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Home My WebLink About202-069David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 07/31/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number 13-29 183-043 50-029-20928-00-00 13-29L1 50-029-20928-60-00 Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/18/2024 Main Folder Contents: Please include current contact information if different from above. T39345 T3934613-29L1 50-029-20928-60-00 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.31 14:54:48 -08'00' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Od - 0 þ?well History File Identifier Organizing (doll~~) RESCAN 0 Two-Sided 0 Rescan Needed Color items: DI<JTAL DATA lØ' Diskettes, No. OVERSIZED (Scannable) ;; 0 Maps: Other items scannable by large scanner Grayscale items: 0 Other, Norrype 0 0 Poor Quality Originals: Other: OVERSIZED (Non-Scannable) 0 0 Logs of various kinds NOTES: 0, Other BY: BEVERLY ROBIN VINCENT SHERY~ WINDY ...,- -- DA Te!::J t:¡ ~ Ölþ/SI VI1P j. ~ 'J ~ VI1 .J~ ~ ~~~ ~ I~~ mD~/ Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY DATE:~~t/SI Scanning Preparation / x 30 = ~~f) +~ = TOTAL PAGES BY: BEVERLY ROBIN VINCENT SHERY~NDY DATE;S;£; 6Lf Isl Production Scanning, . ~ a...d ~ Stage 1 PAGE COUNT FROM SCANNED FilE: 3If - C;nI~ r - (f - PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ¿ YES NO BY: BEVERLY ROBIN VINCENT SHERYL8WINDY DATER; '1r:¡,ID~1 - VM- P Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (indi\lidu;.¡1 ¡ugo; [f.{Jar.i,l/ i!f10/Hionj ,<,<;,)onillif WlI'p/l~¡0d) RESCANNED Bt: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (don c) 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA OD' ALA OIL AND GAS CONSERVATION COM ION i ~~~ ~ ~ 200 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: s ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 202-069 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20928-60-00' 7. KB Elevation (ft): 83, 9. Well Name and Number: PBU 13-29L1 - 8. Property Designation: 10. Field /Pool(s): ADL028314 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12501 ~ feet true vertical 9014 - feet Plugs (measured) None Effective depth: measured 12501 ~ feet Junk (measured) None true vertical 9014 - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 163' 20" 163' 163' 1490 470 Surface 2624' 13-3/8" 2624' ..-_.2624:.._.....,_... 4930 2670 Intermediate Production 11378' 9-5/8" 11378' 8868' 6870 4760 Liner 298' 7" 11071' - 11369' 8650' - 8862' 8160 7020 Liner 1464' 3-1/2" x 3-3/16" x 2-7/8" 11037' - 12501' 8626' - 9014' Perforation Depth MD (ft): Slotted: 11580' - 12499' - Perforation Depth TVD (ft): 8950' - 9014' - 4-1/2", 12.6# 13Cr80 / L-80 11113' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; 10790'; 9-518" x 4-1/2" Baker S-3 packer 10991' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut, pull and dress off tubing to 10918'. Cut, pull and dress off 9-5/8" casing to 1836'. Run 9-5/8" tieback and cement with 132 Bbls Class'G' 741 cu ft / 633 sx . Run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 296 288 1,743 1,450 372 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ~ ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 308-254 Printed Name eyrie Hubble Title Drilling Technologist e O nn~~ Prepared By Name/Number: / Signature Phone 564-4628 Date w ~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~~~ Y ~ ~~ ~ Submit Original Only ~I~~~AL ~` ~-~~~~ 13-29 & 13-29L1, Well History (Pre Rig Workover) Date Summary 7/20/2008 T/I/O=SSV/450/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Alemite external check installed. Stung into test port (500 psi), bled to 0 psi. Function LDS, all were very tight but functioned (2 1/4"). Left one backed out (flagged), it didn't seem to want to turn all the way in. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Alemite external check installed. Stung into test port (200 psi), bled to 0 psi. Function LDS, all functioned properly (2 1/4"). Pumped through void, clean returns. Re energized secondary Y seal with 1 J stick plastic. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 7/21/2008 T/I/O=S/I/375/50 CMITxIA PASSED to 3500 psi(Pre RWO), Pressured up T/IA w/ 22 bbls Crude for CMIT to 3500 psi. On 1st test T/IA lost 70/60 in the 1st 15 min, and lost 30/30 in the 2nd 15 min. Pass Bled TxIA to starting pressures. FWP= 980/320/100. Tags hung, casing valves open to gauges, DSO Notified. 7/22/2008 WELL S/I ON ARRIVAL. MAKE SEVERAL RUNS WITH BAILERS AND G-RINGS TO CLEAR TUBING FOR DUMP RUNS AND JUNK CATCHER RUN. CLEARING TUBING 4,500' TO 4,900' SLM. IN THE PROCESS OF CLEANING UP TIGHT SPOTS FROM 4,955' TO 5,017' SLM. 7/23/2008 DUMP BAIL 2 BAGS (7.56 GAL) OF SLUGGETS ON WRP ~ 11038' MD. SET 3.750" X 114" JUNK CATCHER ~ 11003' SLM. WELL LEFT S/I, TURNED OVER TO DSO. 7/24/2008 WELL SHUT IN ON ARRIVAL. M-OPEN, IA/OA-OPEN TO GAUGES, SSV-CLOSED INITIAL T/I/O = 900/400/0 PSI. CUT TUBING AT 10934' IN MIDDLE OF FIRST FULL JOINT ABOVE S-3 PACKER WITH 3.65" POWER CUTTER. FINAL T/I/O = 950/350/0 PSI. WELL LEFT IN SAME CONDITION AS PER ARRIVAL, DSO NOTIFIED. JOB COMPLETE. 7/26/2008 T/I/0= ssv/320/50 Temp=S/I Circ. Out (RWO Prep) Pumped 5 bbl meth down TBG, followed by 103 bbls 9.8 Ib NaCI & begin pumping 9.3 Ib NaCI. 7/27/2008 Circ well to 9.3 ppg NaCL brine, CMIT Tx IA FAILED to 3500 psi, MIT OA PASSED to 2000 psi (RWO prep) Pumped 1108 bbls 9.3 ppg NaCL brine down tbg taking returns up IA to open tops. Pumped 9 bbls diesel to freeze protect well to 100'. CMIT Tx IA to 3500 psi. Pumped 9.1 bbls diesel down tbg in attempt to reach test pressure. TP & IAP were tracking to 3200 psi when pressure decreased to 0 psi instantaneously. Pumped an additional 10 bbls diesel down tbg in attempt to gain pressure. Unsuccessful in attempt. Both T & IA continued on a vac. RD from tbg, RU to OA. MIT OA to 2000 psi. Pumped 0.4 bbls crude down OA to reach test pressure. OA lost 40 psi 1st 15 mins, OA lost 40 psi 2nd 15 mins, ran test out an additional 15 mins, OA lost 20 psi 3rd 15 mins for a total loss of 100 psi in 45 mins.(2nd attempt) Bled OAP (-0.7 bbls). Final WHP's =0/0/0 Annulus casing valves open to gauges, tags hung, operator notified. 7/28/2008 WELL SHUT IN PRIOR TO ARRIVAL. RAN DE-CENTRALIZER W/ 3.75" LIB, SET DOWN ~ 5089 UNABLE TO WORK PAST (PARAFFIN ON TOOLS). RAN 3.80 GAUGE RING & WORKED DOWN TO 5104' SLM, BUT UNABLE TO WORK ANY DEEPER (PARAFFIN ON TOOLS). B&F TBG. W/ BRUSH & 3.80" GAUGE RING TO 10800' SLM WHILE LRS PUMPED HOT DIESEL. TAGGED TOP OF JUNK CATCHER ~ 10995' SLM W/ DECENTRALIZER & 3.80" LIB (NO PROBLEMS GOING THRU CUT TBG. ~ 10934'). 7/28/2008 T/I/0= 50/240/50. Assist Slickline with Brush and Flush. (RWO Prep) Pumped 110 bbls of 180° diesel into the TBG. 7/29/2008 Assist Slickline w/ LDL. (RWO Prep) Pump 67 bbls of diesel into the TBG at 2 BPM. Pumped 31 bbls of diesel down TBG at 1.5 BPM for second LDL. Final WHP= 350/340/50. SWS slickline had control of the well upon our departure. Annulus casing valves were open to gauges. Page 1 of 2 • 13-29 & 13-29L1, Well History (Pre Rig Workover) Date Summary 7/29/2008 TWO RUNS W/ PDS LDL FROM 10995' DTR TO 10,700' DTR (depths are from PDS Depthlfime recorder box). PULLED 4-1/2" JUNK CATCHER FROM 10994' SLM. STAND BY FOR GREASE CREW. 7/30/2008 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 250/350/0. RAN LEAK DETECT LOG. ESTABLISHED LEAK IN GLM AT 10964' AND JUST BELOW PACKER IN XO / MOE AT 11004'. RIH WITH BAKER 3.38" IBP. 7/30/2008 T/I/0= 200/340/50 Assist E-Line, LDL (RWO Prep) Pumped 115 bbls of diesel down Tbg as directed. Final WHP= 350/420/50. Annulus casing valves are open to gauges. E-Line has control of well upon departure. 7/30/2008 TAGGED SLUGGITS W/ 3.75" LIB ~ 11,006' SLM. WELL TURNED OVER TO DSO. 7/31/2008 T/I/O=BBV/70/10. Temp=Sl. Bleed WHPs to 0 psi (pre RWO). BBV has been installed in well head. IA FL ~ 450'. Bleed IAP to 0 psi in 6 hrs (fluid & gas mix). OA FL ~ 36'. Bled OAP to 0 psi. Rig on site. Final WHPs BBV/0/0. SV,WV,MV=C. SSV,IA,OA=OTG 7/31/2008 SET 3.38" BAKER IBP AT 10995'. LRS CMIT TO 3500 PSI PASSED, BLEED WHP TO 200 PSI BEFORE RIGGING DOWN E-LINE. LRS TO CONTINUE TO BLEED WHP AFTER E-LINE DEPARTS. SWAB, WING, SSV ALL CLOSED. MASTER AND CASING VALVES OPEN ON E-LINE DEPARTURE. DSO NOTIFIED OF WELL CONDITION, TURNED PERMIT OVER TO LRS SO THEY CAN COMPLETE THEIR OPERATION. FINAL T/I/0 UPON ELINE DEPARTURE = 300/450/0 JOB COMPLETE. 7/31/2008 T/I/0=0/0/0. Set 5" FMC ISA BPV. Pre-Doyon 16. 7/31/2008 T/I/0= 150/420/40 Assist E-Line. (RWO Prep) CMIT TxIA PASSED to 3500 psi. on 2nd attempt. Pumped 100 bbls of 60° diesel to achieve test pressure. (TxIA= 3500/3240) T/IA lost 20/40 psi. in the 1st 15 min. 40/40 psi. in the 2nd 15 min. and 20/20 psi. in the 3rd 15 min. for a total loss of 80/100 psi. in a 45 min. test. U-tubed TxIA again to attempt to equalize pressure. After 1.5 hrs T/IA = 3120/3020.BIed back 47 bbls to Final WHP= 0/0/0 . casing valves open to gauges, IA valve tagged. 8/1/2008 T/I/O/ = vac/0/0 pulled 5 1/8' isa bpv for rig move on used 1 2' ext tag at 108' no problems. Page 2 of 2 BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 7/28/2008 18:00 - 19:00 1.00 MOB P PRE PJSM Move off well C-26 and. spot rig on C-Pad . 19:00 -00:00 5.00 MOB N WAIT PRE Waiting to Move rig to DS-13-29L. Scrubbing the outside of the rig. General light maintenance 7/29/2008 00:00 - 06:00 6.00 MOB N WAIT PRE Move Rig over herculite berm, continue to scrub outside wind walls, and Light Maintenance and cleaning. 06:00 - 08:30 2.50 MOB N WAIT PRE Continue Light Maintenance and cleaning. PJSM with rig crew covering precautions and procedure to UD Derrick. UD Derrick. 08:30 -12:00 3.50 MOB N WAIT PRE Inspect crown sheave for fast line. Place and weld pre-fabbed centrifugal pump discharge line. Performed maintenance on Booster Accumulator. Replace chain to cable swivels on both rig floor winch lines. 12:00 - 00:00. 12.00 MOB N WAIT PRE Continue general rig cleaning and rig servicing projects. Continue installing and painting centrifugal pump discharge line. Inspect derrick crown. Replace grease fittings on tugger sheaves. Service tuggers. Install and weld booster accumulator system in place. 7/30/2008 00:00 - 12:00 12.00 MOB N WAIT PRE Continue to clean rig inside and out. Inspect rig pump #1 and circulating lines. Crew held atable-top Man-Down Drill. 12:00 - 00:00 12.00 MOB N WAIT PRE Continue to clean rig. Install weather stripping on derrick. Evening crew held atable-top Man-Down drill. Driller, Crew, and WSL practiced unpacking, donning, cleaning, and storing rescue/escape SCBA in Doghouse. Continue to performing work orders and inspections of rig. 7/31/2008 00:00 - 12:00 12.00 MOB N WAIT PRE Continue light maintenance and rig work orders. Clean and paint rig components. Receive and install rig boosters wheels. 12:00 - 17:00 5.00 MOB N WAIT PRE Preparing for rig move. Sucked all washdown water and rainwater off the secondary containment, collected it in the Pits, and had it hauled off as Class 2 waste. Perform workorders on Drawworks and Iron Roughneck. Install crown strobe light. Pull rig off Herculite berm. Remove rig mats. Check tire pressures. Check moving system components. 17:00 - 00:00 7.00 MOB P PRE Begin rig move at 1700-hours from C-pad to DS13-29L1. 8/1/2008 00:00 - 02:30 2.50 MOB P PRE Move rig to DS 13-29L1. Arrive at the East side of DS 13 at 0230-hours. 02:30 - 05:00 2.50 MOB P PRE Shuffle rig mats from Deadhorse end of Spine Road to the road around the South end of DS 13. Move rig to area in front of the DS13-29L pad. Remove front and rear boosters. 