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Home My WebLink About202-136Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 12-08C (PTD 202-136) PERFORATING RECORD 12/01/2020 Please include current contact information if different from above. PTD: 2021360 E-Set: 34453 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:202-136 6.50-029-20432-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 14070 14070 9018 none none 8669 , 8756 , 8795 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 73 20" 73 73 1530 520 Surface 2714 13-3/8" 2714 2713 4930 2670 Intermediate 8157 9-5/8" 143 - 8300 143 - 7300 6870 4760 Liner 2560 7" 8121 - 10681 7163 - 8902 72040 5410 Liner 3569 4-1/2" 10501 - 14070 8790 - 9018 8430 7500 Perforation Depth: Measured depth: 10677 - 13910 feet True vertical depth:8899 - 9018 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80/L-80 10505 8792 8669 , 8756 , 8795Packers and SSSV (type, measured and true vertical depth) 7x4-1/2 Baker S-3 (2) , 7x4-1/2" ZXP LNR TOP Tieback Liner 8089 7" 22 - 8111 22 - 7156 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 22513514129427 4558100 1424 314 346 231 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: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 - 4672 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 measured9018 Sundry Number or N/A if C.O. Exempt: n/a no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028330 PBU 12-08C 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 10312 ,10449 , 10509 10312 ,10449 , 10509 By Samantha Carlisle at 10:54 am, Dec 08, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.12.08 09:19:55 -09'00' Bo York SFD 12/8/2020RBDMS HEW 12/9/2020 DSR-12/9/2020MGR04FEB2021 ACTIVITYDATE SUMMARY 11/28/2020 ***WELL FLOWING ON ARRIVAL***(perforating) DRIFTED TBG W/ 2.50" SAMPLE BAILER, TOOLS DEVIATED OUT @ 10,842' SLM.(no sample) DRIFTED TBG W/ 30' x 2-7/8" DUMMY GUNS(3.16" rings) & 3.00" SAMPLE BAILER, TOOLS DEVIATED OUT @ 10,814' SLM.(no sample) ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 11/28/2020 T/I/O = 1950/2000/100 TEMP = SI (PERFORATING) Pre Sline Pumped 2 bbls 60/40 followed by 105 bbls crude down FL for FP. Pumped 38 bbls crude down TBG Hung tags SV,SSV,WV= C MV=O CV's= OTG DSO notified of well status upon departure FWHP's = 1600/2000/100 12/1/2020 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(adperf) PERFORATE 10677'-10707' W/ 2.875", 6 SPF, 60 DEG PHASING LOADED W/ MAXFORCE CHARGES. CORRELATED TO SLB SBHP SURVEY DATED 24-DEC-2005'. ...CONT ON 2-DEC-2020 WSR... 12/2/2020 ***JOB CONTINUED FROM 01-DEC-2020*** (HES E-LINE ADPERF) FINISHED RIGGING DOWN. TURN WELL OVER TO THE DSO. WELL S/I ON DEPARTURE. ***JOB COMPLETE ON 02-DEC-2020*** Daily Report of Well Operations PBU 12-08C MEMORANDUM TO: Jim Regg 11 P. I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 12/9/2020 SUBJECT: No Flow Test PBU 12-08C Hilcorp North Slope LLC PTD 2021360 12/8/2020: 1 arrived on location and met up with Nate Boisso the Hilcorp North Slope representative and reviewed the testing procedure and rig up they were going to use. The well had been shut in on 12/7/2020 @10:00 am and was bled to 0 psi on the tubing. Gas lift was shut in and the IA was also bled to 0 psi. The outer annulus has been cemented off and read 50 psi during this entire test. There was a 25 foot 3/4 -inch Par -flex hose connected to the tree through a 1502 cap with a 1 -inch full port valve, to a flow Tee with a Crystal gauge (10/2020 calibration date), ,f and then to a3/4 -inch Armor -Flo meter (2/2020 calibration date). After the meter there was 50 feet of 3/4 -inch Par -flex hose that terminated at an open top tank. ThP fnllnwinn tahle shows test details: Time Pressures' (psi) Flow Rate Gas — scf/hr Liquid — al/hr Remarks 9:35 0/0/50 Shut in for pressure build u 9:50 1/0/50 15 -minute pressure reading 10:05 2/0/50 15 -minute pressure reading 10:20 2/0/50 15 -minute pressure reading 10:35 3/0/50 >1800 0 1:56 for <900 scf/hr 10:38 0/0/50 Shut in for pressure build u 10:53 1/0/50 15 -minute pressure reading 11:08 2/0/50 15 -minute pressure reading 11:23 3/0/50 15 -minute pressure reading 11:38 3/0/50 >1800 0 1:54 for <900 scf/hr 11:40 0/0/50 Shut in for pressure build u 11:55 2/0/50 15 -minute reading 12:10 3/0/50 15 -minute reading 12:25 4/0/50 15 -minute reading 12:40 4/0/50 >1800 0 1:51 for <900 scf/hr Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: None i 2020-1208_No-Flow_PBU_ 12-08C_11.docx Page 1 of 1 • • V OF TtJ y \@��yy��e� THE STATE Alaska Oil and Gas ��,;- � �, ofA T /(A� ,C) 1 A Conservation Commission 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 '".' Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov October 24, 2016 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: No-Flow Verification PBU 12-08C PTD 2021360 S�HNE® M A`/ = 1 s.l'117 Dear Ms. Cocklan-Vendl: On September 14, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-08C. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-08C. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree bled to zero within 4 minutes. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-08C demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, \JCI- b � c� James B. Regg Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDCWellIntegrityCoordinator@bp.com Ryan Daniel,BPXA • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg )Kef 2 “21°`)1(a DATE: September 14, 2016 P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector PBU 12-08C BP Exploration PTD 2021360 - 09/14/16: Got on location and met with Ryan Moore and Scott Byars (BPXA representatives). We looked at the rig up and confirmed all gauges had current ' calibration stickers. Got all wellhead pressures and shut well in for 3 hours, recording wellhead pressures every hour. After 3 hours the well was opened to a tank via 2" hardline and we monitored the well bleed to ZERO in 4 minutes. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 8:55 0/10/180 9:55 3/10/180 10:55 6/10/180 11:55 9/10/180 11:58 9/10/180 Start bleed to tank (ALL GAS) 12:02 0/10/180 - ZERO Pressure 1 Pressures are T/IA/OA Summary: Witnessed a successful no-flow test of PBU 12-08C following the criteria of 20 AAC 25. 265(l)(1)(B) — "well pressure discharged not later than 5 minutes after a three-hour charted pressure build-up period." Attachments: NONE - SCANNED APR 0 2017 2016-0914 BOP No-Flow_PBU_12-08C_bb.docx Page 1 of 1 .A STATE OF ALASKA _ ALAS~IL AND GAS CONSERVATION CWlMISSION REPORT OF SUNDRY WELL OPERATIONS' " 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program ~ Repair Well ~ Pull Tubing o Operation Shutdown o Other o Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc, ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 69.4' 8. Property Designation: ADL 028330 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 14070 9018 14070 9018 Casing Structural Conductor Surface Intermediate Production Liner Length 73' 2714' 8300' 2560' 3569' 8089' Liner Tieback Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension 4, Well Class Before Work: ~ Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 202-136 6. API Number: 50-029-20432 -03-00 9. Well Name and Number: PBU 12-08C 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 73' 73' 1530 520 13-3/8" 2714' 2713' 4930 2670 9-5/8" 143' - 8300' 143' - 7300' 6870 4760 7" 8121' -10681' 7163' - 8902' 7240 5410 4-1/2" 10501' -14070' 8790' - 9018' 8430 7500 7" 22' - 8111' 22' - 7156' 7240 5410 Slotted Section: 11189' - 13910' 8993' - 9018' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr80 / L-80 10505' 7" x 4-1/2" Baker 'S-3' Packer; Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10312'; 1 0449' Treatment description including volumes used and final pressure: RBDMS BFl MAY :'I 0 7DDb Cut and pulled 9-5/8" casing to 143'. Cement 13-3/8" x 9-5/8" annulus with 141 Bbls Class 'G'. Run 7" Tieoack Liner. Cement with 231.7 Bbls Class 'G'. Run new completion, 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Well Schematic Diagram Representative Daily Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure 15. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Well Status after proposed work: ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my now edge. Sundry Number or N/A if C,O. Exempt 306-098 Printed Name Terrie Hubble Signature ~. Form 10-404 Revised 04/2006 Title Technical Assistant Phone Date 05/U/O~ Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 ORIGINAL . . 12-08C, Rig Workover Prudhoe Bay Unit 50-029-20432-03-00 202-136 Accept: Spud: Release: Ri: 05/02/06 N/A 05/17/06 Nabors 4ES PRE-RIG WORK 03/25/06 DRIFT AND TAG (PRE RWO) DRIFTED W/ 3.70" CENT. AND SAMPLE BAILER TO 10904' SLM. 04/12/06 CORRELATED TO SLB STATIIC BHP SURVEY DATED 24-DEC-2005. PLUG IS BAKER HI-VALUE QUIK DRILL COMPOSITE BRIDGE PLUG SIZE 360. MAX OD = 3.595", SET PLUG AT 10458'. TUBING PUNCHED 4-1/2 FROM 10381' -10383'. SHOTS NOT CENTERED EXACTLY IN CARRIER BUT 80-100 LBS INCREASE IN IA PRESSURE NOTED AFTER SHOOTING. 6 SHOTS SHOT OUT ON THE SAME AXIS AS SCALLOPS AND DECENTRALlZER POSITION BUT SHOT OUT ON THE HIGH END OF EACH. 3 SHOTS FIRED APPROX. 15 DEGREES TO 30 DEGREES OUT OF PHASE. ALTHOUGH PRESSURE CHANGE IN TUBING AND IA WAS NOTICED WHICH INDICATED HOLES IN THE PIPE, THE NEXT PROCEDURE IS A CIRC - OUT PRE WELLHEAD WORK SO A 2ND GUN RUN WAS MADE TO INSURE THAT CIRC - OUT REQUIRED RATE CAN BE REACHED. T/I/O = 0/400/200 SHOT STRING SHOT ACROSS 10389' - 10401', TUBING PUNCH 4-1/2" FROM 10,350' - 10,352'. WELL LEFT SHUT-IN T/I/O = 0/400/200. 04/13/06 CIRC-OUT PRE RWO WITH 1234 BBLS 1% KCL PUMP 158 BBLS DSL AND U-TUBE TO FREEZE PROTECT TBG AND IA. FREEZE PROTECT FLOWLINE WITH 7 BBLS METH AND 93 BBLS DIESEL. CMIT-TXIA TO 3500 PSI. [PASSED] ON 1ST ATTEMPT [SEE DATA].MIT-OA TO 2000 PSI. [PASSED] ON 2ND ATTEMPT [SEE DATA]. FINAL WHP= 0/0/200. 04/25/06 CUT 4-1/2" TUBING AT 10400' WITH 3-5/8" CHEMICAL CUTTER, TUBING PUNCHER AND STRING SHOT RUN 12-APR-06. STRING SHOT FROM 10401' -10389'. CUT TUBING AT 10400'. CCL TO CUTTER = 12.4' CCL STOP DEPTH = 10387.6'. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/711980 End: 5/17/2006 51212006 07:00 - 17:00 10,00 MOB P PRE Move Rig and Rig Components from NGI-08 to DS 12-08C. 17:00 - 20:00 3.00 MOB P PRE Layout herculite and matting boards. Back Rig Sub on matting boards and spot Rig Components over well. Begin to RU on 12-08C. 20:00 - 00:00 4.00 MOB P PRE Raise and scope Derrick. Continue to RIU. Take on seawater to pits and begin pulling Lubricator to Rig Floor. Accepted rig at 19:00 hrs, 05/0212006. 51312006 00:00 - 02:00 2.00 KILL P DECOMP Inspect Tree and no pressure noticed on IA. PU Lubricator and pull BPV, No pressure noted in tubing. RD Lubricator, Continue taking on seawater to pits. RU to circulate and connect lines from Rig to Tiger Tank. 02:00 - 03:30 1.50 KILL P DECOMP Construct berm around Tiger Tank prior to starting circulation. 03:30 - 06:30 3.00 KILL P DECOMP PJSM. Pressure test lines to 3500 psi, OK. Reverse out diesel in tubing at 4 bpm I 380 psi & circulate the long way to displace well to seawater at 5 bpm I 900 psi, 670 bbls. Begin loading 3.5" DP into Pipe Shed. 06:30 - 08:30 2.00 WHSUR P DECOMP PJSM. Monitor well, well dead. Drain tree, pick up lubricator & set BPV. Test same from below @ 1000 psi, OK. 08:30 - 10:30 2.00 WHSUR P DECOMP PJSM. N/D tree. Inspect 5 7/8" RH Acme threads, OK. Install blanking plug in BPV. Check lock downs, OK. 10:30 - 13:30 3.00 BOPSU P DECOMP PJSM. N/U 13 5/8" x 5M BOPE. 13:30 - 19:00 5.50 BOPSU P DECOMP PJSM. Conduct full test on BOPE. Witnessing of BOPE test waived by AOGCC Rep John Crisp, 24 hour notice given. 19:00 - 20:30 1.50 BOPSU P DECOMP Pull Dart and BPV out with Lubricator. Release Drill Site Maintenance. 20:30 - 21 :30 1.00 PULL P DECOMP Make up BHA #1 as follows: Bull Nose, Packoff, ITCO Spear with 3.947" Grapple, ITCO Spear with 3.947" Grapple. PU single joint of 3.5" DP. BOLDS. 21 :30 - 22:30 1.00 PULL P DECOMP PJSM. Plant Spear in Tubing Hanger and begin to pull on completion. Estimated PU weight should be 115K + Blocks. Pull and came free at 160K. UW as coming out with completion = 120K. Begin laying down Tubing Hanger and BHA #1 components. Spear would not come free. Lay down single joint of 3.5" DP. 22:30 - 00:00 1.50 PULL P DECOMP PJSM. POOH with 4.5" 12.6# L-80 Tubing and lay down in Pipe Shed. Inspect all joints and connections for possible re-use as POOH and use thread protectors. 5/4/2006 00:00 - 06:00 6.00 PULL P DECOMP Continue POOH with single joints of 4.5" 12.6# L-80 Tubing. Inspect on way out and use thread protectors for possible re-use, Lay down in Pipe Shed. 06:00 - 06:30 0.50 PULL P DECOMP Service rig, 06:30 - 07:30 1.00 PULL P DECOMP PJSM. Continue to POOH w/4 1/2" TCII completion string, Recovered 262 jts, (5) GLMs & cut off jt ... 19.11'. Cut looked very good, 4.58" OD at end of cut. 07:30 - 10:00 2.50 CLEAN P DECOMP PJSM. Finish loading & strapping 3 1/2" DP. Clear Iclean rig floor & rig up to run DP. Install wear bushing. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. Pick up 4 1/2" tubing stub dress off BHA & casing scraper... see BHA tab for details. 12:00 - 21 :00 9.00 CLEAN P DECOMP PJSM. RIH wI tubing dress off BHA on 3 1/2" DP, picking up DP 1 x 1. Tag top of 7" Liner gently at 8120' DPM. Rotate and fell right into Liner. Continue TIH 1 x 1 to top of Tubing Stump @ 10,400'. 21 :00 - 22:00 1.00 CLEAN P DECOMP In with joint # 318. Establish parameters before dressing off Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/711980 End: 5/17/2006 5/412006 21 :00 - 22:00 1.00 CLEAN P DECOMP Tubing Stump. Up Wt = 155K, Dn Wt = 115K. PU joint # 319 and RIH to tag top of Stump. Tag top of 4.5" Tubing Stump @ 10,399' DPM. Lay down joint # 319. PU and MU Kelly. Up Wt = 159K , Dn Wt = 119K. Bring on circulation @ 3 bpm I 480 psi. Rotate pipe to establish parameters. Rotating Wt = 135K at 30 RPM with 150 Amps (3,000 ft-Ib) of torque. RIH to top of Stump and dress off about 3". 22:00 - 00:00 2.00 CLEAN P DECOMP PU 2' above Tubing Stump and circulate a 20 bbls high-vis sweep down the DP @ 5 bpm 11300 psi. Pumped a total of 626 bbls to displace the sweep all the way back to surface. 5/5/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Continue circulating the high-vis sweep around. Getting it back as of 00:00 hrs. Stop circulating at 00:30 and stand back Kelly. 01 :00 - 06:00 5.00 CLEAN P DECOMP PJSM. Begin TOH with BHA #2 on 3.5" DP while standing back DP. Total of 106 stands of DP (318 joints). 06:00 - 08:30 2.50 CLEAN P DECOMP PJSM. Stand back 4 3/4" DCs & UD tubing stub dress off BHA. Pick up Halliburton 7" RBP. 08:30 - 12:00 3.50 CLEAN P DECOMP RIH wI Halliburton 7" RBP on 3 1/2" DP. 86 stands. Up wt = 117K, Down wt = 95K. Work thru liner top. 12:00 - 13:00 1.00 CLEAN P DECOMP PJSM. WI 86 stands & (2) singles in, set Halliburton RBP wI fishneck @ 8221'. 13:00 - 14:30 1 .50 CLEAN P DECOMP PJSM. Pressure test RBP wI 2500 psi 115 minutes, good test, no indication of pressure increase on 0/A. Dump 700# of river sand down DP & chase wI seawater, (1) DP volume. Tag top of sand @ 8187' DPM. 14:30 - 18:00 3.50 CLEAN P DECOMP PJSM. POOH w/3 1/2" DP & Halliburton running tool. 18:00 - 18:30 0.50 CLEAN P DECOMP Halliburton running tool on surface. Break down and lay down running tool. Service the Rig and pre-tour safety meeting I crew change out. 18:30 - 19:30 1.00 CLEAN P DECOMP P/U and M/U BHA #3 as follows: "TBR" Polishing Mill, XO, Spacer Sub, "TBR" Top Dressing Mill, Pup Jt, Double Pin Sub, 9 5/8" Casing Scraper, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Jar, (9) Drill Collars. OAL = 328.22'. 19:30 - 22:00 2.50 CLEAN P DECOMP PJSM. Begin TIH with BHA #3 on 3.5" DP from Derrick. 22:00 - 22:30 0.50 CLEAN P DECOMP P/U and M/U Kelly. Establish parameters: Up Wt = 130K , Down Wt = 103K. RIH and stack weight at 25' Kelly in the hole = 8125'. Pick up and bring on rotation at 45 RPM with 120 Amps (2500 ft-Ib) of torque and Rotating Wt = 117K. Circulating at 3 bpm I 350 psi. Work BHA up and down through Liner Top at 8120' multiple times to clean out I dress. 22:30 - 00:00 1.50 CLEAN P DECOMP Line up to reverse circulate and begin reverse circulating a 30 bbl high-vis sweep. Chase the sweep with 555 bbls of hot seawater pumped at a rate of 5 bpm 11000 psi. Returns indicating scale like material coming back, 5/6/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Continue reverse circulation of 30 bbl high-vis sweep. Sweep came back impregnated with scale pieces. 01 :00 - 03:30 2.50 CLEAN P DECOMP PJSM. Blow down lines and stand back Kelly. Begin TOH with BHA #3 while standing back 82 stands (246 jts) of DP in the Derrick. 03:30 - 04:00 0,50 CLEAN P DECOMP PJSM, On surface with BHA #3. Break down and lay down components. Inspected boot baskets and had about (1) cup of scalelfill in them. 04:00 - 06:00 2.00 EV AL P DECOMP PJSM. RD Flow Adapter and RU Shooting Flange. Schlumberger E-line on location and begin spotting equipment. Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/711980 End: 5/17/2006 5/612006 04:00 - 06:00 2.00 EVAL P DECOMP PU logging tools and equipment to Rig Floor. 06:00 - 06:30 0.50 EVAL P DECOMP Pre Job meeting wI Schlumberger & rig personel regarding USIT logging. 06:30 - 07:00 0.50 EVAL P DECOMP Finish rigging up SWS, 07:00 - 09:30 2.50 EVAL P DECOMP Run USIT from 2900' to surface. Tentative cement top showing to be @ 280'. Repeat pass. 09:30 - 12:00 2.50 EVAL P DECOMP PJSM. Rig down SWS. N/D shooting flange, nipple up flow nipple, prep floor. 12:00 - 13:30 1.50 FISH P DECOMP PJSM. Pick up Baker multi string cutter dressed to cut 9 5/8" casing, blades will extend out to 11", M/U on (2) stands 4 3/4" DCs. 13:30 - 14:00 0.50 FISH P DECOMP RIH wI cutting BHA on 3 1/2" DP, (2) jts. Kelly up, Up wt = 23K, down wt = 23K, rotating wt = 23K. Bring on pump @ 200 psi & slack off, locating collar @ 266'. Repeat to verify, OK. 14:00 - 14:30 0.50 FISH P DECOMP PJSM. Position cutter @ 260' DPM. Kick in rotary table @ 70 - 80 RPM & gradually bring on pump to 3114 bpm 1725 psi & observe torque increase from 1500 ftllbs to 3000 ftllbs during cutting operations. After (20) minutes, see torque smooth out @ 1500 ftllbs. Pump pressure remaining @ 725 psi, due to stops on cutter not allowing cutter blades to fully extend past 11 ". 14:30 - 15:00 0.50 FISH P DECOMP PJSM. Close annular preventor. Line up 9 518" x 13 3/8" annulus thru choke to tiger tank & attempt to break circulation. Observe pressure increase to 2000 psi with no indication of returns, See pipe begin to hydraulic out of the hole wI 2200 psi 7 shut down pump. Bleed pressure off, close pipe rams & repeat process. With 2000 psi, unable to break circulation. Shut down pump & bleed off all pressure. No fluid lost during this operation. 15:00 - 16:00 1.00 FISH P DECOMP PJSM. Reposition cutter @ 260' as before & repeat cutting procedure in same spot. Slack off 1 K a couple of times, effectively cutting a section & seeing cement back in returns. 16:00 - 17:30 1.50 FISH P DECOMP PJSM. Line up & attempt to circulate down 95/8" casing & up 9 5/8" x 13 3/8" annulus, pumping 3 bpm I max pressure achieved = 250 psi. 17 bbls away wI no indication of pressure increasing, Line up on 9 5/8" x 13 3/8" annulus & pump (7) strokes, or 1/2 bbl & observe pressure increase to 2500 psi. Shut down & observe pressure slowly bleed to 1650 psi in 10 minutes. 95/8" casing is on a vacuum.... 17:30 - 18:00 0.50 FISH P DECOMP Service the Rig and crew changeout. Consult with Anchorage Engineering for plan forward. Pressure up on OA one more time and achieved 2500 psi with 1/4 bbl pumped. Bleed pressure off. 18:00 - 19:30 1.50 FISH P DECOMP PJSM. Break down BHA #4 and lay down components. PU and begin MU BHA #5 as follow: Bull Nose, Pack Off, ITCO Spear, Extension, Stop Sub, XO. OAL = 14.45'. 19:30 - 20:30 1.00 FISH P DECOMP PJSM with Nabors, Baker and Cameron, RIH with Spear and plant in the 9 5/8" Casing Hanger. BOLDS. Remove all personnel from Drilling Floor. Work pipe up to 100K, 95/8" casing not coming free. Decision made to re-cut 9 5/8" above collar @ 174'. Release Spear and break down BHA #5. 20:30 - 21 :00 0.50 FISH C DECOMP RILDS. MU BHA #6 to cut 9 5/8" Casing as follows: Multi-String Cutter, XO, Stabilizer, XO, DC's. OAL = 100.98'. Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/7/1980 End: 5117/2006 5/612006 21 :00 - 22:30 1.50 FISH C DECOMP Start TIH wiht BHA #6. PU and MU Kelly to locate collars. Locate collars @ 107',150' and 190'. Cement sheath around collar at 150' so decision made to cut 2' above it at 148'. Collar depths compared to those on USIT. 22:30 - 23:30 1.00 FISH C DECOMP Begin cutting at 148' per Baker rep. UW = 12K, DW =12K , RW = 13K. Bring on rotation at 45 RPM with 60 Amps (1,000 ft-Ib) of torque pumping at a rate of 2 bpm 1180 psi. Increase rotation to 60 RPM and pump rate to 4 bpm I 950 psi. Torque increased to 90 Amps (2,000 ft-Ib). 23:30 - 00:00 0.50 FISH C DECOMP Attempt to establish circulation with seawater down the DP and up the OA taking returns to the Tiger Tank. Establish circulation rate of 4 bpm 11000 psi and getting returns to Tiger Tank. Initial returns were diesel so continue to circulate until getting seawater returns. Pumped a total of 30 bbls. 5/7/2006 00:00 - 00:30 0.50 FISH C DECOMP TOH with BHA #6. 00:30 - 01 :00 0.50 FISH C DECOMP On surface with BHA #6. Break down and MU BHA #7 as follows: Bull Nose, Pack Off, ITCO Spear, Extension, Stop Sub, XO. OAL = 14.45'. (Same configuration as BHA #5) 01 :00 - 01 :30 0.50 FISH C DECOMP PJSM. BOLDS. Plant Spear in 9 5/8" Casing Hanger and begin working pipe. Came free at 70K. Weight as bringing string to surface was 20K. Got Hanger to surface and completely coated with metal shavings from both cuts. Wipe down Hanger. 01 :30 - 02:00 0.50 FISH C DECOMP PJSM. RU to handle 95/8" Casing. 02:00 - 03:30 1.50 FISH C DECOMP Begin POOH with 9 5/8" Casing joints and laying them down in the Pipe Shed. Recovered (2) full joints and the cut joint below it. Lengths of 9 5/8" Recovered: Hanger = 4.55', Joint #1 = 41.00', Joint #2 = 38.76', Cut Joint = 39.91 '. OAL = 124.22', 03:30 - 06:00 2.50 FISH C DECOMP PJSM. RD 9 5/8" handling equipment off Rig Floor. Clear and clean Rig Floor. 