 Ibs pump off Time drill, 10,163' to 10,174' @ 2 ft I hr, 180 L 10,174' to 10,184' @ 3 ft / hr, 150 L 10,184' to 10,189' @ 5 ft I hr, 150 L 10,189' to 10,192' @ 6 ft I hr, 130 L Time drill from 10,192' to 10,205' @ 10' I hr, 150 L Wash, no rotation, 150 L, from 10,205' to 10,359', orient Time drill, from 10,359' to 10,370' @ 10ft I hr, 150 L, 5 - 8,000 Ibs WOB 10,370' to 10,385' @ 15 ft I hr, 150 L, 10 -13,000 Ibs WOB 10,385' to 10,400' @ 20 ft I hr, 150 L, 10 -13,000 Ibs woe Directional drill from 10,400' to 10,543' Circulate sweep and bottoms up, flow check, pump dry job Trip out, good exit through the window Handle BHA, download MWD, set motor straight, LID, P/U motor, stabilizer blade, bit, set motor to 1.22 degrees Upload MWD, PJSM, load nuclear sources, RIH wI BHA, shallow test MWD Trip in to 6900' Slip and cut drilling line, service top drive PU, MU, run RTTS storm packer, set st 55' RU to and pull wear bushing PU, MU, install test plug, PJSM, rig up to pressure test Pressure test BOPE as per AOGCC I BP regulations, Pressure test BOPE as per AOGCC / BP regulations RD test equipment, run wear bushing RU to pull RTTS storm packer, pull and RD RTTS Trip in to 10,445', wash to 10,543' Directional drill 6 3/4" production wellbore AST 2.17, ART 1.71, ADT 3.88 Directional drill AST 3.10, ART 4.15, ADT 7.25 Directional drill 6 3/4" production wellbore from 11,570' to 11,634' AST ART ADT Repair, weld standpipe wash out, wiper trip 10 stds to 10,540' Directional drill from 11,634' to 11,695' AST 6.77, ART 3.18, ADT 9.95 Directional drill from 11,695' to 12,365' AST 1.99, ART 3.18, ADT 9.27 Drill from 12,365' to 12,444'. AST=O, ART=1.55. Pump sweep and circulate bottoms up. Mad pass from 12,363' to 12,444' at 100 fph. Flow check. Well static. POH to 10,447'. Work tight spot from 11,480' to 11,420'. RIH no problem. Criculate bottoms up with sweep. Spot liner running pill. Pump dry job. Drop ESS. Flow check. Well static. POH. Survey check shot at 11,774' and 11,489'. SLM. No - Printed: 12/31/2001 10:07:05AM ( (' BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: NK-22 Common Well Name: NK-22A Spud Date: 10/5/1993 Event Name: REENTER+COMPLETE Start: 12/14/2001 End: 12/29/2001 Contractor Name: DOYON Rig Release: 12/29/2001 Rig Name: DOYON 14 Rig Number: Date From-To Hours Activity Code NPT Phase Description of Operations 12/26/2001 09:00 - 15:00 6.00 DRILL P PROD1 correction. 15:00 - 15:30 0.50 DRILL P PROD1 Flow check at BHA. Flush BHA with water. Change elevators. 15:30 -16:30 1.00 DRILL P PROD1 LD HWDP, Jars, DC's. 16:30 - 18:30 2.00 DRILL P PROD1 Remove RA sources. Download MWD. LD BHA. Function blind rams. 18:30 - 19:00 0.50 DRILL P PROD1 Clear rig floor. 19:00 - 20:00 1.00 CASE P CaMP RU 4 1/2" casing equipment. 20:00 - 00:00 4.00 CASE P CaMP PU float equipment and check floats. RIH with 4 1/2", 12.6#, L80, HYD 521 liner. 12/27/2001 00:00 - 01 :30 1.50 CASE P CaMP MU liner hanger and packer. 01 :30 - 02:00 0.50 CASE P CaMP Break circulation. Circulate one liner volume at 5 bpm, 320 psi. PU=75K, SO=75K. 02:00 - 07:00 5.00 CASE P CaMP RIH with 4 1/2" liner on 4" DP to 9,986'. 07:00 - 09:30 2.50 CASE P CaMP Circulate bottoms up at 6 bpm, 1,150 psi. PU=163K, SO=135K. MU and stand back cement head. Rotate liner at 20 rpm, 5K ft*lbs for base line torque value. Rotating Wt.=160K 09:30 - 10:30 1.00 CASE P CaMP RIH with liner to 12,440'. PU=195K, SO= 145K. 10:30 - 12:00 1.50 CASE P CaMP Circulate and condition mud at 5.5 bpm, 1480 psi. 12:00 - 12:30 0.50 CASE P CaMP RU and pressure test cement lines to 4,000 psi. 12:30 - 14:00 1.50 CASE P CaMP Pump 45 bbls CW100, 40 bbls 12.7ppg spacer, 54 bbls 15 ppg Flexstone cement. Displace with rig pumps and reciprocate liner. Bumped plug on calculated volume. 14:00 - 14:30 0.50 CASE P CaMP Bleed off pressure and check floats. Release from liner and set liner top packer with slack off and rotation. Good indication of packer setting. 14:30 - 15:00 0.50 CASE P CaMP CBU at 8 bpm, 1,900 psi. 15:00 - 15:30 0.50 CASE P CaMP Pressure test casing to 3,500 psi for 30 minutes. 15:30 - 17:00 1.50 CASE P CaMP RD cement lines and LD cement head. Clear rig floor. Blow down cement lines and top drive. 17:00 - 00:00 7.00 CASE P CaMP LD 25 stands of 4" DP from derrick in mouse hole, clean pits, take on seawater, chain inspection on draw works while WOC. 12/28/2001 00:00 - 09:30 9.50 CASE P CaMP Wait on cement to gain compressive strength. Slip and cut drilling line while waiting. 09:30 - 11 :00 1.50 CASE P CaMP Flush mud pump with seawater. Displace well bore from liner top and above to seawater. Pump 40 bbl high vis water spacer and 550 bbls seawater at 7 to 8 bpm, 2,100 psi. Reciprocate and rotate pipe during displacement. 11:00 -14:00 3.00 CASE P CaMP POH and stand back 60 stands of 4" DP. 14:00 - 17:00 3.00 CASE P CaMP POH and LD 43 stands of DP. 17:00 - 17:30 0.50 CASE P COMP Make service breaks on liner running tool and LD same. 17:30 - 18:00 0.50 CASE P CaMP Pull wear bushing. 18:00 - 18:30 0.50 RUNCO~ P CaMP Rig up to run 4 1/2" tubing. 18:30 - 00:00 5.50 RUNCO~ P CaMP Run 4 1/2" , 12.6#, L-80, IBTM tubing to 4,300'. 12/29/2001 00:00 - 02:30 2.50 RUNCO~ P CaMP Run 4 1/2" tubing. 02:30 - 03:30 1.00 RUNCO~ P CaMP PU Halliburton CP2 TRSSSV. RU control line and test to 5,000 psi for 10 minutes. 03:30 - 07:00 3.50 RUNCO~ P CaMP RIH with 4 1/2" tubing and control line. 07:00 - 08:30 1.50 RUNCO~ P CaMP Space out tubing. MU tubing hanger and control line. Test control line to 5,000 psi for 10 minutes. PU=150K, SO= 120K. 08:30 - 09:30 1.00 RUNCO~ P CaMP Land tubing and RILDS. RU to circulate and test. 09:30 - 11 :00 1.50 RUNCO~ P CaMP Spot 83 bbls corrosion inhibited seawater in annulus. 11 :00 - 12:00 1.00 RUNCO~ P CaMP Drop ball and set packer. Test tubing to 3,500 psi for 30 Printed: 12/31/2001 10:07:05 AM ( /" t BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: NK-22 Common Well Name: NK-22A Spud Date: 10/5/1993 Event Name: REENTER+COMPLETE Start: 12/14/2001 End: 12/29/2001 Contractor Name: DOYON Rig Release: 12/29/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations ", " , 12/29/2001 11 :00 - 12:00 1.00 RUNCO~ IP COMP minutes. Bleed tubing pressure to 1,500 psi. Test annulus to 3,500 psi for 30 minutes. Bleed off tubing pressure and shear RP valve. 12:00 - 12:30 0.50 RUNCO~ IP COMP LD landing joint. 12:30 - 13:00 0.50 RUNCO~ rP COMP Install TWC and test from below to 3,500 psi. 13:00 - 14:30 1.50 BOPSUR P COMP ND BOP. 14:30 - 16:00 1.50 WHSUR P COMP Hook up control line and NU tree. 16:00 - 17:00 1.00 WHSUR P COMP Test adapter flange to 5,000 psi. Functon test TRSSSV and test same to 5,000 psi for 10 minutes. Test tree to 5,000 psi. 17:00 - 17:30 0.50 WHSUR P COMP Pull TWC with lubricator. 17:30 -19:00 1.50 WHSUR P COMP RU hot oil unit and test lines. Pump 204 bbls diesel down IA. 19:00 - 20:30 1.50 WHSUR P COMP U-tube diesel freeze protection into tubing. 20:30 - 21 :00 0.50 WHSUR P COMP Install BPV and test from below to 3,500 psi. 21 :00 - 22:00 1.00 WHSUR P COMP Secure tree. Release rig at 22:00 hrs, 12/29/2001. Printed: 12/31/2001 10:07:05 AM ( (' Well: Field: API: Permit: NK-22A Niakuk Oil Pool 50-029-22402-01 201-228 Rig Accept: Rig Spud: Rig Release: DrillingJ:!!g: 12/16/01 12/20101 12/29/01 Doyon 14 -,-"-,,,,-, "".--",.-......,.,-".-..,,--, ,,- ""..".--,..--,--.--.,..-------.....--,-,------,..,..",,---,,-.......--.---------"..--""......--......,.......,-..--------"---..,-..--,..,..-.,,,.""",--'----'------"-"',-",--""""""""---,---,-",,,""'-',."'-"'---'-------""""-- PRE - RIG WORK 12/04/01 TAG PBTD 13018' CTD, CORRECT TO 13026' MD, PUH 10', FLAG PIPE. PT CEMETERS, PUMP 14 BBLS 15.8 PPG CLASS 'G' CEMENT WI AGG HOLDING 1400 PSI WHP. PULL TO SAFETY. BUMP PRESSURE TO 2100 PSI WHP. HOLD FOR 40 MINS, DROP 3/4" BALL. CHASE WI 75 BBLS BIO. CONTAMINATE DOWN TO CLEAN OUT DEPTH OF 12,750'. POOH AT 80% WASHING JEWELRY. FP WELL TO 2500' WITH METHANOL. 12/07/01 TAGGED TOC @ 12739' SLM WIA 3.625" CENT AND S. BAILER. MIT TUBING TO 3500 PSIG FOR 30 MINS- FINAL PRESSURE 3480 PSIG - PASSED. RE-TAGGED TOC AT 12740' SLM 12/09/01 MIRU ELINE. RIH WITH 3 7/16" JET CUTTER, TIE INTO TUBING TALLEY, CUT TUBING AT 10505' WITH 3- 7/16" JET CUTTER, IA PRESSURE CHANGE FROM 550 PSI TO 850 PSI AFTER CUT MADE, POOH. POST - RIG WORK 12/31/01 PULLED B&R. PULLED STA# 1,2, & 4 BK-DGLV's; STA# 3 BK-RP SHEAR. SET STA# 2 & 4 BK-LGLV'S; STA# 3 BK-DGL V. 01/01/02 SET STA# 1 BK-OGLV. PULLED RHC PLUGBODY. DRIFT W/ 3.6" CENT & 3.5" D.G. TO 11,050' SLMDID NOT SIT DOWN, BUT POOH DUE TO HEAVY PU WEIGHT IN LINER (RIG LEFT MUD IN HOLE FROM LINER TOP TO PBTD). 01/05/02 RAN 3 3/8" DUMMY GUN W/ TEL & SAMPLE BAILER & TAG EOT @ 9933' SLM (NO ELMD ON SCHEM) CONT' IN HOLE & TAG TD @ 12,376' SLM. SAMPLE BAILER EMPTY. 01/08/02 SCMT LOGGED FROM 12406'-9600'. LOG SHOWS GOOD BOND FROM 12210-11512. RUN 3-3/8" PJ HSD 6 SPF FROM 12369'12389'. 01/09/02 PERFORATED INTERVAL 12349'-12369' WITH 3-3/8" PJ HSD GUN - 6SPF, PERFORMED STATIC TEMPERATURE / PRESSURE AT MEASURED DEPTHS 12026' = 5122 PSI, 12128' = 5160 PSI, 12229' MD = 5205 PSI (9100',9200',9300' SSTVD). (l ~,' d"'~""ò q,"',"~,!',,':,"',',',:IJ,',,'i::';I,','t~,',','.:,,',',,',":C"',',"','(Ý,',T',' è ',I,_,',lt'~bC:K:'b, 11-Jan-O2 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well NK-22A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,993.41 ' MD Window / Kickoff Survey , MD Projected Survey: 12,444.