05:00 - 12:30 7.50 MOB P PRE Wait for DS 13-29L1 pad prep to be performed by same personnel who worked on rig move with assistance from Doyon 16 forklift operator. Load BOP stack onto stump in cellar. Hold PJSM to raise Derrick at 0830-hours. Raise Derrick and R/U Rig Floor starting at 0900-hours. 12:30 - 16:00 3.50 MOB P PRE Move rig over well. Center rig over well and align. Continue to R/U floor. Position auxiliary pump and power modules and H/U to rig. 16:00 - 17:30 1.50 WHSUR P DECOMP P/U DSM Lubricator and M/U to top of tree. Test lubricator to 500-psi. Take on hot seawater to Pits. Accept rig at 1600-hours. RIH with lubricator extension and screw into BPV. 0-psi on IA and OA. Pull BPV and tubing is on a slight vacuum. R/D lubricator and prepare to circulate well-kill fluid. 17:30 - 18:00 0.50 KILL P DECOMP PJSM for well kill. R/U and pressure test line to 3500 psi, good test. .,_.....a. nnnnnn ~~•eo•eQ eye BP EXPLORATION Page 2 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/1/2008 18:00 - 21:00 3.00 KILL P DECOMP Pump 20-Bbl high visc spacer and chased with seawater at 6 bpm with 610 psi. Well took 33-Bbls to get returns. Returns were cut with gas and crude. Slow pump to 3 bpm with 175 psi and held a back pressure with choke while filling tubing with seawater. Pumped 165-Bbls to fill tubing. Shut in well and monitor shut in pressures. Well stabilized with SITP- O psi, SICP- 280 psi. Bring pump on line to SPR maintaining casing pressure at 300 psi to ICP of 275 psi at 4 bpm. Maintain ICP/FCP at 275 psi until gas was expelled from wellbore. Increase pump rate to 6 bpm while maintaining casing pressure to a new FCP of 575 psi. Continue to pump with same parameters until high visc spacer out of hole. 21:00 - 21:30 0.50 KILL P DECOMP Monintor well, well stable with no losses or gains. 21:30 - 22:30 1.00 KILL P DECOMP CBU at 7 bpm with 820 psi, choke position- full open. No losses or gains during circulation. 22:30 - 23:00 0.50 KILL P DECOMP Monitor well, well stable with no losses or gains. 23:00 - 00:00 1.00 DHB P DECOMP Blow down circulating lines. R/U to set BPV. Suck fluids out of tree. M/U BPV to T-bar. Install BPV. 8/2/2008 00:00 - 01:00 1.00 DHB P DECOMP R/U and test BPV from below to 1000 psi for 10 charted minutes, good test. R/D testing equipment. 01:00 - 02:00 1.00 WHSUR P DECOMP R/D circulating lines from tree and IA. Remove circulating equipment from cellar. Blank off control lines and ports. PJSM with rig crew covering N/D tree and removing it from cellar area. 02:00 - 03:00 1.00 WHSUR P DECOMP N/D tree and adapter flange. Remove from cellar. 03:00 - 07:00 4.00 BOPSU P DECOMP Set BOPE stack on wellhead and N/U same. Connect BOP control lines. Prepare for BOP test. 07:00 - 14:00 7.00 BOPSU P DECOMP PJSM for testing BOPE. AOGCC test witness waived by John Crisp. Test BOPE to 250-psi low and 3,500-psi high with 4" and 4-1/2" test joints for the Hydril. Had to chase pressure leaks within system for 2-hours, then all tests proceeded very smoothly for solid tests. 14:00 - 14:30 0.50 BOPSU P DECOMP R/D BOP test equipment. Blowdown lines. P/U Landing Joint with blanking{~lugruNpull tool, RIH andsorew intQblanking plug and POH and UD plug. 14:30 - 15:00 0.50 BOPSU P DECOMP PJSM for Dutch riser installation and for DSM to pull the BPV. P/U Dutch Riser, RIH, and RILDs in the Dutch adaptor. P/U DSM lubricator and M/U to the Dutch riser; PT to 500-psi. 15:00 - 15:30 0.50 BOPSU P DECOMP RIH with BPV ruNpull tool, latch onto BPV, release from hanger. No pressure under BPV. Fluid column steady inside the Dutch riser. No pressure or bleed from the IA during the entire BOP test. No pressure or bleed from the OA during the BOP test. Break off and UD the DSM lubricator. 15:30 - 17:30 2.00 FISH P DECOMP PJSM for Schlumberger Slick-line operations. Bring SWS equipment to rig floor. R/U and test Schlumberger BOPS, pump-in sub, and lubricator. Pressure test lubricator to 500-psi, good test. 17:30 - 19:30 2.00 DHB P DECOMP P/U and RIH with 3-3/8" IBP equalizing tool to 10,970' SLM. Jar down on equalizing sleeve to equalize IBP. Monitor for pressure to equalize. No noticeable pressure. POOH with equalizing tool 19:30 - 20:00 0.50 DHB P DECOMP Re-rig up to SWS lubricator to blocks to better align with well. Fill hole, took 103-Bbls to fill hole. Printed: 9/?J2008 11:48:48 AM BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/2/2008 20:00 - 21:30 1.50 DHB P DECOMP Re-run 3-3/8" IBP equalizing tool with tattle tail pins to 10,970'. Jar down to equalize pressure on 3-3/8" IBP. Fluid losses at 78 bpm. POOH with equalizer tool. Tattle tail show signs of getting deep enough to equalize pressure. 21:30 - 23;30 2.00 DHB P DECOMP P/U and RIH with 3-3/8" IBP equalizer sleeve and retrieving tool to 10,970' SLM. Jar down on IBP several. times and unable to latch to IBP. POOH with retrieving tool. 23:30 - 00:00 0.50 DHB P DECOMP Examine retrieving tool. JDC not sheared. R/U 3-3/8" IBP retrieving tool with centralizer and knuckle joint. 8/3/2008 00:00 - 00:30 0.50 DHB P DECOMP RIH with 3-3/8" IBP JUC pulling tool with 3.625" centralizer and knuckle joint to 3000' SLM. Receive orders from PE to change out from 1-3/8" to 1-3/4" fish neck. 00:30 - 02:00 1.50 DHB P DECOMP Change out fish neck to 1-3/4" with JUS pulling tool with 3.625" centralizer and knuckle joint. Engage IBP at 10,970' SLM. Allow IBP elements to relax when slick line weight increased from 800 Ibs to 1025 lbs. IBP was sucked down to 10,984' and stopped. Attempt to pull .loose. Jarred up 4 times and sheared off of IBP. POOH with pulling tool. 02:00 - 03:30 1.50 DHB P DECOMP Re-dress IBP pulling tool from JUS to JDC pulling tool and RIH to 10,900'. Consult rig town team. Decision made to POOH with SWS. RIH with junk catcher and set on top of IBP. R/D SWS slick line unit. 03:30 - 04:30 1.00 DHB P DECOMP POOH with IBP pulling tool. UD pulling tool. 04:30 - 06:00 1.50 DHB P DECOMP R/U 3.75" Junk Catcher on slickline. RIH on 4-1/2" GS tool and set at 10,980'. 06:00 - 07:30 1.50 PULL P DECOMP SWS POH and R/D slickline equipment. Pull Dutch riser and UD. 07:30 - 08:00 0.50 PULL P DECOMP Clear and clean rig floor. 08:00 - 08:30 0.50 PULL P DECOMP P/U, M/U Baker Double 5-1/2" spear with Stop Sub to Landing joint. M/U to Top Drive. 08:30 - 09:00 0.50 PULL P DECOMP RIH and engage spear into hanger until stacking out on Stop Sub. P/U -5K-Ibs to ensure engagement. BOLDSs. P/U to 175K-Ibs and hanger comes free. Pull to string weight of 160K-Ibs and continue P/U about 2', set slips and CBU. Discuss with ADW Engineer and RWO Supt and agree to CBU, then POH and VD the 4-1/2" tubing string. 09:00 - 10:30 1.50 PULL P DECOMP Circulate Bottoms Up. Took 75 Bbls to fill after being S/I for -20-minutes. Circulate 8-BPM at 970-psi for 800-Bbls with a loss rate of 266-BPH. Did not see any gas in returns. 10:30 - 12:00 1.50 PULL P DECOMP PJSM with Doyon Casing hand, Schlumberger Spooler Tech, crew, Toolpusher and WSL for POH and UD tubing and control lines. Pull Hanger to floor, terminate control lines. Backout double spear from hanger and VD. VD Hanger, 9.2' x 5-1/2" Pup Joint, and change out elevators. 12:00 - 13:30 1.50 PULL P DECOMP POH and UD 4-1/2" tubing. Joint #52 UD at 1340-hours, immediately above the Camco W RDP Bal-O SSSV. Using constant hole fill of -112-BPH with no retums. 13:30 - 14:00 0.50 PULL P DECOMP B/O and UD Bal-O SSSV. Recovered 33 SS-clamp. Schlumberger spooler operator said that he thought the spacing of the SS-clamps showed that there should not have been more than the 33 we recovered, although the original running summary reported 35 SS-clamps were utilized. All of the dual control lines were recovered. o-...,.a. mm~nnn ~~•en•en ewe BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/3/2008 14:00 - 15:00 1.00 PULL P DECOMP Continue POH and L/D 4-1/2" tubing to get to 75-joints POH. Stop to circulate bottoms up. 15:00 - 16:30 1.50 PULL P DECOMP Circulate 9-BPM at 900-psi.. Took 77-Bbls to fill for a fluid level at 1120' from surface while keeping hole-fill at -112-BPH. Circulated 428, lost 270-Bbls, but saw no gas in the returns. S/I for 5-minutes and resumed pumping, took 9-minutes to catch for a calculated static loss rate of 135-BPH. 16:30 - 23:00 6.50 PULL P DECOMP Resume POH and L/D tubing, keeping hole-fill at -112-BPH. Total recovery- 255 full joints of 4-1 /2 TBG, 1 cut joint of 4-1/2" tubing 21.22' with 5" flare cut, 10 GLM assemblies, 1 tubing hanger assembly, 1 SSSV assembly with dual control lines and 33 SS band. Tubing condition showed little outer corrosion and considerable inside corrosion, pin threads were in fair shape, box end threads and collar were good. 23:00 - 23:30 0.50 PULL P DECOMP Clear and clean rig floor. R/D Doyon casing equipment. 23:30 - 00:00 0.50 WHSUR P DECOMP P/U and install wear ring in tubing spool. Continue constant hole fill at 112-BPH.. 8/4/2008 00:00 - 01:30 1.50 CLEAN P DECOMP P/U and RIH with dress off assembly consisting of 8-1/2" x 4-9/16" dress off shoe, (3) 8-1/8" extensions, boot basket with inner dress mill, 9-5/8" casing scraper, bit sub, (6) 6-1/4" drill collars. 01:30 - 11:00 9.50 CLEAN P DECOMP RIH with tubing dress off assembly on 4" HT-38 drill pipe from pipe shed. Stop with joint #337 RIH to prepare to slip and cut drilling line. 11:00 - 12:30 1.50 CLEAN P DECOMP PJSM. Slip and cut drilling line. 12:30 - 13:30 1.00 CLEAN P DECOMP P/U joint #338 and get parameters: P/U wt 195K, S/O wt 145K, free torque at 40-RPM = 4-5K-Ib-ft, 4-1/2-BPM at 330-psi. Stop rotating and continue in, soft tagging at _10,919'. P/U and start rotating at 40-RPM and see stub with outside mill, continue in, swallowing 17'. Mill with 2-5K-Ibs WOB at 40-RPM. Mill to -10,918'. P/U, stop rotating, and POH to 5' above the stub with no excess or jerky drag while OD dress-off cutters pass the stub. Slowly RIH and soft tag on stub, P/U, start rotating and have no trouble getting over stub. Stop rotating and continue in to stack out 6-7K-Ibs on stub at 10,918'. P/U above stub and have same results while POH as well as RIH to 10,918' for good dress-off. 13:30 - 15:30 2.00 CLEAN P DECOMP Pump Hi-Vis sweep 6-BPM at 810-psi. Saw no gas during the circulation of 720 Bbls, with 408-Bbls lost to the formation. 15:30 - 19:30 4.00 CLEAN P DECOMP POH and S/B DP in Derrick. Continue using constant hole fill at 112-BPH. 19:30 - 20:00 0.50 CLEAN P DECOMP POOH with dress off assembly. Stand back 2 stands of 6-1/4" drill collars, L/D BHA. 20:00 - 20:30 0.50 CLEAN P DECOMP Clear and clean rig floor. 20:30 - 00:00 3.50 DHB P DECOMP PU/MU HES 9-5/8" RBP and RIH on 4" HT-38 drill pipe from derrick. 8/5/2008 00:00 - 01:30 1.50 DHB P DECOMP Continue to RIH with HES 9-5/8" RBP on 4" HT-38 drill pipe from derrick to 10,823'. Establish parameters of P/U Wt- 182,000Ibs; S/O Wt- 142,000 Ibs. 01:30 - 02:00 0.50 DHB P DECOMP Set HES RBP at 10,853'. S/O 15,000 Ibs on RBP. P/U 5000 Ibs overpull to confirm set. Release from RBP and P/U to 10,823'. Go through setting procedures to insure release from RBP. R/U to circulate and test casing. o--...a. mm~nnn ~~.en.en ewe BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/5/2008 02:00 - 03:00 1.00 CLEAN P DECOMP Fill hole and circulate wellbore at 12-BPM with 3020 psi. 03:00 - 04:00 1.00 DHB P DECOMP R/U and test casing to 3500 psi for 30 charted minutes, good t est. R/D testing equipment. 04:00 - 08:30 4.50 DHB P DECOMP POOH with HES running tool standing back 4" HT-38 drill pipe in derrick. B/O and UD HES RBP running tool. 08:30 - 10:00 1.50 EVAL P DECOMP P/U Dutch Riser and install in BOP stack, RILDS on Dutch riser. PJSM. R/U Schlumberger equipment and prepare to RIH with USIT Logging tool without full pressure control. R/U line wiper. 