06:00 - 06:30 0.50 FISH C DECOMP Service rig & review plan forward. 06:30 - 07:00 0.50 FISH C DECOMP Pick up & make up Halliburton 9 5/8" Fas Drill composite bridge plug on (3) stands 4 3/4" DCS. 07:00 - 07:30 0.50 FISH C DECOMP PJSM. Pick up (1) jt DP & RIH 5'. 23K up wt, 23K down wt. WI bridge plug @ 290' DPM, rotate to the right (25) turns, max torque = 2500 ftllbs. Shut down rotary table & pick up to 35K & wait 5 minutes. Close annular preventor to minimize surface shock & pick on up to 65K. Pull to 78K, (55K over), and observe shear. Set back down on bridge plug & verify set, OK. 07:30 - 08:30 1.00 FISH C DECOMP POOH & UD Halliburton running tool. 08:30 - 09:30 1.00 FISH C DECOMP PJSM. M/U muleshoe on DP & RIH (3) stands & tag top of Fas Drill Bridge Plug @ 295'. 22K up wt, 22K down wt. Pick up (2') & M/U headpin. 09:30 - 10:00 0.50 FISH C DECOMP PJSM. Line up on 80 degree 9,8 ppg brine & pump down DP @ 4 bpm 1120 psi. 10 bbls to fill hole. Pump 57 bbls, getting 9.7 ppg back. Close annular preventor & inject @ 2 bpm 1120 psi, 3 bpm 1190 psi, & 4 bpm I 240 psi. 10:00 - 11 :00 1.00 FISH C DECOMP PJSM. POOH wI DP & UD mule shoe, 11 :00 - 12:00 1.00 FISH C DECOMP PJSM, M/U Halliburton 9 5/8" composite cement retainer. 12:00 - 17:00 5.00 FISH C DECOMP PJSM. RIH wI Halliburton retainer on DP, tag & stack out @ top of 9 5/8" stub @ 145'. Unable to work thru, POOH & pick up (2) stands DCs & attempt to get thru, no go. Inspect retainer, nothing unusual. M/U 9 5/8" scraper & RIH, work thru 9 5/8" stub @ 145' wI 2 - 3K, work scraper up & down thru stub Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/7/1980 End: 5117/2006 5/7/2006 12:00 - 17:00 5.00 FISH C DECOMP & run on down to setting depth of 240', OK. POOH, UD scraper & pick up retainer. RIH, bounce her thru, (lightly), & go on down to setting depth of 240'. (6) 43/4" DCs, (1) jt of 31/2" DP & 14' in on 3 1/2" DP pup. M/U headpin & circulating hose. 19K up & down. 17:00 - 17:30 0.50 FISH C DECOMP PJSM. Rotate retainer (25) turns to the right. Close annular preventor & shear w/70K, (51 K over). Rotate another 35 turns, stab back in & verify able to inject @ 2 bpm 1190 psi, OK. Wait on cementers. 17:30 - 20:00 2.50 FISH C DECOMP Crew changeout at 18:00 hrs. Wait on cementers and cement test. 20:00 - 21 :30 1,50 REMCM C DECOMP RU Schlumberger cementers and get Rig Floor ready for cement job. 21 :30 - 22:00 0.50 REMCM C DECOMP PJSM with Nabors, Schlumberger and Veco personnel to discuss pumping procedure and hazards associated. 22:00 - 00:00 2.00 REMCM C DECOMP Check all lines. Start pumping 5 bbl freshwater lead at a rate of 3 bpm 1350 psi through the lines down the DP. Shut down and pressure test to 2000 psi - good test. Start batching up cement in cementers. Begin pumping neet, Class G, 15.8 ppg cement. Slowly increase to a pump rate of 4 bpm I 550 psi. Pump a total of 50 bbls. Begin pumping cement with 10 Iblbbl aggregate immediately behind the neat cement. Pumping at a rate of 4 bpm I 700 psi. Pump a total of 50 bbls. Slow rate down to 0.5 bpm I 90 psi continuing to pump cement with 10 Iblbbl aggregate. The well appears to be on a slight vac so after 10 more bbls pumped away (110 total away) increase to a rate of 3 bpm I 400 psi and increase to 15 Iblbbl aggregate to try and lock up. Shut down pumping with 141 total barrels away. PU and sting off of retainer. Displace cement in DP and lines on top of retainer with 2 bbls of water. CIP @ 23:30 hrs. 5/8/2006 00:00 - 00:30 0.50 REMCM C DECOMP PJSM. PU to reverse circulate DP clean of any cement stringers. Reverse circulate at a rate of 6 bpm I 640 psi. Pumped a total of 60 bbls. Blow down lines over to the cementers. Begin to RD Schlumerger and have them clean out with 100 bbls of fresh water. 00:30 - 01 :00 0.50 REMCM C DECOMP Begin TOH with Halliburton setting tools. Break down on surface and inspect tools. Looked good. 01 :00 - 09:00 8.00 REMCM C DECOMP Wait on cement to harden prior to continuing downhole work. Maintain Rig. 09:00 - 10:30 1.50 REMCM C DECOMP PJSM. P/U BHA #8 which consists of 8 1/2" medium mill tooth bit & (2) junk subs, jars & bumper sub on (6) 4 3/4" DCs. Tagged top of 9 5/8" stump @ 143'. 10:30 - 11 :30 1.00 REMCM C DECOMP PJSM. Kelly up. 20K up, 20K down & 20K rotating wt. Bit @ 213'. Dry tag top of cement 16' in on kelly @ 229'. Pick up & bring on pump @ 4 bpm I 90 psi. Wash down & tag up again @ 229', unable to wash thruough. 11 :30 - 12:00 0.50 REMCM C DECOMP PJSM. Kick in rotary table @ 80 RPM I 500 ftllbs of torque & mill 4' of medium hard cement to 233'. @ 233', milling became significantly harder. Floor sample of cement is hard. 12:00 - 20:00 8.00 REMCM C DECOMP PJSM. Continue milling on cement. Encounter top of retainer @ 233'. DPM. Mill on retainer wI 5K WOM, pumping 4 bpm 190 psi. Saw fibergalss pieces across shaker from 233'. 20:00 - 21 :30 1.50 REMCM C DECOMP Getting cement returns across shakers with 25.5' Kelly in the Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/2/2006 5/17/2006 Spud Date: 2/7/1980 End: 5117/2006 51812006 20:00 - 21 :30 1.50 REMCM C DECOMP hole = 238.5'. No more plastic or composite returns seen. Maintaining 3K-5K WOM and pumping 6 bpm I 200 psi. Continue milling on cement. 21 :30 - 22:00 0.50 REMCM C DECOMP Kelly completely in. PU pup joint of DP (length = 23.85'). Continue milling to top of Fasdrill. Getting back soft cement returns beneath cut @ 260'. 22:00 - 22:30 0.50 REMCM C DECOMP 18' Kelly in the hole and no longer drilling off the 5K of WOM. Current depth = 287'. Stop milling and PU about 5'. RIH to tag and tag at same spot. Continue to circulate until clean returns observed. Shut down circulation and perform hole check for any losses for 30 minutes. No fluid loss observed after 30 minutes. 22:30 - 00:00 1.50 REMCM C DECOMP Begin milling Fasdrill Plug. Begin to ship out 9.8 ppg brine in Pits to Tiger Tank and displacing well to seawater. Fill Pits with seawater. At 22:45 hrs, getting pieces of rubber back in the returns across the Shakers. 5/9/2006 00:00 - 02:30 2.50 REMCM C DECOMP Continue milling through Fasdrill Plug and swapping well and Rig over to seawater. Maintaining about 80 RPM with pump rate of 6 bpm / 200 psi. Plug fell down after milling 26" off of it = 289'+. Total plug length = 46.6". Total piece remaining that fell = 20" +/-. Confirm with Halliburton in the morning of how much Plug to anticipate on top of 7" Liner. 02:30 - 06:00 3.50 REMCM C DECOMP Set back Kelly. Lay down pup joint and single joint of DP. PU (1) stand of Drill Collars and begin TIH with 3.5" DP from Derrick. 182 stands + (1) 10' pup. Pick up kelly Tag up 25' in on Kelly @ 8118'. 06:00 - 07:00 1.00 REMCM C DECOMP PJSM. Establish parameters. 130K up wt, 109K down wt, 115K rotating wt. Rotating @ 70 -80 RPM, off bottom torque = 3000 ftllbs. Pumping 4 bpm @ 550 psi. Mill on junk on top of 7" liner w/3 - 5K WOB. Mill to 8119' & note torque increase. 07:00 - 09:00 2.00 REMCM C DECOMP PJSM. Circulate sweep around @ 5 bpm / 900 psi, rubber & fiberglass across shaker, 09:00 - 12:30 3.50 REMCM C DECOMP PJSM. POOH w/3 1/2" DP & milling BHA. 12:30 - 13:30 1.00 REMCM C DECOMP PJSM. Stand back DCs & UD 8 1/2" milling BHA. 13:30 - 14:30 1.00 REMCM C DECOMP PJSM, Pick up and make-up BHA #9 which consists of 6 1/8" bit, 7" junk subs & 9 5/8" scraper. 14:30 - 17:00 2.50 REMCM C DECOMP TIH with BHA #9 on 3.5" DP. Tag @ 8119'. Lay down jt # 246. 17:00 - 20:00 3.00 REMCM C DECOMP PU and MU Kelly. UW = 130K , DW = 104K. Bring on the Pump at a rate of 4 bpm / 500 psi. Kick in the Rotary Table at 50 RPM with 150 Amps of torque (3,000 ft-Ib). Begin milling @ 8119' with 3K WOM. Work mill down into 7" Liner until 95/8" Casing Scraper bottomed out on Liner Top @ 8120'. No problems milling up. 20:00 - 00:00 4.00 REMCM C DECOMP PJSM. Begin TOH with BHA #9 while standing back DP. Cut and slip 84' of drilling line while TOH from 20:30 - 21 :30 hrs. Continue TOH. 5/10/2006 00:00 - 01 :30 1.50 REMCM C DECOMP On surface with BHA #9. Break down BHA components and lay down. PU and MU BHA #10 as follows: "TBR" Polishing Mill, XO, Spacer Sub, "TBR" Top Dressing Mill, Double Pin Sub, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Jar, Drill Collars. OAL = 317.78'. 01 :30 - 03:30 2.00 REMCM C DECOMP PJSM. TIH with BHA #10 on 3.5" DP. 03:30 - 04:00 0.50 REMCM C DECOMP 82 stands (246 jts) in the hole. PU a 23.85' pup jt. PU and MU Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/7/1980 End: 5117/2006 5/10/2006 03:30 - 04:00 0.50 REMCM C DECOMP Kelly. Establish parameters as follows: UW = 131K, DW=103K , rotating at 50 RPM with 150 Amps (3,000 ft-Ib) of torque, RW = 115K , pumping at a rate of 3 bpm I 340 psi. RIH with Mill and tag at 11'+ in on the Kelly = 8125'. PU and work down to same spot. Repeat third time. Never saw any weight on way down to top of Liner. Length from bottom of BHA to stop = 5' so bottomed out at 8120' on top of Liner. 04:00 - 06:00 2.00 REMCM C DECOMP Set back Kelly. Lay down pup joint and PU single (31.93'). Place bottom of BHA at 8119'. MU Headpin and begin reverse circulating at 3.5 bpm I 500 psi. Pump a 45 bbl hi-vis sweep around. 06:00 - 07:30 1.50 REMCM C DECOMP Finished reverse circulating Hi-Vis sweep back to surface at 3.2 bpm/500 psi. Clean returns with barrel for barrel returns. 07:30 - 10:30 3.00 REMCM C DECOMP Trip out with BHA #10. 10:30 - 11 :30 1.00 REMCM C DECOMP Lay down BHA #10. Polish Mill showed good indications that Liner Top is dressed. 11 :30 - 12:30 1.00 BOPSU C DECOMP Install test plug. Tighten gland packing nuts. 12:30 - 13:30 1.00 BOPSU C DECOMP Install 7" Pipe Rams. 13:30 - 19:00 5.50 BOPSU C DECOMP Rig-up test equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. Good Test. See comments in the remarks section. 19:00 - 20:30 1.50 CASE P TIEB1 RD 3.5" Equipment and RU 7" Handling Equipment including Torque Turn Equipment. Prepare Rig Floor for running of 7" Liner. 20:30 - 00:00 3.50 CASE P TIEB1 Run 7" Completion per program. Baker Lok'd 7" XO Joint with the Landing Collar Insert to the 7" Pup Joint below it. Added a free floating centralizer to this connection. Could not add centralizers to other pups in the shoe track due to Baker-Lok'd prior to showing up on Rig. All BTC threaded 7" being doped with Best-O-Life compound. Inserting (1) free-floating centralizer per Joint. Make-up torque = 9,000 ft-Ib. PU to check if Float Collar is holding fluid back from coming into Liner - OK. Continue running 7" BTC filling each joint up with seawater. 5/11 12006 00:00 - 04:00 4.00 CASE P TIEB1 Continue running 7" tie-back Liner BTC Joints. Ran a total of 124 Joints of 7",26# L-80 BTC, Run 7" BTC to 7" TC-II XO, Length = 38.90'. Call out Nabors Casing for TC-II running operations. 04:00 - 05:00 1.00 CASE P TIEB1 RU Nabors Casing Torque Turn to run 7" TC-II, 05:00 - 07:30 2.50 CASE P TIEB1 Continue running 7" tie-back Liner TC-II Joints. Make-up torque = 10,100 ft-Ibs. 07:30 - 08:30 1.00 CASE P TIEB1 Stop Operations to clear Derrick and Crown section of falling ice build-up. 08:30 - 11 :30 3.00 CASE P TIEB1 Continue running 7" Tie-Back Liner. Cementers and Vac Trucks on location. 11 :30 - 13:30 2.00 CASE P TIEB1 Pick-up Jt 197. PUW = 195K. SOW = 157K. Bring Pump on line at 0.5 bpm/30 psi. Ease in hole with Tie-Back Seal Assembly. Locate top of Liner. Pressure increased to 120 psi. Shut down Pump. Locate Stop Ring. Un-sting Seal section from Tie-Back Receptacle and pressure dropped to 0 psi. Lay down Jt 197 and 196, Add a 19.88', 7" 261b/ft L-80 TCII Pup Joint (drifted). Pick-up Joint 196. Sting back into Tie-Back Receptacle same as before to complete space-out. 13:30 - 14:30 1.00 CASE P TIEB1 Rig down Casing Tongs. Rig down Torque Turn equipment. Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/7/1980 End: 5117/2006 5/11/2006 14:30 - 15:30 1.00 CASE P TIEB1 Finish rig-up cementers. Install Wiper Plug in Cement Head. 15:30 - 16:00 0.50 CASE P TIEB 1 Hold pre-job safety and operations meeting with all. 16:00 - 20:30 4.50 CEMT P TIEB1 Un-sting from TBR. Trouble shoot computer problems and resolve. Prime up with 5 bbls fresh water, Pressure test lines to 4500 psi. Pump 10 bbls fresh water at 4.0 bpm. Full returns to Tiger Tank. Batch up Cement. Start Cement at 3.0 bpm/200 psi, Density 15.5 Iblgal. 15 bbls pumped at 4.8 bpm/320 psi. Density 15.791b/gal. 100 bbls pumped at 4.8 bpm/330 psi. Density 15.761b/gal. 200 bbls pumped 4.8 bpm/320 psi. Density 15.781b/gal. Final Cement pumped 231.7 bbls. End density 15.30 Ib/gals. Shut down Cement Pump. Launch Wiper Plug. Tattle-Tail "flipped" falling Cement had Well on a vacuum. Bring cement Pump back on line with Sea Water at 5.0 bpm/115 psi. Density 8.50 Iblgal. Caught pressure with 170 bbls displaced. 200 bbls displaced 3.0 bpm/940 psi. 210 bbls displace. Shut down for slight leak in Cementing Head. UN-able to completly stop. Resume displacement with caution. 240 bbls displaced. Re-route returns to Slop Tank. 298 bbls displaced. Cement returns to Slop Tank. Reduce rate to 1.0 bpm/2840 psi. Bumped Plug at 20:13 hrs with 317.4 total bbls displaced. Increase pressure to 3350 psi. Hold pressure. Close Hydrill. Open Pipe Rams. Stack-off And sting back into TBR to Stop Ring. Beed back pressure and recover 3.5 bbls. Monitor. No returns. (note calculated displacement was 310 bbls plus 2 bbls for Lines. Estimate 1 bbl for the leak. Recovered 3.5 bbls after pressure bled from landing plug). 20:30 - 21 :00 0.50 CEMT P TIEB1 RID cementing lines. Pump thru choke & kill lines to insure they are clear of cement. Prep stack to lift. 21 :00 - 22:00 1.00 WHSUR P TIEB1 N/D tubing spool. Remove choke & kill lines. P/U BOP stack. 22:00 - 22:30 0.50 WHSUR P TIEB1 P/U on casing & set slips wI 100K. 22:30 - 00:00 1.50 WHSUR P TIEB1 RID cementing head. Drain 7" casing. Make final cut wI Wachs cutter. Back out XO in 7" casing & UD cut off jt. 5/12/2006 00:00 - 00:30 0.50 WHSUR P TIEB1 Set back BOP. N/D & remove old tubing spool. 00:30 - 03:30 3.00 WHSUR P TIEB1 Clean up casing spool. Junk ring wouold not go over 7" casing stub. Run into shop & machine out junk ring. Prep to install new spool. 03:30 - 05:30 2.00 WHSUR P TIEB1 Install new new pack off & tubing spool. N/U BOP stack. 05:30 - 06:00 0.50 BOPSU P TIEB1 Change out 7" pipe rams to 3 1/2" x 6" VBPRs. 06:00 - 07:30 1.50 BOPSU P TIEB1 Test Pack-off to 3,800 psi/30 min. Good. Tested 3 1/2" VBPR at 250/3500 psi/5 min. Good test. Tested new TIW Valve at 250/3,500 psi. Good. 07:30 - 08:30 1.00 BOPSU P TIEB1 Rig-down test equipment. Pull Test Plug. Set Wear Bushing. 08:30 - 09:30 1.00 REMCM P TIEB1 Make-up BHA #11 as follows: 6 1/8" Bit, 2 ea Boot Baskets, 7" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, 9 ea 4 3/4" Drill Collars. 09:30 - 14:00 4.50 REMCM P TIEB1 Trip in with BHA #11 and 3 1/2" Drill Pipe (245 Joints). Pick-up Kelly. PUW = 142K. SOW = 96K. RW = 114K. Pump rate = 6.0 bpm/950 psi. Tag soft cement at 8,072.5'. Rotate at 70 rpms. Rotate and wash through soft Cement down to Landing Collar at 8,085'. 14:00 - 15:00 1.00 REMCM P TIEB1 Reverse Circulate & pump 20 bbl Hi-Vis sweep. 5 BPM @ 1030 psi. Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/2/2006 5/17/2006 Spud Date: 2/7/1980 End: 5/17/2006 5/1212006 15:00 - 18:00 3.00 REMCM TIEB1 Drill float collar & shoe track from 8085 to 8120'. Pump 20 bbls Hi-Vis sweep. 5.5 BPM @ 1250 psi. 18:00 - 20:00 2.00 REMCM P TIEB1 Con't to drill out cement stringers & shoe track from 8120 to 8187' . 5 BPM @ 1000 psi. WOB 4-8K, 75 RPMs, P/U Wt = 142K, SIO wt = 96K. Rot Wt = 115K. 20:00 - 21 :00 1.00 REMCM P TIEB1 Circulate hole clean. 5.3 BPM @ 1100 psi. Circulated out much cement. 21 :00 - 21 :30 0.50 REMCM P TIEB1 Blow down lines. Set kelly back. Pull & UD 2 jts of 31/2" DP. 21 :30 - 22:30 1.00 REMCM P TIEB1 RIU test equip. Test 7" casing to 3500 psi for 30 min. Recorard on Chart. OA valve open and monitored. Good test. 22:30 - 23:00 0.50 REMCM P TIEB1 Reverse out 2112 DP volumes.. 5 BPM @ 1000 psi. recoverd some drilled cement. 23:00 - 00:00 1.00 REMCM P TIEB1 POOH w/3 1/2" DP. 5/13/2006 00:00 - 01 :30 1.50 REMCM P TIEB1 Con't to POOH wI Clean out assy & stand back 31/2" DP. 01 :30 - 02:00 0.50 REMCM P TIEB1 Break out & UD BHA. Clean out boot baskets. Recovered 1 sliver ( 4" long) of casing from cutting operation. & 2 gals of cement. 02:00 - 02:30 0.50 REMCM P TIEB1 M/U BHA # 12 to clean up junk as follows; RCJB, XO, 2 boot baskets, XO, Bumper Sub, Jars, 9' 4 3/4" DCs. TL = 320.06'. 02:30 - 05:00 2.50 REMCM P TIEB1 RIH wI BHA #12 on 31/2" DP. P/U kelly & break circulation. 05:00 - 06:00 1.00 REMCM P TIEB1 Tag up on fill @ 8183'. Wash, drill & mill wI RCJB from 8183 to 8192'. 5 BPM @ 1400 psi. 50 RPMs, Torq 3-4.5K, P/U wt = 142K, SIO Wt = 97K, Rot Wt = 115K. 06:00 - 06:30 0.50 REMCM P TIEB1 Lube Rig. Inspect Derrick. 06:30 - 09:00 2.50 REMCM P TIEB1 Trip out with 3 1/2" Drill Pipe and RCJB Run #1. 09:00 - 09:30 0.50 REMCM P TIEB1 Lay down RCJB and Boot Baskets. Recovered some rubber, 1 piece of metal, small pieces of Composit Plug, and a jumbo size part from the Composit Plug. Boot Baskets were full of sand. 09:30 - 10:00 0.50 REMCM P TIEB1 Make-up the same BHA for Run#2, 10:00 - 12:00 2.00 REMCM P TIEB1 Trip in with 3 1/2" Drill Pipe and BHA Run #2. 12:00 - 13:30 1.50 REMCM P TIEB1 Pick-up Kelly. Wash and rotate down to 8,200'. 13:30 - 14:00 0.50 REMCM P TIEB1 Set back Kelly. 14:00 - 17:00 3.00 REMCM P TIEB1 Trip out with 31/2" Drill Pipe and BHA Run#2. 17:00 - 17:30 0.50 REMCM P TIEB1 Lay down RCJB and Boot Baskets. Recovered a few pieces of rubber and Composite Plug. Nothing big. Boot Baskets were full of sand. 17:30 - 19:30 2.00 REMCM P TIEB1 RIH wI RCJB, Run # 3 on 3 1/2" DP. 19:30 - 20:00 0.50 REMCM P TIEB1 M/U kelly. Break circulation, 5 BPM @ 1400 psi. Wash from 8200 to 8207'. work RCJB up & down several times. Did not need to rotate. 83 stands + BHA + 20' kelly. P/U & set back kelly. 20:00 - 22:30 2.50 REMCM P TIEB1 POOH & stand back 31/2" DP. 22:30 - 23:00 0.50 REMCM P TIEB1 UD RCJB & empty boot baskets. Recovered 20, 112 dollar size & smaller pcs of metal + 3 pcs of rubber. 23:00 - 23:30 0.50 REMCM P TIEB1 P/U BHA wI RCJB & longer extension. 23:30 - 00:00 0.50 REMCM P TIEB1 RIH wI BHA # 14 on 3 1/2" DP. 5/14/2006 00:00 - 02:00 2.00 REMCM P TIEB1 RIH wI BHA #14 on 3 1/2" DP. 02:00 - 03:00 1.00 REMCM P TIEB1 Cut & slip 84' of drilling line. 03:00 - 03:30 0.50 REMCM P TIEB1 P/U kelly break circulation, 5 BPM @ 1400 psi. Wash down wI RCJB wlo rotating from 8207 to 8221' (tag top of Halco RBP). 83 stands + BHA + 31' kelly. Work RCJB up & down 5 times. 03:30 - 06:00 2.50 REMCM P TIEB1 Set back kelly & POOH wI RCJB & stand back 31/2" DP. Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/2/2006 5/17/2006 Spud Date: 2/7/1980 End: 5117/2006 5/14/2006 06:00 - 06:30 0.50 REMCM P TIEB1 Lub Rig. Inspect Derrick. 06:30 - 07:30 1.00 REMCM P TIEB1 Finished POOH with 3 1/2" Drill Pipe and RCJB Run #4. 07:30 - 08:00 0.50 REMCM P TIEB1 Lay down RCJB and Boot Baskets. RCJB was empty. Both Boot Baskets were full of sand. 08:00 - 08:30 0.50 PULL P DECOMP Pick-up Halco Retrieving Tool. 08:30 - 11 :00 2.50 PULL P DECOMP Trip in with Retreiving Tool and 3 1/2" Drill Pipe. Tag sand at 8,219'. 11 :00 - 12:00 1.00 PULL P DECOMP Mix and reverse in with a 40 bbl Hi-Vis sweep at 5.0 bpm/1500 psi. Reverse circulate out remaining sand and clean up Well. 12:00 - 12:30 0.50 PULL P DECOMP Latch Halco RBP at 8,221' Release RBP. 12:30 - 16:00 3.50 PULL P DECOMP Trip out with 3 1/2" Drill Pipe and Halco RBP. 16:00 - 16:30 0.50 PULL P DECOMP Lay down RBP. Recovered both elements. However, a few chunks were missing form the upper element. 16:30 - 17:00 0.50 PULL P DECOMP Clean and clean Floor. Prep for the next BHA. 17:00 - 18:00 1.00 PULL P DECOMP P/U & M/U BHA # 15 as follows: 35/8" 5 bladed mill, Shear-thru Sub, Triple connect, 4 jts of 2 7/8" PAC DP, X),XO, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, Pump Out Sub, 9 * 43/4" DCs. TL = 444.38'. 18:00 - 21 :30 3.50 PULL P DECOMP RIH wI BHA # 15 on 31/2" DP. 21 :30 - 22:30 1.00 PULL P DECOMP Tag up on 41/2" liner top @ 10399'. P/U & work pipe & go down into 4 1/2" liner. P/U kelly & break circulation. Tag up on FDBP @ 10458'. 105 stands +31.93' sigle + 19' of kelly. P/U Wt = 184K, SIO Wt = 105K. 3 BPM @ 600 psi. attempt to rotate string. rotary stalling out @ torque limit for PAC DP connections. ( 4000 ft-Ibs). Work pipe up & down & attempt @ lower gear. No good. 22:30 - 00:00 1.50 PULL N DPRB DECOMP Mix 50 bbl Steel Lube EP pill. Pump around @ 4 BPM, 1050 psi & work pipe. Drag dropped off 9K, but still not able to rotate wlo stalling @ torq limit. attempt several times in low & 2ng Gear. Plan to POOH & P/U motor. 5/15/2006 00:00 - 04:30 4.50 PULL N DPRB DECOMP POOH wI BHA #15 & stand back 31/2" DP. 04:30 - 07:00 2.50 PULL N DPRB DECOMP Re-dress BHA & P/U 2 7/8" Mud Motor. BHA #16 as follows: 5-Blade Junk Mill, Mud Motor, XO, Shear Through Bit Sub, 6 1/8" Mill Shoe, 3 ea Extentions, Shear Through Giude, 4 ea 2 7/8" PAC Drill Pipe, XO, XO, 2 ea Boot Baskets, XO, Bumper Sub, Oil Jar, 9 ea 4 3/4" Drill Collars, Pump-Out-Sub. 07:00 - 11 :00 4.00 PULL N DPRB DECOMP Trip in with BHA #16 and 3 1/2" Drill Pipe. Center over 41/2" Tubing Stump at 10,399'. Shear pins and allow Mill to continue down to Fas-Drill Plug at 10,458' with no problems. 11 :00 - 11 :30 0.50 PULL P DECOMP Pick-up Kelly. PUW = 156K. SOW = 119K. Bring pump on line at 2.0 bpm/300 psi. 11:30 -14:00 2.50 PULL P DECOMP After several minutes of drilling on Plug all returns were lost. Plug appears to be "spinning". Slowly working plug downhole. Rate 2.0 bpm/30 psi. Continue to chase Plug out through end of Tubing Tail. WLEG = 10,504'. Mill depth = 10,520'. 14:00 - 14:30 0.50 PULL P DECOMP Set back Kelly. 14:30 - 22:00 7.50 PULL P DECOMP POOH with 3 1/2" Drill Pipe and BHA. Single down Drill Pipe in Pipe Shed. ( Double displace). 