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED J:'N 1 7 2002 AJaska Oil & Gas Cons. Commissiori Anchnraop. "",' .t ... North Slope Alaska Alaska Drilling & Wells NIAKUK, Slot NK-22 NK-22A Job No. AKMM11211, Surveyed: 26 December, 2001 (----- SURVEY REPORT 11 January, 2002 Your Ref: API 500292240201 Surface Coordinates: 5979979.87 N, 721865.42 E (70020' 51.2211" N, 148011' 55.4647" W) Surface Coordinates relatIve to Project H Reference: 979979.87 N, 221865.42 E (Grid) Surface Coordinates relative to Structure: 5524.28 S, 5726.10 E (True) Kelly Bushing: 53.41ft above Mean Sea Level ( Survey Ref: svy11064 A Halliburton Company c' Sperry-Sun Drilling Services . Survey Report for NK-22A Your Ref: API 500292240201 Job No. AKMM11211, Surveyed: 26 December, 2001 Alaska Drilling & Wells North Slope Alaska NIAKUK Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eaetlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO /1 OOft) 9993.41 50.950 62.770 7273.17 7326.58 2765.57 N 5498.15 E 5982906.99 N 727279.29 E 6153.78 Tie On Point MWD Magnetic 10030.00 50.810 63.230 7296.26 7349.67 2778.46 N 5523.44 E 5982920.62 N 727304.19 E 1.048 6182.16 Window Point 10068.80 49.800 63.470 7321.04 7374.45 2791.85 N 5550.12 E 5982934.80 N 727330.46 E 2.646 6212.02 10097.53 50.190 63.650 7339.51 7392.92 2801.65 N 5569.83 E 5982945.18 N 727349.87 E 1 .440 6234.02 (--., 10129.40 50.430 63.870 7359.86 7413.27 2812.49 N 5591.83 E 5982956.67 N 727371.54 E 0.922 6258.54 10162.54 50.980 64.100 7380.85 7434.26 2823.74 N 5614.87 E 5982968.59 N 727394.24 E 1.744 6284.19 10193.21 50.570 64.320 7400.25 7453.66 2834.08 N 5636.27 E 5982979.56 N 727415.32 E 1.448 6307.95 10228.19 50.610 64.570 7422.45 7475.86 2845.74 N 5660.65 E 5982991.93 N 727439.35 E 0.564 6334.98 10259.87 49.850 64.820 7442.72 7496.13 2856.14 N 5682.66 E 5983002.99 N 727461.04 E 2.474 6359.32 10290.03 49.670 65.060 7462.20 7515.61 2865.90 N 5703.52 E 5983013.35 N 727481.60 E 0.852 6382.35 10354.87 46.230 65.610 7505.62 7559.03 2885.99 N 5747.26 E 5983034.74 N 727524.73 E 5.343 6430.48 10385.17 44.730 65.880 7526.87 7580.28 2894.87 N 5766.96 E 5983044.19 N 727544.15 E 4.991 6452.07 10419.79 40.350 66.210 7552.37 7605.78 2904.37 N 5788.34 E 5983054.32 N 727565.25 E 12.668 6475.46 10451.41 37.130 66.530 7577.03 7630.44 2912.30 N 5806.47 E 5983062.79 N 727583.13 E 10.203 6495.23 10479.26 33.890 66.880 7599.70 7653.11 2918.70 N 5821.32 E 5983069.62 N 727597.79 E 11.657 6511.39 10545.24 26.280 75.050 7656.77 7710.18 2929.71 N 5852.41 E 5983081.55 N 727628.54 E 13.075 6544.17 10576.74 23.090 78.700 7685.39 7738.80 2932.72 N 5865.21 E 5983084.94 N 727641.24 E 11.219 6557.00 10608.04 19.880 78.280 7714.51 7767.92 2935.01 N 5876.44 E 5983087.55 N 727652.40 E 10.267 6568.11 10640.24 16.620 78.960 7745.09 7798.50 2937.00 N 5886.33 E 5983089.84 N 727662.22 E 10.146 6577.87 10671.05 13.130 74.720 7774.86 7828.27 2938.77 N 5894.03 E 5983091.83 N 727669.87 E 11.858 6585.58 10703.92 11 .020 64.540 7807.01 7860.42 2941.10 N 5900.47 E 5983094.36 N 727676.24 E 9.097 6592.39 ( 10735.71 10.830 63.650 7838.22 7891.63 2943.74 N 5905.89 E 5983097.15 N 727681.58 E 0.799 6598.41 10767.48 10.680 70.600 7869.43 7922.84 2946.04 N 5911.34 E 5983099.61 N 727686.96 E 4.107 6604.32 10862.37 10.090 79.870 7962.78 8016.19 2950.42 N 5927.82 E 5983104.48 N 727703.30 E 1.865 6621.07 10958.00 9.400 87.020 8057.03 8110.44 2952.30 N 5943.86 E 5983106.83 N 727719.28 E 1 .455 6636.33 11054.66 10.250 87.470 8152.27 8205.68 2953.09 N 5960.34 E 5983108.11 N 727735.72 E 0.883 6651.50 11150.60 9.480 79.520 8246.80 8300.21 2954.90 N 5976.64 E 5983110.41 N 727751.96 E 1.629 6666.96 11246.11 8.670 85.430 8341.11 8394.52 2956.91 N 5991.55 E 5983112.85 N 727766.81 E 1.292 6681.26 11343.24 9.090 87.340 8437.08 8490.49 2957.85 N 6006.51 E 5983114.23 N 727781.73 E 0.528 6695.14 11437.59 10.490 83.580 8530.05 8583.46 2959.15 N 6022.49 E 5983116.01 N 727797.67 E 1.630 6710.09 .. ,..,......-......-----..--- ------,--------.--. -.., 11 January, 2002 - 16: 10 Page 2 of 4 DrlllQuest 2.00.09.003 , North Slope Alaska Measured Depth (ft) 11533.08 11628.46 11725.20 11821.94 11918.36 12014.51 12110.60 12206.60 12302.88 12380.37 12444.00 Incl. Azim. . Sperry-Sun Drilling Services' Survey Report for NK-22A Your Ref: AP/500292240201 Job No. AKMM11211, Surveyed: 26 December, 2001 Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth Northings Eastlngs Northlngs Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8624.10 8677.51 2960.27 N 6038.95 E 5983117.61 N 727814.09 E 1.477 8718.15 8771.56 2960.39 N 6054.83 E 5983118.20 N 727829.96 E 0.385 8813.18 8866.59 2962.17 N 6072.78 E 5983120.52 N 727847.85 E 2.988 8907.76 8961.17 2968.46 N 6092.06 E 5983127.37 N 727866.94 E 3.303 9002.05 9055.46 2976.57 N 6110.52 E 5983136.03 N 727885.14 E 1.201 9096.40 9149.81 2983.39 N 6127.71 E 5983143.35 N 727902.13 E 1.079 9191.03 9244.44 2988.64 N 6143.54 E 5983149.07 N 727917.79 E 1.595 9285.85 9339.26 2991.53 N 6158.27 E 5983152.39 N 727932.43 E 1.648 9381.08 9434.49 2993.44 N 6172.30 E 5983154.72 N 727946.40 E 0.498 9457.78 9511.19 2994.85 N 6183.26 E 5983156.45 N 727957.31 E 0.644 9520.77 9574.18 2995.73 N 6192.20 E 5983157.60 N 727966.23 E 0.000 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 9.430 88.970 9.740 90.150 11.850 79.540 12.550 64.740 11.600 67.910 10.580 68.900 9.430 74.740 8.620 83.420 8.290 81.050 8.120 84.340 8.120 84.340 Magnetic Declination at Surface is 26.760° (30-Dee-01) The Dogleg Severity is in Degrees per 100 feet (US)., Vertical Section is from Well and calculated along an Azimuth of 64.180° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12444.00ft, The Bottom Hole Displacement is 6878.79ft, in the Direction of 64.183° (True). -- - -.....,. 11 January, 2002 - 16:10 '" u_--- ..---..,_.... -'-"---'---' --"--""'-"--- ----,--'.. --u.... .. Page 3 of 4 Vertical Section 6725.39 6739.74 6756.68 6776.77 6796.92 6815.36 6831.89 6846.42 6859.87 6870.3ô 6878.79 . Alaska Drilling & Wells NIAKUK Comment c---- Projected SUrvAY \, DrlllQuest 2.00.09.003 North Slope Alaska Comments Measured Depth (ft) 9993.41 10030.00 12444.00 Sperry-Sun Drilling Services Survey Report for NK-22A Your Ref: API 500292240201 Job No. AKMM11211, Surveyed: 26 December, 2001 . 2765.57 N 2778.46 N 2995.73 N Survey tool program for NK-22A ~ . Alaska Drilling & Wells NIAKUK Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 7326.58 7349.67 9574.18 From Measured Vertical Depth Depth (ft) (ft) 0.00 9993.41 11 January, 2002 - 16: 10 0.00 7326.58 To Measured Vertical Depth Depth (ft) (ft) 9993.41 12444.00 7326.58 9574.18 ... .. .. ..- Comment 5498.15 E 5523.44 E 6192.20 E Tie On Point Window Point Projected Survey '-m Survey Tool Description Good Gyro (NK-22) MWD Magnetic (NK-22A) ( -....0"" ---"'-""'----- '--'-"--' -, Page 4 of 4 DrillQuest 2.00.09.003 01/24/02 Sc_ltnbepger NO. 1742 Alaska Data & Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ( Well Job # Log Description Date Blueline Sepia Color Prints CD ( D.S. 1-31 , >?/....- J "2.. ..J PRODUCTION PROFILE 01/07/02 1 1 NK-22A ~- t')-) - ~çI STATIC PRESSUREITEMP 01/09/02 1 1 W-02A ã}D 1-,,:)/4 22005 MCNL 12/19/01 1 1 1 D.S. 4-31 IKS-Oit.../ 22016 RST-SIGMA 12/11/01 1 1 1 D.S. 5-12B _lr'\) -/)(0 22017 MCNL 12/16/01 1 1 1 D.S. 11-16 I~ I.tJ-O79 22020 RST-SIGMA 12/23/01 1 1 1 D.S. 11-18 / '6lo - ,,;;) 22022 RST-SIGMA 12/26/01 1 1 1 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E, Benson Blvd. Anchorage. Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Received & ~p-D JAN 2 5 2002 AIãïIäOiJIGãSCons. Commission Anchorage Date Delivered: ( ~1ffÆ1fŒ (ill~ fÆ~fÆ~~~ (' / ( TONY KNOWLES, GOVERNOR AlAS KA. 0 IL AND GAS CONSERVATI ON COMMISSION 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson , Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: N iakuk NK - 22A BP Exploration (Alaska), Inc. Permit No: 201-228 Sur Loc: 1435' NSL, 694' WEL, Sec. 36, TI2N, RISE, UM Btmhole Loc. 4438' NSL, 4623' WEL, Sec. 32, TI2N, RI6E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Niakuk NK- 22A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~~'~ Cammy 6tchsli Taylor ( Chair . BY ORDER OF THE COMMISSION DATED this 4th day of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKP( STATE OF ALASKA ~- L AND GAS CONSERVATION COMrJ: PERMIT TO DRILL 20 AAC 25.005 310N ~ò-f:r :"\- ::?~" ù~\O\ -),~ '\v' 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas g; Sing.* Zone 0 Multiple Zane 2. Name of Operator 5. Datum Elevation (DF or KB) i O. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 52.7' Niakuk Oil Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ó3':¡"~~A'^ADL 034635 4. Location of well at surface 7. Unit ór Property Name 11. Type Bond (See 20 AAC 25.025) 1435' NSL, 694' WEL, SEC. 36, T12N, R15E, UM Niakuk At top of productive interval 8. Well Number 4430' NSL, 4676' WEL, SEC. 32, T12N, R16E, UM NK-22A Number 2S 100302630-277 At total depth 9. Approximate spud date 4438' NSL, 4623' WEL, SEC. 32, T12N, R16E, UM 12/15/01 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028338, 4438' MD No Close Approach 2560 12415' MD / 9574' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10040' MD Maximum Hole Angle 0 Maximum surface 4406 psig, At total depth (TVD) 9293' / 5335 51 psig 18. Casing Program Specifications Setting Depth l of"" (iize TClo ";Ul JI Hole Casino Weiaht Grade Collolina Lenath MD TVD MD TVD fin", , 'NO stane data) 6-3/4" 4-1/2" 12.6# L-80 Hvdril 521 2515' 9900' 7261' 12415' 9574' 03 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary . Total depth: measured 13540 feet Plugs (measured) true vertical 9989 feet Effective depth: measured 13026 feet Junk (measured) Fill tagged at 13026' (03/01) true vertical 9488 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 2011 280 cu ft AS (Approx.) 80' 80' Surface 4969' 10-3/411 3267 cu ft PF 'E', 435 cu ft Class 'G' 5011' 4148' Intermediate Production 13478' 7-5/811 720 cu ft Class 'G' RECE IVEð66 Liner NOV 28 2001 Perforation depth: measured Open: 12936' - 12963', 12990' - 13010' Sqzd: 12936' - 13036', 13052' - 13070' Alaska Oil & Gas Cons. Commission true vertical Open: 9401' - 9427', 9453' - 9472' Anchorage Sqzd: 9401' - 9497', 9513' - 9530' 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: BiII/sa8:cson, 564-5521 Prepared By Name/Number: Terrie Hubb/e, 564-4628 21, I hereby certify that th~9 is true ~rect to the best of my knowledge , Signed Brian Robertson ~ U r/!. -'" ~" Senior Drilling Engineer Date I'-Z~"-\j, l ,', ' , " ".' ','. ..\ ',/:', ...", ....'