10:00 - 11:00 1.00 EVAL P DECOMP RIH with Schlumberger USIT logging tool to -2,820' (bottom of tool). 11:00 - 12:00 1.00 EVAL P DECOMP POH and log up in Cement Bond/Corrosion mode at 4500-FPH, stop at -2500' and return to -2820' to ensure tool was working properly. POH at 4500-FPH to surface. Cement was looking ratty from 2400' on up with a "good" TOC around 2175'. Log sent Real-Time to Chevie (?) Meyers in Anchorage. 12:00 - 13:00 1.00 EVAL P DECOMP R/D Schlumberger E-liners tools and equipment. 13:00 - 13:30 0.50 DHB P DECOMP P/U RBP #2 and RIH to 2303' on 4" HT-38 drill pipe from derrick. 13:30 - 14:00 0.50 CLEAN P DECOMP Continue to wait on conformation of logs. 14:00 - 14:30 0.50 DHB P DECOMP POOH with RBP fk2 from 2303' to 1940'. Set RBP at 1942' COE and 1937' Top of fishneck. 14:30 - 15:30 1.00 DHB P DECOMP R/U testing equipment and test RPB to 1500 psi for 15 charted minutes, good test. R/D testing equipment. 15:30 - 18:00 2.50 DHB P DECOMP POOH to 1828'. R/U sand hopper on top of drill string stump and dump 2200 Ibs of 20/40 mesh sand on top of RBP #2. Pump sand clear of drill pipe at 2 bpm with 50 psi. Allow sand to fall for 45 minutes. RIH and tag top of sand at 1895'. P/U to 1850'. 18:00 - 19:30 1.50 CASE P DECOMP PJSM with rig crew and CH2MHill vac truck drivers. Discuss up coming displacement and procedures. Displace well to 120 deg F 9.8 ppg NaCI Brine. RBIH and tag top of sand at 1891'. 19:30 - 20:00 0.50 CASE P DECOMP POOH with HES RBP running tool standing back 4" HT-38 drill pipe in derrick. UD RBP running tool. 20:00 - 20:30 0.50 CASE P DECOMP P/U Baker multi string casing cutter. Secure cutting blades with wire and duct tape. 20:30 - 21:30 1.00 CASE P DECOMP RIH with casing cutter on 4'' HT-38 drill pipe from derrick to 1830'. 21:30 - 22:00 0.50 CASE P DECOMP Establish cutting parameters of P/U Wt- 65,000 Ibs; S/O Wt- 65,p001bs; Rot Wt- 65,000 lbs; Pump Pressure- 300 psi at 3 bpm. Open cutter blades. RIH and locate lower casing collar at 1852'. P/U and locate upper casing collar at 1810'. RIH and spot cutting blades at 1830'. 22:00 - 22:30 0.50 CASE P DECOMP PJSM with rig team, vac truck drivers, LRHOS, and Baker Fisherman. Discuss up coming operations of cutting casing and displacing Arctic Pack. 22:30 - 23:00 0.50 CASE P DECOMP Cut 9-5/8" casing at 70 rpm with 2500 to 3000 ft-Ibs torque, pump rate at 4.4 bpm with 550 psi and stage up pump rate to 5.6 bpm with 1020 psi. Torque increased to 4500 ft-tbs, pump pressure decreased from 1020 psi to 850 psi, and pump rate increased from 5.6 to 5.9 bpm, torque decreased to 2000 ft-Ibs. Casing cut through in 11 minutes. 23:00 - 00:00 1.00 CASE P DECOMP Close annular preventer and open OA to flow back tank. o-...a...l• OMMl1llA 11~A A•AA AI.A BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date:. 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/5/2008 23:00 - 00:00 1.00 CASE P DECOMP Establish circulation through cut to OA at 2.5 bpm with 1500 psi. Shut in OA and open annular preventer. Pump 18 bbls of 120 deg F diesel down drill pipe with LRHOS at 2 bpm with 300 psi. Open OA and close annular preventer. Continue pumping 42 bbls of 120 deg F diesel with LRHOS at 2 bpm with 425 psi. Pump 40 bbls Safe Surf O pill and spot on OA with 20 bbls high visc sweep at 2 bpm and 450 psi. Returns were full of Arctic Pack. Some gas was mixed with the Arctic. Pack during the first part of the circulation but broke out after pumping 45 bbls. The Arctic Pack did not ever get thick. It looked like new Arctic Pack. Shut down pump and shut in OA. Allow OA to soak. 8/6/2008 00:00 - 02:00 2.00 CASE P DECOMP Allow diesel and Safe Surf O pill soak on OA. 02:00 - 02:30 0.50 CASE P DECOMP PJSM. Open OA and pump 130 bbls of 120 deg F 9.8 ppg brine at 7 bpm with 1450 psi. Spot 9.8 ppg brine on OA with 20 bbl high visc sweep. Shut in OA 02:30 - 03:00. 0.50 CASE P DECOMP Allow hot brine to soak in OA, 03:00 - 04:30 1.50 CASE P DECOMP Open OA and pump 130 bbls of 120 deg F 9.8 ppg brine at 7 bpm with 1330 psi. Shut in OA and open annular preventer. CBU at 6 bpm with 670 psi. Monitor well, small amount of gas breaking out of wellbore. Continue circulating one more bottoms up. 04:30 - 05:00 0.50 CASE P DECOMP Monitor OA, IA, and drill pipe. Well stable and dead. 05:00 - 06:30 1.50 CASE P DECOMP POOH with casing cutter standing back 4" HT-38 drill pipe in derrick. 06:30 - 07:30 1.00 CASE P DECOMP Clear and clean rig floor. Pull wear ring. P/U Bowen ITCO spear on 1 joint of drill pipe. 07:30 - 08:30 1.00 CASE P DECOMP PJSM. Monitor well. 08:30 - 10:00 1.50 CASE P DECOMP RIH with ITCO spear and engage 9-5/8" casing. Pull 125,000 Ibs without any movement of casing. Continue to pull up to 325,000 Ibs, no movement. 10:00 - 11:30 1.50 CASE P DECOMP Release spear from casing and POOH. VD ITCO spear assembly. P/U 9-5/8" packoff pulling tool on 1 joint of drill pipe and RIH. Engage packoff. Pull 90,000 Ibs on packoff. Pulling tool "J" slot pins sheared off. POOH and UD pulling tool. 11:30 - 12:00 0.50 CASE N WAIT DECOMP Send for replacement packoff pulling tool. 12:00 - 13:00 1.00 CASE P DECOMP P/U replacement 9-5/8" packoff pulling tool on 1 joint of drill pipe and RIH. Engage packoff. Pull 110,000 Ibs on packoff without coming free. Apply steam to wellhead. Continue to make several attempts to pull packoff free without success. POOH and UD pulling tool. 13:00 - 14:30 1.50 CASE P DECOMP M/U Bowen ITCO spear assembly consisting of ITCO spear with packoff, stop ring, jars, 1 joint of 6-1/4" drill collar, accelerator jars, crossovers and drill pipe pup joint. Total length of BHA- 82.92'. RIH and engage casing. 14:30 - 15:00 0.50 CASE P DECOMP Attempt to jar casing free. Jar on casing with 225,000 Ibs and 325,000 Ibs straight pull. Attempt several cycles without success. 15:00 - 15:30 0.50 CASE P DECOMP Shut down jar operations and inspect top drive and derrick. 15:30 - 16:30 1.00 CASE P DECOMP Continue attempting to jar casing free. Jar on casing with 225,000 Ibs and 325,000 Ibs straight pull. Attempt several cycles without success. Pump on casing with 700 psi at 1.5 bpm while pulling on casing. • BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/6/2008 16:30 - 17:00 0.50 CASE P DECOMP Slack off on casing hanger. RILDS and measure LDS. BOLDS. P/U on casing to 325,000 Ibs straight pull. RILDS and take measurements. BOLDS. Continue to jar on casing with 225,000 Ibs and 325,000 Ibs straight pull. No movement of casing. 17:00 - 17:30 0.50 CASE P DECOMP Shut down jar operations and inspect top drive and derrick. 17:30 - 18:00 0.50 CASE P DECOMP Service rig. 18:00 - 18:30 0.50 CASE P DECOMP Wait on orders. 18:30 - 19:00 0.50 CASE P DECOMP Disengage from 9-5/8" casing and POOH. UD jars and 9-5/8" spear assembly. 19:00 - 19:30 0.50 CASE P DECOMP P/U Baker Multi String Casing Cutter Assembly consisting of cutter and stabilizer. Change out cutting knives on casing cutter. Total length of BHA- 11.85'. Set wear ring. 19:30 - 20:00 0.50 CASE P DECOMP RIH with casing cutter on 4" HT-38 drill pipe from derrick to 440'. Establish cutting parameters of P/U Wt- 47,000 Ibs; S/O Wt- 45,000 Ibs. 20:00 - 21:00 1.00 CASE P DECOMP Open cutting knives with 500 psi at 4.7 bpm. RIH and locate casing collar at 446'. P/U 5' to 441'. Start cutting casing with 50 rpm and 2000 ft-Ibs free torque; Rot Wt- 47,000 Ibs. Bring pump pressure up to 650 psi at 4.5 bpm, torque increased to 2500 ft-Ibs. Continue bringing pump pressure up to 1100 psi with 6.3 bpm, torque up to 3500 ft-Ibs. Continue cutting until torque increased to 4000 to 8000 ft-Ibs then dropped to 2000 to 7500 ft-Ibs. P/U and S/O 2x to confirm cut with out definite confirmation. Spot cutting knives at 441' and continue to cut casing with same parameters. Torque smoothed out at 4500 ft-Ibs then dropped to 2500 ft-Ibs and pump pressure decreased to from 1020 psi to 900 psi at 6 bpm. Shut down cutting operation. P/U and S/O 2x and confirm cut at 441'. S/O 10,000 Ibs on cut. Final Cut Depth- 441'. 21:00 - 21:30 0.50 CASE P DECOMP Shut in annular preventer and open OA. CBU of OA at 5.5 bpm with 980 psi. Small chucks of cement were noticed in returns along with a small amount of Arctic Pack. Close OA and open annular preventer. CBU IA at 6 bpm with 920 psi. Monitor well, well stable. 21:30 - 22:00 0.50 CASE P DECOMP POOH with casing cutter to 292'. Establish cutting parameters of P/U Wt- 46,000 Ibs; S/O Wt- 45,000 Ibs. Open cutting knives with 480 psi at 4.5 bpm. RIH and locate casing collar at 370'. P/U 5' to 365'. Start cutting. casing 50 rpm and 2000 ft-Ibs free torque; Rot Wt- 46,000 Ibs. Bring pump pressure up to 960 psi at 6 bpm, torque increased to 3000 ft-Ibs. Continue bringing pump pressure up to 1090 psi with 6.2 bpm, torque up to 4000 ft-Ibs. Continue cutting until torque increased to 4000 to 8000 ft-Ibs then dropped to 2000 ft-Ibs. P/U and S/O and confirm cut at 365'. S/O 10,000 Ibs on cut. Final Cut Depth- 365'. 22:00 - 22:30 0.50 CASE P DECOMP Shut in annular preventer and open OA. CBU of OA at 5.7 bpm with 890 psi. A small amount of Arctic Pack. Close OA and open annular preventer. CBU IA at 6 bpm with 900 psi. Monitor well, well stable. 22:30 - 23:00 0.50 CASE P DECOMP POOH with casing cutter standing back 4" HT-38 drill pipe in derrick. 23:00 - 23:30 0.50 CASE P DECOMP UD Baker Multi String Cutter. Clear and clean rig floor. Pull wear ring. Printed: 9/2!2006 11:48:48 AM BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/6/2008 23:30 - 00:00 0.50 CASE P DECOMP P/U M/U Baker Bowen ITCO spear on 1 joint of drill pipe. 8/7/2008 00:00 - 00:30 0.50 CASE P DECOMP RIH and engage CSG. P/U on casing hanger, hanger broke free at 75,000 lbs. P/U casing hanger 5' and monitor well with 54,000 Ibs P/U Wt. 00:30 - 01:30 1.00 CASE P DECOMP CBU on IA at 6.3 bpm with 50 psi. Monitor well. Small amount of gas breaking out of wellbore. Continue. circulating one more bottoms up. Monitor well. Small amount of gas breaking through wellbore, but less than the time before. Continue circulating one more bottoms up. Monitor well, well dead. 01:30 - 02:00 0.50 CASE P DECOMP POOH with casing hanger. B/O and UD spear. B/O and UD casing hanger. 02:00 - 03:00 1.00 CASE P DECOMP POOH and UD 9-5/8° casing. Recovered 8 full joints and (1) 34.49' cut off joint of 9-5/8" casing, and 2 bow spring centralizers with 17 half blades missing. Average break out torque for casing- 35,000 ft-Ibs. Casing was in good condition with no noticeable corrosion. 03:00 - 03:30 0.50 CASE P DECOMP Clear and clean rig floor. 03:30 - 04:00 0.50 CASE P DECOMP P/U Bowen ITCO spear assembly consisting of 9-5/8 spear with packoff, extension, stop sub, jars, 2 stands of 6-1/4" drill collars from derrick, and accelerator jars. Total length of BHA- 226.96'. 04:00 - 04:30 0.50 CASE P DECOMP RIH with ITCO spear assembly on 4" HT-38 drill pipe from derrick to 360'. Establish fishing parameters of P/U Wt-.52,000 Ibs; S/O Wt- 57,000 Ibs. Engage casing stump at 365' and attempt to set spear several times with no dramatic overpull. S/O Wt up to 61,000 Ibs. P/U 20' and S/O, did not see packoff or spear re-enter casing stub. Monitor well. 04:30 - 05:00 0.50 CASE P DECOMP POOH with spear assemlby standing back 4" HT-38 drill pipe in derrick. POOH with BHA standing back 2 stands of drill collars in derrick. 05:00 - 06:00 1.00 CASE P DECOMP UD spear and 9-5/8" casing. 06:00 - 07:00 1.00 CASE P DECOMP M/U 9-5/8" Spear Assembly BHA #7, with stop sub, Oil Jars, DC's and Accel Jars. Total Length = 226..96 ft. RIH to 441 ft 07:00 - 10:00 3.00 CASE P DECOMP P/U Wt= 60,000 Ibs, S/O Wt = 60,000 Ibs Engage Spear to Stop Sub at 452'. Work Pipe with jar licks up to 120,000 Ibs over and straight pull up to 275,000 Ibs over. Used pump pressure to assist up to 1200 psi while working pipe. Lost circulation at 2000 psi pump pressure at 3,5 bpm, started seeing losses at this point. 