22:00 - 23:00 1.00 PULL P DECOMP Break out & UD BHA. 23:00 - 23:30 0.50 PULL P DECOMP P/U running tool & retreive Wear Bushing. UD same. 23:30 - 00:00 0.50 PULL P DECOMP Clear & clean rig floor. Load pipe shed wI completion jewelry. 5/16/2006 00:00 - 01 :00 1.00 RUNCO P RUNCMP RIU floor & Torq Turn equip to run 4 1/2" completion. Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/7/1980 End: 5117/2006 Hold PJSM wI all hands. Review running procedure & assignment for completion. 01 :30 - 02:30 1.00 RUNCMP P/U & Baker-Lok tail pipe assys. Run Packer & "X" nipple assy. Torq turn all connections to 4440 ft-Ibs. 02:30 - 06:00 3.50 RUNCMP P/U & RIH w/4 1/2" 12.6#, 13Cr, Yam Top tubing. Torq Turn all connections to 4440 ft-Ibs. Using double displacement fill while running completion, 06:00 - 18:00 RUNCMP Finished running 4 1/2" Completion as Follows: Unique Overshot, X-Nipple w/RHC-M Plug, 1 Jt Tbg, Baker Packer, X-Nipple, 7 Jts Tbg, GLM w/Dummie, 60Jts Tbg, GLM w/Dummie, 58 Jts Tbg, GLM w/Dummie, 38 Jts Tbg, GLM w/Dummie, 40 Jts Tbg, GLM w/DCK Shear-Out Valve, 27 Jts Tbg, X-Nipple, 48 Jts Tbg, (Space out Pups as needed) 1 Jt Tbg (Jt #280). Pick Joint # 281 to tag. 18:00 - 19:30 1.50 RUNCO P RUNCMP Tag top of stub wI 27' in on jt 281. Con't down to 32' & located shear pins. Sheared pins wI 15K & bottomed out @ 35.5' in on jt # 281. P/U wI 5K overpull, then dropped off to P/U wt. M./U circulating pin & break circulation to verify. No change in pressures (due to Well drinking fluid as fast as pumped). Bottomed out @ same depth (10397'). P/U 2' & calculate space out. POOH & UD jt #281. Space out & bury 5.83' & 3.71' pups. M/U hanger & landing jt. Prep to circdulate. P/U Wt =119K, SIO Wt= 95K. 19:30 - 20:30 1.00 RUNCO RUNCMP Clear floor & RID Torq Turn equip. 20:30 - 23:30 3.00 RUNCO RUNCMP Pump 210 bbls of 140 degree seawater followed by 200 bbls of 140 degree inhibited seawater. Pumped 3 BPM @ 50 psi. No returns. 23:30 - 00:00 0.50 RUNCO RUNCMP Land hanger. RILDS. Drop rodlball. UD landing jt. P/U Wt = 119K, SIO Wt = 95K. 5/17/2006 00:00 - 02:30 2.50 RUNCO RUNCMP Fill tubing wI charge pump, Est. FL +1- 1800'. Took approx. 25 bbls. Lots of air. Repeat several times to get air out of tubing.Took 1 hr & 45 min, to get enough air out to attempt test. Pressure up on tubing & set packer, con't to pressure up to 3500 psi & test tubing for 30 min. Good test. Charted same. Bleed tubing to 1500 psi. & SI. 02:30 - 04:30 2.00 RUNCO P RUNCMP Fill annulus in 10 bbl stages to get air out of IA. Wait 5 min between pumping. total fluid pumped until returns were 32 bbls. Calc FL @ +1- 1700'. Pressure up on IA to 3500 psi & test for 30 min, Good test. Charted same. Bleed off tubing pressure to 1100 psi & D CK-2 sheared. IA & tubing bled to 0 psi. Pump thru DCK-2 both ways @ 3 BPM, 1500 psi. 04:30 - 05:00 0.50 WHSUR P RUNCMP Blow down lines. Set TWC & test 1000 psi. 05:00 - 06:00 1.00 BOPSU P RUNCMP N/D BOPE. 06:00 - 07:30 1.50 WHSUR P RUNCMP N/U Adapter Flange & Tree. 07:30 - 08:00 0.50 WHSUR P RUNCMP Pressure test hanger void to 5000 psi. Test Good. 08:00 - 08:30 0.50 WHSUR P RUNCMP Fill tree & testr tree to 5000 psi. Test Good. 08:30 - 09:30 1.00 WHSUR P RUNCMP P/U lubricator & pull TWC. UD same. 09:30 - 11 :00 1.50 WHSUR P RUNCMP RIU Hot Oilers & pressure test lines to 1000 psi. Pumped 80 bbls of diesel to freeze protect well. Pumped 2 BPM @ 1000 psi. 11 :00 - 12:00 1,00 WHSUR P RUNCMP RIU tree to U-tube. Allow well to U-tube & equalize. 12:00 - 12:30 0.50 WHSUR P RUNCMP Install BPV. 12:30 - 13:00 0.50 WHSUR P RUNCMP Blow down & RID all lines. Secure cellar & wellhead, Printed: 5/22/2006 11 :56:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/2/2006 Rig Release: 5/17/2006 Rig Number: Spud Date: 2/711980 End: 5/17/2006 5/17/2006 12:30 - 13:00 0.50 WHSUR P RUNCMP ...RELEASE RIG @ 1300 Hrs... Printed: 5/22/2006 11 :56:53 AM TREE - 4-1/16" CrN WELLHEA>D ¡: McBlOY SSH I GRAY GEN 2 ACTUA TOR = KB. ELBI - BF. ELBI - KOP- Max Angle = Datum MD = Datum1VD- 69.40' 23.77' 8300' 93 @ 11090' 10517' 8800' SS I TOP OF 9-5/8" CSG I 113-3/8" CSG, 72#, L-80, ID = 12.347" I 17" TIEBACK CSG, 26#, L-80 TCII, ID = 6.276" I 17" TIEBACK CSG, 26#, L-80 BTC, ID = 6.276" 17" TIEBACK CSG, 26#, L-80 TCII, ID = 6.276" Minimum ID = 3.725" @ 10493' 4-1/2" HES XN NIPPLE TOP OF WHIPSTOCK I 4-1/2"TBG, 12.6#, 13CR80VAM, .0152 bpf, ID = 3.958" . SA_~OTES: ***4-1/2" CHROMETBG*** 20W"0 TALLY DEPTH DISCREPANCY - ALL DEPTHS NOTED BY"*" (OVERSHOT SWALLOWED 6' OF TBG STUB). 12-08C ~ g / ~ I . I 2090' * --J4-1/2" HES X NIP, ID = 3.813" I 143' 2714' 2936' I GAS LIFT MANDRELS ST MD 1VD DBI lYPE VLV LATCH 5 3237 3235 4 KBG-2 DCK BEK 4 4938 4802 37 KBG-2 DMY BK 3 6453 5990 43 KBG-2 DMY BK 2 8228 7245 40 KBG-2 DMY BK 1 10052 8498 48 KBG-2 DMY BK ~ PORT DATE o 05/14/06 o 05/14/06 o 05/14/06 o 05/14/06 o 05/14/06 L 8051' I 8110' I 8111' -17"TIEBACKSEALASSY,ID=6.18" I 8121' -19-5/8" x 7" ZXP LNR TOP PKR, ID = 6.300" I I MILLOUT WINDOW 8300' - 8316' I I 10291' * 1-14-1/2" HES X NIP, ID = 3.813" I .J 10312'* LJ7"X4-1/2"BKRS-3PKR,ID-3.875" I .J 10336' * 1--J4-1/2" HES X NIP, ID = 3.813" I .J 10399' 1-14-1/2" TBG STUB (05/14/06 DIMS) I 10390' * 1-17" X4-1/2" UNIQUE OVERSHOT I 10428' -14-1/2" HES x NIP, ID = 3.813" I 10449' -17" x 4-1/2" BKR 8-3 PKR, ID = 3.875" I J 10472' 1-14-1/2" HES x NIP, ID = 3.813" I 8300' 10388' I-- ~ ~ I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9295' 1----'- ~ I TOP OF CEMENT I 10138' ) 17" x 3-1/2" OTIS BWD PERM PKR, ID = 4.00" I 10359' Co ~ ~ 17" LNR, 29#, L-80, .0372 bpf, ID = 6.184" I 1 0650' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 90 @ 11189' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SLTD 11189 -11699 0 07/22/02 SLTD 12018-12411 0 07/22/02 SL TD 12806 - 12923 0 07/22/02 SLTD 13558 - 13910 0 07/22/02 DATE 03/26/80 12/11/81 07/22/02 05/14/06 05/21/06 OS/24/06 RBI BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (12-08B) DAV/KK RIG SIDETRACK (12-08C) N4ES RWO DCRlTLH DRLG DRAFT CORRECTIONS /TLH TREE/WH CORRECTIONS .A 10493' -14-1/2" HES XN NIP, ID = 3.725" I I 10504' 1--14-1/2" WLEG, ID = 3.958" I I H ELMD TT NOT LOGGED I ~509' 7" X 4-112" ZXP LNR \Y \" TOP PKR, Ð ~ 4.420" , t- , , , , , , , 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10504' I ! 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 10681' 1 ' "" '. ~ 14-1/2"LNR,12.6#,L-80,.0152bPf,ID=3.958" H 11189' I ' " 14-112" SL TO LN" 12.6#, L-80. .0152 bpI, ID ~ 3.958" ~' DATE COMMENTS PRUDHOE BA Y UNIT WELL: 12-08C PERMIT No: "'2021360 API No: 50-029-20432-03 SEC 18, T10N, R15 339' FSL & 2' FEL, E RBI BY BP Exploration (Alaska) RECEIVED Schlumbergel' MAY 2 4 2006 ~ C~ & Gõs G..."I1S. Comm~{;;: Anchcrage NO. 3812 Alaska Data & Consulting Services 2525 Gambel! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 . I Anchorage, AK 99501 _ \ Ô \p Field: Prudhoe Bay ¡ t:J a.. Well Job# Log Description Date BL Color CO D-23A 10942207 MCNL Ie¡ tc - í~-K 04/22/05 1 (j) if IA r :/t,'chL "" L3-08 11136738 RST I/<~ - (./~ 11/04/05 1 1 L3-08 11212839 RST 1-7," ~ - 1'-/3 03/29/06 1 1 03-14A 11212846 US IT GC,", '" I~ '.J ~ 04/24/06 1 D.S. 3-09 11212840 US IT 1"1"1 - ð :}.D.. 03/31/06 1 D.S.15-17 11221562 SCMT iy;I..{-/")~ 04/10/06 1 NGI-08 11225958 US IT "·Ie... l1- (~-b;'1~ 04/11/06 1 D.S.01-04A N/A USIT -;:)L\ 1- f~;:¡ 05/06/06 1 12-08C 11221571 US IT riò';) -13 J.. 05/06/06 1 AGI-07 11221569 US IT LJ'!:c- \'1~ -óQ+ 05/05/06 1 E-15B 11212857 USIT C'\c, -04 ;J 05/18/06 1 L-50PB1 40012467 OH LDWG EDIT OF MWD/LWD ~I/~,~ - I"'=< to, 10/18/05 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~,Jt- ~I e s1l5f,o 05/19/06 . e e , e e rm,' n'I" ¡" ~i?, :1", I,!,L;::J IU¡·, ,p '\:d) , FRANK H. MURKOWSKI, GOVERNOR ALASIiA. OIL AND GAS CONSERVADONCO~SSION David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 tf).J \ '?I (p ;)J .. Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 12-08C Sundry Number: 306-098 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. / DATED this¡jday of March, 2006 Encl. .... !IC i2..fJ./oC e STATE OF ALASKA IJft} tJ ri\¡f' ALASKA OIL AND GAS CONSERVATION CO M;tj¡ON Y APPLICATION FOR SUNDRY APPROVAL. C emission ¡} 15 J I z 3 ~ 20 AAC 25 280 Alaska 011 & Gas ons. om \lJGA- ~ I z.~ll..DO(, RECEIVED MAR 2 2 2006 f Anchorage 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Other -----------~~~~ o Alter Casing III Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program III Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. / 202-136 ./ !HI Development o Exploratory 3. Address: o Stratigraphic o Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20432-03-00 7. KB Elevation (ft): 69.4' 9. Well Name and Number: PBU 12-08C /' 8. Property Designation: 10. Field / Pool(s): ADL 028330 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14070 9018 14070 / 9018 None None Casing Length Size MD ,. TVD Burst Collapse Structural 73' 20" 73' 73' 1530 520 Surface 2714' 13-3/8" 2714' 2713' 4930 2670 8300' 9-5/8" 8300' 7300' 6870 4760 LinAr 2560' 7" 8121' -10681' 7163' - 8902' 7240 5410 Liner 3569' 4-1/2" 10501' - 14070' 8790' - 9018' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): Slotted Section: 11189' - 1391 OV 8993' - 9018' 4-1/2", 12.6# / L-80 10505' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer Packers and SSSV MD (ft): 10449' / 12. Attachments: 13. Well Class after proposed work: !HI Description Summary of Proposal o BOP Sketch o Exploratory !HI Development o Service o Detailed Operations Program 14. Estimated Date for A~i 2006 15. Well Status after proposed work: / Commencing Operations: !HI Oil o Gas o Plugged o Abandoned 16. Verbal Approval: Dãte: o WAG DGINJ DWINJ o WDSPL Commission Representative: 17. I he,"byce~ at the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Nam [ avid Reew /"'\ Title Drilling Engineer J J L/ /f¿p".-.. Phone 564-5743 3/21 JOh Prepared By Name/Number: Signature ./ Date Terrie Hubble, 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ê£xo .. ro >< o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: T.e.s.+ f:>o P f {o ~SOO f~ Subsequent Form Required: \O-~ APPROVED BY ~ft~h6 Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 07/2005 O~IGtNAL RBDMS BFL MAR 2 4 zooi~~ S{¡bmit I~ Duplicate e e Well Status: Shut-in Ivishak gas-lifted producer. Well has confirmed inner x outer annulus communication when on gas-lift. The IA x OA leak path is not believed to be through the wellhead. Well is secured with a composite bridge-plug in the tubing tail. Proiect: Retrieve existing 4.5", 12.6#, L-80 IBT completion, run 7", 26#/ft, L-80 tie- back liner to surface and fully cement same, re-complete well with 4.5", 12.6#, l3Cr-80 VamTop tubing. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. 1. MIRU 4ES. Pull BPV, set and test TWC in tUbiæg h . ND tree and adapter flange. NU BOPE. Test annular to 250 psi (low) 50 si (high), remaining BOPE to 250 psi (low)/3500 psi (high) per BP and AO "" regulations. 5. 6. 7. 8. 9. Fully circulate through the pre-RWO tubing cut with heated seawater. --- Pull 4.5" , 12.6#/ft, L-80 IBT down to the tubing cut just above the packer. Run 7.5" tie-back polish mil and 9-5/8" casing scraper. Dress tie-back receptacle at 8121'md. ' Set 7" RBP at -8200'md and stack -30' of 20x40 river sand on RBP. / Run USIT log to find TOC in 9-5/8" x 13-3/8" annulus. Cut and pull 9-5/8" from TOC logged on the USIT. /' Run 13-3/8" scraper to the 9-5/8" stub. Run 7", 26#/ft, L-80 tie-back liner (top -3000' to be TC-II, remainder to be BTC-M) with ported seal-stem shoe-track. 10. Split stack and land 7" on emergency slips in existing Gray Gen2 casing head. 11. Fully cement tie-back liner to surface. / 12. Cut off excess 7" casing and install secondary pack-off. 13. NU stack and pressure test same to 250 psi/3500 psi per BP/AOGCC regulations. / 14. PT casing to 3500 psi for 30-minutes (charted). / 15. Mill up shoe track and wash down to the RBP. 16. Pull RBP. / 17. Run 7" scraper and dress-off 4.5" tubing stub. 18. Mill up composite plug. LDDP. 19. Run new 4.5", 12.6#/ft, 13Cr-80 Yam Top completion. Set and test packer to 3500 psi (tubing and inner annulus) for 30-minutes each (charted). 20. RDMO 4ES. 21. Tie well in and place on gas-lift production. / 2. 3. 4. 12/~¡J~5' óA Po SÕl- 2.48 bbls AS 1 55' bbL5 J.isr\fACeVYIlfit qHec As1 J ¿ooops; SÕ'l THEE = GRA Y 5K INU.LHEAO, = 13-5/8" GRAY G ACTUATOR = KB, ELEV = BF, ELEV = Max Angle = Datum MO = .~yr_ ,----_.~.~.~.._¥_~"m"",-".. ._y~y Datum1VD= 113-3/8" CSG, 72#, L-80, 10 = 12.347" I Minimum ID = 3.725" @ 10493' 4-1/2" HES XN NIPPLE I TOP OF WHIPSTOCK I 19-5/8" CSG, 47#, L-80, 10 = 8,681" I I TOP OF CEMENT 17" X 3-1/2" OTIS BWD ÆRM PKR, ID = 4,00" I 7" LNR, 29#, L-80, ,0372 bpf, ID = 6.184" PERFORA1l0N SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLID 11189 - 11699 SLID 12018-12411 SLID 12806 - 12923 SLID 13558-13910 DATE 03/26/80 12/11/81 07/22/02 08/12/02 09/29/02 03/08/03 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (12-088) DAV/KK RIG SIDETRACK (12-08C) RL/KAK GLV C/O BMlTP WAIVER SAFETY NOTE JKfTP BK LATCH CORRECTION - 12-08C 10138' 10359' 10650' ~oo~, PBD4P 92.14 GAS LIFT MANDRELS ST MO 1V0 OEV TYÆ VLV LATCH 5 2995 2993 4 MMGM DMY RK 4 3882 3870 16 MMGM DOME RK 3 6483 6010 44 MMGM DOME RK 2 8381 7358 45 KBG-2 DOME BK 1 10362 8698 51 KBG-2 SO BK PORT DATE o 08/12/02 16 08/31/03 16 08/31/03 16 08/31/03 28 08/31/03 8121' I~ 9-5/8" X 7" ZXP LNR TOP PKR, ID = 6.300" MILLOUTWINDOW 8300' - 8316' H ELMD TT NOT LOGGED I 7" X 4-1/2" ZXP LNR TOP PKR, 10 = 4.420" , , , , , '- ~ '\, , 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 7" LNR, 26#, L-80, ,0383 bpf, ID = 6.276" 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3,958" I 14-1/2" SL TO LNR, 12.6#, L-80, ,0152 bpf, ID = 3.958" I OA TE REV BY COMMENTS 08/31/03 JLJ/TLH GL V C/O 10/01/05 ElL/PAG WAIVERSFTY NOTE DELETED PRUDHOE BAY UNrr WELL: 12-08C ÆRMrr No: '2021360 API No: 50-029-20432-03 SEC 18, T10N, R15 339' FSl & 2' FEL, E BP Exploration (Alaska) TREE=' GRAY 5K WELLHEAC\=13-5/8" GRAY G ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = ~2-08C Proposed e 9-5/8" cut off just above cement top in 9-5/8" x 13-3/8" annulus /~ 7" 26#/ft L-80 tie-back liner fully cemented to surface. 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 3.725" @ 10493' 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12,6#, 13Cr-80, ID = 3.958" 1- I TOP OF WHIPSTOCK I 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I I TOP OF CEMENT 17" X 3-1/2" OTIS BWD ÆRM PKR, ID = 4.00" 17" LNR, 29#, L-80, .0372 bpf, ID = 6.184" PERFORA~ONSUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF IN1ERVAL OpnlSqz DA1E SLID 11189 -11699 SLID 12018-12411 SLID 12806 -12923 SLID 13558 -13910 DATE 03/26/80 12/11/81 07/22/02 08/12/02 09/29/02 03/08/03 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (12-08B) RIG SIDETRACK (12-08C) GL V C/O WAIVER SAFETY NOTE BK LATCH CORRECTION DA V /KK RLlKA K BMlTP JKlTP -2100' -14-1/2" HES X NIP, ID = 3.813" I ST 5 4 3 2 1 GAS LIFT MANDRELS MD 1Y PE KBG-2 KBG-2 KBG-2 KBG-2 KBG-2 VLV DCK DUMMY DUMMY DUMMY DUMMY ~ 8121' H 9-5/8" X 7" ZXP LNR TOP PKR, ID = 6.300" 7" X 4-1/2" ZXP LNR TOP PKR, ID = 4.420" 10138' 10359' 10650' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I 14-1/2" SL TD LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I DA TE REV BY COMMENTS 08/31/03 JLJ/TLH GL V C/O 10/01/05 EZLlPAG WAIVER SFTY N01E DELETED PRUDHOE BA Y UNIT WELL: 12-08C ÆRMIT No: "2021360 API No: 50-029-20432-03 SEC 18, T10N, R15 339' FSL & 2' FEL, E BP Exploration (Alaska) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Z-01 Y-13 L2-14B Y-08A X-36 X-30 S-29A P2-01 DS 12-08C ;10~" (30 D.S. 09-28A P2-34 Q-05A NK-09 NK-38A BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 11087166 N/A 10670029 11047356 11075908 10662973 11087187 11072880 11087208 11094347 N/A 11087203 11062632 11075902 .. 0 . ... ,..... . r f, iI ~ "ô fl ') fì 01 Þ. ~ANNED JMr\' &¡ U ,-v V Log Description LDL PRODUCTION LOG PROD PROFILE MEMORY/SENSA LDL MEMORY INJECTION PROFILE GLS INJECTION PROFILE LDL SBHP SURVEY LDL INJECTION PROFILE SBHP SURVEY PROD PROFILE WIDEFT MEMORY PROD PROFILE Date 08/05/05 05/01/05 08/20/04 10/15/05 08/17/05 12/02/03 10/04/05 08/06/05 12/24/05 12/28105 06/02/05 11/27/05 07/01/05 07/27/05 01/04/06 NO. 3642 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD ~ '--" Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 :::v:e:~h Permit to Drill 2021360 [)J. A~ ~.~~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 . í tÀ Jv~~ ,{ G ù )... J (J t,t-¿ )-"1 --/J V\J API No. 50-029-20432-03-00 Well Name/No. PRUDHOE BAY UNIT 12-08C Operator BP EXPLORATION (ALASKA) INC MD 14070 t// TVD 9017"'/' Completion Date 7/22/2002.-r/ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION ----"- Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, PWD, DIR, GR, RES, ASI Well Log Information: Log/ Data Digital Type Med/Fnnt fpt-c. -- ! i I i i i lbør ~c D ~( , ~ D I I ¡ I ! i ! (data taken from Logs Portion of Master Well Data Maint) Electr Dataset Number Name Directional Survey Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 8295 14070 Open 8/23/2002 -' A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/1/2002. 8295 14070 Open 8/23/2002 MWD DirectionâlStJr"Vey DirectionalSur'lJey LIS Verification 8295 14070 Open 8/23/2002 8206 14016 Case 1/31/2003 8206 14016 Case 1/31/2003 /,11507 LlSVerificatiori An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 7/1/2002. 8295 14070 Open 8/23/2002 MWD ~ c..e6~. D Directional Survey j~ CCC ;Pd:cff J>1~1117~7~555 ~:::;i:::::tiðri ~ED ~ Induction/Resistivity -~ 8206 14069 8300 14070 Case 8300 14070 Case ROP, DGR, EWR ROP, DGR, EWR 25 25 Well Cores/Samples Infonnation: Name Interval Start Stop Sample Set Number Comments Sent Received Permit to Drill 2021360 MD 14070 TVD 9017 ADDITIONAL INFORM~N Well Cored? Yl!.!Y Chips Received? ,- '(" tN -- Analysis Received? .....::f,.J.-#-- . Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Well Name/No. PRUDHOE BAY UNIT 12-08C Operator BP EXPLORATION (ALASKA) INC Completion Date 7/22/2002 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? r,. '\ C:tA N Formation Tops /?\ l!iN ~ Date: API No. 50-029-20432-03-00 -~ ).. '( ~ 'u'1'\} '1 -~ ') jO:l f 5k, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 05, 2003 RE: MWD Formation Evaluation Logs: 12-08C, AK-MW-22115 12-08C: .Digital Log Images 50-029-20432-03 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 Datk~/(~ð3 Signed: ~ , ) i WKLLLOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cûtlltll. Attn.: Lisa \Veepie ............ .'1:.",,,. . -th.. . .....'.. ~ ." ,., j j j 'IV est. f AVçmR\ ~Ultc p.)U Anchorage~ Alaska RE: MWD Fonnation Evaluation Logs 12-08C, 1 LDWG formatted Disc with verification listing. APl#: 50-029-20432-03 January 30,2003 AK-MW -22115 c51Da-/ð(o ... 11~7 L~~TTER TO THE ATTI!~NT1ON OF: . . PLE1"",SE ACKl~O"7LEDGE RECEIPT BY SICNINC AND P...ETUP....1\ffflG A. COpy OF THE TRA~rSIVHTTA!, Speny-Sun Drilling Services Attn:.Rob Kalish 6900 Àrctic Blvd. Anchorage, Aiaska 995 j ð BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 9ÛO E. Benson Blvd. "... .. ill ... -- -..-^ Ancnoragc~) AJaSKèl ~)':):JlJö Sia-~{k~j Date: RECEIVED JAN 31 2003 AJ88ka Oil & G8s Con6. Q,.. IUhl\ Anctøaae ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Ii Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 . 'yo, ,- ~ \, ~ ~, . , 4. Location of well at surface . EOMFLE'iGh\ t '!LOCA~~ ~~o~~'p~~~v~~?e~:i nON, R15E, UM .. -~-~£~:-.:J tmJ1 1865' SNL, 4205' WEL, SEC. 19, T10N, R15E, UM . YERi).,"Jill. l J.., " At total depth A~ ~ l~L.. ,.,. '.,.",::,,' .,~~~~.' 3784' SNL, 2684' WEL, SEC. 19, T10N, R15E, UM ~,- --.:~..~"~~~J ~.....--~'C-.. .,;¡u 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 69.4' ADL 028330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/12/2002 7/19/2002 7/22/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14070 9017 FT 14070 9017 FT Ii Yes 0 No 22. Type Electric or Other Logs Run MWD, PWD, DIR, GR, RES, ABI Classification of Service Well 7. Permit Number 202-136 8. API Number 50- 029-20432-03 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-08C 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2195' MD 1900' (Approx.) WT. PER FT. 94# 72# 47# 26# 12.6# CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 73' 30" 423 sx Arcticset Surface 2714' 17-1/2" ;2.279 sx Fondu Surface 8300' 12-1/4" 1500 sx Class 'G' 8121' 10681' 8-1/2" 186 sx Class 'G' 10501' 14070' 6-1/8" Uncemented Slotted Liner 23. CASING SIZE 20" 13-3/8" 9-5/8" 7" GRADE H-40 L-80 L-SO /500-95 L-80 L-80 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. SIZE 4-1/2", 12.6#, L-80 MD TVD 11189' - 11699' 8992' - 8998' 12018' -12411' 9007' - 9005' 12806' - 12923' 9009' - 9016' 13558' - 13910' 9019' - 9016' TVD MD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 10505' PACKER SET (MD) 10449' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 125 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 8, 2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL 8/18/2002 6.1 TEST PERIOD 454 Flow Tubing Casing Pressure CALCULATED OIL-BBl Press. 24-HoUR RATE GAs-McF 3228 GAs-McF WATER-BBL 7582 WATER-BBL CHOKE SIZE 83.7 OIL GRAVITY-API (caRR) GAS-Oil RATIO 7106 ::>8. 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. ,"~!f:.~:iC¿~ L,.,: .~ G \/ 0: ¡ .,--, ¡ N A ~ 0 M S B F l SEP I I ?(JQ(,mit In Duplicate Form 10-407 Rev. 07-01-80 ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 10675' 8897' Shublik 10720' 8922' Sadlerochit 10902' 8986' Sadlerochit 12735' 90041 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terne Hubb1e --ró ~ - tit ~ Title Technical Assistant 12-08C 202-136 Well Number Permit No. / Approval No. Date oCt .O&, -0 ~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ¡ " ' I t \. ! ~~- I ' .I " c Form 10-407 Rev. 07-01-80 Legal Name: 12-08C Common Name: 12-08C Test Date 7/11/2002 7/16/2002 FIT FIT Test Type Test Depth (TMD) 8,300.0 (ft) 10,701.0(ft) BP Leak-Off Test Summary TestDepth (TV D) 7,322.0 (ft) 8,912.0 (ft) AMW 10.20 (ppg) 8.50 (ppg) Surface Pressure 495 (psi) 697 (psi) Leak . Off Pressure (BHP) 4,375 (psi) 4,632 (psi) EMW 11.50 (ppg) 10.01 (ppg) ---' '"","-",,r' Printed: 7/29/2002 4:43:50 PM ') ) Legal Well Name: Common Well Name: Event Name: Con tractor Name: Rig Name: 12-08C 12-08C REENTER+COMPLETE NABORS NABORS 2ES Start: 7/8/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 2/7/1980 End: Date From-To Hours Task Code NPT Phase De$cription of operations 7/7/2002 04:30 - 05:30 1.00 MOB P DECOMP Held PJSM. Moved Camp, Rig Shop,and Pits to the End of Pad. 05:30 - 07:30 2.00 MOB P DECOMP Held PJSM. Bridled up, Lowered Cattle Chute. 