<:",,'.:..,:::,C~nîÎniS$iQ~.~,e!Ø'n,IY" ',' ",',',:/', ' ,,' ":,:".'.,:' ,.".. " , ' ,', Permit Numbe~l p) API Number APpr,'I)l B ~ J See cover letter 2.tr") - ,~Z(. , 50- 029-22402-01 for other reQuirements Conditions of Approval: Samples Required DYes IKI No Mud Log Requirec DYes (g No Hydrogen Sulfide Measures &I Yes DNo Directional Survey Required Œ ' Yes DNo Required Working Pressure for BOPE D2K D3K 0 4K~ 5K D10K D15K 0 3.5K psi for CTU Other: Original Signed BV / ~ IrJ/ó / by order of Approved By Cammy n. . .. Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit'ln tri licate ORIGINAl p f' :( ( 'Well Name: INK-22A Drill and Complete Summary L!ïPe of Redrill (producer or injector)-=-J Producer Surface Location: x = 721,865.42 / Y = 5,979,979.87 14351 FSL 6931 FEL S36 T12N R15E Umiat Target Location: x = 727,936.00 / Y = 5,983,158.00 4430' FSL 4676' FEL S32 T12N R16E Umiat Bottom Hole Location: x = 727,989.00 / Y = 5,983,168.00 4438'FSL 4623' FEL S32 T12N R 16E Umiat I AFE Number: 15L0522 1 Estimated Start Date: 112/15/01 ~ Doyon 14 lQperatin~s to complete: 116.0 I MD: 112,415' I I TVD: 19574' I I I Cellar Elevation: 119.2' I 1 RKB: 152.7' I Well Desi~(conventional, slim hole, etc.)~ Conventional Slimhole - 7-5/8" Sidetrack ~ective: 1 Niakuk Kuparuk Development Formation Markers Formation Tops MD TVDss Comments Base Permafrost SV3 SV1 Ugnu 4A West Sak 1 7271' Kick-off Point 10,040' 7303' Kick-off in lower-most West Sak Sands CM3/ K-12 10,205' 7414' Tuffs 11 ,498' 8629' Top HRZ 11,902' 9022' 9.6 ppg required as per HRZ shale study Top Kuparuk 12,181' 9293' Est. pore pressure 5335 psi (10.98 ppg EMW at Top Kuparuk at 9346' TVD) Base Zone 3A 12,280' 9390' TO 12,415' 9521' TD with-in Kuparuk Top Kinqak Not Reached TD Criteria: 135' MO below Base of Zone 3A to provide -50' of cased hole rat-hole. 6-3/4" Tubin Grade Conn Length Top Btm MDrrVD MDrrVD 12.6# L-80 H dril 521 -2515' 9,900' /7261' 12,415' / 9574' 12.6# L-80 IBT-M -9870' GL 9,900' / 7267' Page 1 NK-22A Permit to Drill . '- ( ( Directional KOP: I 10,040' MD Maximum Hole Angle: -510 At and above the planned KOP -130 From -10,640' to well TD. Close Approach Well: All wells pass BP Close Approach guidelines. The nearest close approach well is NK-06 which is -1012' welHo-well at 12,399' MD and passes under Major Risk rules. NK-06 was drilled from the NK-04 island and is P&A'd. Survey Program: Standard MWD Surveys from kick-off to TD. M dP u rogram 6-3/4" Production Hole LSND (10,040' to 12,415' MD) Interval Density PV VP Tauo pH HTHP (ppg) (cp) (lb/100ft2) (lb/1 OOfF) (cc's) Millina 9.4 9-12 25-35 3-8 Colville 9.4 - 9.6 1 0-15 20-25 4-7 8.5 - 9.5 Tuffs 9.6 1 0-15 20-25 4-7 8.5-9.5 (increasing to 11.4) HRl 11.4 12-18 20-25 4-7 8.5 -9.5 <9 Kuparuk 11.4 12-18 20-25 4-7 8.5 -9.5 <9 Open Hole: Cased Hole: MWD IGR IRes I PWD - Realtime over entire interval. Den I Neu - Recorded over entire interval. Sam Ie catchers throu h the Ku aruk interval onl . No 0 en hole 10 s are lanned. Cased hole USIT 10 for cement evaluation is lanned c tP emen ro~ ram Casina Size 4-1/2" Production Liner I Basis: Lead: None Tail: Based on 1635' of open hole with 30% excess and 83' of 4-1/2" shoe joint. Tail TOC: -11,010' MD (8209' TVD).- approximately 1400' MD above top Kuparuk. Fluid Sequence & Volumes: Pre 40 bbls Chemical wash at 8.3 ppg Flush Spacer 30 bbls MudPUSH Viscosified Spacer weighted 1.0 ppg over mud weight in hole Lead None Tail 54 bbl I 303 fe I 259 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.17 cf/sk, BHST 1930 I BHCT 1600 (use actual circulating temps recorded by MWD at TD), TT:::: Batch Mix + 3.5 to 4 hrs *See Attached Dowell Cement Program for Details on Cement Formulation* NK-22A Permit to Drill Page 2 ( ( Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential suriace pressures. Based upon calculations below, BOP equipment will be tested to 5000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 5335 psi @ 9293' TVDss - Kuparuk . Maximum surface pressure: 4406 psi @ suriace (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 5000 psi 8.7 ppg Seawater /6.8 ppg Diesel . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . NK-22A Permit to Drill Page 3 ( ( Sidetrack and Complete Procedure Summary Pre-Ria Work: 1. RU slickline, drift tubing and tag PBTD. Dummy off all GLM's. Test the integrity of the dummied off tubing string by applying -2000 psi on the annulus. 2. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement. Use adequate cement volume to fill the 7-5/8" casing from PBTD and extend the cement plug up into the tubing tail approximately 100', plus squeeze 5 bbls to the perforations. 3. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. 4. Test the integrity of the cement plug and 7-5/8" casing by simultaneously pressure testing both the tubing and 7 -518" annulus to 3500 psi for 30 minutes. 5. RU E-line. Cut the 4 Y2" 13Cr-80 tubing at approximately 10,500' MD using either a jet or chemical cutter. 6. Displace the well to clean seawater by circulating down tubing through the tubing cut. Freeze protect top 2200. MD with diesel. 7. Test the FMC 7-5/8" mandrel packott and tubing hanger seals to 5000 psi for 30 minutes. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Remove the well house and flowlines. If necessary, level the pad. Ria Operations: 1. MIRU Doyon 14. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. 3. Nipple down tree. Nipple up and test BOPE to 250 I 4000 psi. Pull TWC. 4. Pull and lay down 4-1/2" tubing from E-line cut and above. 5. MU 7-5/8" window milling assembly and RIH with 4" DP to top of tubing stub. Circulate well clean. POOH. 6. RU E-line and set CIBP to place top of whipstock at -10,040' MD, which is in a clean sandstone at the base of the West Sak. Test the 7-5/8" casing to 4500 psi for 30 minutes. 7. RIH with 7-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Displace to milling fluid and mill window in 7-5/8" casing. Perform leak-off test. POOH. 8. MU 6-3/4" PDC drilling assembly including MWD/GR/RES/NEU/DEN. RIH to whipstock. Kick-off and drill the 6-3/4" hole section as per directional plan to TD at +1-12,415' MD (9574' TVD). Condition hole for running liner, spot liner running pill, and POOH. 9. Run and cement a 4 Y2", 12.6# production liner. Displace cement with drilling mud. Release from liner and set liner top packer. Circulate hole clean above liner top with mud and wait on cement. Test wellbore to 2000 psi to verify liner top packer is set. If test is good, displace well to seawater above the liner top. POOH. 10. Run 4-1/2", 12.6# L-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" liner tie-back sleeve. 11. Drop ball/rod & set packer. Test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 12. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Freeze protect the well to -100' below the top GLM and secure the well. 14. Rig down and move off. Post-Ria Work: 1. RU slickline. Pull the ball and rod I RHC plug from 'XN' nipple below the production packer. Install gas lift valves. 2. RU CTU. RIH and displace drilling mud from 4-1/2" liner with clean filtered seawater. 3. RU e-line. Run USIT in 4-1/2" liner to evaluate cement across the Kuparuk. Perforate -160' of Kuparuk interval with 3-3/8" guns. NK-22A Permit to Drill Page 4 ( (' Job 1: MIRU Hazards and Contingencies ~ NK-42 is the only well requiring shut-in for the NK-22A rig move. The well is located -15' from NK-22 and requires well house removal for the move in of Doyon 14. The other immediate offset well, NK-23, is located 30' from NK-22 and will not require wellhouse removal or the need to be shut-in. NK-42 will need to be shut-in at the surface and the SSSV. All surface flowlines and gas lift lines will be depressured to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. ~ Heald Point Niakuk Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: NK-22 40 ppm Mar 29, 2001 (well was shut-in 2ndQ 2001) Adjacent producers at Surface: NK-42 40 ppm Aug 6, 01 NK-21 40 ppm Aug 6, 01 NK-20 25 ppm Aug 6, 01 N K-25 15 ppm Aug 6, 01 Adjacent producers at TD: All as above: NK-22, 21, 42 NK-18 20 ppm Jun 8, 00 (prior to switch to injection) The maximum recorded level of H2S on the pad was 60 ppm from NK-28 on June 15, 2000. "w"", " Job 2: Decomplete Well Hazards and Contingencies ~ The perforations in this well were P&A'd during pre-rig operations. However monitor the well for any signs of pressure. Prior to plugging, a static reservoir pressure of 5337 psi at 9300' TVDss was measured. ~ NORM test all retrieved well head and completion equipment. ,,' " ,,' "L", '" , , Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Job 7: Drilling Intermedia~roduction Hole Hazards and Contingencies ~ No fault crossings are planned in the drilling of NK-22A. As planned, the well bore will drill parallel to the large east/west-trending Niakuk fault with approximately 400' of separation at the Top Kuparuk Location and approximately 200' at TD. This fault will be south of the wellbore when entering the Kuparuk target and the target polygon should be adequately sized to assure this fault is avoided. ~ Cuttings gas and gas cut mud has been encountered within the West Sak interval at Niakuk. This interval does not contain substantial amounts of hydrocarbons and will not require cement isolation. The most recent Niakuk drilling history has shown this interval to be drilled with mud weights ranging from 9.1 to 9.3 ppg without any problems, nevertheless monitor for any signs of overpressure. ~ The NK-22A well path will drill full sections of the Tuffs and HRl shales, and both formations have been troublesome in the Niakuk area. The Tuffs is typically slow and erratic drilling, which can wipe out a PDC bit if proper drilling parameters are not maintained. The HRl on the other hand has shown severe hole instability problems. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. ~ The Kuparuk reservoir pressure is expected to be 5335 psi (10.98 ppg EMW) at the NK-22A bottom hole location. Because of low wellbore inclinations, the surrounding shale intervals only require mud weights in NK-22A Permit to Drill Page 5 (' (' the 9.6 ppg range. Therefore, the 11.4 ppg mud weight requirement is based upon approximately 200 psi overbalance to the estimated Kuparuk pressure. The pressure estimate is +/-100 psi, therefore, monitor the well closely after penetrating the Kuparuk for any signs of inadequate overbalance. ~ Differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the permeable West Sak or Kuparuk Sands. ~ The kick tolerance for the 6-3/4" open hole section would be a 23 bbl influx assuming a kick from the Kuparuk at -12,178' MD. This is a worst case scenario based on an 11.2 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 7-5/8" window, and 11.4 ppg mud in the hole. Prior to penetrating the reservoir, hold a Pre-Reservoir Safety Meeting to raise awareness of the low kick tolerance and communicate individual well control responsibilities to all members of rig team. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is NK-06 which is -1012' well-to-well at 12,399' MD and passes under Major Risk rules. Note tolerance lines and allowable deviation from the planned NK-22A well-path. Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ Long shale intervals will be exposed while running the liner. Rotation of the liner may be necessary if downward progress is not possible. To minimize ECD spikes and associated shale stability problems, bring pumps on slow and control downward surges with pipe. ~ Differential sticking could be a problem in the West Sak and Kuparuk. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. , WL",' IU,I " , '",' Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Job 13: ND/NU/Release Ria Hazards and Contingencies ~ See Job 1 for adjacent well spacing. These are close well centers. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ..""".."""" "', "...u",.""""",."",."'",,., " , ',.. " '," " """',', ,,' , ""."""." , ", "", " NK-22A Permit to Drill Page 6 TREE = 4-1/16" 5M CrN N~(-22 Current Sí~tus WELLHEAD = 13-5/8" - 5M FMC -----'--"'- --.-..----.----.- ACTUATOR = BAKER KB. ELEV = 37.33' --- BF. ELEV = 19' KOP= 1200' Max Angle = 54 @ 11 000' Datum MD = 12349' Datum ìVD = 8800' SS 6) 2061' I 10-3/4" CSG, 45.5#, NT-80S, ID = 9.953" I ST MD ìVD 6 3354 3000 5 7224 5513 4 9878 7194 3 11814 8399 2 12572 9011 1 12676 9107 5011' Minimum 10 = 3.725" @ 12846' 4-1/2" PARKER SWN NIPPLE 12740' 12795' 12795' -i 4-1/2" TRSV, HES CP-2 NIP, 10 = 3.813" I GAS LIFT MANDRELS DEV TYÆ VLV LATCH 46 CA-KBMG BK-5 51 CA-KBMG BK-5 51 CA-KBMG BK-5 43 CA-KBMG BK-5 24 CA-KBMG BK-5 18 CA-KBMG BK-5 !=DRT DA TE -i 4-1/2" PARKER SWS NIP, ID = 3.813" I -i SABL-3 W/KBH-22 ANCHOR LATCH, ID = 3.94" I -1 7-5/8" X 4-1/2" PKR, ID = 3.94" I I 7-5/8" CSG, 29.7#, NT95HS, ID = 6.875" I 12720' 12825' -i 4-1/2" PARKER SWS NIP, ID = 3.813" I 12846' -1 4-1/2" PARKER SWN NIP, ID = 3.725" I 4-1/2" TBG, 12.6#, NT13CR-80, 0.0152 bpf, ID = 3.958" 12867' 12867' -i 4-1/2" TUBING TAIL WLEG, ID = 3.96" I I 12848' l-i ELMD TT LOGGED 11/06/93 I ÆRFORA TION SUMMARY REF LOG: SBT 1116/93 ANGLEATTOPÆRF: 16 @ 12936' Note: Refer to Production DB for historical perf data Fill last tagged at 13,026' MD on 3/15/01 SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 12936-13036 S 02/26/94 3-3/8" 6 13052-13070 S 02/26/94 2-7/8" 6 12936-12963 0 10103/98 3-318" 6 12990-13010 0 03/27/01 I PaTD I 13401' 13417' 7-5/8" CSG, 29.7#, NT13CR-80, ID = 6.875" I 13516' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/31/93 ORIG COMPLETION, (!=DOL 7) 01/22/01 SIS-isl CONV ERTED TO CA NV AS 02/27/01 SIS-LG FINAL 09/09/01 RNfTP CORRECTIONS -i FISH - 3" X 28" BULLNOSE GUIDE - 11/06/93 I NIAKUK UNIT WELL: NK-22 ÆRMIT No: 93-135 API No: 50-029-22402-00 Sec. 36, T12N, R15E, 3392.54 FEL 237.37 FNL BP Exploration (Alaska) TREE = 4-1/16" 5M CIW , WELLHEAD = 13-5/8" - 5M FMC oooo.OO'OO"'OOOO'OOOOooOOOOoo"OOOOOOOOOOOOOO,oo oooo. """"",ooOOooooOOOO.oo.oooooooo.oo,oooooooo,oo. , ACTUATOR = BAKER .",.", ""'W"'^'-"""'^""""""""""""'W"'""'w' "WM""" """""'"""""w."'w"'" KB. ELEV = 37.33' BF. ELEV = 19' ......""."",.".""",."""""'","',',,,w,..w,',,',W..,w...,..,"",',^""""""",'"""""" KOP= 120a oooooo 'oo' ,oooo" ,oou ...oou uOOOO 'uoou, oo,u u ,oo...,... uoo 'oou "u",'u"'u 'u Max Angle = 54 @ 11000' ".' ..-' ",_.",wW"-"'-""W'-,.'ww'w"',"w'wW"W"""""",,',,,w',,'"""... Datum MD = 12349' oo,oo, " Datum 1VD = 8800' SS Nu :-22 Proposed Prl Rig 2061' 18!\, .,'1",','", . ST MD 1VD 6 3354 3000 5 7224 5513 4 9878 7194 3 11814 8399 2 12572 9011 1 12676 9107 I 10-3/4" CSG. 45.5#. NT-80S. ID = 9.953" I 5011' Tubing cut at -10,500' MD -l 4-1/2" TRSV. HES CP-2 NIP, ID = 3.813" I GAS LIFT MANDRELS DEV ìYPE VLV LATCH 46 CA-KBMG BK-5 51 CA-KBMG BK-5 51 CA-KBMG BK-5 43 CA-KBMG BK-5 24 CA-KBMG BK-5 18 CA-KBMG BK-5 PORT DATE 12740' -i 4-1/2" PARKER SWS NIP, ID = 3.813" I 12795' -1 SABL-3 W/KBH-22 ANCHOR LATCH, ID = 3.94" I 12795' -1 7-5/8" X 4-1/2" PKR, ID = 3.94" I Top of Cement P&A Plug at -12,767' MD I 7-5/8" CSG, 29.7#, NT95HS, ID = 6.875" I 12720' 12825' -l 4-1/2" PARKER SWS NIP, ID = 3.813" I 12846' -i 4-1/2" PARKER SWN NIP, ID = 3.725" I 4-1/2" TBG, 12.6#, NT13CR-80, 0.0152 bpf, ID = 3.958" 12867' 12867' -l 4-1/2" TUBING TAIL WLEG, ID = 3.96" I I 12848' l-i ELMD TT LOGGED 11/06/93 I PERFORATION SUMMARY REF LOG: SBT 11/6193 ANGLE AT TOP PERF: 16 @ 12936' Note: Refer to Production DB for historical perf data , Cement , P&A. Plug Fill last tagged at 13,026' MD on 3/15/01 SIZE SPF INTERV A L Opn/Sqz DATE 3-318" 6 12936-13036 S 02/26/94 3-3/8" 6 13052-13070 S 02/26/94 2-7/8" 6 12936-12963 0 10103/98 3-318" 6 12990-13010 0 03/27/01 13401' I PBTD I 13417' 7-5/8" CSG, 29.7#, NT13CR-80, ID = 6.875" I 13516' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/31/93 ORIG COMPLETION, (POOL 7) 01/22/01 SIS-isl CONV ERTED TO CA NV A S 02/27/01 SIS-LG FINAL 09/09/01 RNlTP CORRECTIONS -l FISH - 3" X 28" BULLNOSE GUIDE - 11/06/93 I NIAKUK UNIT WELL: NK-22 PERMIT No: 93-135 API No: 50-029-22402-00 Sec. 36, T12N, R15E, 3392.54 FEL 237.37 FNL BP Exploration (Alaska) ( NK-22A Proposed Completion TREE: 4-1/16" - 5M CIW WELLHEAD: FMC 135/8" UNIVERSAL (SH) Actuator: Baker 103/4",45.5 #/ft, NT-80, BTC I 5011' I BAKER 7 5/8" x 4 1/2" Liner Tie Back Sleeve zXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger Window Milled from Whipstock Top of Window at +/-10,040' MD Bridge Plug set at +1-10,058' Mrr--- Pre-Rig Tubing Cut at +/-10,500' Top cement P&A plug at -12,700' MD 7-5/8",29.7 #/ft, NT95HS NSCC to 12,720' XO to 7-5/8" 29.7#/ft, 13Cr80 NSCC 113,516' I Date 11/26/01 Rev By WSI Comments Proposed Completion GL. ELEV = 19.2' Doyon 14 RKB = 52.7' 4-1/2" Halliburton 'CP-2' tubing retrievable SSSV wI control line to surface. 1+1-2200' 1 4-1/2" Cameo 'KBG-2' GLM's with handling pups installed. ---------------- G A s-Lï-Fi-MA N DRE-LS----------' ------------l ------------ ------------------------- -, --,.._, --- '.------------.--,------- # TVD Size Valve Type ---- -------,------~---- ----'.----------------- 1 2 3 4 TBD TBD TBD TBD DV RP Shear DV DV 4 1/2" X 1" 41/2"x1" 41/2"x1" 41/2"x1" ----- --------,--, ._----------,----------,--,--,-- --.---.--,----------- 4-1/2" 12.6# L-80, IBT-Mod Tubing 4-1/2" 'X' Landing Nipple with 3.813"seal bore. 7 5/8" x 4-1/2" Baker '5-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into liner top. Plug Back Depth I +/-12,330' I 4-1/2",12.6 #/ft, L-80, HYD 521 I +1-12.00 NIAKUK WELL: N K-22A API NO: 50-029-22402-01 GPB Drilling & Wells spef"""íI\/-SUI1 bp ø..~.JJ..J..iIi.~-$_II!..I!!.Y-',Ç_I!i._$! North Slope Alaska A HIIIU>utton Compl"" Proposal Data for NK-22A WPO5 NIAKUK NK-22A WPO5 DrillQuest- Single Well Target Data for NK-22A WPO5 --'_____n n'__.n.__--_.. -- -,_.". ..... -.. ....-..- n_.-..- - ...-- -. -- .....-.. -. -- -- -. -- --..-- Target Shape ~?';V "," ~'l"." ",.,~ !\'(~Hn','f!:l/o(~"c" , .. 'N.~I '" ~.....I. \"" ",,"2,1' ,/'Ä~";' "., \.' ~I{~).{~],.,/" ./' ~i'~)O.()(~",.,"""""- """"" -"" ,vA.,22,\ 1'/1 7!)()O~<'."- J)I'ÙlffS ':(>{)'I:;"I (\\. .'/1/% ,/ ',,' "~()()O(\ /"'1 \...' '0 .., i.>"" . ." . 41/2.LI ,., "", nor.. ,/' f \ 12415.221\ MD "",.., 00. 0 , , \ I 9574.0911 TVD ~ 710000,/ " . 840Efoo ""'" \ "-'N".?2-". WPO5 \. ':""""", Nli,U11'I,;\ I': ',/ "'. ~J4S.7//' lTV ^.t':;,2,/(~,"'" I', \ ).'1.";'.(1.1 N. 6/61.11/11: ,,',,-_..\ .",1' (.II(' " \ 6.3/4" Hole, Total Depth: 12415.22ftMD,9574.09ftTVD Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Measurement Units: ft Coordinate Point Type Well Well ft True North Target Name Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 64.180° Vertical Section Descriptlon:Well Vertical Section Origin: 0.00 N,O.DO E Measured Incl. Azlm. Vertical Northlngs Eastlngs Vertical Dogleg Depth Depth Section Rate WO40.20 50.76~ 6~J62 n55.86 27R2.26 N 55~O.99 E 6190.61 I (X)60.20 51.0I~ 60.286 7368.48 27119.59 N 5544.67 E 6206.12 12.(KX) 10135.20 47.406 55.243 7417.4R 2819.79 N 5592.70 E 6262.5\ 7.000 10655,(>:\ 13.270 110.996 7860.1)() 2942.23 N 5816.15 E 6516.98 6.1Œ9 12180.56 13.270 110.996 9345.70 2997.03 N 6162'();)E 6852.17 O,(););) 12280.22 13.270 80.996 9442.70 30(X).61 N 6184.60 E 6874.07 O.O(X) 12415.22 1~.270 80.996 9574.09 ~O05.46 N 62J5.20 E 6903.73 (UKK) NK-22A Drillers Pnlygoll (eI <¡if;;' Enlry PoilU Bounúary Point A B C D E F G H I J K l. M N 0 ----'--'-.------------.------.-------.-------..------.-------------------..-...--.......---..-..---.