10:00 - 11:30 1.50 CASE P DECOMP Circulate bottoms up through cut at 1830 ft. Some gas and Arctic Pack Breaking Out While Circulating. Circ Rate of 2.0-2.5 bpm at 1100 to 850 psi. With pump pressure over 1000 psi loss rate at 75 bbls per hour, at 850 or less loss rate at 30 bbls per hour. 11:30 - 12:00 0.50 CASE P DECOMP Pull Spear Free from Casing and Circulate Hole at 6 bpm. Clean Up Arctic Pack in Wellbore. Losses minimal. 12:00 - 13:00 1.00 CASE P DECOMP Monitor Hole, Static Losses at lbbl / 10mins. Fluid Level Falling Slowly. PQOH and Stand Back 3 Stands of DP and 2 Stand of DC's. UD Bumper, Jars, and Accelerator. 13:00 - 14:00 1.00 CASE P DECOMP M/U Multi String Cutter for 9-5/8" casing with Bullnose to DP. RIH with cutter to 1100 ft. P/U Wt = 67,000 Ibs. S/O Wt = 67,000 Ibs. Locate Collar at 1096 ft. 14:00 - 14:30 0.50 CASE P DECOMP PUH to 1090 ft and Make Cut on Casing. Pump Rates Initially Printed: 9/2/2008 11:48:48 AM BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours TasK Code NPT Phase Description of Operations 8/7/2008 14:00 - 14:30 0.50 CASE P DECOMP at 3.4 bpm and 300 psi / 6.3 bpm and 970 psi. Free Torque at 2,000 ft Ibs with 70 rpms. Casing Cut in 4 mins with 6.5 bpm, torque climbed from 3,000 ft-Ibs and Spiked at 10,000 ft Ibs then dropped off, pump pressure climbed to 1190 psi then dropped off as well. Continue to Rotate with cutter blades open for another 8 mins. Pump Pressure at 6.8 bpm of 930 psi and torque at 2,500 - 3,000 ft Ibs. 14:30 - 15:00 0.50 CASE P DECOMP Circulate Bottoms up at 8 bpm and 1290 psi initally, increase to 1470 psi and leveled off. Monitor well for 10 mins. Fluid level falling. 15:00 - 15:30 0.50 CASE P DECOMP P/U spear BHA, C/O grapples. Check service breaks. 15:30 - 17:00 1.50 CASE P DECOMP RIH with spear on 4" HT-38 drill pipe from derrick to 441'. Monitor well and establish parameters of P/U Wt- 55,000 Ibs; S/O Wt- 60,000 Ibs. 17:00 - 19:00 2.00 CASE P DECOMP Monitor well and allow gas to break out of wellbore. POOH with 9-5/8" casing. Casing having to be worked and pumped out of hole by hitting with jars and straight pull up to 325,000 Ibs, pumping out of hole at 1.5 bpm with up to 950 psi. Attempt to POOH without pump no success. Continue pumping and working out of hole to 248' 19:00 - 20:30 1.50 CASE P DECOMP Stop pulling casing out of hole to perform derrick and top drive inspection. Monitor well. 20:30 - 21:00 0.50 CASE P DECOMP Release spear from 9-5/8" casing. POOH with spear assembly. Stand back 2 stands of 6-1/4" drill collars. UD acceleratorjars. 21:00 - 21:30 0.50 CASE P DECOMP RIH with ITCO spear on 4" HT-38 drill pipe from derrick to 248'. Establish parameters of P/U Wt- 45,000 Ibs; S/O Wt- 46,000 lbs. 21:30 - 00:00 2.50 CASE P DECOMP Engage casing and set grapple. Continue pulling and pumping out of hole at 1 bpm with 900 psi. Attempt to pull without pumping, jarring at 225,000 Ibs and 325,000 Ibs straight pull with no success. Pumping and working the pipe out of the hole without jarring would keep the pipe moving. 8/8/2008 00:00 - 01:00 1.00 CASE P DECOMP Continue pulling and pumping out of hole at 1 bpm with 900 psi. Pumping and working the pipe out of the hole without jarring would keep the pipe moving. Casing stub at surface. 01:00 - 02:00 1.00 CASE P DECOMP B/O and UD spear and jars. B/O 5' cut joint of 9-5/8" casing. R/U long bails with 150 ton elevators. M/U circulating head to x/o to 9-5/8" casing. 02:00 - 05:00 3.00 CASE P DECOMP Continue pulling and pumping out of hole at 1-1.5 bpm keeping pump pressure below 500 psi. Pumping with circulating head and cement line. Casing continued to pull ratty with straight pull from 150,000 to 300,000 Ibs. UD 6 joints of casing. Seventh joint to casing would not pull through the well head. 05:00 - 07:30 2.50 CASE P DECOMP Casing Stuck Attempt to Work Pipe Up to 300,000 Ibs up and attempt to work down - no luck. Try pumping down OA, just pressuring up unable to circ. Try to circ down the kill line, pressured up as well. Able to pump down casing but not seeing returns ,pump at up to 1200 psi pump pressure, just forcing away fluid. 07:30 - 10:30 3.00 CASE P DECOMP Discuss Option with town and make out plan forward. Wait on tools to be made up at BOT machine Shop. Change Out Bails and Elevators for up coming work. 10:30 - 11:30 1.00 CASE P DECOMP PJSM with rig crew on washing over casing and cutter BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours. ~ Task ~ Code NPT ~ Phase ~ Description of Operations 8/8/2008 10:30 - 11:30 1.00 CASE P DECOMP operations. P/U 11-3/4" wash pipe joint and 12" rotary drag shoe. 11:30 - 12:30 1.00 CASE P DECOMP Wash Over Casing. Circ at 6 bpm and 40 psi. Rotate at 30 rpms and 2,000 ft-Ibs free torque. Tag cement 8 ft below rig floor. Pump and Rotate over casing easily w/ little to no weight on bit or additional torque down to 20 ft . Required up to 3,000 WOB and up to 5,000 ft-Ibs torque to get through tbg spool and casing spool. Wash down to 30 feet below rig floor. Soft Cement, Arctic Pack and Hard cement in returns at shaker. Circ High Visc Sweep after washing down to 30 ft to clean hole. 12:30 - 13:30 1.00 CASE P DECOMP UD Wash Pipe and DP Pup Joint. Rig up Circ head, still unable to Circ around but can pull upon casing and able to pump up hole. 13:30 - 14:30 1.00 CASE P DECOMP P/U 1 joint of DP, 15 ft pup joint and Multi String Cutter. Place Ball in center jet of cutter to pressure up on. 14:30 - 15:00 0.50 CASE P DECOMP RIH with Cutter to 29 ft. Make Cut on Casing. Possitive Indication on Cut -Top Section of Casing Spinning. Required 10 mins to make cut and up to 1170 psi on pump pressure. 15:00 - 15:30 0.50 CASE P DECOMP UD Multi String Casing Cutter and UD Cut Joint of 9-5/8" Casing. Cut Joint = 35.05ft. (Jt # 18 = 38.35 ft) 15:30 - 16:30 1.00 CASE P DECOMP P/U Clean Out Tool for BOP Stack and Flush Out Stack. Drain Stack and Inspect for Debris. Function Rams and Hydril. 16:30 - 18:00 1.50 CASE P DECOMP PJSM on P/U Spear BHA. M/U Spear BHA for Jarring Down on Casing. Mule shoe, XO, 6 DC's, XO, Pack Off Assembly, 9-5/8" Spear and Grapple, Extention, Stop Sub, 6-1/4" Bumper Sub, Oil Jar, XO, DC, XO. Total Length = 258.55 ft. 18:00 - 19:00 1.00 CASE P DECOMP Establish parameters of P/U Wt- 60,000 Ibs; S/O Wt- 60,000 Ibs; RIH without engaging spear into casing. Bump down and move 9-5/8" casing free. Engage spear and P/U with 9-5/8 casing until 300,000 Ibs P/U was reached. Disengage spear from casing and bump down until casing could move without bumping. Engage spear and continue working down. P/U one joint of drill pipe and continue working fish down. 19:00 - 23:30 4.50 CASE P DECOMP Break circulation at 1 bpm with 200 psi. Continue circulating and washing packed off cement free. Pump pressure improved to 2 bpm with 600 psi. Continue to work pipe down with 2 joints of drill pipe and pumping. Pump pressure continue to improve. Able to pump at 9 bpm with 150 psi with a lot of cement coming across shakers. Work pipe 105' with no pumps or jarring and very little drag. Pump high visc sweep. Sweep brought back much more cement in large half dollar size chucks. 23:30 - 00:00 0.50 CASE P DECOMP POOH and stand back 1 stand consisting of 2 joints of 4" HT-38 drill pipe and (1) 6-1/4" drill collar. POOH with 0-10,000 Ibs drag. Casing stub to rig floor. 8/9/2008 00:00 - 00:30 0.50 CASE P DECOMP PU/RU false table stripping stand. 00:30 - 01:00 0.50 CASE P DECOMP Release spear and POOH standing back 2 stands of 6-1/4" drill collars in derrick. 01:00 - 01:30 0.50 CASE P DECOMP R/D stripping stand. Pull 3.32' cut joint. Release spear. B/O and UD spear. 01:30 - 03:00 1.50 CASE P DECOMP POOH and UD 9-5/8" casing. Recovered 9 full joints and 2 cut off joints (3.32' and 32.13' ), and 3 bow spring centralizers. Average breakout torque G~ 35,000 ft-Ibs. Casing in good ori.,~sa• onnnna 11•dR~dA OM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/9/2008 01:30 - 03:00 1.50 CASE P DECOMP condition without corrosion. Tally to date- 27 full joints and 1 partial joint (32.13') of casing POOH. Casing stump at 1090'. 03:00 - 03:30 0.50 CASE P DECOMP Clear and clean rig floor. R/U and RIH with one stand of 2 joints of drill pipe and 1 drill collar from derrick. POOH and UD 2 joints of drill pipe. and 1 drill collar. 03:30 - 07:00 3.50 CASE P DECOMP P/U BOPE cleaning tool and wash out BOPE. Inspect BOP cavities. Perform full derrick and top drive inspection. Clean out OA and IA valves. Prepare for BOP test. 07:00 - 07:30 0.50 BOPSU P DECOMP R/U to Test BOP's. 07:30 - 08:30 1.00 BOPSU N DECOMP Set Test Plug in BOP Stack, try to pressure up, unable to maintain high pressure, leaking by. Call Out Cameron Wellhead Tech. Pull Test Plug and Inspect. Style of Test Plug requires 4 LDS to be run in after intial pressure up to fully seat and extrude rubber walling elements. 08:30 - 13:30 5.00 BOPSU P DECOMP Test BOP's to 250 psi low and 3500 psi high. Test VBR's with 4" and 4-1/2" Test Joints. All Tests Charted and held for 5 mins. All Components Passed . Witness to Test waived by Chuck Scheve with AOGCC. 13:30 - 14:30 1.00 BOPSU P DECOMP R/D Down Test Equipment and Pull Test Plug. Gather BHA Equipment. 14:30 - 15:30 1.00 CASE P DECOMP M/U BHA #15, 8-1/2" Bit, Drill Collars, 13-3/8" Scraper, Bumper, Jars, DC's. Total Length = 224.56 ft. 15:30 - 16:00 0.50 CASE P DECOMP RIH with BHA #15 to top of Casing Stub with 4" DP. P/U Wt = 70,000 Ibs S/O Wt = 70,000 lbs. 16:00 - 17:00 1.00 CASE P DECOMP Tag up on debris at 1080 ft (10 ft above Casing Stub). Wash and Ream through debris, clean out top of casing and continue down to 1175 ft. The top 10 feet above the casing stub and 20 feet inside the 9-5/8" casing contained debris. Required up to 5,000 Ibs WOB with 60 rpm's and 5,000 ft-Ibs of torque to work through. Pump rate at 8 bpm and 340 psi. 17:00 - 18:00 1.00 CASE P DECOMP Pump 20 bbl high visc sweep and chase out of the hole at 12 bpm and 470 psi. Large volume of cement in retums, size ranged from sand size pieces to quarter size chuncks. Circulated an additional full well volume to get returns cleaned up. 18:00 - 19:00 1.00 CASE P DECOMP Blow down top drive and POOH standing back 4" HT-38 drill pipe in derrick. Pulled 30,000 Ibs overpull off bottom and came free immediately. 19:00 - 19:30 0.50 CASE P DECOMP POOH with clean out assembly. Stand back 2 stands of 6-1/4" drill collars. UD BHA. Clear and clean rig floor. 19:30 - 20:00 0.50 CASE P DECOMP P/U 9-5/8" casing spear assembly consisting of bull nose, ITCO spear assembly with packoff, extension, stop sub, bumper sub, jars, 2 stands of 6-1/4" drill collars from derrick, and accelerator jars. Total length of BHA- 235.99' 20:00 - 20:30 0.50 CASE P DECOMP RIH with 4" HT-38 drill pipe from derrick to 1090'. 20:30 - 00:00 3.50 CASE P DECOMP Establish fishing parameters of P/U Wt- 67,000 Ibs; S/O Wt- 70,000Ibs. Run spear into casing stub until no go out on stop ring. S/O 10,000 Ibs on no go. P/U to 110,000 overpull with no movement. Continue pulling with 180,000 Ibs overpull, still no movement. Jar on fish with 100,000 Ibs overpull and staight pull 220,000 Ibs overpull with no movement. Jar on fish with 125,000 Ibs overpull and 220,000 Ibs straight overpull with no movement. Bring pump online and break circulation at 1 bpm Printed: 9/2P2008 11:48:48 AM BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/9/2008 20:30 - 00:00 3.50 CASE P DECOMP with 600 psi. Well conditions trying to pack off. Fish pulled free with 1150 psi pump pressure and 183,000 Ibs overpull. Work pipe up hole, circulation continue to try to pack off. Circulation increased from 2-8 bpm with 100 to 1200 psi. Continue to pump and pull fish up hole. Pump pressure smoothed out at 8 bpm with 1200 psi. Pump high visc sweep Returns full of cement and arctic pack. Casing continued to pull ratty. 