07:30 - 10:00 2.50 MOB P DECOMP Held PJSM wi Rig Crews, Security, CPS, Tool Service. Moved Sub-Base off Well 0-08. Lowered Derrick. Moved Camp, and Pits to OS 12-08C. 10:00 - 22:30 12.50 MOB P DECOMP Moved Sub-Base from 0-08 to OS 12-08C. 22:30 - 00:00 1.50 MOB P DECOMP Rig on OS 12. Held PJSM. Laid Herculite and Prepared to Spot Rig over 12-08C. 7/8/2002 00:00 - 00:30 0.50 MOB P DECOMP Held PJSM. Spotted Rig Over Well, Leveled Sub-Base. 00:30 - 03:30 3.00 MOB P DECOMP Raised and Pinned Derrick, Pinned Cattle Chute. RID Bridle Lines. Rigged Up Top Drive. Set Pits, Set Berm and Cuttings Tank. 03:30 - 06:30 3.00 RIGU P DECOMP Took on Sea Water, Set Camp and Shop. R I U Rig Floor. Accepted Rig @ 0330 hrs 7/8/2002 06:30 - 07:30 1.00 RIGU P DECOMP Held Pre-Spud and Environmental Awareness Meeting wi Rig Crew. 07:30 - 08:30 1.00 RIGU P DECaMP M I U Secondary Annulus Valve. 08:30 - 09:00 0.50 RIGU P DECaMP R I U Circulating Hoses. 09:00 - 10:00 1.00 PULL P DECOMP Held PJSM. R I U DSM Lubricator, Pulled BPV, No Pressure under BPV. RID Lubricator. 10:00 - 16:30 6.50 PULL P DECOMP Circulated out Diesel Freeze Protect and Displaced Well to Clean Sea Water. Pump Rate 3 bpm, 350 psi. 16:30 - 17:00 0.50 PULL P DECOMP Held PJSM. R I U DSM Lubricator and Set BPV. Tested BPV to 1,000 psi. OK. RID DSM. 17:00 - 19:00 2.00 WHSUR P DECOMP Held PJSM. N I 0 Production Tree and Adapter Flange. Checked Tubing Hanger Threads. Changed Out One Lock Down Screw. 19:00 - 20:30 1.50 BOPSUR P DECOMP Held PJSM. N I U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Ram wi 3-1/2" x 6" Variable Rams, Blind Ram, Mud Cross, Lower Pipe Rams wi 2-7/8" x 5" Variable Rams, Lower Mud Cross. 20:30 - 21 :30 1.00 BOPSURP DECOMP Held PJSM. R I U to Test BOPE Equipment. Witnessing of BOPE test Waived by Chuck Sheeve-AOGCC. 21 :30 - 00:00 2.50 BOPSURP DECOMP Tested BOPE. Tested Blind Rams, Choke Manifold, Valves, HCR, Kill Line, Choke Line. Tested BOPE to 3,500 psi High I 250 psi Low. All Tests Held fl 5 Min. All Pressure Tests Held wi No Leaks or Pressure Loss. 7/9/2002 00:00 - 02:30 2.50 BOPSURP DECOMP Continue pressure testing BOPE to 250 I 3,500 psi, for 5/5 minutes. 02:30 - 04:00 1.50 BOPSUR P DECOMP Pull test plug. Pull TWC with lubricator. 04:00 - 05:00 1.00 PULL P DECOMP Rig up handling equipment for tubulars. 05:00 - 05:30 0.50 PULL P DECOMP Pull tubing hanger free with 225K lb. Monitor well. UWT= 125K. 05:30 - 06:30 1.00 PULL P DECOMP Lay down landing joint and tbg hanger. 06:30 - 07:30 1.00 PULL P DECOMP Rig up spooling unit for control lines. 07:30 - 11 :30 4.00 PULL P DECOMP Pump slug, POOH and LD 2,264' (55 Jts) of 4-1/2", 12.6 #/ft, 13CR-80 FOX tbg, plus dual control lines. Recovered 55 of 63 SSCL bands. 11 :30 - 12:00 0.50 PULL P DECaMP Rig down spooling unit. 12:00 - 20:00 8.00 PULL P DECOMP Continue POOH and LD a total of 189 jts plus 14.96' cutoff of 4-1/2",12.6 #/ft, 13CR FOX tbg, 5 GLM, and SSSV. Printed: 7/29/2002 4:44:07 PM ) ) BP Operations SUrnrnaryReport Legal Well Name: Common Well Name: Eve nt Name: Contractor Name: Rig Name: 12-08C 12-08C REENTER+COMPLETE NABORS NABORS 2ES Start: 7/8/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 2/7/1980 End: Date From..Tö Hours Task Code NPT Phase Description of Operations 7/9/2002 20:00 - 22:00 2.00 PULL P DECOMP RD tubular handling equipment and clean rig floor. 22:00 - 22:30 0.50 CLEAN P DECOMP Install WB. 22:30 - 00:00 1.50 CLEAN P DECOMP PJSM. PU Milling BHA. 7/10/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT PU, RIH with mills for guage run. 01 :00 - 02:30 1.50 STWHIP P WEXIT . Slip and cut 101' of drill line. Service Top Drive. 02:30 - 08:00 5.50 STWHIP P WEXIT RIH picking up 5" drillpipe (240 jts). 08:00 - 08:30 0.50 STWHIP P WEXIT Tag up on tubing stump at 8,366' DPM. UWT=225K, DWT= 185K, ROT= 200K, Torque OFF= 6,000 ft-Ib at 10 BPM and 721 psi. 08:30 - 11 :00 2.50 STWHIP P WEXIT Pump slug, POOH to BHA. 11 :00 - 12:30 1.50 STWHIP P WEXIT Stand back BHA, LD mills. 12:30 - 15:30 3.00 STWHIP P WEXIT PJSM. RU EZSV on electric line and RIH. Correlate on depth with CCL and set at 8,320' WLM. POOH and RD electric line. 15:30 - 16:00 0.50 STWHIP P WEXIT Test 9-5/8" casing for 30 minutes. 16:00 - 19:30 3.50 STWHIP P WEXIT PU whipstock and mills. PU, orient, and test MWD. RIH. 19:30 - 23:00 3.50 STWHIP P WEXIT Orient whipstock to 11 degrees RHS. Tag up on EZSV at 8,324' DPM. Set down and set whipstock with 30K Ibs of weight. Top of whipstock at 8,300', PU. UWT= 236K, DWT= 160K. 23:00 - 00:00 1.00 STWHIP P WEXIT Displace well to 10.2 ppg milling fluid. 7/11/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT Displace well to 10.2 ppg milling fluid at 9 bbl/min and 1,050 psi. 01 :30 - 10:00 8.50 STWHIP P WEXIT Mill window from 8,300'-8,316' (4 hrs). Recovered 751b of metal. Drill formation to 8,330'. UWT= 210K, DWT= 180K, ROT= 190K. Torque on = 1 OK ft-Ib, Torque off = 8K ft-Ib. 10:00 -11:00 1.00 STWHIP P WEXIT Sweep hole at 10 bbl.min and 1,100 psi while working through the window. 11 :00 - 11 :30 0.50 STWHIP P WEXIT Pull into casing and perform FIT to 11.5 EMW at 7,322' TVD. 11 :30 - 15:00 3.50 STWHIP P WEXIT Pump slug and POOH to BHA. 15:00 - 16:30 1.50 STWHIP P WEXIT Flush, clean and inspect BOP stack. 16:30 -17:00 0.50 STWHIP P WEXIT PU Angle Build BHA, set motor to 1.5 deg bend, and test MWD. 17:00 - 23:30 6.50 STWHIP P WEXIT RIH picking up 5" drillpipe. 23:30 - 00:00 0.50 STWHIP P WEXIT Fill drillpipe and orient toolface to 5 deg RHS. 7/1212002 00:00 - 01 :00 1.00 DRILL P LNR1 Pass thru window without problems. Ream 8.0" hole from 8,320' - 8,330'. 01 :00 - 17:30 16.50 DRILL P LNR1 Drill ahead with 8.5" bit and 1.5 deg motor to 9,368' with an average ROP of 60 ftlhr sliding and 175 ftlhr rotating. TO on = 15K ft-Ib, TO off = 13K ft-Ib. UWT= 210K, DWT= 170K, ROT= 190K. At 9,368' , ROP fell to 50 ftlhr while rotating and torque decreased to 7-8K ft-Ib. AST= 3.1 HR, ART= 8.6 HR. 17:30 - 18:30 1.00 DRILL P LNR1 Sweep hole at 13 bbl/min and 2,150 psi. Continued drilling with ROP decreasing to <15 ftlhr. 18:30 - 23:00 4.50 DRILL P LNR1 Pump slug and POOH. Pulled 15-20K over from 8,810'- 8,765'. Wiped and worked thru until normal up weight. Continue POOH to BHA. 23:00 - 00:00 1.00 DRILL P LNR1 Stand back BHA. LD motor and bit. 7/1312002 00:00 - 03:00 3.00 DRILL P LNR1 Change out bits and motors. Adjust motor to 1.5 deg. Orient MWD. Download MWD data, upload and surface test. RIH to 840', pulse test MWD. 03:00 - 04:30 1.50 DRILL P LNR1 RIH to above the window. 04:30 - 06:00 1.50 DRILL P LNR1 Cut and slip 105' of drill line. Service Top Drive. 06:00 - 06:30 0.50 DRILL P LNR1 Orient toolface and pass thru the window w/o problems. RIH to Printed: 7/29/2002 4:44:07 PM ) ) BP Ope<rätions <Su mrnary .Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C REENTER+COMPLETE NABORS NABORS 2ES Start: 7/8/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 2/7/1980 End: Date From.. To Hours Task Code NPT Phase Descri ptionofOperatiöns 7/13/2002 06:00 - 06:30 0.50 DRILL P LNR1 TD. 06:30 - 12:00 5.50 DRILL P LNR1 Drill 8.5 deg hole with 1.5 deg motor to 9,667' md. ART=3.3 hr, AST= .7 hr. UWT= 215K, DWT= 172K, ROT= 195K, Torque Off= 8-9K ft-Ib, Torque On= 9-12K ft-Ib. 12:00 - 00:00 12.00 DRILL P LNR1 Drill 8.5 deg hole with 1.5 deg motor to 10,385' md. ART=6.4 hr, AST= 1.9 hr. UWT= 230K, DWT= 170K, ROT= 200K, Torque Off= 1 OK ft-Ib, Torque On= 10-11 K ft-Ib. 7/14/2002 00:00 - 05:00 5.00 DRILL P LNR1 Drill 8.5 deg hole with 1.5 deg motor to 10,681' md. ART= 3.4 hr, AST= 0.7 hr. UWT= 240K, DWT= 175K, ROT= 205K, Torque Off= 10K ft-Ib, Torque On= 11-12K ft-Ib. 05:00 - 06:30 1.50 DRILL P LNR1 Sweep hole, monitor well, pump slug. 06:30 - 07:30 1.00 DRILL P LNR1 POOH to inside casing at 8,254' wlo problems. 07:30 - 08:00 0.50 DRILL P LNR1 Service Top Drive. 08:00 - 09:00 1.00 DRILL P LNR1 RIH to TD wlo problems. No fill. 09:00 - 10:30 1.50 DRILL P LNR1 Sweep hole, monitor well, pump slug. 10:30 - 15:30 5.00 DRILL P LNR1 POOH to BHA, laying down 60 jts of 5" drillpipe. SLM - No correction. 15:30 -18:00 2.50 DRILL P LNR1 LD BHA, download MWD. 18:00 - 19:00 1.00 DRILL P LNR1 Clean rig floor. 19:00 - 20:00 1.00 CASE P LNR1 Change out top pipe RAMs to 7". 20:00 - 20:30 0.50 CASE P LNR1 PuIlWB. 20:30 - 21 :00 0.50 CASE P LNR1 Install 7" test plug and test joint. Test upper Rams to 250 I 3,500 psi for 5/10 min. 21 :00 - 21 :30 0.50 CASE P LNR1 Install WB. 21 :30 - 22:00 0.50 CASE P LNR1 RU casing handling equipment. PJSM. 22:00 - 00:00 2.00 CASE P LNR1 PU shoe joints with Float equipment. Thread lock first three joints. Check floats. Run 10 joints of 7", 26#/ft, L-80, BTC-M liner, filling every 5 joints. 7/15/2002 00:00 - 02:00 2.00 CASE P LNR1 Continue to run 7", 26#/ft, L-80, BTC-M liner (63 joints total). PU/MU liner hanger, liner top packer and running tool. 02:00 - 02:30 0.50 CASE P LNR1 Circulate liner volume. 02:30 - 05:30 3.00 CASE P LNR1 Run liner on drill pipe to above the window at 8,218. 05:30 - 06:00 0.50 CASE P LNR1 Circulate drill pipe + liner volume 06:00 - 08:00 2.00 CASE P LNR1 RIH from 8,218' to TD at 10,681', without any problems. No fill. 08:00 - 09:30 1.50 CASE P LNR1 Circulate until returns are clean. Rig up cementing equipment. PJSM. 09:30 - 11 :00 1.50 CASE P LNR1 Pump 5 bbl of water and test lines to 4,000 psi. Pump 5 bbls water, followed by 40 bbl of 11.6 ppg Alpha Spacer pumped at 4-4.5 BPM, followed by 38 bbl (184 sx) of 15.8 ppg Class "G" cement plus additives (FW=O%, WL=120), pumped at 3 BPM. Drop wiper plug and displaced slurry with 234 bbl of 10.6 ppg mud, at 6-7.5 BPM. Bump plug and pressure up to 3,500 psi. Bled back pressure and checked floats - okay. CIP at 1100 hrs 4/15/2002. 11 :00 - 11 :30 0.50 CASE P LNR1 Rotate and release from Hanger 11 :30 - 12:00 0.50 CASE P LNR1 Circulate bottoms up at 12 BPM. 12:00 - 12:30 0.50 DRILL P PROD1 Slack off and set down with 70K, and had indications of liner top packer setting. PU and repeat set down with 70K, while rotating. 12:30 - 13:00 0.50 DRILL P PROD1 Pump slug. LD cement head. 13:00 - 15:30 2.50 DRILL P PROD1 POOH with 5" DP and test choke manifold. 15:30 - 16:00 0.50 DRILL P PROD1 LD and inspect liner running tool. - okay. Printed: 7/29/2002 4:44:07 PM ') BP Operations.Sumrnary ..Report Page 40f 6 Legal Well Name: Common Well Name: Eve nt Name: Contractor Name: Rig Name: 12-08C 12-08C REENTER+COMPLETE NABORS NABORS 2ES Start: 7/8/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 2/7/1980 End: Date From- To Hours Task Code NPT Phase Description. of Operations 7/15/2002 16:00 - 17:00 1.00 DRILL P PROD1 Change out top set of RAMs from 7" to Variable Bore RAMs. 17:00 - 17:30 0.50 DRILL P PROD1 PuIlWB. 17:30 - 20:00 2.50 DRILL P PROD1 Test upperllower pipe RAMS, and hyd choke to 250 13,500 psi for 5/5 minutes. Test Annular and manual Kill and Choke valves to 250/3,500 psi, for 5/5 minutes. Test TD, (2) TIW valves, and dart valve to 250 I 3,500 psi for 5/5 minutes. Test Blind RAMS, HYD Kill and Choke valves to 250 I 3,500 psi for 5/5 minutes. Test witnessing waived by John Crisp of the AOGCC. 20:00 - 20:30 0.50 DRILL P PROD1 Install WB. 20:30 - 21 :30 1.00 DRILL P PROD1 Test 7" liner x 9-5/8" casing to 3,000 psi for 30 min. 21 :30 - 00:00 2.50 DRILL P PROD1 MU 6-1/8" Angle Build BHA. Set motor angle to 1.5 deg. Orient MWD and upload data. 7/16/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Continue MU 6-1/8" Angle Build BHA. Test MWD. 01 :00 - 04:30 3.50 DRILL P PROD1 RIH picking up 192 joints of 4" drillpipe. 04:30 - 06:30 2.00 DRILL P PROD1 PJSM. Cut and slip 106' of drill line. Service Top Drive. 06:30 - 08:30 2.00 DRILL P PROD1 Continue RIH with 5" drill pipe. Tag up on landing collar at 10,597'. 08:30 - 09:30 1.00 DRILL P PROD1 Drill out float collar and shoe track to 10,679'. 09:30 - 12:00 2.50 DRILL P PROD1 Displace drilling mud to 8.4 ppg QuickDriln mud. 12:00 - 13:00 1.00 DRILL P PROD1 Drill out float shoe plus 20' of new hole to 10,701'. 13:00 - 13:30 0.50 DRILL P PROD1 Perform FIT to 10 ppg EMW with 700 psi surface pressure. 13:30 - 00:00 10.50 DRILL P PROD1 Drill ahead 6-1/8" hole from 10,701'-11,065' with a 1.5 deg motor. ART= 1.2 hr, AST= 7.3 hr. 7/1712002 00:00 - 12:00 12.00 DRILL P PROD1 Drill ahead 6-1/8" hole from 11,065' - 11,753' with a 1.5 deg motor. ART= 4.2 hr, AST= 3.8 hr. UWT=21 OK, DWT= 170K, ROT= 190K. Note: A transition zone was crossed at 11,631' md, and 11,870' md, with and increase in Torque and a decrease in penetration rate, wlo fluid losses. 12:00 - 20:00 8.00 DRILL P PROD1 Drill ahead 6-1/8" hole to 12,192'. ART= 1.3 hr, AST= 3.5 hr. 20:00 - 21 :00 1.00 DRILL P PROD1 Short trip to inside the 7" casing shoe at, 10,680'. No problems. 21 :00 - 21 :30 0.50 DRILL P PROD1 Service Top Drive. 21 :30 - 22:00 0.50 DRILL P PROD1 RIH to TD at 12,192'. No problems, no fill. 22:00 - 00:00 2.00 DRILL P PROD1 Drill ahead 6-1/8" hole from 12,192' - 12,265' with a 1.5 deg motor. ART= 0 hr, AST= 1.2 hr. UWT=21 OK, DWT= 160K, ROT= 190K. 7/18/2002 00:00 - 08:00 8.00 DRILL P PROD1 Directional Drill f/13,141' to 14,070' w/1.5 degree motor, survey wi MWD-DIR-GR-RES. ART= 5.4 hr, AST= .3 hr. UWT= 225K, DWT= 150K, ROT= 190K. Torque=11/15K ft-Ib. 7/19/2002 00:00 - 08:00 8.00 DRILL P PROD1 Directional Drill f/13, 141' to 14,070' w/1.5 degree motor, survey wi MWD-DIR-GR-RES. ART= 5.4 hr, AST= .3 hr. UWT= 225K, DWT= 150K, ROT= 190K. Torque=11/15K ft-Ib. 08:00 - 10:00 2.00 DRILL P PROD1 Circulate a HI-VIS sweep from surface to surface. 10:00 - 12:00 2.00 DRILL P PROD1 Short trip to the 7" casing shoe at 10,681'. Had a 15K overpull at 12,950'. 12:00 -14:00 2.00 DRILL P PROD1 Cut and slip 70' of drill line. Service Top Drive. 14:00 - 16:00 2.00 DRILL P PROD1 RIH to TD at 14,070. Tight spot at 12,950' with 20K excess down weight. 16:00 - 18:30 2.50 DRILL P PROD1 Circulate a HI-VIS sweep and spot a liner running pill of 140 bbl of new QUIKDRILn mud + 6% lubricants. 18:30 - 22:00 3.50 DRILL P PROD1 POOH laying down excess 5" drill pipe. 22:00 - 00:00 2.00 DRILL P PROD1 Continue POOH to 10,596'. Drop rod and open circulating sub. Printed: 7/29/2002 4:44:07 PM ) BP Operations. Summary ..Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-08C 12-08C REENTER+COMPLETE NABORS NABORS 2ES Page50f6 Start: 7/8/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 2/7/1980 End: Date From - To Hours Task Code NPT 7/19/2002 22:00 - 00:00 2.00 DRILL P PROD1 7/20/2002 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 02:30 0.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 04:00 1.00 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 08:00 3.50 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 11 :00 2.00 DRILL P PROD1 11 :00 - 11 :30 0.50 DRILL P PROD1 11 :30 - 12:00 0.50 DRILL P PROD1 12:00 - 14:30 2.50 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 17:00 1.50 DRILL P PROD1 17:00 - 17:30 0.50 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 20:30 2.50 DRILL P PROD1 20:30 - 00:00 3.50 DRILL P PROD1 7/21(2002 00:00 - 01 :30 1.50 DRILL P PROD1 01 :30 - 02:30 1.00 RUNCOIVP COMP 02:30 - 03:00 0.50 RUNCOI\tP COMP 03:00 - 05:00 2.00 RUNCOI\tP COMP 05:00 - 20:30 15.50 RUNCOI\tP COMP 20:30 - 23:30 3.00 RUNCOI\tP COMP 23:30 - 00:00 0.50 RUNCOI\tP COMP 7/22/2002 00:00 - 03:00 3.00 RUNCOI\tP COMP 03:00 - 05:00 2.00 RUNCOIVP COMP Description of Operations Continue POOH (dry) standing back 4" drillpipe. Change out elevators and slips. Continue POOH with 4" drill pipe to the BHA. PJSM. LD mud motor and BHA. Download MWD data. LD MWD, clear rig floor. PJSM. RU 4-1/2" liner running equipment. MU shoe joint, run 3,543' of 4-1/2" solid/slotted 12.6 Ib/ft, L-80, IBT-M liner, made up to the mark. (Average MU torque using Best-O-Life 2000 thread compound = 3,800 ft-Ib). Installed centralizers on the 12 solid joints (#74-85) just outside the 7" casing shoe. MU liner hanger, liner top packer and running tool. RD liner handling tools. Circulate liner volume. Weight + Blocks = 70K. RIH with 4" drillpipe to 9,580'. Change from 4" to 5" tools, continue RIH to 10,615'. Circulate pipe volume at 100 SPM and 875 psi. Continue RIH in open hole to TD at 14,070'. Circulate the open hole volume. UWT= 225K, DWT= 150K. Drop 7/8" steel ball. Pressure up string to 2,500 psi and set liner hanger. Continue to pressure up to 3,540 psi sheared out ball, release from liner assy, plu 6' to extend dogs on liner running tool, slo wi 50 k down weight set packer, had good surface indication of packer shearing to setting, performed same several times, also rotate and slo wi 50k several times. Displace well to seawater at 10, 490' wi 220spm at 2000 psi POOH to 10,280' laying down 5" drill pipe. Service Top Drive. Continue POOH to 4,511' laying down 5" drill pipe. Change out from 5" to 4" pipe handling tools. POOH to liner running tool, laying down 4" DP. Finish laying down 4" DP. Break connections and LD liner running tool. Change out saver sub. Change out grabber die blocks from 4-1/2" IF to HT-40 thread connection. Pull wear ring. PJSM. RU tubing compensator, recorder, and handling equipment. Make up and thread lock all connections below the S-3 production packer. Run a total of 262 joints of 4-1/2", 12.6 Ib-ft, L-80, TC-II tubing. Make with an average MU torque of 2,700 ft-Ib, using Best-O-Life PTC compound. RIH and tag up on the No-Go of the tie-back recepticale at 10,509'. Space out adding 2.0 and 8.74' pup joints. PU hanger and change out top seal. RIH and land tubing at 10,506' . Run in LDS. Circulate and spot clean sea water plus EC1124A corrosion inhibitor 10,506'-2,996'. Continue to circulate and spot clean sea water plus EC1124A corrosion inhibitor 10,506'-2,996'. Drop Ball/Rod (1-3/8" fishing neck). Pressure up 4-112" tubing to 3,000 psi and set S-3 permanent packer. Hold pressure for a Printed: 7/29/2002 4:44:07 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') BP Operations.. Summary Report 12-08C 12-08C REENTER+COMPLETE NABORS NABORS 2ES Page 60f 6 Start: 7/8/2002 Rig Release: 7/22/2002 Rig Number: Spud Date: 2/7/1980 End: 7/22/2002 03:00 - 05:00 From..To Hours Task Code NPT Phase Description of Operations Date 2.00 RUNCOrvP COMP 05:00 - 05:30 0.50 RUNCOrvP COMP 05:30 - 06:00 0.50 RUNCOrvP COMP 06:00 - 09:00 3.00 RUNCOrvP COMP 09:00 - 11 :30 2.50 RUNCOrvP COMP 11 :30 - 13:00 1.50 RUNCOrvP COMP 13:00 - 16:00 3.00 RUNCOrvP COMP 16:00 - 21 :00 5.00 RUNCOrvP COMP 21 :00 - 21 :30 0.50 RUNCOrvP COMP 30 minute test. Bleed down tubing pressure to 1,500 psi. Pressure up annulus to 3,000 psi, testing packer, and tubinglcasing annulus, for 30 minutes. Bleed down the tubing pressure and shear RP with 2,300 psi differential pressure. Install TWC. Pressure test from below to 2,000 psi. Blow down all surface lines and equipment. ND BOPE. NU VETCO-GRAY Xmas Tree. Test to 5,000 psi. RU lubricator, pull TWC, RD lubricator. RU Hot Oil Services and pump 125 bbl of diesel freeze protect. U-tube same. Set BPV and test from below to 2,000 psi. (Had to set two different BPVs, making four different runs before a sucessful test). Remove secondary annulus valve and secure the well. RIG RELEASED: 21 :30 hours - 7-22-02. Printed: 7/29/2002 4:44:07 PM ) ) 19-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 12-08C Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,295.40 I MD Window / Kickoff Survey 8,300.00 I MD (if applicable) Projected Survey: 14,070.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, DEFINITIVE Survey Manager Attachment(s) RECEIVED , ~ :(~ ? ~ ')002 J-.¡..) .