-------. NK-22A TIA EJllrY Point 3300 3100 2900 .:s:: 0 0 (\ II .c. 0 .S ,... ","~(lO (~) ",/' \ ... ,,;.,., / ,.,0' /' ,.,., )\/../'. / Decrease In Dlr Rate @ 6.889°'100lt: 10135.201t MD. 7417.481t TVD . / Begin Dlr @ 7.000°/10011: 10060.2011 MD, 7368.48ft TVD ST Exit: Start Dlr @ 12.0ooo'1001t 85.00° Left TF: 10040.20ftMD,7355.86ftTVD End Dir. Start Sail @ 13.270. : 10655.03ftMD,7860.90ftTVD Q) 270ÒÎ. \ n:s 0 Cf) 5400 5600 Scale: 1 inch = 200ft 5800 6000 6200 Eastings (Well) n..,""""__'~~~~~~~~ TVD 11:\45.70 11:\45.70 'H4S.70 \I~5.70 9:\45.70 9:\4S.70 9345.70 9345.70 '1345.70 934S.70 9345.70 9~5.70 934S.70 934S.70 9345.70 934S.70 9345.70 6400 Northing. Eastlngs SSTVD Northlngs Eastlngs ASPY ASP X 2'J97.03 N 6162.00E 92\13'(K) 59S315!1.00 N 727936.00 E 3024.33 N 6lbl.R8 E \1293.00 5983\R5.29 N 727935.07 E 3023.11 N 6175.40 E 9293,(K) S9S3184.47 N 7279411.62 E 3016.34 N 61111.lKI F. 9293.00 51/!l317S.16N 727964.41 E 3000.61 N 62(KU)6 E 1/2\l3'(K) 59S311>2.71 N 7271/73.93 E 29RMII N 6194.20 E 9293.IK) 5983145.61 N 727\168.58 E 2973.23 N 6181.56 E \/293.<X1 5983134.79 N 7271156.25 E 2967.75 N 6168.68 E \l293.0() 5983128.93 N 727943.54 E 2965.11 N 6155.92 E '1293.00 5IJ!l312.~-92 N n793()$6 E 29ti5.12N 6142.mE \/293.00 5983125.51 N 727\/16.\15 E 291'>9.44 N 6126.21 E 9293.00 598312l .37N 727~)I.O4 E 2982.21 N f>l13.15 E ~)293.W 5983/41.75 N 7~7I1S7.1'; E 3()(Xl51 N 6114.45 E 'J293.(XJ 598311>0.07 N 727888.31> E 3013.42 N 6126.45 E 9293,(K) 5983173.33 N 727X99.9XF. 30 9.92N 6138.97 E 9291<X) 5'1113180.20 N 727912.30E 302112 N 6150.32 E 92\13.00 5983183.74 N 727923.55 E 2\197.<J3 N 61 b2.W E 'J293,(K) 59S3\ 5s'(x) N 727'J3I>.IX) E b ----. Polygon Circle- ( , Current Well Properties """""""""""""""""""""""'-...................."............................-....................................................................................,..,...................""-""""""""""""""""""""""" Well: NK.22A WP05 Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: 5979979.87 N, 721865.42 E 5524.28 S, 5726.10 E 70020' 51.2211" N, 148011' 55.4647" W North Reference: Units: 52. 70ft above Mean Sea Level 52. 70ft above Structure True North Feet (US) 6600 6800 7000 Reference is True North spe~i'~-su" bp IU!l\,;J....lR~A!~!~~~~ North Slope Alaska 7200 7600 8000 ~ "Q) 3: - :5. 8400 Q) 0 co u 1:: Q) > 8800 9200 -= 0 0 ~ II .c. 0 c :;= 9600 Q) (ij 0 C/) ~.."',..,,... ~ ~~ ~~ ,,~~ ..-.--.-.. '~SI~1,(J() "'- 'ST Exit: Start Dir 0 12.0000/100ft 85.00. Left TF : 10040.2OftMD,7355.86ItTVD "",- / "'- / -- Begin Dir 0 7.000°/100II: 10060.201t MD, 7368.481t TVD :J(ffiia)iao Decrease In Dir Rate 0 6.889°/100ft: 10135.2011 MD, 7417.4811 TVD ".""""""""""""" ......................................................T9P.Ç~1~1.~~~6..?C?I!.1'!9 Vertical Origin: Horizontal Origin: Measurement Units: North Reference: "'-",- "-", (Ht~I.U(J End Ojr. Start Sail @ 13.270°: 10655.03I1MD.7860.9011TVD 1°40«:00 / ',../ I"', / 'J""')() ,,1):\1\ . X / '" " "'-" "', '" 1111001\0 ", " " " , '", ¡ 13,)I1,IX1 "', "".""" '", "', "-, 11(;0(\ (10 ',,- ' "'- '" '" '. """':.;119(1\).\)\) ,I\" 1,'"" ,. '\. ':'/ :\ '1". " ......, ....., .".. ................... ".." ..... ...... ....... ..... ..... ............., ..... ..T!,p.1,~~r~,.~.6~IJ}.(!I!J.v.~.. ...<;>:~!:: .. ..... ...... ..... "'" .......... .... """ ..... ........". 1.1.~q9,q9... ".. .."""'" ..... ...1.~p.!i!~2;.~QI1.!9!t.!,Y\?.. ...... -z. ~ ~ £ ""'" ~ """""'" ~ ... ".'.".."'" .........., "'" """,."". ...........~.~~'..... NA.2}.1 V/'íll<m' l'.)~vg()¡' (1; 90".}. :vg.::~,\ '1'1 A "1./4:;]/1' nil) ,,'I<¡i.l13i,....MtU.I¡flli 8E>:ee-.. ...... ..... ....!~P}~'!11'1r.u)<...~~~~.?9t'.1.:yg.., ...... .. ........ ....,... "". ... .""'. ........., ..... ..... ........... ...... ..... ,.!3.(\$I§'.~'! !C1.~w.~e.??!1.!'.~~"f ~j~¿r.q,f!:r.v.Q... ....... 4 1/2' LIner 12415.2211 MD 9574.0911 TVD 6-3/4" Hole, Total Depth: 12415.22ftMD,9574.09ftTVD 6000 Scale: 1 inch = 400ft 6400 6800 7200 7600 Section Azimuth: 64.180° (True North) NIAKUK NK-22A WPO5 DrillQ uest" Proposal Data for NK.22A WPO5 Well Well ft True North 50.763 51.013 47.406 13.270 13.270 13.270 13.270 63.362 60.286 55.243 80.996 80.996 80.996 80.996 .. --------- --... --- -- .------.. .--- ..--- -_.. -.-... .-.. -" --- ..-...... , "-' ---. ...- ..--.. ..--..,. ..' - -- -- ----,. -. -- - --- -. - -- - -- --.,.- Vertical Depth 7355.86 7368.48 7417.48 7860.90 9345.70 9442.70 9574.09 --'-----"-----"'--------- '------"-----..,-..---.-- Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 64.180° Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azim. Depth 10040.20 10060.20 10135.20 10655.03 12180.56 12280.22 12415.22 Northings Eastings Vertical Dogleg Section Rate 2782.26 N 5530.99 E 6190.61 2789.59 N 5544.67 E 6206.12 12.000 2819.79 N 5592.70 E 6262.51 7.000 2942.23 N 5816.15 E 6516.98 6.889 2997.03 N 6162.00 E 6852.17 0.000 3000.61 N 6184.60 E 6874.07 0.000 ", 3005.46 N 6215.20 E 6903.73 0.000 t.--- Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: Current Well Properties NK-22A WPS 5979979.87 N, 721865.42 E 5524.28 S, 5726.10 E 70020' 51.2211" N, 1480 11' 55.4647" W North Reference: Units: 52. 70ft above Mean Sea Level 52. 70ft above Structure True North Feet (US) -,.. --.--- -.--.--..---- - .--..----, ..0- --...- """ -.. -- -, --... --0' - ...-.. ...-- --.., -.... .....,. .. ---..,. -.' "........ -. --"'- ..--... .' ,--,..., - -. -"""--"""'" -.... -, - -- ' ( 1~1'!:'::~" , ~~ '. ~"', '.-';II;¡"'" ~~:tllo "~.'., ... ~)..,. ..,.'. "o;;;;j'¡ft" . ~:,¡,.:;;:", .ri:'"k',11 .'" ,,\ I:¡:f.~" "~';'r,~t "~ßi\;,;,(\ r/i"'" ..,. '.,' 'f"~;:.:::::r ;i:"'~:~I~ .f ,,".. ,ot'~:. :'!";; , " - " " " "",,, ,,' ""h SlQS,( !'Alaska 4"."" "oril17ng & Wells ", ,,""';"tf'~ , Slot NK-22A N.I{-r.22A WPS - N K -22A WPO5 Revised: 26 November, 2001 c-- PROPOSAL REPORT 26 November, 2001 ( ",,- Surface Coordinates: 5979979.87 N, 721865.42 E (70020' 51.2211" N, 148011' 55.4647" W) Surface Coordinates relative to Project H Reference: 979979.87 N, 221865.42 E (Grid) Surface Coordinates relative to Structure: 5524.28 S, 5726.10 E (True) Kelly Bushing: 52. 70ft above Mean Sea Level spal'l'y-sul! DAIL..L..ING SE!iRVIc:es " " A Halliburton Company Proposal Ref: pr011017 North Slope Alaska Measured Depth (ft) NK-22A Recca 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 Incl. 0.000 0.427 0.409 0.583 1.386 2.052 2.805 4.022 6.315 7.591 8.574 9.455 10.479 11 .279 12.055 13.490 14.875 16.347 18.133 20.251 22.750 26.028 28.750 29.922 31.694 32.700 33.623 35.751 36.684 38.787 Azim. 0.000 134.945 125.673 121.842 101.996 91.921 84.685 72.624 69.382 68.585 65.272 65.592 69.062 70.213 65.284 64.386 62.867 64.331 61.541 60.665 55.492 53.071 53.370 55.638 57.900 59.343 58.895 59.071 60.708 62.304 Sub-Sea Depth (ft) -52.70 47.30 147.30 247.29 347.28 447.23 547.14 646.97 746.55 "," 845.81".,',. " '" Vertical Depth (ft) 0.00 100.00 200.00 299.99 399.98 499.93 599.84 699.67 , ..;??I~~'à:;1,;"",. '."""',.' 944.81". 991-;§1 ~ ~:~:~~l~,~:~:~~ 1240.27 1292.97 1338.21 1390.91 1435.73 1532.69 1629.00 1724.51 1818.95 1912.01 2003.07 2091.80 2179.00 2264.86 2349.47 2433.23 2515.41 2596.13 2675.20 1488.43 1585.39 1681.70 1777.21 1871.65 1964.71 2055.77 2144.50 2231.70 2317.56 2402.17 2485.93 2568.11 2648.83 2727.90 Sperry-Sun Drilling Services Proposal Report for NK-22A WPS Revised: 26 November, 2001 Local Coordinates Northings Eastings (ft) (ft) 12.22 N 18.76 N 25.40 N 31.88 N 39.59 N 48.98 N 59.93 N 71.80 N 85.34 N 101.13 N 120.58 N 144.79 N 172.43 N 200.84 N 228.89 N 256.57 N 284.63 N 314.03 N 343.64 N 372.79 N 0.00 E ',""O:28E ',.'0.83 E ,,',1.51 E '.'S,.13,E '""..,;,'-"" 6.10 E 10.32 E 16.03 E 24.58 E 35.91 E 48.82 E 63.05 E 79.04 E 96.77 E 115.40 E 135.42 E 157.33 E 181.46 E 207.80 E 236.61 E 267.58 E 301.05 E 337.93 E 377.79 E 420.68 E 466.21 E 513.09 E 561.89 E 612.94 E 666.76 E Global Coordinates Northings Eastings (ft) (ft) ,','. 5979,9~9;aI,~ ' ' 5979979.59 N 5979979.14 N 5979978.68 N 5979978.20 N 5979977.97 N 5979978.23 N 5979979.66 N 5979982.93 N 5979987.59 N 5979993.53 N 5980000.49 N 5980007.60 N 5980014.60 N 5980022.86 N 5980032.84 N 5980044.43 N 5980057.01 N 5980071.32 N 5980087.96 N 5980108.31 N 5980133.50 N 5980162.23 N 5980191.81 N 5980221.11 N 5980250.13 N 5980279.56 N 5980310.40 N 5980341.50 N 5980372.23 N 721865.42 E 721865.71 E 721866.27 E 721866.96 E 721868.60 E 721871.58 E 721875.79 E 721881.46 E 721889.92 E 721901.11 E 721913.86 E 721927.89 E 721943.67 E 721961.21 E 721979.60 E 721999.33 E 722020.91 E 722044.68 E 722070.60 E 722098.93 E 722129.32 E 722162.05 E 722198.10 E 722237.10 E 722279.14 E 722323.83 E 722369.86 E 722417.76 E 722467.92 E 722520.85 E Dogleg Rate (o/100ft) 0.427 0.070 0.176 0.861 0.729 0.812 1 .407 2.310 1.280 1.087 0.882 1.187 0.829 1.263 1.449 1.434 1.523 1.968 2.137 3.134 3.426 2.726 1.614 2.116 1.266 0.955 2.130 1.344 2.319 Vertical Section 0.00 0.13 0.42 0.82 2.05 4.59 8.44 14.13 23.14 35.22 49.27 64.93 82.21 101.00 121.13 143.24 167.73 194.62 224.22 257.04 293.39 334.05 379.29 427.55 478.37 531.42 585.83 642.57 701.42 762.56 . Alaska Drilling & Wells NIAKUK Comment c--- ( "'" "nono, no,'n m n n m ,n'..m "n n n n m m,' n..", non n.n" nono nnonno.no .no.n",", n. n", nnono" .no...... ......non nno.. n........".. uno n n'nono'.non..........no. n uno_non nono '.nono no..no.. nn n nono.... .nn.nonnonon nnno. no.",""""'" n- _non.. n...no."no .....-...........- nno.non....._no"," .............. m......n',," ........... n...n...nono .nono uno nono.no.. no"""""""" .nno.n uno .no. ...... n....... no mno _no non uno m........""" ...n- n.. n n.. ..... nono.. nono.no m.' n.. n... m.."'" ".......". n n n n n n.no n n n'. no............."'" n n_... n. m m..... -. ..... ..nonno nno' no 26 November, 2001- 15:31 Page 2 of 10 DrillQuest 2.00.09.006 North Slope Alaska Measured Depth (ft) 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 Incl. 40.719 43.227 44.652 45.376 46.111 46.268 46.661 48.904 49.513 50.268 50.914 51.306 50.842 50.317 49.645 49.472 49.560 48.621 48.041 48.466 48.813 48.887 48.851 48.709 48.497 49.148 49.906 50.136 50.490 50.762 Azim. 62.913 63.915 65.210 63.572 61.940 61.547 61.589 64.130 64.221 66.861 66.724 66.308 65.000 63.477 65.227 65.251 66.107 66.948 64.910 63.619 61.788 64.277 62.320 62.227 62.641 61.817 60.870 62.082 61.303 60.734 Sub-Sea Depth (ft) 2752.11 2826.40 2898.38 2969.08 3038.84 3108.07 3177.04 3244.16 3309.50 3373.92 Sperry-Sun Drilling Services Proposal Report for NK-22A WPS Revised: 26 November, 2001 Vertical Depth (ft) 2804.81 2879.10 2951.08 3021.78 3091 .54 3160.77 3229.74 3296.86 3362.20 3426.62 Local Coordinates Northings Eastings (ft) (ft) 402.20 N 432.16 N 461.85 N 492.42 N 525.27 N 559.44 N 594~O3J9". .,:~~~ '"",.,, , ;:~~ :~~ .,(::.'