8/10/2008 00:00 - 01:00 1.00 CASE P DECOMP Pump out of the hole slowly. Casing continue to pull ratty from 100,000 Ibs to 200,000 Ibs P/U Wt. Each stand up was worked up and down until it could move smoothly and with good circulation for the first 5 stands. Fish pulled free without pumping or jarring after 5 stands out. Stand back 4" HT-38 drill pipe in derrick. 01:00 - 01:30 0.50 CASE P DECOMP POOH with spear assembly. Stand back 2 stands of 6-1/4" drill collars. UD BHA. Pulled casing to rig floor. 01:30 - 02:00 0.50 CASE P DECOMP R/U rig floor to UD 9-5/8" casing. B/O UD 5.26' cut joint. R/U to circulate casing. 02:00 - 02:30 0.50 CASE P DECOMP Pump high visc sweep at 11 bpm with 970 psi. Sweep brought back more cement in fines and chucks to the shakers. Shut down pumps and monitor well. 02:30 - 04:30 2.00 CASE P DECOMP Blow down top drive and circulating lines. POOH and UD 9-5/8" Casing. Recovered 18 full and 2 cut joints (5.26' and 20.92') of 9-5/8" casing, 4 bow spring centralizers with 5 partial blades missing. Bottom cut was flared out to 10.625". Casing was in good condition with no noticeable corrosion. Average break out torque ~ 40,000 ft-Ibs. 04:30 - 05:00 0.50 CASE P DECOMP R/D Casing Equipment and Handling Tools. Clean and Clear Rig Floor 05:00 - 06:00 1.00 CASE P DECOMP M/U Stack Washer and Wash out BOP of Cement and Debris. P/U Spear and Cutter and make service breaks. 06:00 - 07:00 1.00 CASE P DECOMP M/U Dress Off BHA for 9-5/8" casing consisting of 12" x 9-5/8" Dress Off Shoe, wash pipe extension, inside dress off mill, Wash Over Boot Basket, 13-3/8 Casing Scraper, Bit Sub, Bumper, Oil Jar, DC's. 230.79 ft total length. 07:00 - 08:00 1.00 CASE P DECOMP RIH with Dress Off BHA to top of 9-5/8" casing stub. Tag Up at 1817' 08:00 - 09:30 1.50 CASE P DECOMP Establish Parameters P/U Wt = 80,000 Ibs S/O Wt = 80,000 Ibs Rot Wt = 80,000 Ibs with 2,500 tt-Ibs free toque at 40 rpms. Pump rate 10 bpm at 540 psi. Clean Out Debris from 1817' to 1841'. Required 3-5,000 Ibs WOB to Clean Out fill and dress off 9-5/8" casing stub. A large amount of cement seen at the shakers. 09:30 - 10:30 1.00 CASE P DECOMP Circulate 20 bbl safe surf followed by 20 bbl high visc sweep. Chase with 110 degree brine. Large volume of ground up cement with sweep. Cleaned up well after sweep. 10:30 - 11:00 0.50 CASE P DECOMP POOH and Stand Back DP. 11:00 - 12:00 1.00 CASE P DECOMP B/O and UD Dress Off BHA. 12:00 - 12:30 0.50 CASE P DECOMP Clean and Clear Rig Floor. 12:30 - 14:00 1.50 CASE P TIEB1 R/U to Run 9-5/8" Casing. Bring Equipment Up to Rig Floor and Organize Pipe in shed. 14:00 - 14:30 0.50 CEMT P TIE61 PJSM on running 9-5/8" casing and using equipment. 14:30 - 19:00 4.50 CASE P TIEB1 Run 9-5/8" 47# L-80 Hyd 563 Casing with Bowen Casing Patch, Baker External Casing Packer, HES ES Cementer. Printed: 9/2/2008 71:48:48 AM BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/10/2008 14:30 - 19:00 4.50 CASE P TIEB1 Baker Lock ES Cementer and all Contection Below. M/U and Torque Turn Hyd 563 Connections as per manufacture recommendations to 15,800 ft-Ibs. Run casing to 1826'. 19:00 - 19:30 0.50 CASE P TIE61 Establish parameters of P/U Wt- 117,000 Ibs; S/O Wt- 120,000 lbs. Tag top of casing stub at 1833'. Slowly ease down with 9-5/8" casing patch with right hand rotation over 9-5/8" casing stub. No Go out on casing stub. Final depth of casing patch ~ 1835'. S/O 50,000 Ibs on casing stub. P/U 30,000 Ibs overpull to 150,000 Ibs. Continue to P/U to 250,000 Ibs. S/O and M/U HES cement head to top of casing string. P/U to 125,000 Ibs overpull to 245,000 Ibs. 19:30 - 20:30 1.00 CASE P TIEB1 PJSM with rig crew, HES, Baker completions and fisherman, Doyon toolpusher and BPX WSL. Discuss upcoming PKR setting and testing operations and safety. Attempt to pressure test casing, change out HES cement head seal. Pressure test casing to 1000 psi for 10 charted minutes, good test. 20:30 - 22:30 2.00 CASE P TIE61 Stage up casing pressure in 200 psi increments to 1600 psi to shear open ECP inflate. HES cement head leaking. C/O x/o from casing to HES cement head. Stage up casing pressure from 1000 to 1600 psi in 200 psi increments. ECP inflate opened at 1800 psi. Allow ECP packer element to inflate. Element took .4 bbls to inflate. 22:30 - 00:00 1.50 CASE P TIE61 Pressure test casing to 2000 psi for 10 charted minutes, good test. 8/11/2008 00:00 - 01:00 1.00 CASE P TIE61 Bleed pressure off casing and pressure up to 2000 Ibs on 13-3/8" x 9-5/8" annulus. Could not get a test. Pressure bled off 800 psi in 18 minutes. Consult town engineer. Decision to pump cement with 2 ppb Cem Net and squeeze with 500 psi after cement is to surface. Pressure on OA bled down 700 psi in 70 minutes. Pressure leveled off at 700 psi. 01:00 - 01:30 0.50 CASE P TIE61 Open ES Cementer with 2700 psi. Circulate hot 9.8 NaCI brine at 7 bpm with 470 psi until return came back at 80 deg F. 01:30 - 03:30 2.00 CEMT P TIE61 PJSM with rig crew, Schlumberger cementers, HES, Doyon Toolpusher, and BPX WSL. Discuss upcoming cement job and job assignments and procedures. Discuss safety precautions of working around high pressure. Discussed spill prevention and to double check all rig ups. Pressure test cementing lines to 4500 psi. Bleed pressure and start cement job. Pump 132 bbls 15.8 ppg Class G cement with D047 antifoam- .4 gps; D065 dispersant- 3% BWOC; D600G GASBLOK- 1.5 gps; S002 accelerator- .4% BWOC; D974 LCM- 2 ppb. First 10-15 bbls of cement had red dye marker. Pump cement. at 5.7 bpm with 650 to 950 psi pump pressure. Turn over to rig pump. Drop closing dart, closed annular preventer and open OA to flowback tank. Displace cement with 9.8 ppg brine at 6 bpm with 630 psi. Watch for cement at surface. Cement to surface after displacing 98 bbls while pumping at 5.7 bpm with 1190 psi. Slow pump rate down to 3 bpm at 110 bbfs into displacement. Maintain 500 psi backpressure with choke while pumping at 2.5 bpm with 1340 psi pump pressure. Maintain 500 psi backpressure for the rest of the cement job. Bump plug with 129.7 bbls displacement at 1.5 bpm with 1310 psi. CIP at 03:20 hrs. Increase pressure and close ES Cementer with Printed: 9/2/2008 11:48:48 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/11/2008 01:30 - 03:30 2.00 CEMT P TIE61 1900 psi. Definite indication at rig floor of cementer closing. Hold 2600 psi. Release pressure, with no flow back. 03:30 - 06:00 2.50 CASE P TIE61 Suck out BOP stack and N/D BOPE at tubing spool/ casing spool flange. Pullout BOP studs from bottom of tubing spool flange. Set emergency slips with 120,000 lbs. 06:00 - 07:30 1.50 CASE P TIEB1 Continue to remove BOP studs from tubing spool flange. R/U and make WACHS cut on 9-5/8" casing stub. POOH and UD casing cut off. 07:30 - 10:00 2.50 WHSUR P TIE61 Set BOPE aside and secure. Break flanges between BOPE and tubing spool. Remove old McEvoy tubing spool and remove from cellar. Install new McEvoy SSH 13-5/8" x 13-5/8", 5000 Ibs tubing spool. Install BOPE and N/U same. Install double IA valves. 10:00 - 10:30 0.50 WHSUR P TIEB1 R/U and test new 9-5/8" packoff to 3800 psi for 30 minutes. 10:30 - 11:30 1.00 WHSUR P TIEB1 Set test plug and R/U to test ROPE. Clean out BOPE. 11:30 - 13:00 1.50 WHSUR P TIE61 Pressure test tubing spool/ BOP break and perform full BOP body test to 250 psi low pressure and 3500 psi high pressure. Each test was held tests for 5 charted minutes, good tests. R/D BOP testing equipment. 13:00 - 13:30 0.50 CASE P TIEB1 P/U cement drill out assembly consisting of 8-1/2" used bit, 2 boot baskests, 9-5/8" scraper, bit sub, bumper sub, jars, 6-1/4" drill collars. Total length of BHA- 227.05' 13:30 - 14:30 1.00 CASE P TIEB1 RIH with drill out assembly on 4" HT-38 drill pipe from derrick to 1750'. Establish drilling parameters of P/U Wt- 75,000 Ibs; S/O Wt- 80,000 Ibs; Rot Wt- 78,000 Ibs at 80 rpm with 3000 ft-Ibs free torque; Pump Pressure- 80 psi at 3.5 bpm. RIH and tag wiper plug at 1776'. 14:30 - 15:30 1.00 CASE P TIEB1 P/U to 1765' and CBU 2X at 7 bpm with 260 psi. Wait on cement UCA lab test to report 1000 psi. 15:30 - 16:30 1.00 CEMT P TIEB1 RIH and retag wiper plug at 1776'. Commence to drill out cement tract with 8000-10,000 Ibs WOB at 60 rpm and 2000 to 5000 ft-Ibs torque and a pump rate of 8 bpm with 430 psi. Drili to 1780'. 16:30 - 17:00 0.50 CEMT P TIE61 Circulate high visc sweep at 8 bpm with 350 psi. Sweep brought back cement and rubber in the returns. 17:00 - 18:00 1.00 CEMT P TIE61 Continue to drill through cement with 5000 to 10,000 Ibs WOB at 80 rpm with 2000 to 5000 ft-Ibs torque at a pump rate of 8 bpm with 430 psi. Drill bit occasionally packing off. Drill to 1885'. 18:00 - 19:00 1.00 CEMT P TIE61 Circulate high visc sweep at 8 bpm with 320 psi. Continue to circulate well at 13 bpm with 980 psi until returns came clean. Sweep brought back large amounts of cement chunks to surface. 19:00 - 19:30 0.50 CEMT P TIE61 Dry drill from 1885' to 1888'. Top of sand at 1888'. Continue to dry drill to 1891'. P/U to circulate out the last of the old cement. 19:30 - 20:00 0.50 CEMT P TIE61 Circulate hole clean with high visc sweep at 8 bpm with 320 psi. Sweep brought back large amounts of cement to surface. 20:00 - 21:30 1.50 CEMT P TIEB1 POOH and stand back 4" HT-38 drill pipe in derrick. 21:30 - 22:00 0.50 CEMT P TIE61 POOH with drill out BHA stand back 6-1/4" drill collars. UD BHA. Empty out boot baskets and recover 3 gallons of cement and 2-3 Ibs of metal from bow spring centralizer blades. 22:00 - 22:30 0.50 CASE P TIE61 Clear and clean rig floor. R/U equipment to test casing. Printed: 9/2/2008 11:48:48 AM BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/1.8/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/11/2008 22:30 - 00:00 1.50 CASE P TIEB1 Test casing to 3500 psi. Not getting a good straight line test. Bump up pressure and continue testing. Workover sensater. 8/12/2008 00:00 - 02:00 2.00 CASE P TIEBi Continue to test casing to 3500 psi. Not getting a good straight line. Inspect all surface equipment closely. Disconnect sensor line and purge. Retest, no test. Bleed pressure down to 1500 psi and work manual valves on tubing spool. Retest 9-5/8" casing to 3500 psi for 30 charted minutes. R/D rig testing equipment. 02:00 - 02:30 0.50 CASE P TIEB1 P/U RCJB BHA consisting of RCJB, 2 boot baskets, bit sub, bumper sub, and 2 stands of 6-1/4"drill collars from derrick. Total length of BHA- 218.15' 02:30 - 03:30 1.00 CASE P TIE61 RIH with RCJB assembly on 4" HT-38 drill pipe from derrick to 1835'. 03:30 - 04:30 1.00 CASE P TIEB1 Slip and cut drill line. 04:30 - 05:00 0.50 CASE P TIEB1 Establish parameters of P/U Wt- 83,000 Ibs; S/O Wt- 83,000 Ibs; Rot Wt- 83,000 Ibs at 30 rpm with 2000 ft-Ibs free torque; Pump pressure- 620 psi at 8 bpm. Drop ball and pump at 8 bpm with 620 psi. RIH and tag top of sand at 1893'. Dry drill into sand to 1893'. Reverse jet through sand to 1900' with initial WOB at 5000 Ibs then the RCJB took 0 Ibs WOB. Pump pressure at 2110 psi with 8 bpm. 05:00 - 05:30 0.50 CASE P TIEB1 CBU at 8 bpm with 2110 psi. Returns brought back sand, and small amounts of rubber and cement. 05:30 "- 07:00 1.50 CASE P TIEBi POH and S/B DP and DCs in Derrick. Clean out Junk Baskets and get 1-Ib of metal and some small pieces of the ES Cementer. 