~. '- "J '- Alaska Oil & Gas Cons. Commission Anchorage aoa-/30 DEF t\'-V~ North Slope Alaska BPXA PBU_EOA DS 12, Slot 12-08 12-08C Job No. AKZZ22115, Surveyed: 19 July, 2002 SUR VE Y R EP 0 R T 19 August, 2002 Your Ref: API 500292043202 Surface Coordinates: 5930670.93 N, 697611.52 E (70012' 53.0860" N, 148024' 21.7068" W) Kelly Bushing: 69.400 above Mean Sea Level sper'I'Y-sul'1 DRIL.L-ING SEæAVIc:eS A Halliburton Company Survey Ref: svy11277 Sperry-Sun Drilling Services Survey Report for 12-0BC Your Ref: API 500292043202 Job No. AKZZ22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU_EOA DS 12 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 OOft) 8295.40 40.230 241.700 7226.75 7296.15 1295.53 S 2450.65 W 5929311.70 N 695195.62 E 1487.08 Tie On Point AK-6 BP _IFR-AK 8300.00 40.230 241.820 7230.26 7299.66 1296.93 S 2453.27 W 5929310.22 N 695193.04 E 1.685 1488.69 Window Point 8392.58 45.630 241.510 7298.02 7367.42 1326.86 S 2508.75 W 5929278.86 N 695138.36 E 5.837 ~ 1522.95 ~ 8423.00 45.410 241.410 7319.34 7388.74 1337.23 S 2527.81 W 5929267.99 N 695119.57 E 0.760 1534.81 8454.28 45.290 241.310 7341.32 7410.72 1347.89 S 2547.34 W 5929256.82 N 695100.33 E 0.446 1547.00 8485.38 45.030 241 .200 7363.25 7432.65 1358.50 S 2566.68 W 5929245.71 N 695081.28 E 0.873 1559.11 8516.58 44.580 241.110 7385.39 7454.79 1369.11 S 2585.94 W 5929234.60 N 695062.31 E 1.457 1571.22 8548.33 44.030 241.010 7408.11 7477.51 1379.84 S 2605.35 W 5929223.37 N 695043.19 E 1.746 1583.47 8579.72 43.810 240.910 7430.72 7500.12 1390.41 S 2624.38 W 5929212.30 N 695024.43 E 0.735 1595.53 8609.96 43.720 240.810 7452.56 7521.96 1400.59 S 2642.65 W 5929201.64 N 695006.44 E 0.375 1607.14 8641.62 43.290 240.720 7475.52 7544.92 1411.24 S 2661.67 W 5929190.51 N 694987.70 E 1.372 1619.27 8702.67 45.420 242.290 7519.17 7588.57 1431.59 S 2699.18 W 5929169.18 N 694950.74 E 3.925 1642.55 8767.43 47.380 243.390 7563.83 7633.23 1452.99 S 2740.91 W 5929146.70 N 694909.58 E 3.267 1667.21 8861.59 51.540 242.490 7625.02 7694.42 1485.55 S 2804.61 W 5929112.48 N 694846.76 E 4.477 1704.75 8954.77 51.370 243.150 7683.08 7752.48 1518.84 S 2869.44 W 5929077.50 N 694782.82 E 0.583 1743.11 9049.62 50.490 243.510 7742.86 7812.26 1551.89 S 2935.24 W 5929042.74 N 694717.91 E 0.973 1781.32 9142.75 49.290 243.420 7802.86 7872.26 1583.71 S 2998.96 W 5929009.26 N 694655.04 E 1.291 1818.12 9236.43 47.100 243.940 7865.31 7934.71 1614.67 S 3061.55 W 5928976.67 N 694593.29 E 2.374 1853.99 9333.32 45.170 243.730 7932.44 8001.84 1645.47 S 3124.24 W 5928944.24 N 694531.42 E 1.998 1889.69 9424.75 45.050 243.200 7996.97 8066.37 1674.41 S 3182.19 W 5928913.80 N 694474.24 E 0.431 1923.17 -- 9518.02 45.170 243.430 8062.80 8132.20 1704.09 S 3241.23 W 5928882.59 N 694416.00 E 0.217 1957.46 9612.21 43.970 243.080 8129.89 8199.29 1733.83 S 3300.26 W 5928851.31 N 694357.77 E 1.300 1991.82 9705.74 47.590 243.500 8195.11 8264.51 1763.95 S 3360.13 W 5928819.63 N 694298.71 E 3.884 2026.62 9800.16 47.770 243.990 8258.68 8328.08 1794.83 S 3422.75 W 5928787.12 N 694236.93 E 0.428 2062.41 9894.19 46.750 243.070 8322.50 8391.90 1825.61 S 3484.57 W 5928754.74 N 694175.94 E 1.301 2098.02 9988.47 48.510 241.230 8386.04 8455.44 1858.16 S 3546.14 W 5928720.59 N 694115.24E 2.359 2135.38 10081.85 48.320 240.800 8448.02 8517.42 1892.00 S 3607.23 W 5928685.16 N 694055.05 E 0.400 2174.00 10174.90 47.500 240.220 8510.39 8579.79 1925.99 S 3667.34 W 5928649.60 N 693995.85 E 0.995 2212.68 10270.60 50.240 240.370 8573.33 8642.73 1961.71 S 3729.95 W 5928612.26 N 693934.20 E 2.866 2253.28 10364.77 50.700 243.000 8633.27 8702.67 1996.15 S 3793.88 W 5928576.16 N 693871.19 E 2.209 2292.72 19 August, 2002 - 9:32 Page 2 of 6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 12-0BC Your Ref: AP/500292043202 Job No. AKZZ22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU_EOA DS 12 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 OOft) 10458.17 49.860 242.520 8692.96 8762.36 2029.03 S 3857.75 W 5928541.62 N 693808.20 E 0.982 2330.59 10551.25 50.800 244.030 8752.38 8821.78 2061.24 S 3921.75 W 5928507.74 N 693745.07 E 1.606 2367.81 10629.27 51.560 243.620 8801.29 8870.69 2088.05 S 3976.30 W 5928479.51 N 693691.24 E 1.057 2398.90 10655.89 53.480 243.720 8817.48 8886.88 2097.42 S 3995.23 W 5928469.65 N 693672.56 E 7.219 2409.75 ~ 10683.95 54.360 243.810 8834.01 8903.41 2107.45 S 4015.57 W 5928459.09 N 693652.49 E 3.147 2421.37 10715.35 57.180 243.920 8851.67 8921.07 2118.88 S 4038.88 W 5928447.05 N 693629.49 E 8.986 2434.62 10747.63 61.960 244.020 8868.02 8937.42 2131.09 S 4063.88 W 5928434.19 N 693604.82 E 14.810 2448.79 10777.72 65.990 241.870 8881 .22 8950.62 2143.39 S 4087.95 W 5928421.27 N 693581.08 E 14.852 2462.98 10809.66 69.660 241.11 0 8893.27 8962.67 2157.51 S 4113.93W 5928406.47 N 693555.47 E 11.700 2479.12 10839.53 72.890 238.270 8902.86 8972.26 2171.79 S 4138.35 W 5928391.56 N 693531.44 E 14.071 2495.31 10872.27 76.080 235.250 8911.62 8981.02 2189.08 S 4164.72 W 5928373.58 N 693505.53 E 13.187 2514.65 10902.55 78.850 231.740 8918.19 8987.59 2206.67 S 4188.47 W 5928355.38 N 693482.25 E 14.550 2534.07 10934.83 81.290 227.670 8923.76 8993.16 2227.23 S 4212.71 W 5928334.20 N 693458.55 E 14.538 2556.51 10964.96 85.320 224.800 8927.27 8996.67 2247.92 S 4234.31 W 5928312.94 N 693437.50 E 16.382 2578.86 10996.57 89.750 222.970 8928.63 8998.03 2270.68 S 4256.20 W 5928289.62 N 693416.21 E 15.161 2603.29 11 027.12 91.780 220.230 8928.22 8997.62 2293.52 S 4276.48 W 5928266.26 N 693396.54 E 11.161 2627.67 11058.88 92.710 216.100 8926.98 8996.38 2318.46 S 4296.08 W 5928240.81 N 693377.59 E 13.320 2654.11 11090.46 92.950 211.490 8925.42 8994.82 2344.67 S 4313.62 W 5928214.15 N 693360.75 E 14.600 2681.63 11120.85 91 .850 206.540 8924.14 8993.54 2371.21 S 4328.35 W 5928187.23 N 693346.72 E 16.671 2709.26 11152.21 90.430 201 .170 8923.52 8992.92 2399.88 S 4341.02W 5928158.25 N 693334.80 E 17.709 2738.85 11183.71 90.180 196.280 8923.35 8992.75 2429.70 S 4351.13 W 5928128.17 N 693325.48 E 15.544 2769.38 -" 11214.50 91.970 191.260 8922.77 8992.17 2459.59 S 4358.46 W 5928098.10 N 693318.94 E 17.306 2799.76 11245.52 91.660 186.420 8921.79 8991.19 2490.22 S 4363.22 W 5928067.36 N 693314.98 E 15.627 2830.67 11277.46 91.600 185.310 8920.88 8990.28 2521.97 S 4366.48 W 5928035.52 N 693312.55 E 3.479 2862.59 11371.95 91.050 185.200 8918.70 8988.10 2616.04 S 4375.13 W 5927941.26 N 693306.36 E 0.594 2957.05 11466.03 86.860 184.280 8920.41 8989.81 2709.76 S 4382.90 W 5927847.37 N 693301.05 E 4.560 3051.09 11560.27 88.090 184.030 8924.57 8993.97 2803.66 S 4389.73 W 5927753.33 N 693296.69 E 1.332 3145.23 11654.80 88.280 184.280 8927.56 8996.96 2897.90 S 4396.57 W 5927658.94 N 693292.31 E 0.332 3239.71 11685.20 87.040 183.020 8928.80 8998.20 2928.21 S 4398.50 W 5927628.59 N 693291.17 E 5.813 3270.08 11716.07 87.230 182.500 8930.34 8999.74 2959.00 S 4399.99 W 5927597.77 N 693290.49 E 1.791 3300.90 19 August, 2002 - 9:32 Page 3 of6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 12-0BC Your Ref: AP/500292043202 Job No. AKZZ22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU_EOA DS 12 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) e/1 OOft) 11748.27 87.910 182.270 8931.71 9001 .11 2991.15 S 4401.33 W 5927565.60 N 693289.99 E 2.229 3333.05 11779.27 89.200 178.790 8932.49 9001 .89 3022.13 S 4401.61 W 5927534.62 N 693290.52 E 11 .969 3363.95 11809.70 89.260 174.130 8932.90 9002.30 3052.49 S 4399.74 W 5927504.32 N 693293.19 E 15.314 3394.07 11841 .80 89.380 173.030 8933.28 9002.68 3084.39 S 4396.15 W 5927472.53 N 693297.61 E 3.447 3425.57 ~ 11872.31 89.690 172.840 8933.53 9002.93 3114.66 S 4392.39 W 5927442.36 N 693302.16 E 1.192 3455.46 11903.72 88.770 171.930 8933.95 9003.35 3145.79 S 4388.23 W 5927411.35 N 693307.13 E 4.120 3486.15 11935.52 86.920 170.980 8935.15 9004.55 3177.22 S 4383.51 W 5927380.06 N 693312.68 E 6.539 3517.10 11966.05 87.110 171.520 8936.74 9006.14 3207.35 S 4378.87 W 5927350.06 N 693318.10 E 1.873 3546.77 12000.05 87.290 171.300 8938.40 9007.80 3240.93 S 4373.80 W 5927316.63 N 693324.05 E 0.835 3579.83 12029.04 87.720 170.880 8939.66 9009.06 3269.54 S 4369.32 W 5927288.14 N 693329.28 E 2.072 3608.00 12059.84 85.940 169.470 8941.36 9010.76 3299.84 S 4364.07 W 5927257.99 N 693335.32 E 7.368 3637.78 12091.67 86.860 169.020 8943.36 9012.76 3331.05 S 4358.14 W 5927226.94 N 693342.06 E 3.216 3668.42 12123.22 89.380 168.160 8944.40 9013.80 3361.96 S 4351.90 W 5927196.21 N 693349.11 E 8.439 3698.73 12154.75 91.780 164.190 8944.08 9013.48 3392.56 S 4344.37 W 5927165.81 N 693357.44 E 14.712 3728.63 12186.63 92.280 163.480 8942.95 9012.35 3423.16 S 4335.50 W 5927135.45 N 693367.11 E 2.723 3758.43 12217.84 92.030 160.1 00 8941.77 9011.17 3452.79 S 4325.76 W 5927106.10 N 693377.62 E 10.852 3787.18 12248.36 91.290 154.500 8940.89 9010.29 3480.92 S 4313.99 W 5927078.28 N 693390.12 E 18.500 3814.28 12279.84 91.230 152.100 8940.20 9009.60 3509.03 S 4299.85 W 5927050.55 N 693405.00 E 7.624 3841 .17 12311.68 91.970 149.640 8939.31 9008.71 3536.83 S 4284.36 W 5927023.16 N 693421.21 E 8.065 3867.65 12342.30 91.780 145.110 8938.30 9007.70 3562.60 S 4267.86 W 5926997.84 N 693438.37 E 14.799 3892.02 12374.39 91 .540 141 .170 8937.37 9006.77 3588.26 S 4248.62 W 5926972.69 N 693458.28 E 12.296 3916.06 - 12405.76 91.970 137.350 8936.41 9005.81 3612.01 S 4228.16 W 5926949.48 N 693479.35 E 12.248 3938.10 12439.87 91.110 132.260 8935.50 9004.90 3636.03 S 4203.98 W 5926926.10 N 693504.16 E 15.128 3960.11 12471.03 91.230 129.990 8934.86 9004.26 3656.52 S 4180.51 W 5926906.23 N 693528.15 E 7.294 3978.66 12499.26 92.640 127.820 8933.91 9003.31 3674.24 S 4158.56 W 5926889.10 N 693550.56 E 9.163 3994.57 12532.89 91.910 122.860 8932.57 9001.97 3693.67 S 4131.16W 5926870.39 N 693578.46 E 14.896 4011.75 12563.36 91.290 119.430 8931.72 9001.12 3709.42 S 4105.09 W 5926855.33 N 693604.93 E 11.435 4025.37 12593.33 90.920 117.110 8931 .14 9000.54 3723.61 S 4078.70 W 5926841.83 N 693631.68 E 7.837 4037.41 12623.80 90.920 114.600 8930.65 9000.05 3736.90 S 4051.29W 5926829.27 N 693659.43 E 8.237 4048.46 12655.54 90.180 114.610 8930.35 8999.75 3750.11 S 4022.43 W 5926816.81 N 693688.63 E 2.332 4059.33 19 August, 2002 - 9:32 Page 4 of6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 12-0BC Your Ref: API 500292043202 Job No. AKZZ22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU_EOA DS 12 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) (0/100ft) 12687.28 86.060 112.080 8931 .39 9000.79 3762.68 S 3993.32 W 5926805.01 N 693718.06 E 15.229 4069.53 12717.71 84.830 108.530 8933.81 9003.21 3773.20 S 3964.87 W 5926795.24 N 693746.77 E 12.311 4077.75 12749.54 85.010 105.150 8936.63 9006.03 3782.39 S 3934.53 W 5926786.85 N 693777.34 E 10.592 4084.49 12781.41 84.950 105.070 8939.41 9008.81 3790.66 S 3903.88 W 5926779.38 N 693808.20 E 0.313 4090.29 12875.20 87.170 103.130 8945.86 9015.26 3813.45 S 3813.14 W 5926758.97 N 693899.50 E 3.140 4105.76 '-- 12968.80 89.200 103.080 8948.82 9018.22 3834.66 S 3722.03 W 5926740.15 N 693991.14 E 2.169 4119.63 13062.52 88.710 102.390 8950.53 9019.93 3855.32 S 3630.63 W 5926721.90 N 694083.05 E 0.903 4132.92 13156.40 89.820 102.730 8951.74 9021.14 3875.73 S 3539.01 W 5926703.89 N 694175.17 E 1.237 4145.95 13250.82 90.180 103.710 8951.74 9021.14 3897.33 S 3447.09 W 5926684.71 N 694267.62 E 1.106 4160.13 13345.00 90.120 105.290 8951.49 9020.89 3920.91 S 3355.91 W 5926663.52 N 694359.39 E 1.679 4176.36 13438.66 89.880 106.090 8951 .49 9020.89 3946.23 S 3265.74 W 5926640.56 N 694450.19 E 0.892 4194.41 13532.08 90.310 106.520 8951.34 9020.74 3972.46 S 3176.08 W 5926616.69 N 694540.51 E 0.651 4213.39 13626.19 90.680 106.980 8950.52 9019.92 3999.58 S 3085.97 W 5926591.94 N 694631.30 E 0.627 4233.23 13720.31 90.740 107.660 8949.36 9018.76 4027.60 S 2996.12 W 5926566.28 N 694721.85 E 0.725 4253.98 13813.38 90.430 106.970 8948.41 9017.81 4055.30 S 2907.28 W 5926540.92 N 694811.39 E 0.813 4274.50 13906.75 89.880 105.350 8948.15 9017.55 4081.29 S 2817.60 W 5926517.29 N 694901.71 E 1.832 4293.24 14000.21 89.820 105.550 8948.40 9017.80 4106.18 S 2727.52 W 5926494.76 N 694992.42 E 0.223 4310.87 14070.00 89.820 105.550 8948.62 9018.02 4124.89 S 2660.28 W 5926477.82 N 695060.12 E 0.000 4324.15 Projected Survey 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. -.- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 184.580° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14070.00ft., The Bottom Hole Displacement is 4908.34ft., in the Direction of 212.819° (True). 19 August, 2002 - 9:32 Page 50f6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 12-0BC Your Ref: API 500292043202 Job No. AKZZ22115, Surveyed: 19 July, 2002 North Slope Alaska BPXA PBU_EOA DS 12 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8295.40 8300.00 14070.00 7296.15 7299.66 9018.02 1295.53 S 1296.93 S 4124.89 S 2450.65 W 2453.27 W 2660.28 W Tie On Point Window Point Projected Survey -- Survey tool program for 12-0BC From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 2739.00 8295.40 0.00 2739.00 2737.86 8295.40 7296.15 14070.00 2737.86 Good Gyro (12-08) 7296.15 Good Gyro (12-08A) 9018.02 AK-6 BP _IFR-AK (12-08C) ~- ----- - 19 August, 2002 - 9:32 Page 60f6 DrillQuest 2.00.09.003 , ) ) aoa~l6io 19-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 12-08G MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,295.40' MD Window / Kickoff Survey 8,300.00 I MD (if applicable) Projected Survey: 14,070.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED !<!JeJ 2~; 2002 Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska BPXA PBU_EOA DS 12, Slot 12-08 12-08C MWD Job No. AKMW22115, Surveyed: 19 July, 2002 ~ SURVEY REPORT 14 August, 2002 Your Ref: API 500292043202 Surface Coordinates: 5930670.93 N, 697611.52 E (70012' 53.0860" N, 148024' 21.7068" W) Kelly Bushing: 69.40ft above Mean Sea Level -' 5r~"""Y-5lS1 DRILLiNG -SERViceS A Halliburton Company Survey Ref: svy11279 Sperry-Sun Drilling Services Survey Report for 12-0BC MWD Your Ref: API 500292043202 Job No. AKMW22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU - EOA DS 12 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) r/1 OOft) 8295.40 40.230 241.700 7226.75 7296.15 1295.53 S 2450.65 W 5929311. 70 N 695195.62 E 1487.08 Tie On Point MWD Magnetic -' 8300.00 40.230 241 .820 7230.26 7299.66 1296.93 S 2453.27 W 5929310.22 N 695193.04 E 1.685 1488.69 Window Point 8392.58 45.630 249.870 7298.08 7367.48 1322.48 S 2510.78 W 5929283.18 N 695136.22 E 8.304 1518.74 8423.00 45.410 245.100 7319.40 7388.80 1330.78 S 2530.82 W 5929274.36 N 695116.40 E 11.210 1528.62 8454.28 45.290 235.290 7341.41 7410.81 1341.82 S 2550.08 W 5929262.82 N 695097.44 E 22.301 1541 . 16 8485.38 45.030 245.960 7363.37 7432.77 1352.61 S 2569.24 W 5929251.54 N 695078.57 E 24.324 1553.44 8516.58 44.580 246.480 7385.50 7454.90 1361.47 S 2589.36 W 5929242.15 N 695058.68 E 1.860 1563.89 8548.33 44.030 247.230 7408.23 7477.63 1370.19 S 2609.75 W 5929232.90 N 695038.53 E 2.392 1574.20 8579.72 43.810 243.150 7430.84 7500.24 1379.32 S 2629.51 W 5929223.25 N 695019.02 E 9.042 1584.88 8609.96 43.720 243.780 7452.68 7522.08 1388.66 S 2648.22 W 5929213.42 N 695000.56 E 1.471 1595.69 8641.62 43.290 241 .870 7475.64 7545.04 1398.62 S 2667.61 W 5929202.97 N 694981.43 E 4.369 1607.16 8702.67 45.420 242.780 7519.29 7588.69 1418.43 S 2705.41 W 5929182.17 N 694944.17 E 3.641 1629.93 8767.43 47.380 241.860 7563.95 7633.35 1440.22 S 2746.93 W 5929159.30 N 694903.23 E 3.197 1654.97 8861.59 51.540 240.970 7625.14 7694.54 1474.47 S 2809.74 W 5929123.42 N 694841.34 E 4.476 1694.12 8954.77 51.370 242.760 7683.21 7752.61 -1508.83 S 2874.00 W 5929087.39 N 694778.00 E 1.513 1733.50 9049.62 50.490 243.330 7742.99 7812.39 1542.21 S 2939.64 W 5929052.30 N 694713.25 E 1.038 1772.02 9142.75 49.290 243.270 7802.99 7872.39 1574.21 S 3003.27 W 5929018.64 N 694650.48 E 1.289 1809.00 9236.43 47.100 243.550 7865.43 7934.83 1605.47 S 3065.71 W 5928985.76 N 694588.88 E 2.348 1845.14 _../ 9333.32 45.170 243.830 7932.57 8001.97 1636.43 S 3128.33 W 5928953.17 N 694527.10 E 2.003 1881.01 9424.75 45.050 242.950 7997.09 8066.49 1665.45 S 3186.24 W 5928922.65 N 694469.97 E 0.694 1914.55 9518.02 45.170 242.570 8062.92 8132.32 1695.69 S 3244.99 W 5928890.88 N 694412.03 E 0.316 1949.39 9612.21 43.970 242.590 8130.02 8199.42 1726.13 S 3303.66 W 5928858.91 N 694354.17 E 1.274 1984.42 9705.74 47.590 243.370 8195.24 8264.64 1756.57 S 3363.37 W 5928826.93 N 694295.28 E 3.916 2019.52 9800.16 47.770 244.010 8258.81 8328.21 1787.51 S 3425.95 W 5928794.36 N 694233.53 E 0.536 2055.37 9894.19 46.750 242.980 8322.62 8392.02 1818.32 S 3487.75 W 5928761.94 N 694172.56 E 1.351 2091.02 9988.47 48.510 241 .190 8386.16 8455.56 1850.94 S 3549.29 W 5928727.72 N 694111.90 E 2.335 2128.44 10081.85 48.320 240.770 8448.14 8517.54 1884.82 S 3610.37 W 5928692.25 N 694051.73 E 0.393 2167.10 10174.90 47.500 240.210 8510.51 8579.91 1918.83 S 3670.46 W 5928656.68 N 693992.55 E 0.988 2205.80 10270.60 50.240 240.300 8573.45 8642.85 1954.59 S 3733.04 W 5928619.29 N 693930.92 E 2.864 2246.44 10364.77 50.700 243.060 8633.40 8702.80 1989.04 S 3796.97 W 5928583.19 N 693867.92 E 2.313 2285.88 -- 14 August, 2002 - 9:30 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 12-0BC MWD Your Ref: API 500292043202 Job No. AKMW22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU - EOA DS 12 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 OOft) 10458.17 49.860 242.820 8693.08 8762.48 2021.72 8 3860.95 W 5928548.84 N 693804.82 E 0.921 2323.56 10551.25 50.800 244.320 8752.50 8821.90 2053.60 8 3925.10 W 5928515.29 N 693741.52 E 1.600 2360.47 ~ 10629.27 51.560 243.840 8801.41 8870.81 2080.178 3979.77 W 5928487.30 N 693687.56 E 1.086 2391.32 10655.89 53.480 243.720 8817.61 8887.01 2089.51 8 3998.72 W 5928477.4 7 N 693668.86 E 7.221 2402.14 10683.95 54.360 243.810 8834.13 8903.53 2099.538 4019.07 W 5928466.92 N 693648.79 E 3.147 2413.75 10715.35 57.180 245.850 8851 .80 8921.20 2110.568 4042.56 W 5928455.27 N 693625.59 E 10.464 2426.63 10747.63 61.960 244.000 8868.14 8937.54 2122.37 8 4067.76 W 5928442.82 N 693600.71 E 15.610 2440.40 10777.72 65.990 241 .890 8881 .34 8950.74 2134.678 4091.83 W 5928429.89 N 693576.97 E 14.800 2454.59 10809.66 69.660 241.140 8893.40 8962.80 2148.778 4117.82 W 5928415.11 N 693551.36 E 11.694 2470.72 10839.53 72.890 238.570 8902.99 8972.39 2162.98 8 4142.27 W 5928400.26 N 693527.28 E 13.539 2486.84 10872.27 76.080 235.600 8911.74 8981.14 2180.138 4168.74 W 5928382.43 N 693501.27 E 13.089 2506.04 10902.55 78.850 232.030 8918.32 8987.72 2197.588 4192.59 W 5928364.36 N 693477.89 E 14.701 2525.34 10934.83 81 .290 228.240 8923.89 8993.29 2217.958 4216.99 W 5928343.35 N 693454.03 E 13.815 2547.60 10964.96 85.320 225.370 8927.40 8996.80 2238.43 8 4238.80 W 5928322.31 N 693432.77 E 16.382 2569.76 10996.57 89.750 223.460 8928.76 8998.16 2260.998 4260.89 W 5928299.19 N 693411.27 E 15.259 2594.00 11 027.12 91.780 220.440 8928.35 8997.75 2283.70 8 4281.31 W 5928275.95 N 693391.46 E 11.910 2618.27 11058.88 92.710 216.270 8927.11 8996.51 2308.58 8 4301.00 W 5928250.56 N 693372.43 E 13.442 2644.65 11090.46 92.950 211.660 8925.55 8994.95 2334.73 8 4318.61 W 5928223.95 N 693355.50 E 14.600 2672.12 11120.85 91.850 206.840 8924.27 8993.67 2361.22 8 4333.44 W 5928197.09 N 693341.37 E 16.254 2699.71 -" 11152.21 90.430 201.390 8923.65 8993.05 2389.82 8 4346.25 W 5928168.16 N 693329.32 E 17.955 2729.24 11183.71 90.180 196.990 8923.48 8992.88 2419.578 4356.60 W 5928138.16 N 693319.75 E 13.991 2759.72 11214.50 91.970 191 .450 8922.90 8992.30 2449.398 4364.16 W 5928108.14 N 693312.97 E 18.905 2790.05 11245.52 91.660 186.750 8921.92 8991.32 2480.00 8 4369.06 W 5928077.42 N 693308.87 E 15.177 2820.95 11277.46 91.600 185.660 8921.01 8990.41 2511.748 4372.51 W 5928045.60 N 693306.25 E 3.416 2852.87 11371.95 91.050 184.980 8918.83 8988.23 2605.80 S 4381.27 W 5927951.34 N 693299.96 E 0.925 2947.32 11466.03 86.860 183.260 8920.54 8989.94 2699.598 4388.03 W 5927857.40 N 693295.66 E 4.814 3041.36 11560.27 88.090 183.150 8924.69 8994.09 2793.59 8 4393.29 W 5927763.30 N 693292.86 E 1.310 3135.48 11654.80 88.280 182.620 8927.69 8997.09 2887.95 8 4398.05 W 5927668.84 N 693290.57 E 0.595 3229.92 11685.20 87.040 182.880 8928.93 8998.33 2918.29 8 4399.50 W 5927638.48 N 693289.91 E 4.167 3260.28 11716.07 87.230 182.530 8930.47 8999.87 2949.098 4400.96 W 5927607.65 N 693289.26 E 1.289 3291.09 14 August, 2002 - 9:30 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 12-0BC MWD Your Ref: API 500292043202 Job No. AKMW22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU_EOA DS 12 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) r/1 OOft) 11748.27 87.910 181.920 8931.84 9001.24 2981.248 4402.21 W 5927575.48 N 693288.86 E 2.836 3323.24 11779.27 89.200 178.700 8932.62 9002.02 3012.22 8 4402.38 W 5927544.51 N 693289.50 E 11 . 186 3354.14 .- 11809.70 89.260 174.030 8933.03 9002.43 3042.588 4400.45 W 5927514.21 N 693292.22 E 15.347 3384.24 11841.80 89.380 173.080 8933.41 9002.81 3074.47 S 4396.84 W 5927482.42 N 693296.66 E 2.983 3415.75 11872.31 89.690 172.540 8933.66 9003.06 3104.748 4393.03 W 5927452.26 N 693301.27 E 2.041 3445.62 11903.72 88.770 171.970 8934.08 9003.48 3135.86 8 4388.79 W 5927421.26 N 693306.31 E 3.446 3476.30 11935.52 86.920 171.020 8935.27 9004.67 3167.298 4384.09 W 5927389.97 N 693311.83 E 6.539 3507.25 11966.05 87.110 171 .840 8936.86 9006.26 3197.448 4379.55 W 5927359.95 N 693317.16 E 2.753 3536.94 12000.05 87.290 171.510 8938.52 9007.92 3231.04 8 4374.63 W 5927326.49 N 693322.96 E 1.105 3570.04 12029.04 87.720 170.960 8939.79 9009.19 3259.668 4370.22 W 5927297.99 N 693328.12 E 2.407 3598.22 12059.84 85.940 169.560 8941 .49 9010.89 3289.978 4365.02 W 5927267.83 N 693334.11 E 7.348 3628.02 12091.67 86.860 169.080 8943.49 9012.89 3321 .19 8 4359.13 W 5927236.78 N 693340.82 E 3.259 3658.66 12123.22 89.380 168.230 8944.52 9013.92 3352.108 4352.93 W 5927206.04 N 693347.83 E 8.429 3688.98 12154.75 91.780 164.170 8944.20 9013.60 3382.71 8 4345.41 W 5927175.63 N 693356.14 E 14.957 3718.89 12186.63 92.280 163.490 8943.07 9012.47 3413.31 8 4336.54 W 5927145.28 N 693365.81 E 2.646 3748.69 12217.84 92.030 160.140 8941 .90 9011.30 3442.94 8 4326.81 W 5927115.92 N 693376.32 E 10.756 3777.44 12248.36 91.290 154.820 8941 .02 9010.42 3471.118 4315.13 W 5927088.06 N 693388.73 E 17.592 3804.59 12279.84 91.230 152.400 8940.32 9009.72 3499.308 4301.14 W 5927060.25 N 693403.45 E 7.688 3831.57 12311.68 91.970 149.950 8939.43 9008.83 3527.188 4285.79 W 5927032.78'N 693419.52 E 8.035 3858.14 - 12342.30 91.780 145.150 8938.43 9007.83 3553.00 8 4269.38 W 5927007.40 N 693436.61 E 15.680 3882.57 12374.39 91.540 141.110 8937.50 9006.90 3578.65 8 4250.14 W 5926982.25 N 693456.51 E 12.607 3906.60 12405.76 91.970 137.350 8936.54 9005.94 3602.39 8 4229.66 W 5926959.06 N 693477.60 E 12.058 3928.63 12439.87 91.110 132.270 8935.62 9005.02 3626.42 8 4205.48 W 5926935.68 N 693502.40 E 15.099 3950.65 12471.03 91.230 129.990 8934.99 9004.39 3646.91 8 4182.02 W 5926915.81 N 693526.40 E 7.326 3969.20 12499.26 92.640 127.840 8934.03 9003.43 3664.63 8 4160.07 W 5926898.66 N 693548.80 E 9.104 3985.11 12532.89 91.910 122.550 8932.70 9002.10 3683.99 8 4132.62 W 5926880.03 N 693576.75 E 15.867 4002.22 12563.36 91.290 119.000 8931 .85 9001.25 3699.57 8 4106.45 W 5926865.14 N 693603.31 E 11 .823 4015.66 12593.33 90.920 116.720 8931 .27 9000.67 3713.57 8 4079.96 W 5926851.83 N 693630.16 E 7.706 4027.50 12623.80 90.920 114.550 8930.78 9000.18 3726.758 4052.50 W 5926839.38 N 693657.96 E 7.121 4038.45 12655.54 90.180 114.550 8930.48 8999.88 3739.948 4023.63 W 5926826.95 N 693687.17 E 2.331 4049.29 -- ---- --- 14 August, 2002 - 9:30 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 12-0BC MWD Your Ref: API 500292043202 Job No. AKMW22115, Surveyed: 19 July, 2002 BPXA North Slope Alaska PBU_EOA DS 12 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 OOft) 12687.28 86.060 112.050 8931.52 9000.92 3752.48 S 3994.50 W 5926815.17 N 693716.61 E 15.180 4059.47 12717.71 84.830 108.540 8933.93 9003.33 3763.00 S 3966.05 W 5926805.40 N 693745.32 E 12.188 4067.68 ~ 12749.54 85.010 105.200 8936.75 9006.15 3772.20 S 3935.72 W 5926797.00 N 693775.89 E 10.467 4074.43 12781.41 84.950 1 05.150 8939.54 9008.94 3780.51 S 3905.08 W 5926789.49 N 693806.74 E 0.245 4080.27 12875.20 87.170 103.210 8945.99 9015.39 3803.43 S 3814.37 W 5926768.96 N 693898.01 E 3.140 4095.87 12968.80 89.200 103.200 8948.95 9018.35 3824.80 S 3723.30 W 5926749.98 N 693989.62 E 2.169 4109.90 13062.52 88.710 102.450 8950.66 9020.06 3845.60 S 3631.93 W 5926731 .58 N 694081.50 E 0.956 4123.33 13156.40 89.820 102.850 8951 .86 9021.26 3866.16 S 3540.34 W 5926713.43 N 694173.59 E 1.257 4136.51 13250.82 90.180 104.020 8951.86 9021.26 3888.10 S 3448.50 W 5926693.90 N 694265.97 E 1.296 4151.05 13345.00 90.120 105.690 8951.62 9021.02 3912.24 S 3357.47 W 5926672.15 N 694357.60 E 1.774 4167.85 13438.66 89.880 107.010 8951.62 9021.02 3938.61 S 3267.60 W 5926648.14 N 694448.13 E 1 .432 4186.95 13532.08 90.310 107.200 8951.46 9020.86 3966.08 S 3178.32 W 5926623.01 N 694538.11 E 0.503 4207.21 13626.19 90.680 107.730 8950.65 9020.05 3994.33 S 3088.55 W 5926597.13 N 694628.58 E 0.687 4228.19 13720.31 90.740 107.810 8949.48 9018.88 4023.05 S 2998.93 W 5926570.76 N 694718.93 E 0.106 4249.67 13813.38 90.430 106.680 8948.53 9017.93 4050.64 S 2910.05 W 5926545.51 N 694808.50 E 1.259 4270.07 13906.75 89.880 105.100 8948.28 9017.68 4076.20 S 2820.25 W 5926522.30 N 694898.94 E 1.792 4288.38 14000.21 89.820 105.000 8948.53 9017.93 4100.47 S 2729.99 W 5926500.41 N 694989.79 E 0.125 4305.37 14070.00 89.820 105.000 8948.74 9018.14 4118.53 S 2662.58 W 5926484.12 N 695057.66 E 0.000 4317.99 Projected Survey --' 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. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 184.580° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14070.00ft., The Bottom Hole Displacement is 4904.25ft., in the Direction of 212.882° (True). 14 August, 2002 - 9:30 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 12-0BC MWD Your Ref: API 500292043202 Job No. AKMW22115, Surveyed: 19 July, 2002 North Slope Alaska BPXA PBU_EOA DS 12 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment -- 8295.40 8300.00 14070.00 7296.15 7299.66 9018.14 1295.53 S 1296.93 S 4118.53 S 2450.65 W 2453.27 W 2662.58 W Tie On Point Window Point Projected Survey Survey tool program for 12-0BC MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 2739.00 8295.40 0.00 2739.00 2737.86 8295.40 7296.15 14070.00 2737.86 Good Gyro (12-08) 7296.15 Good Gyro (12-08A) 9018.14 MWD Magnetic (12-08C MWD) -~ ------ 14 August, 2002 - 9:30 Page 60'6 Dril/Quest 2.00.08.005 ~ufÄ1Jæ ]j~ ) fE\ ~ @@r«. '..~ IJ--ü LSl0j Q)) uuU Ù I / / ¡ , TONY KNOWLES, GOVERNOR AT{ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 ÞHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit l2-08C BP Exploration (Alaska), Inc. Pennit No: 202-136 Surface Location: 339' NSL, 2" WEL, Sec. 18, TlON, R15E, UM Bottomhole Location: 3791' SNL, 2695' WEL, Sec. 19, TlON, R15E, UM Dear Mr. Robertson: Enclosed is the approved application for pennit to redrill the above development well. The pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test perfonned before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (Il M, .-. ^/ 0-u.U . ~ C;~;&chsli Taylor Chair BY ORDER OF THE COMMISSION DATED thi~f\.Lday of July, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA I STATE OF ALASKA )AND GAS CONSERVATION COMM¡ PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB 69.5' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool , ADL 028330 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 12-08C 9. Approximate spud date 07/15/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14117' MD / 9096' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 91 Maximum surface 2560 psig, At total depth (TVD) 8920' / 3350 psig Setting Depth Top Bottom MD TVD MD TVD 8150 7187' 10688' 8906' 10538' 88151 11925' 9030' 11925' 9030' 14117' 9095' VJ 6A-- 1/110 '1- )ON -;:;:tF1i11 óV ;-. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 339' NSL, 2' WEL, SEC. 18, T10N, R15E, UM At top of productive interval 1977' SNL, 4299' WEL, SEC. 19, T10N, R15E, UM At total depth 3791' SNL, 2695' WEL, SEC. 19, T10N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028335, 1489' MD 12-15 is 625' away at 11596' MD 16. To be completed for deviated wells Kick Off Depth 8300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlina 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 Yam Ace 4-1/2" 12.6# L-80 Slotted 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 8-1/2" 6-1/8" 6-1/8" Lenath 2538' 1387' 2192' Quantity of Cement (include staae data) 165 sx Class 'G' 118 sx Class 'G' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Tieback Liner 1 0651 feet 9088 feet 1 0620 feet 9063 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 73' 20" 2714' 13-3/8" 9345' 9-5/8" 1666' 7" 531' 7" 423 sx Arcticset 2279 sx Fondu 73' 2714' 73' 2713' 1500 sx Class 'G' 435 sx Class 'G' 200 sx Class 'G' 9295' R E ( E I Vt;tJ~1~::~I' 8045' 7819' - 9087' 7418' - 7819' Alaska on & Gas Cans. Commission Anchorage 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program ~DePth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897Ç:' tf2J/ Prepared By Name/Number: Terrie Hubble, 564-4628 21. I ~erebY certify that the~o.re. i..ng is tru~ðn<;¡. nd ..orrect to t ...e.. b..es. .t.,o. .f..m. Y.~.now.,I~~9.,...e . Signed Brian Robertson ~ ~ . .- Title Semor Dnlllng Engineer Date ~ -:25'- ð <- Commission Use Only Permit Number API Number Z\ý>J?~o al ~te See cover letter 2CJZ: - / 3 ~ 50- 029-20432-03 ~ I,,7J (j d- for other requirements Conditions of Approval: Samples Required 0 Yes t8I No Mud L g equired 0 Yes 181 No Hydrogen Sulfide Measures ]S] Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: 'T ~St- B~ ¡ e fð ~~tj\Q (JL/. OnglOal Signed By Cammy Oechsli Taytor Commissioner true vertical 10422' - 10444', 10540' - 10587' 8904' - 8921', 8998' - 9036' JUN 26 2002 Perforation depth: measured Approved By Form 10-401 Rev. 12-01-85 by order of the commission Date Z~ ¿;cate I~'''''\ l, :' , ~ J' ~f\~!\L ~ i \J l'""\ ) ) I Well Name: I DS 12-08C Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Sidetrack Horizontal Producer Surface Location: Estimated Target Location: Sadlerochit Zone 48 Bottom Hole Location: I AFE Number: 14J0503 x = 697,611.52 Y = 5,930,670.93 3391 FSL, 2' FEL Sec. 18, T10N, R15E Umiat X = 693,385.00 Y = 5,928,245.00 TVDss 8930 3303' FSL , 791' FWL Sec. 19, T10N, R15E Umiat X = 695,042.00 Y = 5,926,473.00 TVDss 9020 14891 FSL, 2402' FWL Sec. 19, T10N, R15E Umiat I RiQ: 1 Nabors 2ES I OperatinQ days to complete: 123.1 I Estimated Start Date: 107/7/02 1 I TVD: 19096' I I MD: 114,117' I 1 BF/MS: 141.0' 1 I RKB: 169.5' I Well DesiQn (conventional, slim hole, etc.): 1 Horizontal Sidetrack I Objective: I Zone 48, Sadlerochit Casingrrubing Program Hole Size Csgl WtlFt Tbg O.D. 7" 8 Y2" 6 1/8" 6 1/8" Tubing 4 Y2" 4 Y2" 4 Y2" Directional KOP: 18,300' MO (400 incl) Maximum Hole Angle: Close Approach Well: Survey Program: DS12-08C Sidetrack 26# 12.6# 12.6# 12.6# Grade Conn Length Top 8tm MDITVD MDITVD L-80 BTC-mod 2538' 8150/7187' 10,688/8906' L-80 Vam Ace 1387' 10,538' /8815' 11,925' / 9030' L-80 Slotted 2192' 11,925' /9030' 14,117' / 9095' L-80 TC-II 10,510' GL 10,538' /8815' Up to 910 in the target section 480 @ 6900' in original well The closest wellbores are the 12-08A and 12-08B abandoned sections, diverging from the planned well. At 11,596' MO (9010' TVD) a close approach has been identified with OS12-15 at 625' center-to-center distance. This well passes minor risk criteria (intersection potential below the production packer in the 9 5/8" casing shoe section). Standard MWO + IFR/Cassandra survey from kick-off to TO. Page 1 ) ) Mud Program Window Milling Mud Properties: LSND I Whip stock Window 95/8" I Density (ppg) Viscosity PV YP tauO HTHP pH API FI 9.5 50 - 60 10-13 25 - 35 6-8 <10 9.0 <6 Drilling Mud Properties: LSND 18 Y2" Hole Section in HRZ I Density (ppg) Viscosity PV YP tauO HTHP pH API FI 10.6 45 - 55 11 -15 20 - 30 4-7 <10 8.5 - 9.0 <6 Production Mud Properties: Quickdril-N I 6 1/8" hole section I Density (ppg) Viscosity PV YP tauO MBT pH API FI 8.4 - 8.6 45 - 55 6-8 22 - 27 4-7 <3 8.5 - 9.0 NIC LOQging Program 8 %" Intermediate: Sample Catchers - None Drilling: MWD PWD Dir/GR- Real time throughout entire interval. Open Hole: None Cased Hole: None 61/8" Production: Sample Catchers - Two, at Company man call out Drilling: MWD ABI Dir/GR/Res - Real time GR/RES throughout entire interval to help geosteer Open Hole: None Cased Hole: None Cement Proc ram ~ Casing Size 7" Intermediate Liner Basis: Lead: None Tail: Based on 85' of 7" shoe tract and 1000' of 8 V2" open hole x 7" casing annulus with 40% excess. (no liner lap or 9 5/8" x 4" DP annulus volume). Tail TOC: -9690' I' MD (8245'TVDbkb). Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer Lead Tail 30 bbls Alpha Spacer at 11.6 ppg None 35 bbl I 196 ft3 I 165 sks of Halliburton 'G' at 15.6 ppg and 1.19 dIsk, BHST 2100 @ 8825' TVDss TT = Batch Mix 4 to 4.5 hrs Casing Size I 4 %" Bonsai Production Liner I Basis: Lead: None Tail: Based on 1237' of 6 1/8" open hole with 1 0% excess, 150' of 4 %" x 7" liner lap. The ECP depth is estimated only. The cement volume should be recalculated based on actual ECP depth. Tail TOC: -10,538' MD (8815' TVDbkb).- Liner top. Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer Lead Tail 30 bbls Alpha Spacer at 9.5 ppg None 25 bbl I 140 ft3 1118 sks of Halliburton 'G' at 15.6 ppg and 1.19 dIsk, BHST 2150 @ 9020' TVDss TT = Batch Mix 4 to 4.5 hrs DS12-08C Sidetrack Page 2 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3350 psi @ 8920' TVOss - Ivishak . Maximum surface pressure: 2560 psi @ surface (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-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 OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . Planned BOP test pressure: Planned completion fluid: . . . . Markers Formation Tops (Wp#10) CM2 CM1 THRZ BHRZ TJE TJC TJB TJA TSGR TSHU TSADfTZ4B Target I Heel of horizontal TZ4A TD TVDss 8185' 8355' Not Correlated 84351 8610' 8730' 8825' 88451 89201 8930' Not Penetrated 9020' 3500 psi 8.6 ppg seawater /7.2 ppg Diesel MDbkb Comments 9714' 10.6 ppg minimum MW required 9966' 252' MD (170' TVD) of HRZ @ 47.5° Incl 10,084' 10,343' 10,522' 10,678' 10,716' 10,939' 11,052' 3350 psi (7.2 ppg EMW) 14,117' 3065' MD heel to toe TD Criteria: Planned TD is -9,020' SS to allow logging through the top of the HOT. This value may be modified by the wellsite geologist based on logging and sample information. DS12-08C Sidetrack Page 3 ') .' ) Sidetrack and Complete Procedure Summary Ria Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4 Y2" tubing from cut. 5. Change out 9 5/8" casing packoff if necessary. 6. MU window milling BHA drift down to the KOP. 7. Set bridge plug on wireline at :t8318' such that the window will not be cut through a casing collar. Test casing to 3000 psi. 8. RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on bridge plug. Change well over to milling fluid. Mill window in casing at:t 8300' MD. Perform FIT to 11.5 ppg. POOH. 9. Kick-off and drill the 8 Y2" section as per the directional plan to top of Sag River formation. 1 O. Change pipe rams as required. Run and cement a 7" drilling liner, displace with mud. 11. Test casing to 3000 psi. Drill out shoe and displace well to 8.5 ppg QuickDRILn mud. Drill 20' of new formation, perform FIT to 10.0 ppg. 12. Drill 6 1/8" production hole as per directional plan to TD well at :t14, 117' MD. 13. Short trip, CBU, spot liner running pill, POH. 14. Run and cement a 4 Y2", 12.6#, L-80 slotted x solid ("Bonzai") production liner to TD. Displace with perf pill and seawater. Circulate the well to clean seawater at the liner top, POOH. 15. Run 4 Y2", 12.6# L-80 completion tying into the 4 Y2" liner top. 16. Set packer and test the tubing and annulus to 3000 psi for 30 minutes. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well. 19. Rig down and move off. Post-RiQ Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. DS12-08C Sidetrack Page 4 ) ') . ffl,:~:m.,~"~~,.:.t,~, Job 1: MIRU Hazards and Contingencies þ;> No wells will require shut-in for the rig move to 12-08B. DS12-08B is at the end of a row with DS12-30as the closest well at 60' center to the north. ~ D-Pad is a designated as an H2S site: Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Closest BHL Wells 12-07A 20ppm H2S (4/3/2002) 12-33 No recorded H2S 12-30 12ppm (6/12/1997) 12-34 No recorded H2S The maximum level recorded of H2S on the pad was 200 ppm on 7/17/2001. D-17A measured 25 ppm in May, 2001. ).- Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud wW«~;(~--"''''''W'''''.'N...''''''~''''''~''''::X)«#H+!':''>:~:::;::::::;;~oh.,....-.J'-.:~"I:!'~:N-IoI::;;X+.~ Job 2: De-complete Well Hazards and Contingencies þ;> The perforated intervals and lower section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. _»:o~~~~~~-~--»--~~~-~-¡.:.c.~,..,..¡.¡.;.I:':II+Ioo(.»N..~');.;",,*,,1~4I«1::'II":.II.111~__~,,';~1*H+_T_~....oJo;.¡':'~I+,*,'¡'_,~1@t~\t:, o"-""""'-"-"-~'U-"--''''''\oi ''''''.'.' ._._-~ v_x 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 there. M<~~~~~~ .:'1')¡'~'-'~»,:II'~~.:¡\J.I:I;:I;r..~~~:-»>,I:IJ,~:I;:X:.:.i1i\.'f.!I:\,~':,~~~,'i;';:,:~r!1":'!Ynlf.:n\..":¡;'.,.:)"r,'i~~~.,.(¡#,,'),¡,;:;:t:¡,,."',:~,:I;~,,'¡I.1AA'~;'L:/."";,)",:,:",.,I)¡,I~;;.','I""""~:""'i',.;,;;.~.....";¡;J<;.,;,'",,.:>.~'m;¥'/IiI: Job 4: Drill 8 V2" Intermediate Hole Hazards and Contingencies ~ The well will be kicked off in the Colville shale and drilling through the Kingak; wellbore stability is a major concern. Ensure the mud weight does not drop below the minimum stated requirement. Use PWD to ensure good drilling and connection practices. ~ KICK TOLERANCE: In the worst-case scenario of 10.0 ppg pore pressure at the Sag River depth, a fracture gradient of 12.0ppg at the 9 5/8" casing window, and 10.6ppg mud in the hole, the kick tolerance is infinite. " '~'-'''''-_r;::~... T ""1.;;;,1;11'./'1;111-1' ';'1 ..;... ./:m;...;..;I;mu-' '; ¡-¡'t;;;IIIII::;:mj.tllm", ;;IIU¡,.;.,;,I;mlll. , ¡O!";mml\;II:¡IIII.;"':;;'-:;U/U',¡'.;;_~..I'IU:Wlllmll;¡ I. *,.1 .In m.~I.1I. .II' "11::,'1;;1; 11+'1,"..;01111111111,111...11..1'.1, '1'1111... Job 6: Install 7" Intermediate Drillinq Liner Hazards and Contingencies ~ Minimize surge while RIH with the drilling liner. The pad data sheet lists several instances of stuck pipe, gas cut mud, and lost circulation in the Kingak area. Job 7: Drill 6 1/8" Production Hole DS12-08C Sidetrack Page 5 ) ) Hazards and Contingencies ~ DS12-34 experienced losses while drilling the Shublik formation and while running and cementing the liner. Be prepared with LCM, following the established decision tree. ~ One fault crossing has been identified in the 6 1/8" production hole section at :1:11,870' MD. The planned trajectory will cross perpendicularly in the center of the 35'-throw fault to minimize the risk of lost circulation. Nevertheless, anticipate losses and establish a lost circulation management plan. ~ If the fault becomes a source of lost circulation, sea water may be pumped to control losses. If the fault is not a source of significant lost circulation a bonzai completion is planned for the well, which would place slotted liner south of the fault. Pay north of the fault will be cased (solid) and perforated with the rig. If the resistivity log indicates lower water saturations and the fault has not resulted in major lost circulation, a bonzai completion could place slotted liner on both sides of the fault. If higher water saturations are observed south of the fault, a cased and perforated completion is possible to limit water production. If water is located above the HOT in the toe, or if the HOT is penetrated, a disposable stinger may be required to isolate this potential water source. Drilling should be stopped immediately if water is encountered in the toe of the well as the well is turned down. ~ Kick tolerance is infinite in this hole section under any reasonable circumstance. >- The closest well is DS12-15 at 600' center to center while drilling at 11,600'. Watch for magnetic interference while surveying in this area. W"~~":_N:1::"!M~_. I!' ~~«<~,,,,,,,,,,,""'M..."-:I:;"',,,,,,,,,,,,,;,,,,,,,,,,,,, Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg Quickdril will be -600 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. þo> Hydraulic isolation may be required at the toe of the well if water is observed above the HOT or the aquifer is penetrated. A CBL may be required to confirm isolation of the fault if consistent returns are not maintained throughout the cementing operation. þo> The base completion case calls for a bonzai liner on the south side of the fault. Perforations north of the fault will be added with the drilling rig. Lost circulation at the fault or high water saturations south of the fault may require revision of the planned completion strategy. -~~»--*N -"'~»II!I:n:I!IIC:I::+ X+I~»II_I_':IC:lm:m~w,-.-_.,,--~. -''''~~''I'''!H''li'I_' .1. ~::I::»!I*"ffl, 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. ,- l'IIIi.IIi_'~TI.- .1. .IL .... Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ Though there are no close proximity surface issues, identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. DS12-08C Sidetrack Page 6 TREE = WELLHEAD= """...""",,,,,....... . ",,""'''''' . . A CTUA TOR= "KEf""'èCE\/"';;';'^'''''''^'''''''''-'"'''''''''''''''w,,,,,,'''''''^''''''''''''""''' ...,,"'''''''''''' ..",,,..' ..... BF. ELEV = ""'''''''''''''''''''''''''' ,,,,,...,,...., "~~..~, ':,~,~!~~""""",w"""'"'''''''''MW''''' Datum MD = ........,,,. .,......,,,,,,, ./....,. Datum TVDss= 113~3/8" 72#, L80, Casing 1-1 14 1/2" 12.6# 13Cr Tubing 2714' 12-088 Pre ~)g J ') I-~ L L 2.) Cut tubing at -84001 MD. ~ 19 5/8" X 7" Brow n Type 'H' Liner top packer 1-1 84711 1 - I If 17" Brow n Tie Back Seal Assembly 1-1 89841 1-1 93451 195/8" 47#, L80, Casing 13 1/2" 9.3# 13-Cr Tubing 1 Top of Cement 11 4 1-1 -95001 1 1 Perfs: 10422' - 10444' (Aperf); 10540'-10587'(Reperf) I 7" 29#, L80, BRTS Liner 1 PBTD 1-1 106201 I 1-1 106511 1 DA TE REV BY 06/18/02 PGS 361 1-15112" X41/2" Crossover 22381 1-141/2" AVA "ACGA" SSSV I.D.= 3.813" I GAS LIFT MANDRELS TVD DEV 1YÆ SIZE L TCH OTIS 4 1/2 RA OTIS 4 1/2 RA OTIS 4112 RA OTIS 4112 RA OTIS 4112 RA COMMENTS ~ ST MD 5 4 3 2 1 86651 1-141/2" X 31/2" Crossover 1.) CØrert prisêrd 1Lö~1ai1 to ¡male. I 103591 1-1 OTIS 'BWD' Permanent Packer 1 104721 1-13-1/2" OTIS 'XN' Nipple, ID=2.75 1 104821 1-13-1/2" OTIS Solid Nose Shear Out sub I 1 104831 I-1Tubing Tail COMMENTS Proposed 12-08B Pre Rig work requirement PRUDHOE BA Y UNrT WELL: 12-08C ÆRMrT No: API No: 50-029-2043203 Sec.18, T10N, R15E BP Exploration (Alas ka) CANVAS UPDATE: 03/08/01 TREE = WELLHEAD= - ÀCTuAToR;'" .W"",WM''''''''''',W,','''','',',''''',''''''''',W,',W,',,,,.'''''''''',''''''W,'"""....",,,,,.,',,,,,,,',',',,,,,,",',",,',',,",,."'" ,., KB. ELEV = "..,. ,,,.., ".,. ,,'''''''' BF. ELEV = 12-~ BC Proposed Coml- ~'etion -) . ",¡""..,..".., """'''''''''' ",... Max Angle = , DaiùmMÒ';"'''"'W''''''w,w^,-^,,,,,,,,",,,,, .... ,,,... ""'"'',...''''' .""""...> Datum 1VDss= . . 113-3/8" 72#, LBO, Casing 1-1 I~ 2714' Tubing: 41/2" 12.6# L-80 TC-II 17" Hanger/Packer 1-1 l 8150' I 1 Whip Stock 1-1 8300' I Bridge Plug l-i 8318' 1...". ...~.. .., ..'" l J~ l ) ~ ~ 195/8" 47#, L80, Casing 1-1 9345' ~ ~ I 7" 29#, L80, BRTS Liner 1-1 10651' I k. DA TE REV BY COMMENTS 06/18/02 PGS A"oposed 12-08C2 String completion. (Wp#10) L 20' 1-i5 1/2" X 41/2" Crossover ~ 2200' 1-i4 1/2" X Nipple 1.0.= 3.813" ST MD 6 5 4 3 2 1 GAS LIFT MANDRELS 1VD DEV TYÆ SIZE L TCH KBG-2 4112 RA KBG-2 4 1/2 RA KBG-2 41/2 RA KBG-2 4 1/2 RA KBG-2 4 1/2 RA KBG-2 51/2 RA ) I I 10470' 1 10485' I 10500' 1 10525' 10538' COMMENTS 1-14 1/2" 'X' Nipple I.D. 3.813" 1-17" X 4 1/2" Baker S-3 Packer 1-14 1/2" 'X' Nipple I.D. 3.813" 1-141/2" 'XN' Nipple I.D. 3.725" - Baker 5" X 7" 'lie back sleeve; 'ZXP Liner top packer; 'HMC' Liner hanqer I 10688' 1-1 7" 26# L-80 BTC Liner - - -- =J 11,925' - 41/2" ECP 11,925' - 41/2" 12.6# L-80 .,. - -- 1 14117' 1-14 1/2" Slotted Liner TO to PRUDHOE BA Y UNIT WELL: 12-08C ÆRMIT No: API No: 50-029-2043203 Sec.18, T10N, R15E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 sper-tï'Y-SUI1 North Slope Alaska DRIL.LING A=.~~~:;':~ BPXA PBU_EOA DS 12 12-oSC WP10 DrillQllest~ Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: 12-08C 5930670.93 N, 697611.52 E 837.87 S, 61.73 E 70° 12' 53.0860" N, 148° 24' 21.7068" W North Reference: Units: 75.500 above Mean Sea Level 75.50ft above Structure True North Feet (US) Dec~ietri~MOR~~ '.~~11~~:k~D~~1~~J~TVD End Dir, Start Sail @ 47.500° : 8396.8OftMD,7370.38ftTVD ; -' Proposal Data for 12-08C wp10 Vertical or~in: Well Horizontal rigin: Well Measurement Units: ft North Reference: True North Dogleg severity : Degrees per 100 feet (US) Vertical Section Azimuth: 184.580° Vertical Section Description:Well Vertical Section Origin: 0.00 N.O.OO E Measured Incl. Azlm. Vertical Northlngs Eastlngs Vertical Dogleg Depth Depth Section Rate 8300.00 40.230 241.710 7301.28 1292.815 2451.38 W 1484.43 8325.00 43.214 242.169 7319.94 1300.64 5 2466.06 W 1493.40 12.001 8396.80 47.500 242.783 737038 1324.23 5 2511.36 W 1520.53 6.000 10475.91 47.500 242.783 8775.00 2025.325 3874.51 W 2328.24 0.000 10677.85 55.578 242.783 8900.50 2097.585 4015.01 W 2411.49 4 .000 10754.76 65.574 242.596 8938.24 2128.285 4074.45 W 2446.84 v 13.000 10773.34 65.574 242.5% 8945.92 2136.07 S 4089.48 W 2455.80 0.000 11051.84 90.000 215.000 9005.50 2314.475 4288.57 W 2649.52 13 .000 11201.57 90.416 197.037 9004.95 2448.475 4353.98 W 2788.32 12 .000 11458.26 90.416 197.037 9003.09 2693.89 5 4429.19 W 3038.96 0.000 11518.62 85.000 197.460 9005.50 2751.475 4447.06 W 3097.78 9 .000 11525.79 84.354 197.454 9006.17 2758.28 5 4449.21 W 3104.75 9.000 11614.52 84.354 197.454 9014.89 2842.52 5 4475.69 W 3190.83 0.000 11925.46 90.000 1 70.000 9030.50 3149.345 4495.50 W 3498.25 9.000 12195.23 90.732 145.731 9028.75 3397.35 S 4394.62 W 3737.42 9.000 ~ 12286.26 90.732 145.731 9027.59 3472.58 S 4343.36 W 3808.31 0.000 12608.02 90.000 120.000 9025.50 3689.63 5 4109.51 W 4005.99 8.000 12743.22 88.933 111.958 9026.76 3748.805 3988.08 W 4055.28 6.000 13139.01 88.933 111.958 9034.13 3896.775 3621.06 W 4173.47 0.000 13286.21 90.000 103.190 9035.50 3941.175 3480.87 W 4206.53 6.000 13786.40 90.000 103.190 9035.50 4055.305 2993.88 W 4281.41 0.000 14051.55 72.500 103.197 9075.68 4114.885 2739.73 W 4320.51 6.600 14117.47 72.500 103.197 9095.50 4129.235 2678.52 W 4329.93 0.000 -1200 - -1800 - Increase DI~~~re g'~:'o1io~~~om.