~~~~~~à:.: ;~~~:¡~~"t,." ;~~~¡~~ ""."j 3690.79~~7:43:49 ,<:,,'::'/, ".. ::'i¿2~7iN :,',;:-is:f76 N .. 785.81 N 819.53 N 852.60 N 3755.67 3820.55 3886.05 3952.58 4019.16 4085.23 4151.03 4216.81 4282.70 4348.87 4414.72 4479.60 4543.86 4607.71 4671.15 '."i."" 3808.37 3873.25 3938.75 4005.28 4071.86 4137.93 4203.73 4269.51 4335.40 4401.57 4467.42 4532.30 4596.56 4660.41 4723.85 884.50 N 915.85 N 945.83 N 976.30 N 1008.66 N 1 043.29 N 1077.23 N 1111.15N 1146.18 N 1180.82 N 1215.88 N 1252.47 N 1288.97 N 1325.47 N 1362.97 N 723.50 E 783.34 E 846.09 E 909.86 E 973.53 E 10,37.09 E'" 1100.79,1$ '. 11'66172}E 1234.81 E 1304.48 E 1375.50 E 1446.93 E 1517.82 E 1587.33 E 1656.38 E 1725.46 E 1794.80 E 1864.16 E 1932.31 E 1999.53 E 2066.13 E 2133.34 E 2200.58 E 2267.16 E 2333.65 E 2400.25 E 2466.96 E 2534.33 E 2602.08 E 2669.68 E Global Coordinates Northings Eastings (ft) (ft) 5980403.31 N 722576.70 E 5980499;O3N ,.722635.63 E 5~8d4Ø~.57N 722697.47 E . 5980499:01N 'i' 722760.31 E , " , 5980533.73 N 722822.98 E ... ", , '.. '¡, ' '.. ,..'" .., "'-". 's9s6569.77 N 5980606.22 N 5980641.83 N 5980676.93 N 5980710.52 N 5980743.04 N 5980776.14 N 5980810.27 N 5980846.04 N 5980881.13 N 5980915.07 N 5980948.45 N 5980980.47 N 5981012.95 N 5981047.28 N 5981083.86 N 5981119.78 N 5981155.68 N 5981192.66 N 5981229.26 N 5981266.27 N 5981304.82 N 5981343.30 N 5981381.79 N 5981421.27 N 722885.49 E 722948.05 E 723013.05 E 723080.12 E 723148.83 E 723218.92 E 723289.41 E 723359.31 E 723427.79 E 723495.83 E 723563.94 E 723632.32 E 723700.77 E 723767.98 E 723834.22 E 723899.76 E 723965.93 E 724032.14 E 724097.65 E 724163.09 E 724228.62 E 724294.22 E 724360.48 E 724427.12 E 724493.58 E Dogleg Rate (0/100ft) 1.971 2.596 1.684 1.366 1.381 0.324 0.394 2.928 0.613 2.156 0.654 0.509 1.118 1.289 1 .499 0.174 0.657 1.134 1.629 1.053 1.4.17 1.875 1.474 0.157 0.377 0.900 1.045 0.957 0.696 0.517 Vertical Section 826.45 893.37 962.78 1033.50 1105.12 1177.21 1249.54 1323.64 1399.34 1475.79 1552.98 1630.78 1708.55 1785.80 1862.36 1938.44 2014.52 2090.01 2164.62 2239.23 2314.26 2389.54 2464.85 2540.03 2614.98 2690.19 2766.19 2842.72 2919.61 2996.79 . Alaska Drilling & Wells NIAKUK Comment c--- ( """-'-""""""'-"""-"""""""""-""""""""""""'"""""""""""""""""""""""""""""""""""""""""""""...................................................................................,...................................................-.....,...........................,.......""""""""""""""""""""""""""""""""""""""""""""""'"""""""""""""""""""""""""""""""""""""""""""""-"""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""'-"""""...............""""""",-"-,,, 26 November, 2001 - 15:31 Page 3 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for NK-22A WPS Revised: 26 November, 2001 Alaska Drilling & Wells North Slope Alaska NIAKUK Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 0 Oft) ..,' 6000.00 50.945 61.084 4734.28 4786.98 1400.68 N 2737.44 E 5981460.98 N ." " 1;?4560 .20 E 0.327 3074.21 6100.00 51.189 61.570 4797.06 4849.76 1437.97 N 2805.77 E 598150.oZ27:N, ' , ,7~4627 .39 E 0.449 3151.96 6200.00 50.181 60.682 4860.48 4913.18 1475.35 N 2873.45 E 598f539.64~ .. 724693.93 E 1.219 3229.16 6300.00 50.395 60.948 4924.33 4977.03 1512.86 N 2940.65 E ' , 598157S.12N. 724760.00 E 0.295 3306.00 l- 6400.00 49.693 60.778 4988.58 5041 .28 1550.17 N 3007:58E 59Sf618iaSN 724825.79 E 0.714 3382.49 """','(, 6500.00 49.686 60.712 5053.25 5105.95 3(>74.10 E.: 1'657.68 N 724891.17 E 0.050 3458.63 6600.00 49.113 61.955 5118.33 5171.03 3140.71""E',',,' 5981696.04 N 724956.68 E 1.105 3534.45 6700.00 48.856 62.848 5184.03 5236.73 320:Z:53E' 5981732.93 N 725022.44 E 0.721 3609.81 6800.00 49.948 63.435 5249.05 5301.75 3275.36 E 5981769.14 N 725089.23 E 1.180 3685.77 6900.00 49.970 61.926 5313.40 5366.10 3343.27 E 5981806.44 N 725156.05 E 1.155 3762.28 7000.00 50.431 64.479 5377.43 ,.,5,~;39.1", ß4 3411.90 E 5981842.94 N 725223.64 E 2.015 3839.07 7100.00 51.084 63.849 5440.66 ", ""5493;36, ,.6.64 N 3481.61 E 5981878.79 N 725292.31 E 0.815 3916.54 7200.00 51.136 63.975 5503.44 5556.~4 '1830.86 N 3551.52 E 5981915.07 N 725361.18 E 0.110 3994.38 7300.00 51.085 64.185 5566.23 5561 ~;,~3 1864.96 N 3621.48 E 5981951.23 N 725430.10 E 0.171 4072.21 7400.00 51.134 65.990 5629.00 i,...?6ß1.70 1897.65 N 3692.13 E 5981985.99 N 725499.76 E 1.405 4150.05 ',',,',),"'" 7500.00 50.832 65.494 5691.98 5744.68 1929.59 N 3762.93 E 5982020.01 N 725569.58 E 0.490 4227.69 7600.00 51.138 65.669 5754.94 5807.64 1961.70 N 3833.68 E 5982054.20 N 725639.35 E 0.335 4305.36 7700.00 51.469 65.707 5817.43 5870.13 1993.87 N 3904.82 E 5982088.46 N 725709.50 E 0.332 4383.41 7800.00 51.199 66.172 5879.92 5932.62 2025.59 N 3976.15 E 5982122.28 N 725779.86 E 0.452 4461.43 7900.00 51.175 64.464 5942.58 5995.28 2058.24 N 4046.91 E 5982157.01 N 725849.62 E 1.331 4539.35 8000.00 50.888 65.069 6005.50 6058.20 2091.37 N 4117.21 E 5982192.20 N 725918.92 E 0.551 4617.07 ( 8100.00 51.255 65.466 6068.33 6121.03 2123.84 N 4187.91 E 5982226.76 N 725988.62 E 0.480 4694.85 8200.00 51.433 64.498 6130.78 6183.48 2157.06 N 4258.60 E 5982262.05 N 726058.30 E 0.776 4772.95 8300.00 51.247 67.302 6193.26 6245.96 2188.75 N 4329.95 E 5982295.84 N 726128.67 E 2.197 4850.97 8400.00 51.174 65.975 6255.89 6308.59 2219.67 N 4401.51 E 5982328.87 N 726199.29 E 1.036 4928.86 8500.00 50.722 65.054 6318.92 6371.62 2251.91 N 4472.13 E 5982363.19 N 726268.93 E 0.846 5006.48 8600.00 50.699 65.537 6382.21 6434.91 2284.28 N 4542.47 E 5982397.62 N 726338.27 E 0.374 5083.88 8700.00 50.044 65.968 6446.02 6498.72 2315.77 N 4612.72 E 5982431.18 N 726407.57 E 0.734 5160.85 8800.00 49.938 63.732 6510.28 6562.98 2348.40 N 4682.04 E 5982465.85 N 726475.89 E 1.716 5237.45 8900.00 49.285 63.030 6575.11 6627.81 2382.49 N 4750.12 E 5982501.94 N 726542.93 E 0.844 5313.58 .... """".........., -_.,............ ............. -0"'" ..... -"'-"""""'" ........-.-........ ................ ....... ... ........... """""" ....................... ....... .................."""- ........ ........... ... ........... ......... "-" ...... ............ ....... "'" ............ ................ "" """""""""""'" "'-"""""""""""'" """"""""""""""""""'- "'-'" .................. .........,.. .................. """""""""""" .... """""" .................".. """'" .............. ....... .... """-""'" ............. ,... """"""""""""'" ...- --..,...-......., ,.. ...".......... ......-..... ---.........,.. .......""- 26 November, 2001.15:31 Page 4 of 10 DrillQuest 2.00.09.006 North Slope Alaska Measured Depth (It) 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 10000.00 10040.20 NK-22A WP05 10060.20 10100.00 10135.20 10200.00 10204.87 10300.00 10400.00 10500.00 10600.00 10655.03 Incl. 49.288 48.451 49.507 49.837 49.677 51.315 51.511 51 .604 51.010 50.894 50.921 50.763 51.013 49.071 47.406 43.012 42.682 36.258 29.557 22.955 16.572 13.270 Azim. 61.944 62.714 63.572 62.780 63.568 62.328 62.546 62.464 63.644 63.280 62.861 63.362 60.286 57.678 55.243 56.358 56.449 58.496 61.453 65.940 73.716 80.996 Sub-Sea Depth (It) 6640.29 6706.16 6771.76 6836.45 6901.15 6964.69 7027.06 7089.19 7151.73 7214.74 Vertical Depth (It) 6692.99 6758.86 6824.46 6889.15 6953.85 7017.39 7079.76 7141.89 7204.43 7267.44 Sperry-Sun Drilling Services Proposal Report for NK-22A WPS Revised: 26 November, 2001 Local Coordinates Northings Eastings (It) (ft) 2417.60 N 2452.55 N 2486.57 N 2521.06 N 2555.38 N 7277.77 7303.1 7315.78 7341.34 7364.78 7410.43 7414.00 7487.40 7571.31 7660.95 7755.03 7808.20 7368.48 7394.04 7417.48 7463.13 7466.70 7540.10 7624.01 7713.65 7807.73 7860.90 2789.59 N 2805.30 N 2819.79 N 2845.65 N 2847.48 N 2880.04 N 2907.31 N 2927.07 N 2939.04 N 2942.23 N 4817.34 E 4883.96 E 4951.34 E 5019.35 E 5QS7i:44E ' '."""" '5~56.17 5" 52 . 5364.54 E 5434.01 E 5503.19 E 5530.99 E 5544.67 E 5570.81 E 5592.70 E 5630.71 E 5633.47 E 5684.38 E 5731.32 E 5770.84 E 5802.37 E 5816.15 E Global Coordinates Northings Eastings (It) ,,' (It) ,'. ' """". 5982539.qgN<i'", ~?~609.08 E 59825.7.S¡93N"!i:Z26674.64 E 5~8261!j~93~: "f2$740.98 E 59a26~8:4tN.' 72$807.94 E 5982684.73 N 726874.99 E 5982721.94 N 5982760.13 N 5982798.40 N 5982835.74 N 5982872.47 N 5982909.73 N 5982924.65 N 5982932.38 N 5982948.85 N 5982963.99 N 5982990.96 N 5982992.88 N 5983026.93 N 5983055.57 N 5983076.50 N 5983089.39 N 5983092.98 N 726942.64 E 727010.85 E 727079.21 E 727147.73 E 727216.15 E 727284.25 E 727311.62 E 727325.07 E 727350.74 E 727372.19 E 727409.42 E 727412.13 E 727462.05 E 727508.16 E 727547.08 E 727578.24 E 727591.92 E Dogleg Rate (O/100ft) 0.823 1.018 1.239 0.688 0.623 1.896 0.260 0.113 1.096 0.306 0.326 1.044 12.000 7.000 7.000 6.889 6.889 6.889 6.889 6.889 6.889 6.889 Vertical Section 5389.38 5464.58 5540.04 5616.29 5692.53 5769.72 5847.85 5926.17 6004.19 6081 .83 6159.45 6190.61 6206.12 6236.49 6262.51 6307.99 6311.27 6371 .28 6425.41 6469.59 6503.18 6516.98 . Alaska Drilling & Wells NIAKUK Comment (-- ST Exit: Start Dir @ 12.0000/100ft 85.00° Left TF : 10040.20ftMD,7355.86ftTVD Begin Dir @ 7.000°/1 OOft : 10060 .20f' MD, 7368.48ft TVD Decrease in Dir Rate @ 6.889°/100ft : 10135.20ft MD, 7417.48ft TVD ( Top CM3 End Dir, Start Sail @ 13.270° : 10655.03ftMD,7860.90ftTVD ..........................,.........................................................."""""""""""""""""",-"",""""""""""""""""""""""""..................................................."....................................""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""-"""""""""""'-""""'"""-""""'-"'-""""""-"""""'-""'-"""""""""'-'-"""""""""-""""""""""-"-"""""""""""""""""""""""'"""',................................................,...................................."...................... 