07:00 - 09:30 2.50 CASE P TIEB1 Redress the RCJB and RIH to 1900'. Get parameters: P/U wt 83K, S/O wt 83K, Rot. Wt 83K, 8-BPM at 2290-psi. Tag sand at 1908', dry drill to 1913', and wash down to 1923'. Pump 20-Bbl Hi-Vis sweep 8-BPM at 2290-psi. 09:30 - 11:00 1.50 CASE P TIEB1 POH and S/B DP and DCs. Cleanout and UD RCJB. 11:00 - 11:30 0.50 CASE P TIEB1 P/U and M/U Halliburton RBP pulling tool to DP. 11:30 - 12:30 1.00 CASE P TIEB1 RIH with RBP pulling tool to 1918'. Obtain parameters: P/U wt 68K, S/O wt 70K. Dry tag sand at 1922'. Hold PJSM to unseat RBP. 12:30 - 13:30 1.00 DHB P TIEBi Establish circulation 8-BPM at 290-psi, wash down through sand, tag and latch RBP at 1934'. Pump Hi-Vis sweep and chase with 2%-KCI from Pits. Release RBP and CBU 12-BPM at 630-psi. 13:30 - 14:30 1.00 CASE P TIEB1 Pump dry job, blow down Top Drive, POH, S/B DP in Derrick, and UD RBP #2. 14:30 - 19:00 4.50 CASE P TIE61 Inspect RBP retrieval tool and prepare to RIH to retrieve RBP #1 at 10,853'. RIH to 10,800' and obtain parameters: P/U wt 190K-Ibs, S/O wt 145K-Ibs. 19:00 - 20:30 1.50 DHB P TIE61 RIH to 10,845' and wait on additional truckload of 2%-KCI in anticipation of fluid loss after unseating the RBP. Second truck of 2%-KCI on location. Hold PJSM with Rig crew, HES rep and CH2MHill truck drivers. Discuss RBP releasing procedures, truck placement and staging, fluid transfer permits and tasks for all of the crew. RIH to 10,853' and tag RBP #1. Latch into RBP and unseat with 25K overpull per HES rep. Fluid level dropped. Allow elements to relax. RIH to 10,858' to confirm RBP is free. Printed: 9/2/2008 11:48:48 AM BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task -Code NPT Phase Description of Operations 8/12/2008 20:30 - 21:30 1.00 DHB P TIE61 Break circulation with 6-BPM / 300-psi. Got returns after 94-bbls pumped. Establish dynamic loss rate at -4-BPM (240-BPH). Circulate 1/2 bottoms up, working pumps up to 6.5-BPM / 800-psi for steady returns. No gas observed. Static loss rate at 200-BPH when done circulating. 21:30 - 00:00 2.50 DHB P TIE61 POH with RBP #1 from 10,853' to 5,994'. LD 4-jts of DP. Blow down Top Drive. Maintain continuous hole fill of 150-BPH using charge pump. 8/13/2008 00:00 - 01:30 1.50 DHB P TIE61 RU to circulate. Circulate 1-1/2 times calculated bottoms up at 7-BPM / 880-psi. Saw small amount of gas breaking out half way thru circulation. Slowed considerably thru remainder of circulation. No changes in pump pressure or flow rate of returns while circulating and no flow observed while obtaining static loss rate. Dynamic loss rate of 4.3-BPM (258-BPH) and Static loss rate of 200-BPH. 01:30 - 03:30 2.00 DHB P TIEB1 POH with RBP #1 from 5,994' to surface. Maintain continuous hole fill of 150-BPH while POH. 03:30 - 04:00 0.50 DHB P TIEB1 LD HES RBP #1 and RBP running tool. Some wear on lower rubber element, appears to be from fluid flow past element. Recovered 4 small pieces of metal in upper section of RBP. Clear rig floor in preparation for MU Junk catcher spear BHA. PU Junk catcher spear BHA components and handling tools. Hold PJSM with Baker rep and discuss use of small tongs, pinch points, good communication and monitoring hole fill. 04:00 - 06:30 2.50 FISH P DECOMP Change out elevators and RU 2-7/8" tongs to make up PAC DP. MU Junk catcher spear BHA per Baker rep. BHA = Washpipe w/cut lip guide, internal Itco spear assembly, Shear pin guide, 4-jts 2-7/8" PAC pipe, Pump out sub, Bumper sub, Oil Jar, and 6-jts of 6-1 /4" DCs. Total length of BHA =346.93'. 06:30 - 12:00 5.50 FISH P DECOMP RIH Junk Catcher BHA on DP from Derrick. Fill DP every 30-stands RIH to ensure that the 3/8" ID of the spear does not plug. Stand #90 RIH at 0930-hours. P/U stand #111, M/U to Top Drive, and get parameters: P/U wt 213K-Ibs, S/O wt 145K-Ibs, 1-1/2-BPM at 300-psi. S/D pump and continue slowly RIH. B/O Top Drive and P/U stand #112, M/U to Top Drive, start pumping at 1-1/2-BPM and continue to wash down to stack-out on Stub at 10,921.5' D-16 RKB, see shear pins on cutup guide shear at 12-13K-Ibs. Stop to verify depth calculations with DP tally. Speed up pump to 4-BPM at 2080-psi and wash down slowly to bury stand #112. Stop pumping, B/O Top Drive, P/U stand #113, M/U to Top Drive, slowly continue washing down at 4-BPM, 2080-psi, and stack out 2' in on stand #113, but do not see a pressure increase. P/U 10' and RIH slowly to verify stack-out at same depth. Repeat with same results. P/U 10' and stop pump, RIH slowly to see stack-out at about 4-1/2' in on stand 113. Repeat this operation for same stackout. Decide to POH two stands and CBU. Fluid loss for tour = 1,742-bbls. 12:00 - 13:00 1.00 FISH P DECOMP CBU to check losses. Lose 160-BPH while circulating 5-BPM at 600-psi. Increase rate to 8-BPM after pumping 460-Bbls at 1200-psi and see losses increase to 180-BPH. Decide to stop with 500-Bbls pumped with no sign of any gas breakout. Printed: 9!2/2008 11:48:48 AM BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/13/2008 13:00 - 16:00 3.00 FISH P DECOMP POH and S/B DP in Derrick. Maintain continuous hole fill at 150-BPH while POH. Stop with 5,000' remaining in hole to CBU. 16:00 - 17:30 1.50 FISH P DECOMP Circulate Bottoms Up 6.5-BPM at 350-psi for 420-Bbls, losing 160-BPH. 17:30 - 19:30 2.00 FISH P DECOMP Resume POH and S/B DP in Derrick. POH from 5,000' to top of Junk catcher spear BHA at 346'. Maintain continuous hole fill of 150-BPH while POH. 19:30 - 20:30 1.00 FISH P DECOMP Stand back 6-1/4" DCs. LD jars, bumper sub and 2-jts of 2-7/8" PAC DP. Junk Catcher recovered. Unable to break spear out of Junk catcher. LD spear and junk catcher. 20:30 - 21:30 1.00 FISH P DECOMP Redress pump out sub. MU IBP recovery overshot BHA. Use 2-7/8" tongs and elevators for handling overshot and PAC DP. Maintain continuous hole fill thru kill line while MU BHA. BHA consists of 8-1/8" Cut lip guide and washpipe extension, internal overshot dressed with 2-3/8" grapple, XO bushing, shear pin guide, 4-jts of 2-7/8" PAC DP, pump out sub, bumper sub, oil jar and 2-stds of 6-1/4" DCs. Total length of BHA = 346.93'. 21:30 - 00:00 2.50 FISH P DECOMP RIH with IBP recovery overshot BHA from 347' to 5088' (42-stds in the hole). Maintain continuous hole fill of 150-BPH while RIH. Fluid .loss for tour = 1,525-bbls. 8/14/2008 00:00 - 01:30 1.50 FISH P DECOMP Break circulation at 5-BPM / 450-psi to ensure overshot is clear of debris. Continue to RIH with IBP recovery overshot BHA from 5,088' to 10,895'. Maintain continuous hole fill at 150-BPH while RIH. 01:30 - 02:30 1.00 FISH P DECOMP Slip and cut drilling line at 10,895'. 02:30 - 03:30 1.00 FISH P DECOMP PU 1-std 4" DP. Screw in Top Drive and break circulation at 4-BPM / 450-psi. PU wt = 220K, SO wt = 145K. Wash down and tag tbg stub at 10,918' as expected. Appear to be catching top of stub with cut lip guide. PU and rotate slowly down over top. of stub. Turn pump off and set down 12K-Ibs over to shear the shear pin guide. RIH with rest of stand. PU single jt of DP and screw in with Top Drive. Break circulation with 5-BPM / 620-psi. Note pump pressure begin to rise. Shut pump down and continue in hole. Tag IBP at 11,002' as expected. Break circulation at 1-BPM / 580-psi, indicating catch of IBP. 03:30 - 04:00 0.50 FISH P DECOMP LD single jt of 4" DP. Drop ball to open pump out sub. Rack back 1-std of DP. Screw in Top Drive and pump ball down at 1.8-BPM / 480-psi. Pump out sub shear open at 2,200-psi. 04:00 - 04:30 0.50 FISH P DECOMP Circulate 1/2 calculated bottoms up at 7-BPM / 1,080-psi. Returns after pumping 24-bbls. Establish dynamic loss rate at 2.5-BPM (150-BPH). No gas noted while circulating and no indications of flow. Shut down pump, flow check -well on vac. 04:30 - 09:30 5.00 FISH P DECOMP Blow down Top drive and POH from 10,895' with IBP recovery BHA, laying down DP to pipe shed. Maintain continuous hole fill of -200-BPH and seeing loss rate of -125-BPH. 09:30 - 10:00 0.50 FISH P DECOMP Stop POH with 5,590' of DP in hole to CBU, seeing no gas in returns while circulating at 7-BPM, 870-psi. Took 8-Bbls to get returns after M/U to Top Drive to start circulation. 10:00 - 13:00 3.00 FISH P DECOMP Resume POH and UD DP. Stop at -2,500' to CBU 1-1/2 volumes. Continuous hole fill at -200-BPH with 125-BPH loss BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours. Task Code NPT Phase Description of Operations 8/14/2008 10:00 - 13:00 3.00 FISH P DECOMP to well and -75-BPH returns. 13:00 - 13:30 0.50 FISH P DECOMP Circulate at 7-BPM, 300-psi for 1-1/2BU volumes, seeing no gas in the returns. 13:30 - 16:30 3.00 FISH P DECOMP Resume POH from 2,533' to 345' and UD DP. Use continuous hole fill of -200-BPH. 16:30 - 17:30 1.00 FISH P DECOMP LD 6-1/4" DCs, 2-7/8" PAC DP and BHA. IBP recovered. LD Overshot and IBP. 17:30 - 18:00 0.50 FISH P DECOMP Clear Baker fishing and handling tools from Rig Floor. 18:00 - 18:30 0.50 FISH P DECOMP Service Drawworks and Top Drive. 18:30 - 20:00 1.50 BUNCO RUNCMP RU to run 4-1/2" 12.6# 13cr80 Vam Top Completion with Unique Machine overshot. PU, RU and function test Power tongs and Torque turn equipment. Function test stabbing board. CO bales and elevators. RU Single jt elevators and compensator. Organize pipe shed and jewelry layout. MU 4-1/2" Vam Top XO to TIW valve. 20:00 - 00:00 4.00 BUNCO RUNCMP PJSM on running completion with Baker completion hand, Rig crew and Doyon casing hand. Discussed individual tasks, placement of people, hazards associated with running the completion and stressed staying in the moment on the last day while doing a repetitive task. Run 4-1/2" 12.6# 13cr80 Vam Top completion with Unique Machine overshot, 1-Baker S-3 9-5/8" x 4-1/2" Permanent Packer, 1-XN Nipple, 3-X Nipples, 5-GLMs. Utilize Jet Lube Seal Guard thread compound. Bakerlock ali connections below packer. Torque turn services used on all connections with optimum MU torque of 4,440-Ib-ft. 2045-hrs Packer and jewelry below it in hole (193'). 0000-hrs at tbg jt #37. 8/15/2008 00:00 - 11:00 11.00 BUNCO RUNCMP Run 4-1/2" 12.6# 13cr80 Vam Top completion from tubing jt #37 Utilize Jet Lube Seal Guard thread compound. Torque tum services used on all connections with optimum MU torque of 4,440-Ib-ft. 0330-hrs at Jt #126. 0500-hrs at Jt #158. 0645-hrs ~ #182. 0730-hrs ~ #200. Losses during RIH -110-BPH using Constant Hole Fill. 11:00 - 12:00 1.00 BUNCO RUNCMP P/U joint #282 and M/U with full torque; RIH. P/U joint #283 and M/U with minimum recommended torque (4000-Ib-ft) to prevent galling threads when backing out after space-out. P/U joint #284 and M/U with minimum torque. Slowly RIH and see top of stub at 26' in on #284, continue in -2' and see first set of pins shear at -10K-Ibs; continue 8' further and see second set shear with -10K-Ibs; continue in to No-Go with a swallow of -13-1/2'. Calculate space-out to achieve about 8-1/2' of swallow of the 4-1/2" tubing stub inside the Unique Machine Overshot. Will use 9.91' pup to put bottom of the Overshot at 10,933'; top of the stub is at -10,924'. 12:00 - 13:00 1.00 BUNCO RUNCMP POH and UD joints #284 and #283. P/U 9.91' pup joint and torque turn to 4,440-Ib-ft on tubing string and RIH. P/U joint #283 and torque tum to 4,440-Ib-ft and RIH. M/U floor valve to 4-1/2" TCII Landing Joint and P/U M/U to Hanger with pup. M/U hanger pup to tubing and Torque Turn to 4,440-Ib-ft. P/U weight 170K-Ibs, S/O weight 125K-Ibs. 13:00 - 13:30 0.50 BUNCO RUNCMP PJSM with crew, Cameron technician, Baker Completions technician, CH2MHill pusher and truck drivers to discuss safety and job requirements for all individuals onsite during the hanger BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: 13-29 Common Well Name: 13-29 Spud Date: 4/18/1983 Event Name: WORKOVER Start: 7/28/2008 End: 8/16/2008 Contractor Name: DOYON Rig Release: 8/16/2008 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 8/15/2008 13:00 - 13:30 0.50 BUNCO RUNCMP landing and packer fluid circulation operations. Land Hanger and Cameron technician RILDS. 