~~~WD~~93r~OO:V~ "- End DJr, Start Sail 0 65.574° : 10754.76ftMD,8938.24ftTVD~ \ ''''. .. ..,In DI,. 13.000"I100ft, 19773.34ft MD, "'5.92ft TVD~;;" Decrease Dlr Rate 0 12.0000/100ft: 11051.84ft MD, 9005.5Oft TVD ~ End Dlr, Start Sail 0 90.416° : 11201.57ftMD,9004.95ftTVD T.ttnrling YUIJ5,5IJft TI'D 1.H-U7 S. -I1l18.57 \1'-------- -2400 - ã) ~ CJ) C> C £. t: 0 -3000 - Z - l1-fl/ir Drillen Pn/r Beatn Dlr 0 9.000"/100ft: 11458.26ft MD 9003.~ ~ :nd Drr. Start Sail 0 84.354° : 11526.79ftMD,9006.26ftTVD\. \ Begin Dlr 0 9.000"/100ft: 11614.52ft M.. D, 9014.89ft TVD\ \ lNllir 1'1 \: ')IJ(}5.5(}ft TI'D - . 175/.-17 S, -1-1-17.06 \1 / / 11.0ilC T1 J--- YU3f}.5IJft nv ----- 31-1Y.3-1 S. '¡'¡Y5,5IJ I\" Fal/It 1 3< End Dlr, Start Sail @ 90.732° : 12195.23ftMD,9028.75ftTVD Begin Dlr @ 8.0000/100ft : 12286.26ft MD, 9027.59ft TVD -3600 Decrease Dfr Rate @ 6.000"/100ft : 12608.02ft MD, 9025.5Oft TVD End Dir, Start Sail @ 88.933° : 12743.22ftMD,9026.76ftTVD - Õ 0 <D II s:::. u .5 Y~~5~:&/i~v / 36119.63 S. -1109.51 \I' I -4500 I -3300 I -2700 I -2100 I -5700 Scale: 1 inch = 600ft I -5100 12-01iC1'4 ~ -\-...... ,)(}35.5(}ft TVD 39-11.17 S, 3480.87 W ~in Dir 0 6.0000/100ft: 13139.34ft MßM9034.13tt TVD En ~'I~~~~~.~i:~~~~.~J>ó~~~fvD . EnCl Dfr, Start Sail ~l~i~iJ~l15f.=~~~sJXfvD I -3900 Eastings (Well) 4 1/2" Uner 14117.47ft MD 9095.5Oft TVD <V -4200 - ëij u en "-. - "- . -~ nosc Tf) Y;095.50jt TlD 4119.23 S. 1678,51 W Reference is True North vv~ .. ,.., ",..,..,.. ^"" c::;røi'r'y-sUl'1 North Slope Alaska D~IL..LING A:::~~= BPXA Current Well Properties Idetrack 6° At TF @ 12.001°J100ft: 83OO.00ft MD, 7301.28ft TVD ,Decrease In Dlr Rate @ 6.000oJ100ft : 8325.00ft MD, 7319.94ft TVD .,,,,,., End Dlr, Start Sail @ 47.500° : 8396.8OftMD,7370.38ftTVD ~ ~ ~ ~ ~ ~ - 'I"" ~<§:- tÞ~ ~~ Q) A...~ ,,~ f,.~ of~<;S ~ A...~ ¡;:\Q A...~ ~ ~Q ~~ ¡;:\Q ~ ~ ~ ¡;:\Q ::> ~ +Q'.{I-~ "+Q' ~~ ~ '),~ ~ ~$ ~ ~ ~' ~~". ,¡>¡ff ~ ~'9$- G A3Ç) ~~ ~~. "'~ .,.~ ~~ ~S5 ~~ ~'§ ~<Ø» (I.'? ~ ~"-~':' ~4' ~'? #' ~ 00 ~' A'\' ^'~ Æ)' f:)~" .~' ~ .$}' ~ .~' ~'" !ò~ .~' tY .~' ~ AQ' .... ~' ~. +v ~. ,,'" ~.~, ~. ~' ~.~. ~. ~' ~. ~' §"' ~ ã. ""d.' ~~ .:-: ~~ ~~ -Ã' ~'¡>~,-~ ~~ ~~ '),.f'" ~~ .:--.f '),~ ~~ '),'" .A~ ~'? ~ Q) <:þ'" t§>~ þ" (I.~ f:)<3' "",f:) ~ ,:>" ~t> "cI' rß5 ~~ (l.t/> ,'$ ~<,t(p ~<ò" ~Cj ~ 0 8250 ~ - - - - - - - - - - - - - - -....&::...~ -~.~- ~.~ -~.:;. - rF-.~ - ~otl- ~ - ~A*'- ~.ePfHRZ. 8260.5OftTVD "c" #' . '" o' d" ~~ ,," 0 . ,,'" 0 . t{P t§>° o' ,,~ 0 . ".I' 0 . ~- . (ij ~" '!to #"' ~~ "",. ~"'~. ~~ r§:-" ".g, ~.:-- roo # ~.. f:)t§>.g;:-- #' ~Q' (.') 00 oo!\,dS 0'" 0'''' ~. @ ~. o~<t' <to. o~fS ~. ~ e@ @.". 0 ,,<t' ~. o~. -<'" ~~ . .- ------ -- -----~~/f f:)¡;'-~~-~~-'$~-~~~-~:' ~ -~~-:!ð~-~~-BHRZ.8430.5OttTVD -e.,.". fÞ<-f§ì "q¿¡ ,,~. c? ~ cjJ ~~ fbqj~. c? ~ ~~ c? "'~ c? ro" r# -.!I' Q) ------ -- -----~-~;-~¡þ-~~-~~-w--;§:'-~"- t f0 -~"---TJC.8510.5OfITVD > ~ ...~ ~ ~,!b~ t[f' ~ fb'<$i.* q.'li ~ ø~ ~ ~ fb'<$i ~ ~ R~ Q , Q ~. !fl' ~. V' ~, Q ~' Q , ;...~, Q ~, Q ~. <:1 -------~-- 10300.00 ~~,~~~' <br/'J:_~J>Q -~ ~~Q 9J,p~;...~ ~Q ~'!.-32~Q ~~-~ri'~ ~~,p~;...~ ~:-4~~Q-Î" ----TJB,8685.50fiTVD 8750 - 4= -------- ,',~-- - -- - - -- - - -- -------TJÞ.880S.5OftTVD 0 ß ===========-,.) ===== -= == = =====---=== = -=====~~~~ ::;~:;g;:f:;g II ------ - -~ --- -- . ,jJIRQ _JH -....-mmrr----.- - -iji_____-TSAD!TZ4B 8995"-T"D ~ ? ...--.-- ,}200000 ,}2400. . .00 . , ....~". .~ === = = == = = == = = == = == = = = = === = = = = === = * === = ~.nRr. v.¡p~ - === = \ ....¿ = === = = === ~t,<>~~:ti~.;VD rCasin I / ! / \ ~41/2'Uner 10687.8511 MD umáing 12.08C T1 12-08C Tl 12.08(' T3 11-0Ú: T4 ~2.IJ8C TV 14117.47ft MD 8906.06ft TVD 9IJ05.50/1 TIn 9005.50/1 TlD 9030.50/1 THJ 9025.50jl TYD 9035.5OJt PoD 9095.50jl TI-'D 9095.5Oft TVD 2.1/.1..17 S. 4288.57 W 275Ui S. #17.06 W 31-19.34 S. #95.50 H 3689.63 S, 4109.51 W 3941.17 S, 3480.87 I\' 4119.23 S, 2678.52 W Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates : RKB Elevation : North Reference: Units: 7250 - 7750 - Q) Cã 9250 - () (/) I 1500 Scale: 1 inch = 500ft ""'.'rI- ... ^ ^"" ^^ ",..'" PBU_EOA DS 12 12-08C WP10 DrillQuest~ Proposal Data for 12-08C wp10 12-08C WP10 5930670.93 N, 697611.52 E 837.87 S, 61.73 E 70012' 53.0860" N, 148024' 21.7068" W Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Well Well ft True North 75.50ft above Mean Sea Level 75.50ft above Structure Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 184.580° Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 8300.00 40.230 241.710 7301.28 1292.81 S 2451.38 W 1484.43 8325.00 43.214 242.169 7319.94 1300.64 S 2466.06 W 1493.40 12.001 8396.80 47.500 242.783 7370.38 1324.23 S 2511.36 W 1520.53 6.000 10475.91 47.500 242.783 8775.00 2025.32 S 3874.51 W 2328.24 0.000 10677.85 55.578 242.783 8900.50 2097.58 S 4015.01 W 2411.49 4.000 10754.76 65.574 242.596 8938.24 2]28.28 S 4074,45 W 2446.84 13.000 10773.34 65.574 242.596 8945.92 2136.07 S 4089.48 W 2455.80 0.000 1l051.84 90.000 215.000 9005.50 2314.47 S 4288.57 W 2649.52 13.000 11201.57 90.416 197.D37 9004.95 2448.47 S 4353.98 W 2788.32 12.000 .~ 11458.26 90.416 197.037 9003.09 2693.89 S 4429.19 W 3038.96 OJ)OO 11518.62 85.000 197.460 9005.50 2751.47 S 4447.06 W 3097.78 9.000 11525.79 84.354 197.454 9006.17 2758.28 S 4449.21 W 3104.75 9.000 11614.52 84.354 197.454 9014.89 2842.52 S 4475.69 W 3190.83 0.000 11925.46 90.000 170.000 9030.50 3149.34 S 4495.50 W 3498.25 9.000 12195.23 90.732 145.731 9028.75 3397.35 S 4394.62 W 3737.42 9.000 12286.26 90.732 145.731 9027.59 3472.58 S 4343.36 W 3808.31 0.000 12608.02 90.000 120.000 9025.50 3689.63 S 4109.51 W 4005.99 8.000 12743.22 88.933 111.958 9026.76 3748.80 S 3988.08 W 4055.28 6.000 13139.01 88.933 111.958 9034.13 3896.77 S 3621.06 W 4173.47 0.000 13286.21 90.000 103.190 9035.50 3941.17 S 3480.87 W 4206.53 6.000 13786.40 90.000 103.190 9035.50 4055.30 S 2993.88 W 4281.41 0.000 1405 L55 72.500 103.197 9075.68 4114.88 S 2739.73 W 4320.51 6.600 14117,47 72.500 103.197 9095.50 4129.23 S 2678.52 W 4329.93 0.000 True North Feet (US) I 2000 I 2500 I I 3000 3500 Vertical Section (Well) I I 4000 4500 Section Azimuth: 184.580° (True North) Sperl )-$I.(.rJØ~i~(;.rJ&l;~ê}. )íces Proposal Data, ...12..08C-12-0SC.'wp10 {)ra.ftCóþy 13 December, 2001 - 13:37 - 1 - DrillQuest -' ~. h . .sI Alaska _Drl71fng & Wells . DS 12, Slot 12-0BC 12-0BC wp10 Revised: 5 December, 2001 PROPOSAL REPORT 13 December, 2001 .--' Surface Coordinates: 5930670.93 N, 697611.52 E (70012' 53.0860" N, 148024'21.7068" W) Surface Coordinates relative to Project H Reference: 930670.93 N, 197611.52 E (Grid) Surface Coordinates relative to Structure: 837.87 S, 61.73 E (True) Kelly Bushing: 75.5Oft above Mean Sea Level -I-......I-".Y~c:::t--""'~ D_B~U--LclNG__n~!U=RVfCJæS AKallibUrton CCHnpany Proposal Ref: pro 10979 Sperry-Sun Drilling Services . Proposal Report for 12-D8C Revised: 5 December, 2001 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 12 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) e/100ft) 12-o8A Reca 0.00 0.000 0.000 -75.50 0.00 O.OON 0.00 100.00 0.147 265.300 24.50 100.00 0.018 0.147 0.01 200.00 0.416 257.343 124.50 200.00 0.108 0.271 0.14 .~ 300.00 0.203 270.967 224.50 300.00 0.178 0.224 0.26 400.00 0.275 164.095 324.50 400.00 4 0.386 0.49 500.00 0.324 59.217 424.50 0.90W 5930670.41 N 697610.63 E 0.476 0.56 600.00 0.251 56.637 524.49 0.48 W 5930670.70 N 697611.05 E 0.074 0.26 700.00 0.345 323.422 624.49 0.47 W 5930671.06 N 697611 .05 E 0.438 -0.10 800.00 0.290 142.495 724.49 0.50W 5930671.10 N 697611.01 E 0.635 -0.15 900.00 0.271 307.661 824.49~. 0.53W 5930671.04 N 697610.99 E 0.557 -0.08 1000.00 0.292 106.604 924.49 ~~~~ 9 =k 0.20N 0.48 W 5930671.12 N 697611.03 E 0.554 -0.16 1100.00 0.329 88.648 1024.49 ~ci1QJfi99 0.13N 0.06E 5930671.06 N 697611.57 E 0.104 -0.13 1200.00 0.496 132.201 1124.49 ~'f'T99.99 0.158 0.66E 5930670.80 N 697612.19 E 0.343 0.10 1300.00 0.400 173.289 1224.49 1299.99 0.79 8 1.03 E 5930670.17 N 697612.57 E 0.327 0.71 1400.00 0.281 193.582 1324.48 1399.98 1.388 1.01 E 5930669.58 N 697612.57 E 0.167 1.29 1500.00 0.319 159.928 1424.48 1499.98 1.88 8 1.04E 5930669.08 N 697612.61 E 0.177 1.79 1600.00 0.212 357.492 1524.48 1599.98 1.96S 1.14 E 5930669.00 N 697612.71 E 0.525 1.86 1700.00 0.131 331 .635 1624.48 1699.98 1.67 S 1.07 E 5930669.29 N 697612.64 E 0.110 1.57 1800.00 0.570 103.155 1724.48 1799.98 1.68 S 1.49 E 5930669.29 N 697613.06 E 0.664 1.55 1900.00 0.521 108.217 1824.48 1899.98 1.938 2.42 E 5930669.06 N 697613.99 E 0.069 1.73 '~ 2000.00 0.870 39.281 1924.47 1999.97 1.508 3.33 E 5930669.52 N 697614.89 E 0.838 1.23 2100.00 1.658 40.784 2024.44 2099.94 0.19N 4.75 E 5930671.24 N 697616.26 E 0.789 -0.56 2200.00 2.238 70.677 2124.39 2199.89 1.94N 7.53 E 5930673.07 N 697619.00 E 1.150 -2.54 2300.00 2.771 83.053 2224.29 2299.79 2.88N 11.78 E 5930674.12 N 697623.22 E 0.757 -3.81 2400.00 2.632 84.873 2324.18 2399.68 3.37N 16.47 E 5930674.73 N 697627.90 E 0.163 -4.68 2500.00 3.811 95.985 2424.02 2499.52 3.24N 22.05 E 5930674.74 N 697633.48 E 1.329 -4.99 2600.00 4.145 101.425 2523.78 2599.28 2.17 N 28.91 E 5930673.86 N 697640.36 E 0.503 -4.47 2700.00 4.327 97.656 2623.51 2699.01 0.95N 36.19 E 5930672.82 N 697647.67 E 0.333 -3.83 2800.00 4.477 90.406 2723.21 2798.71 0.41 N 43.83 E 5930672.49 N 697655.33 E 0.576 -3.91 2900.00 5.002 121.002 2822.89 2898.39 1.828 51.48 E 5930670.46 N 697663.03 E 2.549 -2.30 13 December, 2001-13:38 Page 2 of 14 DrillQuest 2.00.09.006 . Sperry-Sun Drilling Services Proposal Report for 12-08C Revised: 5 December, 2001 Alaska Drilling & Wells PBU_EOA DS 12 North Slope Alaska Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) ~ (ft) Dogleg Rate (o/1ooft) Vertical Section Incl. Azim. Comment 3000.00 3100.00 3200.00 3300.00 3400.00 5.172 143.482 4.963 173.647 4.089 194.333 3.374 221.425 4.923 241.501 2922.50 3022.13 3121.82 3221.61 3321.36 2998.00 3097.63 3197.32 3297.11 3396.86 7.70 S 15.64 S 23.41 S 29.08 S 33.32 S 669.62 E 673.00 E 72.79 E 70.10 E 697664.51 E 1.988 2.642 1.837 1.880 2.101 3.05 10.71 18.49 24.37 29.05 --- 3500.00 7.048 242.887 3600.00 9.434 241.417 3700.00 11.932 238.238 3800.00 13.792 235.535 3900.00 15.997 237.671 3420.81 3519.77 3618.03 3715.51 3812.15 3496.31 3595.27 3693.53 3791.01 3887.65 38.15 S N 5930626.88 N 5930617.10 N 5930604.43 N 5930589.74 N 697655.40 E 697642.92 E 697627.18 E 697608.88 E 697587.80 E 2.129 2.395 2.566 1.954 2.272 34.60 42.30 52.91 66.55 82.34 4.38W 25.84 W 4000.00 18.098 237.305 4100.00 20.001 238.188 4200.00 22.443 238.101 4300.00 24.322 239.481 4400.00 27.354 239.993 3907.75 -- 4oo2.2Z::::}?-i? 4095.48\~~~ 41 4187 .26 ~~~~ 42 4277 .26 ._oo~ 50.56 W 78.17W 108.91 W 142.86 W 180.50 W 5930573.35 N 5930555.22 N 5930535.32 N 5930513.88 N 5930490.97 N 697563.49 E 697536.35 E 697506.12 E 697472.72 E 697435.67 E 2.105 1.925 2.442 1.957 3.041 100.02 119.58 141 .07 164.28 189.15 4500.00 29.990 240.986 4600.00 32.414 242.085 4700.00 33.514 243.085 4800.00 35.352 243.593 4900.00 37.005 243.600 4364.99 4450.52 4534.41 4616.89 4697.60 4440.49 4526.02 4609.91 4692.39 4773.10 198.92 S 223.60 S 248.65 S 274.01 S 300.26 S 222.26 W 267.80 W 316.12 W 366.65 W 419.52 W 5930466.26 N 5930440.40 N 5930414.09 N 5930387.42 N 5930359.80 N 697394.55 E 697349.66 E 697302.02 E 697252.17 E 697200.00 E 2.679 2.489 1.227 1.861 1.653 216.03 244.27 273.10 302.41 332.80 5000.00 37.128 243.107 5100.00 37.317 243.297 5200.00 37.221 243.694 5300.00 37.466 244.882 5400.00 37.224 244.506 4777.38 4857.01 4936.59 5016.10 5095.59 4852.88 4932.51 5012.09 5091.60 5171.09 327.29 S 354.57 S 381 .60 S 407.91 S 433.83 S 473.41 W 527.40 W 581 .59 W 636.24 W 691.09 W 5930331 .36 N 5930302.68 N 5930274.24 N 5930246.50 N 5930219.16 N 697146.84 E 697093.58 E 697040.11 E 696986.18 E 696932.02 E 0.321 0.221 0.259 0.761 0.333 364.05 395.55 426.82 457.42 487.63 '- 5500.00 37.328 244.894 5600.00 37.074 246.082 5700.00 37.021 244.623 5800.00 37.148 245.684 5900.00 37.623 246.685 5175.17 5254.82 5334.63 5414.41 5493.87 5250.67 5330.32 5410.13 5489.91 5569.37 459.72 S 484.81 S 509.92 S 535.27 S 559.78 S 745.84 W 800.85 W 855.61 W 910.32 W 965.86 W 5930191 .84 N 5930165.32 N 5930138.79 N 5930112.02 N 5930086.06 N 696877.97 E 696823.64 E 696769.55 E 696715.53 E 696660.64 E 0.257 0.762 0.881 0.652 0.772 517.81 547.21 576.61 606.25 635.12 13 December, 2001 - 13:38 Page 3 of 14 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for 12-0BC Revised: 5 December, 2001 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 12 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) CO/100ft) 6000.00 38.615 246.404 5572.55 5648.05 584.34 S 604.68 E 1.007 664.12 6100.00 39.516 245.612 5650.19 5725.69 609.97 S 7.79 E 1.031 694.26 6200.00 40.466 245.797 5726.80 5802.30 636.41 S 9.93 E 0.957 725.30 6300.00 40.992 244.618 5802.58 5878.08 663.77 S 1.43E 0.932 757.30 6400.00 42.399 244.994 5877 .26 5952.76 692.09 S 696372.02 E 1.429 790.34 ~' 6500.00 43.582 244.803 5950.40 6025.90 696311.05 E 1.191 824.10 6600.00 44.654 243.618 6022.19 6097.69 696249.18 E 1.352 859.29 6700.00 46.226 244.191 6092.36 6167.86 696186.05 E 1.625 895.65 6800.00 47.481 243.609 6160.74 6236.24 696121.38 E 1.325 932.87 6900.00 47.894 243.107 6228.05 6303.55 696056.17 E 0.555 971.20 7000.00 47.654 243.297 1644.18 W 5929746.90 N 695990.97 E 0.278 1009.77 7100.00 47.404 242.315 1709.79 W 5929711.50 N 695926.26 E 0.766 1048.60 7200.00 47.321 243.777 1775.35 W 5929676.43 N 695861 .60 E 1.079 1087.09 7300.00 46.640 244.292 1841.09 W 5929642.71 N 695796.72 E 0.778 1124.24 7400.00 45.881 244.005 1906.11 W 5929609.53 N 695732.54 E 0.787 1160.83 - - 7500.00 45.309 243.409 6637.84 6713.34 1043.50 S 1970.16 W 5929576.22 N 695669.35 E 0.714 1197.49 7600.00 45.054 242.908 6708.33 6783.83 1075.53 S 2033.45 W 5929542.55 N 695606.92 E 0.438 1234.46 7700.00 44.282 243.097 6779.44 6854.94 1107.45 S 2096.09 W 5929509.00 N 695545.14 E 0.783 1271.28 7800.00 43.393 243.494 6851.57 6927.07 1138.58 S 2157.96 W 5929476.26 N 695484.10 E 0.930 1307.25 7900.00 42.592 242.318 6924.72 7000.22 1169.61 S 2218.68 W 5929443.64 N 695424.22 E 1.134 1343.04 8000.00 42.038 242.005 6998.67 7074.17 1201.06 S 2278.20 W 5929410.65 N 695365.54 E 0.593 1379.14 8100.00 41.015 242.000 7073.52 7149.02 1232.18 S 2336.74 W 5929378.00 N 695307.83 E 1.023 1414.84 8200.00 40.232 242.394 7149.43 7224.93 1262.55 S 2394.33 W 5929346.14 N 695251.06 E 0.825 1449.71 -- 8300.00 40.230 241.710 7225.78 7301 .28 1292.81 S 2451.38 W 5929314.40 N 695194.82 E 0.441 1484.43 Sidetrack 60 Rt TF @ 12.001 0/1000 : 8300.00ft MD, 7301.28ft TVD 13 December, 2001- 13:38 Page 4 of 14 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services.-... Proposal Report for 12-08C Revised: 5 December, 2001 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 12 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) (o/100ft) 12-08C wp10 8325.00 43.214 242.169 7244.44 7319.94 1300.64 S 2466.06 W 12.001 1493.40 Decrease in Dir Rate @ 6.000°/1000: 8325.00ft MD, 7319.94ft TVD 8396.80 47.500 242.783 7294.88 7370.38 1324.23 S 6.000 1520.53 End Dir, Start Sail @ 47.500°: 8396.80ftMD,7370.38ftTVD .--" 8400.00 47.500 242.782 7297.04 7372.54 695133.62 E 0.000 1521.78 8500.00 47.500 242.782 7364.60 7440.10 695068.96 E 0.000 1560.63 8600.00 47.500 242.783 7432.16 7507.66 695004.30 E 0.000 1599.47 8700.00 47.500 242.783 7499.72 7575.22 ~. 2710.15 W 5929174.01 N 694939.64 E 0.000 1638.32 8800.00 47.500 242.783 7567.28 7642.78 2775.71 W 5929138.58 N 694874.98 E 0.000 1677.17 8900.00 47.500 242.783 7634.83 ~~óZ O. 2841.28 W 5929103.16 N 694810.32 E 0.000 1716.02 9000.00 47.500 242.783 7702.3Q~'J~~~~ ~~;;.~ 2906.84 W 5929067.73 N 694745.66 E 0.000 1754.87 9100.00 47.500 242.783 7769.95.c:. 78Y 2972.41 W 5929032.31 N 694681.00 E 0.000 1793.72 9200.00 47.500 242.783 7837.51 1595.07 S 3037.97 W 5928996.88 N 694616.34 E 0.000 1832.57 9300.00 47.500 242.783 7905.07 1628.80 S 3103.53 W 5928961.46 N 694551.68 E 0.000 1871.41 9400.00 47.500 242.783 7972.63 1662.52 S 3169.10W 5928926.03 N 694487.02 E 0.000 1910.26 9500.00 47.500 242.783 8040.19 1696.24 S 3234.66 W 5928890.61 N 694422.37 E 0.000 1949.11 9600.00 47.500 242.783 8107.75 1729.96 S 3300.23 W 5928855.18 N 694357.71 E 0.000 1987.96 9700.00 47.500 242.783 8175.31 8250.81 1763.68 S 3365.79 W 5928819.75 N 694293.05 E 0.000 2026.81 9714.35 47.500 242.783 8185.00 8260.50 1768.52 S 3375.20 W 5928814.67 N 694283.77 E 0.000 2032.38 THRZ 9800.00 47.500 242.783 8242.87 8318.37 1797.40 S 3431.36 W 5928784.33 N 694228.39 E 0.000 2065.66 9900.00 47.500 242.783 8310.42 8385.92 1831.12 S 3496.92 W 5928748.90 N 694163.73 E 0.000 2104.51 9965.98 47.500 242.783 8355.00 8430.50 1853.37 S 3540.18 W 5928725.53 N 694121.07 E 0.000 2130.14 BHRZ- 10000.00 47.500 242.783 8377.98 8453.48 1864.84 S 3562.48 W 5928713.48 N 694099.07 E 0.000 2143.35 10084.40 47.500 242.783 8435.00 8510.50 1893.30 S 3617.82 W 5928683.58 N 694044.50 E 0.000 2176.14 TJC 10100.00 47.500 242.783 8445.54 8521.04 1898.56 S 3628.05 W 5928678.05 N 694034.41 E 0.000 2182.20 10200.00 47.500 242.783 8513.10 8588.60 1932.28 S 3693.61 W 5928642.63 N 693969.75 E 0.000 2221.05 10300.00 47.500 242.783 8580.66 8656.16 1966.00 S 3759.18 W 5928607.20 N 693905.09 E 0.000 2259.90 13 December, 2001-13:38 Page 5 of 14 DrillQuest 2.00.09.006 North Slope Alaska Measured Depth (ft) Incl. Azim. 10343.43 47.500 242.783 10400.00 47.500 242.783 10475.91 47.500 242.783 10500.00 48.464 242.783 10521.86 49.338 242.783 10600.00 52.464 242.782 10677.85 55.578 242.783 10687.85 56.877 242.756 10700.00 58.457 242.725 10715.63 60.489 242.686 10754.76 65.574 242.596 10773.34 65.574 242.596 10800.00 67.752 239.660 10900.00 76.323 229.371 10939.32 79.817 225.556 11000.00 85.288 219.823 11051.84 90.000 215.000 11100.00 90.136 209.222 11200.00 90.412 197.225 11201.57 90.416 197.037 11300.00 90.416 197.037 11400.00 90.416 197.037 11458.26 90.416 197.037 11500.00 86.671 197.329 11518.62 85.000 197.460 13 December, 2001 - 13:38 Sub-Sea Depth (ft) 8610.00 8648.22 8699.50 8715.63 8730.00 8779.27 8825.00 Vertical Depth (ft) 8685.50 8723.72 8775.00 8791.13 8805.50 8854.77 8900.50 8830.56 8906.06 ::~:g~,:~iC~: 8862.7 4"K~ 89 8870.42 ~1J9~5.92 - - 8880.98 8911 .87 8920.00 8927.87 8930.00 8929.94 8929.46 8929.45 8928.74 8928.01 8927.59 8928.65 8930.00 8956.48 8987.37 8995.50 9003.37 9005.50 9005.44 9004.96 9004.95 9004.24 9003.51 9003.09 9004.15 9005.50 Sperry-Sun Drilling Services Proposal Report for 12-0BC Revised: 5 December, 2001 Local Coordinates Northings Eastings (ft) (ft) 1980.65 S 1999.72 S 2025.32 S 2033.51 S 2041.04 S 2128.28 S 2136.07 S 2147.89 S 2203.14 S 2229.15 S 2273.35 S 2314.47 S 2355.24 S 2446.97 S 2448.47 S 2542.58 S 2638.19 S 2693.89 S 2733.75 S 2751.47 S 3787.65 W 3824.74 W 3874.51 W 4022.40 W 4031 .53 W 4043.50 W 4074.45 W 4089.48 W 4110.90 W 4188.05 W 4216.38 W 4257.13 W 4288.57 W 4314.16 W 4353.52 W 4353.98 W 4382.82 W 4412.12 W 4429.19 W 4441.51 W 4447.06 W Page 6 of 14 Global Coordinates Northings Eastings (ft) ~ (ft) 5928464.97 N 5928460.04 N 5928453.55 N 5928436.73 N 5928428.55 N 5928416.17 N 5928358.92 N 5928332.18 N 5928286.93 N 5928245.00 N 5928203.57 N 5928110.84 N 5928109.33 N 5928014.50 N 5927918.15 N 5927862.03 N 5927821.86 N 5927804.00 N 77.01 E 40.43 E 91 .35 E 693708.03 E 693652.79 E 693645.50 E 693636.50 E 693624.70 E 693594.17 E 693579.36 E 693558.25 E 693482.58 E 693454.93 E 693415.36 E 693385.00 E 693360.49 E 693323.54 E 693323.12 E 693296.75 E 693269.97 E 693254.36 E 693243.09 E 693238.00 E . Alaska Drilling & Wells PBU_EOA DS 12 Dogleg Rate ("/1ooft) Vertical Section Comment 0.000 2276.77 T JB 0.000 2298.75 0.000 2328.24 Begin Dir @ 4.0ooo/100ft: 10475.91f MD, 8775.000 TVD 4.000 2337.67 4.000 2346.35 T JA .