26 November, 2001 - 15:31 Page 5 of 10 Dri/IQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for NK-22A WPS Rev/sed: 26 November, 2001 Alaska Drilling & Wells North Slope Alaska NIAKUK Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) '. 10700.00 13.270 80.996 7851.97 7904.67 2943.84 N 5826.34 E 5983094~90, N .." ,727602.06 E 0.000 6526.86 10800.00 13.270 80.996 7949.30 8002.00 2947.43 N 5849.01 E 59839~,~it~,:~. >???:624.62 E 0.000 6548.83 10900.00 13.270 80.996 8046.63 8099.33 2951.03 N 5871.68 E 598~1,d'$.42N. 7~~,ß47.17 E 0.000 6570.80 (--- 11000.00 13.270 80.996 8143.96 8196.66 2954.62 N 5894.36 E '. . 59~~1 O~iß,~:~' 72:7669.73 E 0.000 6592.77 " 11100.00 13.270 80.996 8241.29 8293.99 2958.21 N 59t7iO3E 5983111;$:)$èN 727692.28 E 0.000 6614.75 "'¡;""." 11200.00 13.270 80.996 8338.62 8391.32 2961.80 N 5939.70 E '. 5983116.21 N 727714.84 E 0.000 6636.72 11300.00 13.270 80.996 8435.95 8488.65 2965.40N 5$:)62.37 E '. 5983120.47 N 727737.39 E 0.000 6658.69 11400.00 13.270 80.996 8533.28 8585.98 296ß;QßN . 598S;04E 5983124.73 N 727759.94 E 0.000 6680.66 11498.34 13.270 80.996 8629.00 8681.70 29~2¡5¿N~' 6007.34 E 5983128.93 N 727782.13 E 0.000 6702.27 Top Tuffs 11500.00 13.270 80.996 8630.61 8683.31 6007.71 E 5983129.00 N 727782.50 E 0.000 6702.64 11600.00 13.270 80.996 8727.94 ."".,".:~i~:~~....'.'..,.. ......,;1 6030.38 E 5983133.26 N 727805.05 E 0.000 6724.61 11700.00 13.270 80.996 8825.27i 79.76 N 6053.05 E 5983137.52 N 727827.61 E 0.000 6746.58 11800.00 13.270 80.996 8922.60' 8975;30 " 2983.36 N 6075.73 E 5983141.78 N 727850.16 E 0.000 6768.55 11900.00 13.270 80.996 9019.93 9072.63 2986.95 N 6098.40 E 5983146.04 N 727872.72 E 0.000 6790.53 11902.13 13.270 80.996 9022.00 ,907470 2987.03 N 6098.88 E 5983146.13 N 727873.20 E 0.000 6790.99 Top HRZ 12000.00 13.270 80.996 9117.26 9169.96 2990.54 N 6121.07 E 5983150.30 N 727895.27 E 0.000 6812.50 12100.00 13.270 80.996 9214.59 9267.29 2994.13 N 6143.74 E 5983154.57 N 727917.83 E 0.000 6834.47 12180.56 13.270 80.996 9293.00 9345.70 2997.03 N 6162.00 E 5983158.00 N 727936.00 E 0.000 6852.17 Top Kuparuk Target - NK-22A T1 A, 90.00 Radius., Drillers 12200.00 13.270 80.996 9311.92 9364.62 2997.73 N 6166.41 E 5983158.83 N 727940.38 E 0.000 6856.44 ( 12280.22 13.270 80.996 9390.00 9442.70 3000.61 N 6184.60 E 5983162.25 N 727958.48 E 0.000 6874.07 Base Zone 3AlTop Zone 3B 12300.00 13.270 80.996 9409.25 9461.95 3001.32 N 6189.08 E 5983163.09 N 727962.94 E 0.000 6878.42 12400.00 13.270 80.996 9506.58 9559.28 3004.91 N 6211.75 E 5983167.35 N 727985.49 E 0.000 6900.39 12415.22 13.270 80.996 9521.39 9574.09 3005.46 N 6215.20 E 5983168.00 N 727988.93 E 0.000 6903.73 6-3/4" Hole, Total Depth: 12415.22ftMD,9574.09ftTVD 4 1/2" Liner ..................................................................-.........,.""""""""""""""-""""""""""""""""""""""""""""""""'""""""""""""""""""""""""""""""""""""""""""""'".............."..................................."..........................,.............-............................""""""""""""""""""""""""'""""-""""""""""""""""""""'-""""""""""""""""""""""-"'""'-"""""""""""'-"""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""""'" 26 November, 2001 - 15:31 Page 6 of 10 Dr/llQuest 2.00.09.006 ( ( DATE 09/28/01 CHECK NO. 00198745 H 198745 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT 092701 CK092701I PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it to Drill ee 5tH - Terri Hubb e X4628 \\)¥-.?ÂA 'HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100_00 100.00 BPEXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 198745 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00198745 PAY , , " , ONE' HUNDRED & 00/100""**~*************'***,.**************** US DOLLAR , DATE, Q9/2B/Ol, II NOTNALID AFTER 1,20 DAYS , , ' n ' "",~7;"Jl " \~~,~~~ , AMOUNT h O~ ;.()P To The ORDER Of '" ' , , .. ' , , , , "ALA~~A [)ILANJ) Q~S . ".ÇON!3ERVfa T I QI\I(:OMM I 551 ON, ' 33:3:~WES~ 7~~AVENUE .' SUITE 100 ANCHORAGE III ~ '1 a ? ... 5 III I: 0... ~ 2 0 :I a q 5 I: 0 0 a ...... ~ q III ( ( TRANSMIT AL LETTER CHECK LIST CIR CLE APPRO PRIA TE LETTER/P ARA GRAPHS TO BE INCLUDED IN TRANSNUTTALLETTER WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS)- MULTI LATERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) / EXPLORATION ANNULAR P!SPOSAL LYJNO INJECTION WELL ANNULAR DISPOSAL L-) YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, , API No. . ' Production should continue to be reported as a function of the original API number stated above. ' In accordance with 2,0 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal bas not been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS L-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume tbe liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST FIELD & POOL 0 ADMINISTRA TION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . '-r-' 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y .$iA/f~ /L? e4 hè,1.. ,~nDL CB.fr 3D) "¡-~Î rod~ Lþ¡x.... Vh.,-/c-.<.væ 3. Unique well name and number. .. . . . - . . . . . . . . . . . :IN CvtA.d -r: þ. vh... ADL 03'Á '3 . :: ~::: :~:~ ~~p~~~~:t~';:~"; drilli~g ~n¡t tx;u~da;Y: -- '- -- ,~ '*f.--I.£;<t';i2-f-Z'¿ *:;/~~ &/ <>->-t ~",-~ 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . - . N, 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can.be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ~~. ~~~~~~:~~~i~~~~e:II kn~~' us'oŸis.. . . . . . . . . . ~ ~t- , ~\ L t\- \ 16: GMT vol ad~qUate 10 circulate on conduct~r 8. ~urt ~g: : : :. - Y N)'" ,- ~'LC'> ...... ">~' ~ ~" 17. CMT vol adequate to ,tie-in long string to surf csg. . . . . . . . Y N 18. CMT will cover all known productive horizons. . . . .'. . . .. 'i N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ' N , 20. , Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ' N e..,,\~~\~ '- ~, \ ~~ ~ ~~~ ~~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N ~,:) . 22. Adequate wellbore separation proposed.. . . . . . . . . . .. . (:lJ N 23. If diverter required, does it meet regulations. . . . . . . . . . ~ 24. Drilling .fluid program schematic & equip list adequate. . . . . . N . ~~: :g~~spr~~ ~:~::pp~~~~:t~sit¿ . . . . . ~~sig: ~ ~ ~ S2 \) "'~~ Q.. 4. ~(ç. Ç> ~ \ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .. , N 28. Work will occur without operation shutdbwn. . . . . . . . . . . !'l- ~ '\... -- ...~ \ ~. \ \ - '- 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y Q!) \J\'\)o,,>\~ "":)\c:J ~~c.,~~J~ "'"'~ ~('... '""~ . " 30. Permit can be issued w/o hydrogen sulfide measures. . . . ,. Y@ P-/k.~ z. 2- YÞ\ e...4:.5 u ~ '10 ¡::;;PYh ~ ~ c:Y?1 :3,2-1" DI 31. Data presented on potential overpressure zones. . . . . . . ~ l:5,.(-, /'~Sl...:>~ ~+ .-f~'~) ... t (::i'r4.yt..)þ.... ¡¡, /m EJ?ztJ 32. Seismic anal~~is of shallow gas zones. . . . . . . . . . . .. ¡../ A Y N :~ DATE 33. Seabed condition survey (of off-shore). . . . . - - . . ':":Z: Y N /2.. ,{. D /. 34. Contact name/phone for weekly progress reports [explo~ry only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; ,. .' (C) will not impair mechanical integrity pf the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLO Y: ENGINEERING:' ~ COMMISSION: ~~ ~ W WM ~ '8~s TE ,) JM A~ DATE ¡ 12, if,D ENGINEERING APPR DATE (;2(.> GEOLOGY APPR DATE COMP ANY INIT CLASS PROGRAM: exp - dev ~ redrtl serv GEOL AREA Q . UNIT# wellbore seg _ann. disposal para req - '. 5- ON/OFF SHORE afr c 0 Z 0 -f ~ :xl t-.- - -f m - Z -f ,J: - en :Þ :xl m > ( Y N Y N Com mentsllns tructi ons: 12- I Ûl c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ( Ii , Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process. but is part of the history file. , To improve the readability of the Well History file and to simplify finding information. infonnation 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. c (I' " Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 26 11:48:06 2002 Reel Header Service name............ .LISTPE Date.....................02/09/26 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name..... ..UNKNOWN Comments............... ..STS LIS Tape Header Service name............ .LISTPE Date.....................02/09/26 Origin...................STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name.... ...UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit - Niakuk Pool MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-11211 B. HENNINGSE L. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Writing Library. NK-22A 500292240201 BP Exploration Sperry Sun 26-SEP-02 MWD RUN 3 AK-MM-11211 B. HENNINGSE L. VAUGHN 36 T12 R15 1435 694 .00 53.41 19.20 (' Scientific Technical Services Scientific Technical Services (Alaska), Inc. MWD RUN 4 AK-MM-11211 B. HENNINGSE L. VAUGHN 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 5011.0 7.625 10030.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL CASING AND IS NOT PRESENTED. OOJ--dd ~ 1116Lj ( (' 3. MWD RUNS 2 & 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND STABILIZED LITH-DENSITY (SLD). 4. MWD RUN 3 IS DIRECTIONAL UTILIZING GEIGER MUELLER TUBE DETECTORS, RESISTIVITY PHASE 4 (EWR4) . WITH DUAL GAMMA RAY (DGR) ELECTROMAGNETIC WAVE 5. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 9669' MD, 7123' TVD TO 10030' MD, 7350' TVD. 6. GAMMA RAY (SGRC) DATA FROM 9669' MD, 7123' TVD TO 10010' MD, 7337' TVD WAS OBTAINED ON A MADPASS BEFORE DRILLING MWD RUN 2 AND IS APPENDED TO MWD RUN 2 DRILLING DATA. 7. DIGITAL DATA AND LOG DATA IS DEPTH CORRECTED TO THE PDC GR LOG OF 01/08/02 WITH KBE = 59.6' A.M.S.L.. THIS WELL KICKS OFF FROM NK-22 AT 10030' MD, 7350' TVD (TOP OF WHIPSTOCK). ALL MWD LOG AND HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 4 REPRESENT WELL NK-22A WITH API # 50-029-22402-01. THIS WELL REACHED A TOTAL DEPTH OF 12444' MD, 9574' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED 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 SBD2 = SMOOTHED SCO2 = SMOOTHED BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE FORMATION EXPOSURE TIME BULK DENSITY (LOW-COUNT BIN) STANDOFF CORRECTION (LOW-COUNT ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.75" MUD WEIGHT: -11.4 PPG MUD FILTRATE SALINITY: CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: G/CC MATRIX DENSITY: 9.4 700 - 900 PPM 19,000PPM CHLORIDES 1. 00 2.65 $ ( G/CC LITHOLOGY: SANDSTONE File Header Service name.... ".'.'" .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/09/26 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI RHOB DRHO PEF $ 1 ( clipped curves; all bit runs merged. .5000 START DEPTH 9673.5 10028.5 10028.5 10028.5 10028.5 10028.5 10061. 5 10459.0 10459.0 10459.0 10473.0 10473.0 10473.0 STOP DEPTH 12403.5 12410.5 12410.5 12410.5 12410.5 12410.5 12451.5 12366.0 12366.0 12366.0 12382.0 12382.0 12382.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 9673.5 9682.5 9701. 5 9751.5 9756.0 9780.5 9861. 5 9897.5 9968.5 9975.5 9981. 5 10001.5 10019.5 10090.5 10108.5 10130.0 10140.0 10158.5 10178.5 10200.0 10336.5 10369.5 10450.5 10465.0 10479.0 10515.5 10551. 0 10756.0 10853.0 11214.5 11389.0 11393.0 11401. 0 11417.0 11419.0 DEPTH GR 9669.0 9678.0 9698.0 9751.0 9756.0 9779.5 9860.0 9897.0 9967.0 9974.5 9979.0 9998.0 10014.0 10088.0 10106.0 10127.0 10139.0 10158.5 10179.0 10200.5 10336.0 10366.5 10449.5 10463.0 10478.0 10515.5 10551. 5 10753.0 10851. 5 11210.0 11385.5 11389.0 11396.0 11411.5 11412.5 ( 'c ( 11444.5 11452.5 11455.0 11460.0 11462.0 11465.0 11470.5 11474.0 11477.0 11483.0 11497.0 11511.5 11516.5 11519.0 11525.0 11530.5 11533.5 11538.0 11544.5 11547.0 11550.5 11558.5 11566.5 11572.5 11578.5 11584.0 11586.5 11590.5 11595.0 11602.5 11605.5 11607.0 11614.5 11617.5 11621.0 11634.5 11637.5 11643.0 11652.5 11662.0 11667.0 11680.5 11684.5 11687.0 11688.0 11690.5 11704.0 11706.0 11721. 0 11742.0 11746.5 11752.5 11 762 . 0 11772.0 11784.5 11 791. 5 11799.5 11804.5 11808.0 11822.0 11836.5 11847.0 11850.0 11871.5 11873.5 11875.5 11881.0 11895.5 11900.0 11904.0 11906.0 11917 .5 11932.0 11936.5 11950.0 11961. 0 11439.5 11448.0 11450.0 11455.0 11457.0 11462.5 11467.5 11469.0 11471.5 11478.0 11493.0 11506.0 11513.0 11514.5 11519.5 11525.0 11528.5 11533.5 11541.0 11543.0 11546.5 11554.0 11561.0 11567.0 11575.0 11579.5 11582.5 11587.0 11590.0 11596.0 11600.0 11602.0 11609.0 11611. 0 11616.0 11630.5 11635.0 11639.0 11648.5 11657.5 11662.5 11675.5 11680.5 11682.5 11684.5 11686.0 11699.0 11700.5 11716.5 11736.5 11743.0 11747.5 11758.0 11767.0 11779.5 11787.0 11793.0 11799.0 11802.5 11816.0 11831. 5 11842.5 11845.0 11867.0 11869.0 11871.0 c11875.5 11890.5 11896.0 11898.5 11900.5 11912.0 11927.0 11931.5 11945.0 11955.5 i( ( 11965.5 11970.0 11978.0 11980.0 11982.5 11989.5 11991.5 12003.0 12005.5 12013.0 12021.0 12027.5 12037.0 12039.5 12055.5 12064.0 12070.5 12075.5 12077.5 12083.5 12089.5 12095.5 12099.0 12126.5 12132.0 12134.0 12140.0 12144.0 12149.5 12159.0 12162.0 12174.5 12181. 0 12191. 5 12194.5 12200.0 12205.0 12207.0 12214.5 12225.5 12240.0 12250.0 12268.0 12281. 5 12299.5 12303.0 12306.0 12309.0 12318.0 12322.5 12325.5 12360.0 12366.0 12373.5 12451.5 $ 11961.0 11964.5 11972.5 11974.5 11977.0 11984.0 11986.0 11998.0 12000.5 12008.0 12015.5 12023.0 12030.5 12033.0 12048.5 12057.5 12063.5 12069.0 12071. 0 12077.0 12083.0 12090.0 12093.0 12120.5 12125.5 12128.0 12133.0 12138.0 12143.0 12155.0 12157.0 12168.0 12175.0 12185.0 12188.5 12194.0 12199.0 12201.0 12208.0 12219.5 12233.0 12243.0 12261.0 12275.5 12293.0 12297.0 12299.5 12302.5 12312.0 12316.0 12318.0 12353.5 12359.5 12366.0 12444.0 # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 9669.0 3 10074.5 4 10540.5 MERGE BASE 10074.0 10540.0 12444.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........... ..... . Down Optical log depth units..... ..." .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9673.5 12451. 5 11062.5 5557 9673.5 12451. 5 ROP MWD FT/H 0.17 791.23 100.527 4781 10061. 5 12451. 5 GR MWD API 12.46 450.18 116.836 5461 9673.5 12403.5 RPX MWD OHMM 0.78 1097.12 7.78694 4765 10028.5 12410.5 RPS MWD OHMM 0.79 294.77 6.56354 4765 10028.5 12410.5 RPM MWD OHMM 0.15 2000 9.70132 4765 10028.5 12410.5 RPD MWD OHMM 0.47 1708.47 7.12175 4765 10028.5 12410.5 FET MWD HR 0.09 47.25 2.65289 4765 10028.5 12410.5 NPHI MWD PU-S 9.29 58.94 30.0963 3815 10459 12366 FCNT MWD CP30 137.63 1720.58 399.526 3815 10459 12366 NCNT MWD CP30 17355.9 40528.9 24074.1 3815 10459 12366 RHOB MWD G/CM 2.03 2.87 2.47939 3819 10473 12382 DRHO MWD G/CM -0.06 0.62 0.136297 3819 10473 12382 PEF MWD B/E 2.25 17.1 6.62207 3819 10473 12382 First Reading For Entire File.... ..... .9673.5 Last Reading For Entire File.......... .12451.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/26 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...... .02/09/26 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR 2 header data for each bit run in separate files. 2 .5000 START DEPTH 9669.0 STOP DEPTH 10026.0 ( ROP $ 10058.0 10074.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # 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 Block Type.....O Logging Direction... ............ ..Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing....... ............ ..60 .1IN Max frames per record........... ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 21-DEC-01 Insite 4.05.5 66.16 Memory 10074.0 49.5 51.5 TOOL NUMBER PB02342GRV4 6.750 LSND 9.65 50.0 9.1 300 5.3 2.100 .000 2.300 5.200 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 9669 14.54 31. 28 Max 10074 187.97 85.79 Mean Nsam 9871.5 811 101.793 33 57.7277 715 ( 65.0 .0 65.0 65.0 First Reading 9669 10058 9669 Last Reading 10074 10074 10026 ( First Reading For Entire File... ..... ..9669 Last Reading For Entire File......... ..10074 File Trailer Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/09/26 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...... .02/09/26 Maximum Physical Record. .65535 File Type............ ... .LO Previous File Name.. .... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPM RPS GR ROP $ 3 ( header data for each bit run in separate files. 3 .5000 START DEPTH 10023.5 10023.5 10023.5 10023.5 10023.5 10026.5 10074.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 10500.5 10500.5 10500.5 10500.5 10500.5 10493.5 10540.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): 23-DEC-Ol Insite 4.05.5 66.16 Memory 10540.0 33.9 51.0 TOOL NUMBER PB02342GRV4 PB02342GRV4 6.750 LSND 9.65 47.0 8.8 750 5.5 ( ( RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2.300 1.190 2.700 2.700 65.0 132.0 65.0 65.0 # 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 Block Type... ..0 Logging Direction................ . Down Optical log depth units... ....... .Feet Data Reference Point............. .Undefined Frame Spacing........... ......... .60 .1IN Max frames per record... ......... .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10023.5 10540 10281.8 1034 10023.5 10540 ROP MWD030 FT/H 0.51 551.14 105.652 932 10074.5 10540 GR MWD030 API 49.82 120.75 84.8187 935 10026.5 10493.5 RPX MWD030 OHMM 0.78 7.72 3.03057 955 10023.5 10500.5 RPS MWD030 OHMM 0.79 24.15 3.27033 955 10023.5 10500.5 RPM MWD030 OHMM 0.15 2000 20.9754 955 10023.5 10500.5 RPD MWD030 OHMM 0.47 1708.47 7.32987 955 10023.5 10500.5 FET MWD030 HR 0.09 47.25 7.67534 955 10023.5 10500.5 First Reading For Entire File..... .... .10023.5 Last Reading For Entire File..... ..... .10540 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/26 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/26 Maximum Physical Record. .65535 ( File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPD RPX RPM FET RPS ROP $ 4 ( header data for each bit run in separate files. 4 .5000 START DEPTH 10457.5 10457.5 10457.5 10471.5 10471.5 10471.5 10494.0 10501.0 10501.0 10501. 0 10501. 0 10501. 0 10540.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 12359.5 12359.5 12359.5 12374.5 12374.5 12374.5 12396.0 12403.0 12403.0 12403.0 12403.0 12403.0 12444.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 26-DEC-01 Insite 4.05.5 66.16 Memory 12444.0 8.1 26.3 TOOL NUMBER PB02342GRV4 PB02342GRV4 PB02343NL4 PB02343NL4 6.750 LSND 11.40 47.0 8.8 700 3.4 1. 200 .737 1. 500 1. 800 92.0 154.0 92.0 92.0 ,( ( $ # Data Format Specification Record Data Record Type.. .... ....... .....0 Data Specification Block Type.....O Logging Direction....... ......... . Down Optical log depth units... .....,. .Feet Data Reference Point. .... .... .... .Undefined Frame Spacing... ....... ....... ....60 .1IN Max frames per record. .... ..., ... .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10457.5 12444 11450.8 3974 10457.5 12444 ROP MWD040 FT/H 0.17 791.23 98.7371 3808 10540.5 12444 GR MWD040 API 12.46 450.18 135.596 3805 10494 12396 RPX MWD040 OHMM 1.19 1097.12 8.66275 3805 10501 12403 RPS MWD040 OHMM 1. 22 294.77 7.29784 3805 10501 12403 RPM MWD040 OHMM 1.15 182.25 6.82927 3805 10501 12403 RPD MWD040 OHMM 1.2 200.02 7.038 3805 10501 12403 FET MWD040 HR 0.22 25.55 1. 47259 3805 10501 12403 NPHI MWD040 PU-S 9.29 58.94 30.0983 3805 10457.5 12359.5 FCNT MWD040 CP30 137.63 1720.58 399.805 3805 10457.5 12359.5 NCNT MWD040 CP30 17355.9 40528.9 24074.1 3805 10457.5 12359.5 RHOB MWD040 G/CM 2.03 2.87 2.47896 3807 10471.5 12374.5 DRHO MWD040 G/CM -0.06 0.62 0.136575 3807 10471.5 12374.5 PEF MWD040 B/E 2.25 17.1 6.62461 3807 10471.5 12374.5 First Reading For Entire File... ...... .10457.5 Last Reading For Entire File.......... .12444 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/26 Maximum Physical Record..65535 File Type...... ........ ..LO Next File Name......... ..STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/09/26 Origin...................STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS wri ting Library. Scientific Technical Services ( Reel Trailer Service name. ........... .LISTPE Date.....................02/09/26 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name....... ... . UNKNOWN Comments.. """"'."" .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. ( Scientific Technical Services