~ 4.000 2378.30 4.000 2411.49 Increase in Dir Rate @ 13.000°/1000 : 10677.85ft MD, 8900.5Oft TVD TSGR 13.000 2415.87 7" Casing 13.000 2421.29 13.000 2428.40 TSHU 13.000 2446.84 End Dir, Start Sail @ 65.574°: 10754.76ftMD,8938.24ftTVD 0.000 2455.80 Begin Dir @ 13.0000/100ft: 10773.34 MD, 8945.92ft TVD 13.000 2469.29 13.000 2530.53 13.000 2558.71 TSADITZ4B 13.000 2606.03 13.000 2649.52 Decrease in Dir Rate @ 12.000°/1000 11 051.84ft MD, 9005.5Oft TVD Target - Landing, Drillers -- 12.000 2692.21 12.000 2786.79 12.000 2788.32 End Dir, Start Sail @ 90.416° : 11201.57ftMD,9004.95ftTVD 0.000 2884.43 0.000 2982.08 0.000 3038.96 Begin Dir @ 9.0000/100ft: 11458.26t MD,9003.09ftTVD 9.000 3079.68 9.000 3097.78 Target - 12-08C T1, Drillers DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for 12-08C Revised: 5 December, 2001 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 12 Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) e /1 OOft) 11525.79 84.354 197.454 8930.67 9006.17 2758.28 S 4449.21 W 9.000 3104.75 11526.79 84.354 197.454 8930.76 9006.26 2759.23 S 4449.51 W 0.000 3105.72 End Dir, Start Sail @ 84.354° : 11526.7OOMD,9006.26ftTVD 11600.00 84.354 197.454 8937.97 9013.47 2828.73 S 0.000 3176.74 11614.52 84.354 197.454 8939.39 9014.89 2842.52 S 0.000 3190.83 Begin Dir @ 9.000°/1000: 11€ 2t MD, 9014.800 TVD ~/ 11700.00 85.831 189.876 8946.72 9022.22 2925.21 S 693193.84 E 9.000 3274.86 11800.00 87.647 181.047 8952.42 693186.96 E 9.000 3374.58 11900.00 89.520 172.240 8954.89 693195.41 E 9.000 3473.49 11925.46 90.000 170.000 8955.00 693200.00 E 9.000 3498.25 Target - 12-08C T2, Drillers 12000.00 90.208 163.294 8954.86 693219.10 E 9.000 3569.13 12100.00 90.482 154.298 8954.26 693257.65 E 9.000 3659.08 - - 12195.23 90.732 145.731 4394.62 W 5927159.71 N 693307.34 E 9.000 3737.42 End Dir, Start Sail @ 90.732° : 12195.23ftMD,9028.75ftTVD 12200.00 90.732 145.731 8953.19 3401 .30 S 4391 .93 W 5927155.84 N 693310.13 E 0.000 3741.14 12286.26 90.732 145.731 8952.09 3472.58 S 4343.36 W 5927085.85 N 693360.54 E 0.000 3808.31 Begin Dir @ 8.000°/1000: 12286.26t MD, 9027.500 TVD 12300.00 90.702 144.633 8951 .92 9027.42 3483.86 S 4335.52 W 5927074.78 N 693368.68 E 8.000 3818.93 12400.00 90.482 136.635 8950.88 9026.38 3561.10 S 4272.14 W 5926999.22 N 693434.05 E 8.000 3890.87 12500.00 90.253 128.638 8950.24 9025.74 3628.78 S 4198.64 W 5926933.49 N 693509.30 E 8.000 3952.46 12600.00 90.019 120.642 8950.00 9025.50 3685.57 S 4116.43 W 5926878.87 N 693592.97 E 8.000 4002.51 12608.02 90.000 120.000 8950.00 9025.50 3689.63 S 4109.51 W 5926875.00 N 693600.00 E 8.000 4005.99 Decrease in Dir Rate @ 6.000°/1000: 12608.02ft MD, 9025.5Oft TVD Target - 12-08C T3, Drillers -........,./ 12700.00 89.273 114.529 8950.58 9026.08 3731.74 S 4027.78 W 5926835.04 N 693682.80 E 6.000 4041.45 12743.22 88.933 111 .958 8951 .26 9026.76 3748.80 S 3988.08 W 5926819.03 N 693722.94 E 6.000 4055.28 End Dir, Start Sail @ 88.933° : 127 43.22ftMD,9026.76ftTVD 12800.00 88.933 111.958 8952.32 9027.82 3770.02 S 3935.43 W 5926799.19 N 693776.12 E 0.000 4072.23 12900.00 88.933 111.958 8954.18 9029.68 3807.41 S 3842.70 W 5926764.24 N 693869.80 E 0.000 4102.10 13000.00 88.933 111.958 8956.04 9031.54 3844.80 S 3749.97 W 5926729.29 N 693963.48 E 0.000 4131.96 13100.00 88.933 111.958 8957.90 9033.40 3882.18 S 3657.24 W 5926694.35 N 694057.15 E 0.000 4161 .82 13139.01 88.933 111.958 8958.63 9034.13 3896.77 S 3621.06 W 5926680.71 N 694093.70 E 0.000 4173.47 13 December, 2001- 13:38 Page 7 of 14 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 12-08C Revised: 5 December, 2001 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) _4 (ft) 13139.34 88.936 111 .938 8958.63 9034.13 3896.89 S 3620.76 W 13200.00 89.374 108.325 8959.53 9035.03 3917.76 S 3563.82 W 13286.21 90.000 103.190 8960.00 9035.50 3941 .17 S 3480.87 W 13300.00 90.000 103.190 8960.00 13400.00 90.000 103.190 8960.00 13500.00 90.000 103.190 8960.00 13600.00 90.000 103.190 8960.00 13700.00 90.000 103.190 8960.00 13786.40 90.000 103.190 8960.00 13800.00 89.102 103.190 8960.1 13900.00 82.502 103.193 8967.42 14000.00 75.902 103.196 8986.15 14033.75 73.675 103.197 8995.00 14051.55 72.500 103.197 9000.18 14100.00 72.500 103.197 9014.75 14117.47 72.500 103.197 9020.00 9035.50 9035.50 694248.50 E 694346.43 E 3272.73 W 5926596.68 N 694444.35 E ic 3175.37 W 5926576.42 N 694542.28 E 3078.00 W 5926556.16 N 694640.20 E 2993.88 W 5926538.65 N 694724.81 E 2980.64 W 5926535.90 N 694738.13 E 4081.15 S 2883.60 W 5926515.70 N 694835.74 E 4103.56 S 2788.01 W 5926495.80 N 694931.88 E 4110.99 S 2756.31 W 5926489.20 N 694963.76 E 4114.88 S 2739.73 W 5926485.74 N 694980.44 E 4125.43 S 2694.74 W 5926476.38 N 695025.69 E 4129.23 S 2678.52 W 5926473.00 N 695042.00 E 9090.25 9095.50 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. Magnetic Declination at Surface is 26.627° (29-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 184.580° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14117.47ft., The Bottom Hole Displacement is 4921.89ft., in the Direction of 212.970° (True). 13 December, 2001-13:38 Page 8 of 14 . Alaska Drilling & Wells PBU_EOA DS 12 Dogleg Vertical Rate Section Comment (o/100ft) 6.000 4173.57 Begin Dir @ 6.0000/1OOft: 13139.341' MD, 9034.13ft TVD 6.000 4189.83 6.000 4206.53 End Dir, Start Sail @ 90.000° : 13286.21 ftM D ,9035.5OOTVD Target - 12-08C T4, Drillers ~/ 0.000 4208.60 0.000 4223.57 0.000 4238.54 0.000 4253.51 0.000 4268.48 0.000 4281.41 Begin Dir @ 6.600°/1000 : 13786.4ot MD, 9035.500 TVD 6.600 4283.45 6.600 4298.38 6.600 4313.08 6.600 4317.96 MHOT 6.600 4320.51 End Dir, Start Sail @ 72.500° : 14051.55ftMD,9075.68ftTVD 0.000 4327.43 0.000 4329.93 Total Depth: 14117.47ftMD,9095.5OOTVD 41/2" Liner TD ~- Target - 12-08C TD, Drillers DrillQuest 2.00.09.006 ') Sperry-Sun Anticollision Report ') , ,è~ffl~Y: BPAmoco ' 'DIde: 1211'~/2001' 'rfuie:07:,2,,6:~8, : Field:, ,Prl.\dhœBaý 'R~re~~Il~e Site: ,PBDSi12 , .CH~te(~E)Reference: WeU:.12-06;rrueN()rth , R~ff,\~c~Well:, 1';2:.08 ' Ve~cål(TVD)Referenc~~' , 75.50~75;$ , R~ference WeØpath:, ,Plan 12~oaC' "".' , ' , Db:.. . Oracle GLOBAL SCAN APPLIED: All weUpaths within 200'+ 100/1000 of ref ere nee - There are mmHiIimIeUs in this BIMipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 8300.00 to 14117.67 ft Sean Method: TravCylinderNorth Maximum Radius: 1608.32 ft Error Surfaee: Ellipse + Casing Survey Program for Definitive WeUpath Date: 08/01/2001 Validated: No Planned From To Survey ft ft 34.50 2701 .50 2701.50 8300.00 8300.00 14117.65 Casing Points Version: Tooleode 21 10677.84 8900.50 14117.65 9095.58 Summary PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB DS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB OS 12 PB DS 12 PB OS 12 PB OS 12 PB PR1 PB PR1 Site: PB DS 12 WeD: 12-08 WeDpath: 12-08A V4 Reference MD TVD ft ft 8300.00 7301.28 8324.98 7319.92 , '"R...~. ~,~.:,.e.",' , 9t'fs,t,'Çn-~~rl;,,~o..CQ~: '"Allc)w.bl~, " , ,., ,. ¡¡uD, ."":'i.,MJ)':" "'.' I>bI.~~~ Area". ' ,,' aeviå#on 'W~. ' ' , , :'ft:', ",',ft,":' ',ft", ,'ft " ': ,ft,' " Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range FAIL: Major Risk FAIL: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Minor 1/200 Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Tool Name 1 : Sperry-Sun BOSS gyro multi 1 : Sperry-Sun BOSS gyro multi Planned: 12-08c wp1 0 V1 BOSS-GYRO BOSS-GYRO MWD+IFR+MS Sperry-Sun BOSS gyro multishot Sperry-Sun BOSS gyro multishot MWD + IFR + Multi Station 7.000 4.500 8.500 6.125 7" 41/2" , OtTliet\V~Upath--.+~~-,..,,_J~~,.-----~~, ' WeD.','" ..'.:""\y~np~d1',, 12-04 12-04A 12-05 12-06 12-06A 12-07 12-07 A 12-08 12-08 12-08 12-09 12-1 0 12-1 OA 12-11 12-14 12-14A 12-14PB1 12-15 12-16 12-16A 12-18 12-22 12-23 12-30 12-31 12-33 12-34 1 2-35 12-35PB1 12-36 PR181015 PR191015 12-04 V1 12-04A V1 12-05 V1 12-06 V1 12-06A V1 12-07 V1 12-07A V1 12-08 V20 12-08A V4 12-08B V11 12-09 V1 12-10 V1 12-10A V3 12-11 V1 12-14 V1 12-14A V8 12-14PB1 V1 12-15 V1 12-16 V1 12-16A V1 12-18 V1 12-22 V1 12-23 V1 12-30 V1 12-31 V1 12-33 V1 12-34 V1 12-35 V1 12-35PB1 V1 12-36 V1 PR181015 V1 PR191015 V1 10567.73 10600.00 247.921111.76 -794.60 9759.64 9775.00 179.01 869.42 -338.63 11596.80 10500.00 624.72 61.65 624.72 8300.00 8175.00 1102.89 510.47 823.02 8300.00 8175.00 1100.63 510.84 819.71 8300.00 7925.00 1098.87 408.78 692.35 12877.68 10775.00 900.54 315.91 613.24 13981.82 10450.00 1559.70 358.90 1223.82 13981.82 10450.00 1559.70 358.90 1223.82 12465.81 10425.00 1577.95 210.94 1389.99 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft Allowable Deviation ft -121.48 -123.76 Offset MD TVD ft ft 8300.00 7301.28 8325.00 7320.36 Semi-Major ADs Ref Oft'set TFO+AZI TFO-HS Casing ft ft deg deg in 107.70 141.12 61.71 0.00 107.71 142.07 60.94 178.77 Ctr-Ctr No-Go Distance Area ft ft 0.00 779.81 0.65 782.75 Warning FAIL FAIL N.1n~ ~ N'.S I~.Œ .1'I"7(¡.t~ -UJ7-1J =ooð --500 -400 -300 -2CX) -100 -0 -ICX) -2CX) -300 -400 -500 =Ðffj .).W WIII.I~ TAII.~ CO\lPA"Y I~,TMLS SUR\lX PROGRAM A1'o'1l.COLLlSIO~ SEmNGS N<'nlriI1~ F';t\'in;.! L..1ri:u.;.,(" S\.,! BP ArnX0 1_.}n~IUJ~ Imerpolalion M"'thod:MO Inl""val: 50.00 Depth Rang.: From: 8300.00 To: 14117 .67 Maximum Rang"': 1608.32 Rer""",nœ: Plan: 12-08e wplO CalouJatPn M<iboJ, Minimum eUInruæ Erro, S"I<01: ¡Sews... Scan M.-tl>"J<.!; T I'''. C)'ioJer North Error SUJfac" EBiptical + Ca>llg WarnIDg M«hod; Rub 1Ja.-.aJ ~.UìI10 'on 70 1:!-5_Ht\(N I"'':-:!-I ~l.i07W r« O;7(d 1.5~ 17 Wi (l1-UlSAì 0 270 MD ¡¡c From 0 8250 85oo 8750 9000 9250 95oo 9750 100oo 1250 15000 10750 11000 11250 11500 11750 12000 13000 14000 90 180 6{}!ì I . 8300.00 .w.! \ 2n. 71 2 8l15:.oCt .t1.11 2-tL11 c 3 8396.80 ~15!t 2.\.1.78 4 10475.91 t15() :2.\.1.78 5 10677JI.S ,55>1 2-12.78 6 10754.36 6.~~ .:'41..-18 7 1071135 6'ii52 24!.:18 8 11052:09 90.00 215.00 " . I1WV18 90..\2 197.Ot. .¡!t' LH5851 '>0 .\2 1~7.Ot 11 11518.89 ~5.00 197.46 12 11526.0& M..t' 197.46 13 11614.11 >U3< 197.-16 14 11925.16 <¡(.OO 170.00 15 1:2195.28 4.}(}.1~ Ilj~15 \6 1228632 '>07.\ 1-15.75 17 126OiL~ 901lJ IlO.oo 18 1274352 &< 9.- 111.% 19 13139.34 8X.9~ 111.96 20 1328659 W.(', 103.19 21 1378659 <¡(.(." 10.1.19 n 14051.69 T.!5U Kr.U9 23 14117.61 7250 I!tU9 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] Colour ToMD 8250 8500 8750 9000 9250 95oo 9750 WOOO 1250 15000 10750 11000 11250 11500 11750 12000 13000 14000 15000 Azî WI].I.PATH DLTAILS Too] Pim 12.08C MV>'D!-IFR+MS Part-IIt Wcl\-'ath: TiI: on MD: 12-08B 1(»25.00 Rig; R.r. Datum; 755U 75.50f! \.'.Sð:¡j.].n Ang\< Origin +N1-S Oriein +El:\\" S~ FrùmTVD 1::])' Co:.,:;: :::OC.IJ LEGE/'ID ::;::.::t 1!-ILJII:..ILll \1.0."'11([10 1.'.f'-lA II!.UJ-\, M.i," RiSk =- 1.'.Ji"..I:Jr'J. "'L.r'IJ.I'..r.L ~~~ 1.'-Ir.tI.'..cJl.¡ '\",.,JI'.It. - 1~1t\,'I~lr.-" ~l.J"'IRf;;k - 1~-rr.'I~lI"7, p.,L.,.,P..1." ~ I: (('"11\ 1.1.' U1.\\ A.L,..IHt.-k - 1~11'c(I.'~11\"'IIIo!J.lIJRS -- l:r.J'CII:JJ~\ll\iIrlkl:I)RS ~ I!-I~ II 'J.J"'!(h f'-.'ILPJrORS - 1.'I'lII:..f,Ij..M.....,Jtt.L ~ I" In II.! lill "l..Þ' ktoo~ - 1.~IIIA.{I.'III!\iM;;t"IRîs:k - I~ 1111':- 111 ~L"I k..tl. I~ I ~ II! 111 ~'--"'I Rt." - I.' I~'II_' I.IAI \b".r IŒk -- I: I.1l'rlllP IU'RI~ A.l.1j}rR~k - 1~1'11.:a1"'''''hf''',l.r:"lO - 1~1"tl.'lt;IM,,"'IJtl." = :!.':~L~I'.:aI"~~;:'~LJ~~k:.~k ~~ 1'1 ~II!~~I MJ.þ:I t'..bL - I~ ?ql~ :!" Pabr'l R.bL ~ la',,"III':'III_~'bJ..'llhL I: 11 II? ~ II U..J." "'r.~ - 1"1111~1.1þ''''J"Ju..l - I:: 4,1" Lh ,,\it,.... RL.L - 1.'.h":'»I";;,,MoI..JI'...1'ioL - I~ ;"'ElIII~ "I'BI. MaprIUsI;: - I~ w'll:? \t'1 MoI,'1 Rt'oL -- I'RuCIIII'llI('J(lðllil"l. ~lapTllli~ "="-== .'WI~IIII!lIIII~I"'HII"'1 ~~_JtR(st - .''I::..r,I~I".: - I?""~~r,l\l PIm; 12.{J8c "plO(l2-(ti!PIm 12-œc¡ erena! By' P""ch Ho1!zma¡¡ Ch<ckcl, Dat" 1211' D"I<; .-j Dat<: R~iew(\j: Approvcl ; Dal<; SECTION IJETAlI$ TVD +NI-S +E/cW :1011 !~ ì'I~u..f. "1"1147 - ~11" ill )0,"11_""-1 ð".;;I: (17 ~':J.l'" :'\ "'.[b ..., '}lI)..t~ 1II\tN I.MI(~ "Ii 'Mlh -17- I.IIII-t IN- Ijlll150 LIII:,,1"; i'"JfI'7..... 'J{I!.".c:.u '.I!J,,:n':'r, 'IÙ'-11{ l.IIuc,:.., - ~n'.:,ft 1.I(1í.","'¡' u¡"""', .....J 1."1,'81 :-2451.)8: I ~1I64 -2466,«)) I (,? L13 -251L\5- ?J~5 ~ -381451 }t').l"75S 4015-01 ,,".02 -407~19 ~ ", 51 -4088.75 "'IJJ6 4288.94- 2}Þ 12 43..'4.M -"'" , ¡(¡ -+L'>959 ?7'il J8 -4447..16 27'.10 -#t9.61 .¡.U ~33 -4416..Œ "I .Iu 16 -U95.~1 1"J1OS -4395.1~ 'J ':.)3 4343.95 "....ro 4100.94 .'" 16 -398855 -1)0,"", n -362152 "'1, 19 -3481.29 -">"'28 -mus -III J fi..i -214036 -II.'" 19 -2619.10' 0.01' 8.9& .~.U 1-13.99 '127.26 ~-..!_3J 97U.% - 11"'.25 12.{J8c landi I!Ot.OI 1:'517.\ 161.''<5 12-08c A Iti'1052- 1106.<;(1 WIHII 12-tllcß lLC¡~OO ~:t:!",9( !...;21 ï7 12-íßc C 2"71 o~ 2(~.!! H22 28 12-08cD 2i97.07 2...16 10 )I\..l~-"I 12-Œk E IItll lJlU I.'nl hU~ f.IU tolll 1'411 III" -1111 {Il.. I 1 {I' (I IJ:~ un. IIll) I '(II - C,I ~~ I'! III .)0,)[ (..; In) IHII fJll1 I."NI "III 17'''.~ (IUI (II'{I ~tll ';'r¡.( ~nl lU( ~.' 1.1 If I Oil} I<UJ IH .;,,?; I. ¡II ~. .-s Lilli IIIII f. III '" ~ 1'1; - OUi II Iii r.hll .174'-.q (III, ill I) 5929000 5928500 5928000 5927500 5927000 5926500 5926000 692800 - -- - ~~~~ ~- - -~ ~t~¿~f~-:~'-'~4~~;>-~~~~~; .- -- -- 693300 693800 694300 694800 695300 695800 <" VVellPian 10 WTA 12í07/01 .- -B--12-08C -t-DDTarget ~Targets . --' North True Referance )S 12-08C Permit om ission ') ) Subject: DS12-08C Permit omission Date: Tue, 2 Jul2002 12:43:24 -0500 From: "Smith, Phil G (FAIR)" <SmithPG1@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Winton, The summary procedure on page 4 of the drilling permit application omitted a contingent perforating step. For accuracy, please note that step 14.5 should read: "DPC Perforate a short interval in the upper (solid) section of the 4 ~" liner as dictated by logs" Thanks, Phil 1 of 1 7/2/20029:54 AM H 206926 DATE INVOICE I CREDIT MEMO OS/23/02 CK052302I THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 PAY DESCRIPTION GROSS Permit To Drill Fee Pls call Terrie .Hubble X4628 \?--d3C- TOTAL ~ DATE CHECK NO. OS/28/02 H206926 VENDOR . ¡ DISCOUNT NET $100.00 H <ECEIVED JU~ Î ? -" f)LOtfì2 ¡\~ i- D . v Alas1Œ. Oil & Gas Cons. \jommlSSÎon Anchorage - $1:00.00 No.H206926 FIRST NAT10NAL BANK OF ASHLAND ANAfflUATÈOF NATIONAL em BANK CLEVElAND. OHIO ~389 --¡:j'2 B. . D.... .,~i2'~a~ .~.rn,(..'j' . F. . 9~ ...../ tqw. .URIt TO THE ORDER OF Alaska Oil & Gas ConservationCommiss~on 333 W 7th Ave, ste Anchorage, AK. 99501 III 2 0 b Eì 2 b III I: 0... ~ 2 0 3 a Eì 5 I: 0 0 a ...... ~ Eì II' CONSOLIDATED COMMERCIAL ACCOUNT . . ...2002.** .. . . . ~** * * $1QO. d'O** * ***.;'1'/ . NOTNALIO AFTER 12o.DAYS . . . - - .. . -... m¡ .u.. ..... .. u.u. ,~~3Æ~ CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL X EXPLORA TION INJECTION WELL INJECTION WELL RED RILL Rev: 5/6/02 C\jody\templates ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME,Æq CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) ) /2-06'C "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 20 AAC 25.005(t), 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 Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject 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 the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY .ß'P"A-' WELL NAME!'&¡ /2 -o~ C PROGRAM: Exp - Dev - Redrll K Se~ - Wellbore seg - Ann. disposal para req- FIELD & POOL (70)..5"~ INITCLASS /J¡C2¿/ /-cJ// GEOLAREA ?7~ UNIT# /Ih.(ð ON/OFFSHORE ÛK) -ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . (~~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated. is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . \:!J N 14. Conductor string provided. . . . . . . . . . . . . . . . . . . .¥-N- 15. Surface casing protects all known USDWs. . . . . . . . . . . Y---N-- ¡JIlt- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C, T. B & permafrost. . . . . . . N "J / - ") r ç 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N l'4a p,tJ rS '- ç 21. If a re-drill. has a 10-403 for abandonment been approved. . . N Å1,) pY\?" ~d &/2.'5 102.. . 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . . N 23. If diverter required. does it meet regulations. . . . . . . . . . I NI Ar 24, Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs. do they meet regulation. . . . . . . . . . . . . . . . N - r b ./- 26. BOPE press rating appropriate; testto ~~ 00 psig. - N ¡tits P '2-s (p 0 r ~ t. fY/tiX ~ S¡ ~ç,t ~ 000 pç,,/. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . . ~ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . y~ 31. Da~a ~resented. on potential overpressure zones. . . . . .. X A ) /Î 32. SeIsmIc analysIs of shallow gas zones. . . . . . . . . . . . . Y / (./) //-.J .AjfR -p~~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N I)/r '?" /ó.? 34. Contact name/phone for weekly progress reports [exploratory on'" Y N ANNULAR DISPOSAL 35. With proper cementing records. this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP# ;fp ~þ? ENGINEERING APP~ DATE \¿JG'tt- 1 { 1111 L GEOLOGY APPR DA]E &Ø~2 ( /f/vA \ Commentsllnstructions: JDH WGA 'vJ.c,¡r- COT " DTSOì /'0 ?-I 0 <. G:\geology\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process. but is part of the history file. To improve the readability of the Well History file and to simpltfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 29 15:51:11 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/29 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments.... ............ .STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: MWD RUN 1 AK-MW-22115 R. MCNEILL J. RALL / D. MWD RUN 4 AK-MW-22115 J. SACK R. BORDES / MSL 0) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 12-08C 500292043203 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 29-JAN-03 MWD RUN 2 AK-MW-22115 R. MCNEILL J. RALL / D. MWD RUN 3 AK -MW - 2 2115 R. MCNEILL J. RALL / D. 18 ION 15E 339 2 69.40 40.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8305.0 6.125 7.000 10676.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. aoa-J86 -- II ':JOt ) ) THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED WHICH WAS AT 8300' MD AND THE BOTTOM WAS AT POSITIONED DURING MWD RUN 1. FROM A WHIPSTOCK, THE TOP OF 8316' MD. THE WHIPSTOCK WAS 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND PRESSURE WHILE DRILLING (PWD). MWD RUN 4 COMPRISED DIRECTIONAL WITH DGR; AT-BIT-INCLINATION (ABI); AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 4 REPRESENT WELL OS 12-08C WITH API#: 50-029-20432-03. THIS WELL REACHED A TOTAL DEPTH (TO) OF 14070'MD/9018'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. 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 FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/29 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 ROP FET RPD RPM RPS RPX $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 8206.0 8305.0 10624.0 10624.0 10624.0 10624.0 10624.0 STOP DEPTH 14016.0 14069.5 14023.0 14023.0 14023.0 14023.0 14023.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ ) ) # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 4 MERGE TOP 8206.0 8330.5 9408.0 10681.0 MERGE BASE 8330.0 9408.0 10681.0 14069.5 # REMARKS: MERGED MAIN PASS. $ # 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 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 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8206 14069.5 11137.8 11728 8206 14069.5 ROP MWD FT/H 0.03 471.98 128.589 11530 8305 14069.5 GR MWD API 13.8 531.45 99.5658 11621 8206 14016 RPX MWD OHMM 0.67 2000 35.0299 6799 10624 14023 RPS MWD OHMM 0.94 2000 45.972 6799 10624 14023 RPM MWD OHMM 0.06 2000 76.3188 6799 10624 14023 RPD MWD OHMM 0.77 2000 124.402 6799 10624 14023 FET MWD HOUR 0.14 57.33 1. 87951 6799 10624 14023 First Reading For Entire File...... ....8206 Last Reading For Entire File...... .... .14069.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/29 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...... .03/01/29 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 ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 8206.0 8305.0 STOP DEPTH 8330.0 8330.0 # 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: # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 11-JUL-02 Insite 66.37 Memory 8330.0 8305.0 8330.0 .0 .0 TOOL NUMBER 126027 8.510 .0 LSND 10.20 52.0 9.4 800 3.6 .000 .000 .000 .000 .0 149.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 ) Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API Min 8206 0.03 23.7 Max 8330 6.02 71.2 First Reading For Entire File......... .8206 Last Reading For Entire File.......... .8330 File Trailer Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/01/29 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...... .03/01/29 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 ROP GR $ 3 Mean Nsam 8268 249 4.13176 51 50.4873 249 ) First Reading 8206 8305 8206 Last Reading 8330 8330 8330 header data for each bit run in separate files. 2 .5000 START DEPTH 8330.5 8330.5 # 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: # 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): STOP DEPTH 9408.0 9357.0 ll-JUL-02 Insite 66.37 Memory 9408.0 8330.0 9408.0 43.1 51. 5 TOOL NUMBER 126067 8.500 .0 LSND 10.40 51.0 ) 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: 9.0 1000 3.5 .000 .000 .000 .000 .0 131.0 .0 .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.....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 MWD020 FT /H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 8330.5 1.2 36.8 Max 9408 387.91 270.15 Mean Nsam 8869.25 2156 140.119 2156 129.059 2054 First Reading 8330.5 8330.5 8330.5 Last Reading 9408 9408 9357 First Reading For Entire File......... .8330.5 Last Reading For Entire File.......... .9408 File Trailer Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation... ... .03/01/29 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...... .03/01/29 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FI LE HEADER FILE NUMBER: RAW MWD 4 ) i ') header data for each bit run in separate files. 3 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 9357.5 9408.5 STOP DEPTH 10649.5 10681. 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 14-JUL-02 Insite 66.37 Memory 10681. 0 9408.0 10681. 0 44.0 51. 6 TOOL NUMBER 126067 8.500 8400.0 LSND 10.50 46.0 8.8 1000 3.6 .000 .000 .000 .000 .0 156.0 .0 .0 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 ) '\ ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9357.5 10681 10019.3 2648 9357.5 10681 ROP MWD030 FT/H 1. 74 300.72 101. 093 2546 9408.5 10681 GR MWD030 API 70.38 421.5 164.837 2585 9357.5 10649.5 First Reading For Entire File......... .9357.5 Last Reading For Entire File........ ...10681 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/01/29 Maximum Physical Record. .65535 File Type..... ........,. .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/29 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10624.0 10624.0 10624.0 10624.0 10624.0 10650.0 10681.5 # 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: # 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): # STOP DEPTH 14023.0 14023.0 14023.0 14023.0 14023.0 14016.0 14069.5 19-JUL-02 Insite 66.37 Memory 14070.0 10681. 0 14070.0 51. 6 93.0 TOOL NUMBER 65041 148574 6.125 10681. 0 ) ) 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: LSND 8.60 46.0 9.0 500 8.0 3.300 1.880 3.950 4.550 85.0 154.0 85.0 80.0 # 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 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 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10624 14069.5 12346.8 6892 10624 14069.5 ROP MWD040 FT/H 0.35 471.98 136.187 6777 10681. 5 14069.5 GR MWD040 API 13.8 531.45 67.3238 6733 10650 14016 RPX MWD040 OHMM 0.67 2000 35.0299 6799 10624 14023 RPS MWD040 OHMM 0.94 2000 45.972 6799 10624 14023 RPM MWD040 OHMM 0.06 2000 76.3188 6799 10624 14023 RPD MWD040 OHMM 0.77 2000 124.402 6799 10624 14023 FET MWD040 HOUR 0.14 57.33 1. 87951 6799 10624 14023 First Reading For Entire File......... .10624 Last Reading For Entire File......... ..14069.5 File Trailer Service name..... ..., ... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF ) Tape Trailer Service name... """'" .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Next Tape Name..... "" ..UNKNOWN Comments................ .STS LIS Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/29 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 Writing Library. Scientific Technical Services