13:30 - 14:00 0.50 BUNCO RUNCMP Clear and clean rig floor and R/U to reverse circulate corrosion inhibited packer setting fluid. 14:00 - 19:00 5.00 BUNCO RUNCMP Reverse circulate 165-Bbls of 120E 2%-KCi, then 2-ea 290-Bbis truckloads of 120E 2%-KCI with 75-gals, each of EC 1124A Corrosion Inhibitor. All circulation at 3-BPM at 40-psi. 19:00 - 21:00 2.00 BUNCO RUNCMP Drop ball-n-rod. LD landing jt and RU to test thru kill line. Pressure test all lines to 3,500-psi. Pressure up on Tubing to 3,500-psi to set packer and then test tubing. Hold and chart tubing test for 30-minutes -Good Test. Bleed tubing pressure to 1,500-psi. Pressure up on IA to 3,500-psi. Hold and chart IA test for 30-minutes -Good Test. Bleed off tubing pressure quickly to shear DCR valve open. Positive indication of valve shearing with pressures equalizing and then bleeding off. Verify DCR sheared by circulating thru it both directions. Pump down tubing at 3-BPM / 190-psi and then pump down annulus at 3-bpm / 120-psi. 21:00 - 22:00 1.00 BUNCO RUNCMP Cameron tech T-bar in TWC. Test from above to 3,500-psi - good test. Test from below to 1,000-psi -good test. Hold and chart both tests for 10-minutes. 22:00 - 22:30 0.50 BUNCO RUNCMP Blow down all lines and mud pump #1. Drain BOP stack in preparation for ND. 22:30 - 23:00 0.50 BOPSU P RUNCMP PJSM on ND of ROPE. ND all BOPE. 23:00 - 23:30 0.50 WHSUR P RUNCMP Clean top of tubing hanger and API ring gasket groove in preparation for installing adapter flange. 23:30 - 00:00 0.50 WHSUR P RUNCMP NU tubinghead adapter flange per Cameron wellhead tech. 8/16/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP NU 4-1/8" Production tree. 01:00 - 01:30 0.50 WHSUR P RUNCMP RU and test tubinghead adapter flange for 30-minutes -Good test. 01:30 - 03:30 2.00 WHSUR P RUNCMP Fill tree with diesel. RU to test tree. Test tree to 5,000-psi. Hold and chart test for 30-minutes. Good Test. 03:30 - 04:00 0.50 WHSUR P RUNCMP PU & RU DSM lubricator. Test lubricator to 500-psi -good test. Pull TWC with lubricator. No pressure under TWC as well is on vac. LD lubricator and TWC. 04:00 - 04:30 0.50 WHSUR P RUNCMP RU on tree to circulate diesel freeze protection. Spot LRS on pad. PJSM with LRS and rig crew about circulating freeze protection. Discussed necessary permits, monitoring lines, staying clear of high pressure lines and placement of people. Pressure test LRS lines and rig lines to 3,500-psi. Good tests. 04:30 - 06:00 1.50 WHSUR P RUNCMP LRS pump 150-Bbls of diesel freeze protection. Pump at 2-BPM with 650-psi. 06:00 - 07:00 1.00 WHSUR P RUNCMP Allow freeze protect diesel to U-tube. Freeze protect from surface to 2,412'. 07:00- 08:00 1.00 WHSUR P RUNCMP Cameron P/U BPV and install in Hanger. Test from bottom with LRS pump to 1000-psi and hold for 10-minutes for solid test. Bleed down LRS lines, R/D LRS. Bleed down rig equipment. 08:00 - 09:00 1.00 WHSUR P RUNCMP Secure tree and cellar. Remove double annulus valves and ensure ali valves are properly capped. Release rig at 0900-hours. n..-~-~. nMfmnno 71.A O.AC AAA VELLHEAD = MCEVOY ,CTUATOR = AXELSON B. ELEV = 83' F. ELEV = oP= 3200' DRLG DRAFT lax Angle = 91 @ 11930' latum MD = 11401' latum TV D = 8800' SS 5/8" CSG PATCH, 47#, L-80, BTC, ID = 8.681" 1836' 13-3/8" CSG, 72#, L-80, ID = 12.347" 11 262 Minimum ID = 2.38" @ 11454' 3-3/16" X 2-7/8" XO 14-1/2", 13.5#, 13CR85, .0152 bpf, ID = 3.938" I 4-1/2", 12.6#, 13CR80, .VAM TOP, I 10917' .0152 bpf, ID = 3.958" 4-1/2" TUBING STUB (07/24/08) -10921 TOP OF 7" LNR 11071' 4-112" TBG-PC,12.6#, 11113' L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 11378' FLOW-BY WHIPSTOCK PERFORATION SUMMARY REF LOG: BHCS ON 05/02/83 ANGLE AT TOP PERF: 44° @ 11366' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-318" 4 11366 - 11394 O 11/09/89 3-3/8" 4 11412 - 11432 O 05/18/92 3-3/8" 4 11484 - 11513 O 05/18/92 3-118" 4 11522 - 11542 O 03/11/84 3-1/8" 4 11552 - 11562 O 03/11!84 3-118" 4 11574- 11600 O 03!11/84 3-1 /8" 4 11608- 11632 O 01!19/86 PBTD 13-Z9L1 Ilia SAFETY~TES: *""4-1 /2" CHROME TBC~""` 1777' ~ 9-5/8" HES ES CEMENTER 2088' 4-1/2" HES X NIP, ID = 3.812" GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 5 3422 3411 17 MMG DOME RK 16 08/21 /I 4 6338 5494 52 MMG SO RK 20 08/21/1 3 8537 6905 48 MMG DMY RK 0 08/15/1 2 9991 7886 45 MMG DMY RK 0 08/15/1 1 10690 8387 46 MMG DMY RK 0 08/15/1 10760' 4-1/2" HES X NIP, ID = 3.812" 10790' 4-1/2" X 9 5/8" BKR S-3 PACKER, ID = 3.875" 10825' 4-112" HES X NIP, ID = 3.725" 10897' 4-1 /2" HES XN NIP, ID = 3.812" 10933' 9-518" x 4-1 /2" UNIQUE OVERSHOT 10991' 9-518" X 4-1/2" BKR S-3 PKR, ID = 4.750 11007' 6' MIIIOUT EXTENSION, ID = ? 11013' 7-5/8" X 4-112" XO, ID = 3.958" 11037' 4" BKR DEPLOY SLV, ID = 3.00" 11072' ~ 3-1/2" X 3-3(16" XO, ID = 2.80" 11100' 4-1/2" OTIS XN NIP, ID = 3.725" 11112' 4-1/2" BRN SHEAROUT SUB, ID = 4.00" 11113' 4-1/2" WLEG, ID = 3.958" 11097' ELMD TT LOGGED 11 /16192 I 11454' I 3-3116" X 2-7/8" XO,ID = 2.3E ~ ~ ~ ~ ~ ~ 2-7/8" SLTD LNR, 6.16#, L-80, 12501' .0055 bpf, ID = 2.38" 11603' FISH -BKR 3-1/2" PIP PKR (04103/ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 11870' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/11/83 ORIGINAL COMPLETION 09/01/08 JLJ/PJC GLV Ci0 (08/21/08) WELL: 13-29L1 07/14/87 LAST WORKOVER PERMrf No: 183043 / 2020690 04/25/02 JDM/KK CTD LATERAL SIDETRACK API No: 50-029-20928-00 / -60 07/21/07 SWC/PJC SET WRP (07/11(07) SEC 14, T10N, R14E, 761' SNL & 1234' WEL 08/16/08 D16 RWO nRl7d/nR I(:M/R\/ PI II i \A/RPlnR(94lnR1 RP Fvnln.~4inn lAhc4nl 08/25/08 ~.,,. 3 n,-, .., ~- O VJ~S~ a ~t~~ ~c~nberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wpll .Inh !F N0.4826 t~I Company: State of Alaska ~,r~711N~~ S ~,~ .ii ~ ~#1~0 Alaska Oil & Gas Cons Comm U U Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 nn Dasr_rintinn DAFP_ HI. Cnlnr CD A-02 12086677 RST ~ - ( 07/23/08 1 1 A-24 12034903 RST - 06/18/08 1 1 A-13 12086676 RST 07/23/08 1 1 G-02A 11968945 RST $- ~ 06/08/08 1 1 B-19A 12017500 RST - / ~(0 06/14/08 1 1 15-18A 12005216 MCNL - ~ (~ _ 06/24/08 1 1 C-02 11982437 RST / ~ 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) - G / 04/21/08 1 1 B-37 12034907 CH EDIT PDt3-GR 06/10/08 1 V-207 11999031 MDT aO 07!23/08 1 1 V-207 11999031 MDT QUICKLOOK "~ 07/23/08 1 1 V-210 ~ 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /(p 08!16/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) - Q 07/28/08 1 1 B-18 11978471 USIT _ ~ / (~ 0 ~ 08/04/08 1 1 05-31A 12057635 LDL '~ 6 07/21/08 1 1 13-29L1 11962614 LDL ~ a -d(o ~ 07/30/08 1 1 13-29L1 11966271 USIT - /(p 08/05/08 1 1 H-11 12017507 USIT 08/04/08 1 1 `, V ~- µ - l F'LCA,t ALKNUWLtU(at Fitl:tlF'1 tl7 ~ICiNINIoi ANU Fit! UF(NINCi VNt I:UYT tAGFI I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ~~ *~ ~' 900 E. Benson Bivd. ,: o - ~~ Anchorage, Alaska 99508 tt ii Date Delivered: a~v~i ~~ ~ oI~C~~} tit ~ ~~ s~4~~;k~a t?+1 !~ i~ir3S {,+~ts-~ i.>~.,' ;alf', Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-28 ATTN: Beth /~ Received by: Jl/__/ • ~~1~ 08/25/08 \~ .._ _~ ~- ~AS~ta ~t~~ Schl~r~berger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # N0.4826 ~~~~~~~ ~~~ ~ ~ L~UU Company: State of Alaska U Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Lnn np~rrintinn nata BL Celnr Cn A-02 12086677 RST ~ - ( 07/23/08 1 A-24 12034903 RST - ~ 06/18/08 1 1 A-13 12086676 RST (~ 07/23/08 1 1 G-02A 11968945 RST s ~ 06/08/08 1 1 B-19A 12017500 RST / ~~ 06/14/08 1 1 15-18A 12005216 MCNL (~tf - ~ (~ - 06/24/08 1 1 C-02 11982437 RST L / Q 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) - / 04/21/08 1 1 B-37 12034907 CH EDIT PDC-GR 06/10/08 1 V-207 11999031 MDT 07/23/08 1 1 V-207 11999031 MDT QUICKLOOK '~ 07/23/08 1 1 V-210 ~ 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /(p 08/16/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) 0 07/28/08 1 1 B-18 11978471 USIT . ap / (p 0 ~ 08/04/08 1 1 05-31A 12057635 LDL - '~ Q 07/21/08 1 1 13-29L7 11962614 LDL ~ - ~ 07/30/08 1 1 13-29L1 11966271 USIT /(p 08/05/08 1 1 H-11 12017507 USIT 08/04/08 1 1 ~~- w l r'LCAJC A\.I~IYtJ YYLCU\7C r{C\.Clr' I Di AIUIVIIVU HIVU r1C 1 UrfIVIlVIa VIVC GIIYT CAGI'i 1 V: BP Exploration (Alaska) Inc. ~ e Petrotechnical Data Center LR2-1 ~ ~ ~ ~.~ ~ ~ ~~ 900 E. Benson Blvd. .~~ Anchorage, Alaska 99508 Date Delivered: ~~~~~ c~ ~ ~~~~~ ~~~i ~' ~, a~py;: ,~.sgOt~~;1~' Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-283 ATTN: Beth Received by: • • i`1, ~.J • • ~ ~ " __, SARAH PALIN, GOVERNOR 1~T ~1~p~-7~A 0~ ta~``L`~7~-~5T 333 W 7th AVENUE, SUITE 100 C~l`Si/i~~~-~~`~ CD~~II~7'`-7'`I01` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276.7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 y O ~ ~' Anchorage, AK 99519-6612 r~ O a, Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-29L1 Sundry Number: 308-254 Dear Mr. Reem: ~`~~.~~~~ JUG ~~ ~ 200$ 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. Sincerely, Daniel T. Seamount, Jr. /gyp Chair DATED this ~ d]a~y oaf July, 2008 Encl. TAT F ALA KA ~ qj ALA OIL AND GAS CONSERVATION COM~ION i 'V~o L,, ~IUL ~ 1 20108 ,~ APPLICATION FOR SUNDRY APPROVAL ~ 20 AAC 25.280 A1ask~ C~il~ ~~C C~n~. ~,O+sTti?asBSlt~31 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~t'0~ 's 8~ ® Alter Casing _ ®Repair Well ' ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration {Alaska) Inc. ®Development ^ Exploratory 202-069 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20928-ti0-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13-29L1 ' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11: Field /Pool(s): ADL028314- 83.0 ~ Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12501 - 9014 - 12501- 9014 ~ 11038' 10991' Casin Len th Size MD TVD Burst Colla se Structural C nductor 163' 20" 163' 163' 1490 470 Surface 2624' 13-3/8" 2624' 2624' 4930 2670 Intermediate Production 11378' 9-5/8" 11378' 8868' 687 4760 Liner 298' 7" 11071' - 11369' 8650' - 8862' 8160 7020 Liner 1464' 3-1/2" x 3-3/16" x 2-718" 11037' - 12501' 8626' - 9014' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted 11580' - 12499' Slotted 8950' - 9014' 4-1/2", 12.6# L-80 11113' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker S-3 Packer, Packers and SSSV MD (ft): 10991' 4-1/2" CAM BAL-O SSSV Nipple 2209' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 10, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Na a David Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~llb 0~ Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: a S Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity (BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~(~ ~~ t `~~ ~~~ Subsequent Form Required: ~.-`C~` APPROVED BY ~ p~ A roved B ~ COMMISSIONER THE COMMISSION Date 7 2 Form 10-403 Revised 08'2006 Submit In Duplicate o ~N~S ~F~., ,lUl, 2 9100 RIGINAL by c.,,~, 13-29L1 Expense Rig Workover • Scope of Work: Pull 4-'/z" L-80 completion, cut and pull 9 5/e" casing, run and cement to surface 9-5/e" casing, run 4-'/z" 13Cr80 "stacker-packer" completion. MASP: 2900 psi Well Type: Producer Estimated Start Date: August 10, 2008 Production Engineer: Olivia Bommarito Intervention Engineer: Aras Worthington Pre-Ria Work Reauest: S 1 Set Junk-catcher on top of WRP ~ 11,038' MD and dump-bail 10' of sluggits on top of 'unk catcher. Drift tb for 'et cut. E 2 Power Jet cut 4-'h" 13Cr-80 tubing at 10,934' MD, in the middle of the first full joint above the Baker S-3 packer. Reference tubing tally dated 7/14/1987. CMIT T x IA to 3500 si. MITOA to 2000 si. F 3 Circulate well with seawater and FP with diesel thru the cut. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 5 Set a BPV in the tubin han er. W 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proaosed Procedure 1. MIRU. ND tree. NU BOPE with 3-'/z" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-'/2" tubing string to the cut. 3. Run USIT log to determine top of cement in 9 5/8" x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9 5/s" casing from above the top of cement. Note: Pipe rams will not be changed to 9- g/8" as the well has two tested barriers (WRP plug and RBP) to the reservoir. 6. Run and fully cement new 9-g/8" casing to surface. 7. Pressure test new casing and drill out shoetrack. 8. Clean out to retrievable bridge plug and retrieve same. 9. Run 4-'/z" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 10,900' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. TREE= MCEVOY GEN 3 WELLHEAD= MCEVOY ACTUATOR= AXELSON KB. ELEV = 83' BF. ELEV = KOP = 3200' Max Angle = 91 @ 11930' Datum MD = 11401' Datum TVD = 8800' SS 13-29L1 S NOTES: 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2624' Minimum ID = 2.38" @ 11454' 3-3/16" X 2-7/8" XO 4-1/2" WRP PLUG (07/11/07) I~ 11 TOP OF 7" LNR 4-1/2" TBG-PC,12.6#, ~ 11113' L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" FLOW-BY WHIPSTOCK ~-j 11366, PERFORATION SUMMARY REF LOG: BHCS ON 05/02/83 ANGLE AT TOP PERF: 44° @ 11366' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11366 - 11394 G 11/09/89 3-3/8" 4 11412 - 11432 C 05/18/92 3-3/8" 4 11484 - 11513 C 05/18/92 3-1/8" 4 11522 - 11542 C 03/11/84 3-1/8" 4 11552 - 11562 C 03/11/84 3-1/8" 4 11574 - 11600 C 03/11/84 3-1/8" 4 11608-11632 C 01/19/86 PBTD I-i 11836' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" n i~~ 4-1 /2" CA M BA L-O SSSV NIP, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2899 2898 7 CAMCO DMY RK 0 01/29/07 2 5218 4797 51 CA MCO DMY TG 0 01 /29/07 3 7558 6262 49 MERLA DMY TG 0 07/14/87 4 8783 7071 47 CAMCO DMY RK 0 01!29/07 5 9596 7615 48 MERLA DMY TG 0 07/14/87 6 10116 7975 44 MERLA DMY TG 0 05/06/02 7 10356 8148 44 MERLA DMY TG 0 05/06/02 8 10631 8345 45 MERLA DMY TG 0 05/06/02 9 10744 8424 46 MERLA DMY TG 0 05/06/02 10 10854 8500 47 MERLA DMY TG 0 05!06/02 11 10964 8576 47 CAMCO '*DMY RK 0 07/10/07 "S IA I IVN #4 = UMY FWS tX I tNUtU I'AC:KINCi ?? FISH: IBPELEMENTS(10/12/06) 10991' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 4.750 11007' 6' MILLOUT EXTENSION, ID = ? 11013' 7-5/8" X 4-1 /2" XO, ID = 3.958" 11037' 4" BKR DEPLOY SLV, ID = 3.00" 11072' 3-112" X 3-3/16" XO, ID = 2.80" 11100' 4-1/2" OTIS XN NIP, ID = 3.725" 11112' 4-1/2" BRN SHEAROUT SUB, ID = 4.00" 11113' 4-1/2" WLEG, ID = 3.958" 11097' ELMD TT LOGGED 11 /16/92 ' I-I 3-3/16" X 2-7/8" XO, ID = 2.38" I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~ . 2-7/8" SLTD LNR,~6.16#, L-80, 12501' .0055 bpf, ID = 2.38" 11603' FISH -BKR 3-1/2" PIP PKR (04/03/ DATE REV BY COMMENTS DATE REV BY COMMENTS 05/11/83 ORIGINALCOMPLETION 10/12/06 RCT/TLH IBPPULLED/FISH=ELEMENTS 07/14187 LAST WORKOVER 01/29/07 KSB/TLH GLV GO 04/25/02 JDM/KK CTD SIDETRACK 06/19/07 JLJ/PJC GLV GO 08/20/05 RPH~TLH WAVER SFTY NOTE DELETED 07/21/07 SWGPJC GLV GO & SET WRP (07/11/07) 05/31/06 DTM WELLHEAD CORRECTION 06/15/06 RCT/PJC PULL LTTP @ 11037 PRUDHOE BAY UNfT WELL: 13-29L1 PERMff No: 1020690 API No: 50-029-20928-60 SEC 14, T10N, R14E, 761' SNL & 1234' WEL BP Exploration (Alaska) TREE = MCEV OY GEN 3 WELLHEAD = MC2=VOY A'CTl•1ATOR = AXELSON KB. f3EV = 83' BF. ELEV = KOP = 3200' Max Angle = 91 @ 11930' Datum MD = 11401' Datum T/D = 8800' SS 13 -2 ~ 1 Proposed SA~rirNOTES: 9-5/8" CSG, 47#, L-80, Prerrium Threacr 13-3/8" CSG, 72#, L-80, ID = 12.347" 2624' Minimum ID = 2.38" @ 11454' 3-3/16" X 2-7/8" XO 4-1 /2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958 TOP OF 7" LNR 4-1 /2" TBG-PC,12.6#, L-80, .0152 bpf, ID = 3.958" I 11071' I 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I-( 11 FLOW-BY WHIPSTOCK I-~ 11366' PERFORATION SUMMARY REF LOG: BRCS ON 05/02/83 ANGLE AT TOP PERF: 44° @ 11366' Note: Refer to Production DB for historical perf data SIZE SPF .INTERVAL Opn/Sqz DATE 3-3/8" 4 11366 - 11394 C 11/09/89 3-3/8" 4 11412-11432 C 05/18/92 3-3/8" 4 11484 - 11513 C 05!18/92 3-118" 4 11522 - 11542 C 03/11/84 3-118" 4 11552 - 11562 C 03/11/84 3-1/8" 4 11574 - 11600 C 03/11/84 3-1/8" 4 11608-11632 C 01/19/86 PBTD 11836' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11870' u.. 2200' -{4-1/2" HES LANDING NIP, ID = 3.812" -2500' Cement to Surface GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3410 CA MCO DCR 0 2 6348 CAMCO DMY 0 3 8530 CA MCO DMY 0 4 10010 CA MCO DMY 0 5 10900 CAMCO DMY 0 J~ 4-1/2" HES LANDING NIP, ID = 3.812" 4-1/2" X 9 5/8" BKR S-3 PACKER 4-1/2" HES LANO~VG NIP, ID = 3.812" 4-1/2" x 9 5/8" UNIQUE OVERSHOT 10991' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 4.750 11007' 1.1013' 11037' 6' MILLOUT EXTENSION, ID = ? 7-5/8" X 4-1/2" XO, ID = 3.958" 4" BKR DEPLOY SLV, ID = 3.00" 11072' --~ 3-1 /2" X 3-3/16" XO, ID = 2.80" 11100' 4-1/2" OTIS XN NIP, ID = 3.725" 11112' 4-1/2" BRN SHEAROUT SUB, ID = 4.00" 111 113, I--~4-1/2" WLC-G, ID = 3.958" 11097' ELMD TT LOGGED 11/16/92 11454' H 3-3/16" X 2-7/8" XO, ID = 2.38" I \ ~ ~ ~ 2-7/8" SLTD LNR 6.16#, L-80, 12501' .0055 bpf, ID = 2.38" 11603' FISH -BKR 3-1/2" PIP PKR (04/03/02) DATE REV BY COMMENTS DATE REV BY COMMENTS 05/11183 ORIGINAL COMPLETION 10/12/06 RCT/TLH IBP PULLED /FISH=ELEMENTS 07!14187 LAST WORKOV Fat 01 /29/07 KSB/TLH GLV GO 04125/02 JDM/KK CTD SIDETRACK 06/19/07 JLJ/PJC GLV GO 08/20/05 RPHITLH WAVER SFTY NOTE DELETED 07/21/07 SWGPJC GLV GO & SET WRP (07/11/07) 05/31/06 DTM WELLHEAD CORRECTION 06/15!06 RCT/PJC PULL LTTP @ 11037 PRUDHOE BAY UNff WELL: 13-29L1 PERMff No: `1020690 API No: 50-029-20928-60 SEC 14, T10N, R14E, 761' SNL & 1234' WEL BP Exploration (Alaska) 4< ,-..___.."..... .-',-'- Schlumberger SCANNED JUN· 2 1 2007 NO. 4306 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ¿)Od-O~C} Company: State of Alaska Alaska Oil & Gas Cons .:::omm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WI! CI CD J b# L D . f D t BL e 0 og escrlptlon ae o or L3-12 11695062 PRODUCTION PROFILE 06/06/07 1 GNI-03 11637128 PRESS/TEMP SURVEY 06/06/07 1 Y-11C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29L 1 11686753 LDL OS/28/07 1 Y-OSA 11628778 MEMORY INJECTION PROFILE OS/28/07 1 L5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROFIIPROF 06/05/07 1 Y-35A 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13/07 1 01-07A 11626098 PRODUCTION PROFILE OS/28/07 1 13-29L 1 11686753 LDL OS/28/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDL 06/13/07 1 G-23A 11638639 LDL 06/03/07 1 14-05A 11813055 PPROF W/RST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWD/LWD 09/19/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: "11 H\ ~) ,0 20m Received by: 10,ll \..f' -7 06/18/07 . . STATE OF ALASKA . SEP 2 20 ALASKA OIL AND GAS CONSERVATION COMMISSION ' 7 06 REPORT OF SUNDRY WELL OPERA TtONS& Gas Cons. Commission . RECEIVED . 1. Operations Performed: .;:1' Abandon 0 Repair Well 0 Plug PerforationsD Stimulate 0 Otherl!JCMIT - TxlA Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD . 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20928-00-00 7. KB Elevation (ft): 9. Well Name and Number: 83.00 13-29L 1 8. Property Designation: 10. Field/Pool(s): ADL-028314 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12501 feet true vertical 9014.0 feet Plugs (measured) 3-3/8" IBP set @ 11022 (07/31/2006) Effective Depth measured 12501 feet Junk (measured) true vertical 9014.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 125 20" 91.5# H-40 38 - 163 38.0 - 163.0 1490 470 SURFACE 2587 13-3/8" 72# L-80 37 - 2624 37.0 - 2624.0 4930 2670 PRODUCTION 11342 9-5/8" 47# L-80 36 - 11378 36.0 - 8868.0 6870 4760 LINER 298 7" 29# L-80 11071 - 11369 8650.0 - 8862.0 8160 7020 LINER 30 3-1/2" 9.2# L-80 11037 - 11072 8626.0 - 8650.0 7240 5410 LINER 724 3-3/16" 6.2# L-80 11072 - 11454 8650.0 - 8910.0 8520 7660 LINER 1573 2-7/8" 6.4# L-80 11454 - 12501 8910.0 - 9014.0 10570 11160 Perforation depth: Measured depth: 11366-11394,11412-11432,11484-11513,11522-11542,11552-11562,11574-11600,11608-11632, 29L1 STLN 11580-12501 True vertical depth: 8860-8879,8889-8900,8922-8932,8934-8940, 8943-8945, 8948-8954, 8956-8960, 29L 1 STLN 8930-9014 Tubing ( size, grade, and measured depth): 4·1/2" 12.6# L-80 @ 34 - 11113 ,,~a.lt ~ ¿Duo Packers & SSSV (type & measured depth): 9-5/8" Baker SB-3 Packer @ 10991 ,Y':':':;~:: 4-1/2" Cam BAL-O SSSV Nip @ 2209 12. Stimulation or cement squeeze summary: RBDMS 8Ft 0 CI {} 3 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: SI 0 0 --- - Subsequent to operation: SI 0 0 -- -- 14. Attachments: 15. Well Class after proposed work: ExploratoryD Developmentl! ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWaYlJe R. Schnorr Title Petroleum Engineer Signature .kd ¿;;P~.l -~ Phone 564-5174 Date 9/25/06 , ;Ð. Form 10-404 Revised 4/2004 r~AL . . 13-29L 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/23/2006 T/I/O = 720/520/20. CMIT TxlA to 2600 psi. (PASSED) on 2nd attempt. Pumped 35 bbls crude to reach test pressure. IA lost 30 psi tbg lost 100 psi in 15 min IA lost 20 psi and tbg lost 50 psi in second 15 min bumped up pressure with 2 bbls IA lost 40 psi in 15 min tbg lost 50 psi in second 15 min IA lost 40 psi tbg lost10 psi (see mit data sheet) bleed back pressure. Final WHP's = 800/850/20. 08/18/2006 CMIT Completed on 08-17-06 Awgers MITxOA (Passed) Pre-Test Press.=1275/1000/120 Initial Press.=1250/950/2600. 15 min press.=1250/950/2420. 30 min.press=1250/950/231 O. ( Failed) Re-TesUntial Press.=1250/950/2600. 15 min press=1225/900/2520. 30 min pres = 1225/900/2490. FWHP = 1225/900/160 08/17/2006 TII/O=700/900/120. Load IA w/ 206 bbls crude. CMIT TxlA to 2600 psi. (FAILED) Initail Press.=2650/2600/180.15 min press=2550/2380/180.30 min press.=2250/2200/180.( Failed ) RE-TEST:lnitail Press =2660/2600/180.15 min press.=2525/2440/180. 30 min press.=2450/2330/180. (Failed) RE-Testlnitail press.=2700/2600/180. 15 min press.=2600/2500/180.30 min press.=2525/2420/180 ( Failed) Attempted LLR could not establish a minimum rate. Bleed back press. Swap To OA. ( MITx OA ) 08/15/2006 T/I/O=600/830/100. Temp=SI. WHP's post-bleed (pre-CMIT-TxIA). No change in IA & OAP. 08/14/2006 TII/O=SSV/830/100. Temp=SI. WHP's post-bleed (pre-CMIT-TxIA). DSO was not avilable to open SSV. lAP increased 690 psi from 140 psi to 830 psi. No change in OAP. 08/13/2006 T/I/O=630/1660/100 Temp=SI Bleed TBG & IA < 500 psi, TBG & IA FLs (pre-CMIT-TxIA). AIL disconnected. IA FL @ 4206' (225 bbls) between ST# 1 & 2. Bled lAP from 1660 psi to 600 psi in 2 hrs 15 minutes (FTS). While bleeding the lAP the TBGP decreased 410 psi to 220 psi. Swapped bleed to TBG. TBG FL @ 1218' (18.5 bbls). While swapping to TBG bleed the lAP increased 40 psi to 640 psi and the TBG increased 20 psi to 240 psi in 15 minutes. Bled TBGP from 240 psi to 60 psi in 30 minutes. While bleeding the TBGP the lAP increased 60 psi to 700 psi. Shut in TBG bleed and monitor for 30 minutes. TBGP increased 80 psi and the lAP increased 40 psi. Final WHPs=740/140/100 08/07/2006 T/I/O= 780/1660/100. Temp= SI. Tubing and IA FL's (pre-CMIT-TxIA). AIL spool removed. Tubing FL @ 516' (8 bbls). IA FL @ 4348' (233 bbls) between sta# 1 & 2. 07/31/2006 WELL SHUT IN. T/I/O 650/1600/100.3-3/8" BAKER IBP SET MID-ELEMENT AT 11,028 FT. TOP OF PLUG AT 11,021.5 FT; BOTTOM AT 11,032 FT. DEPTH TIED TO TUBING TALLY DATED 14-JUL-1987. WELL LEFT SHUT-IN TII/O 650/1600/100. *****JOB COMPLETE***** 07/29/2006 TII/O=1950/ 1600/100 Load TBG F-protect F-Line (Eval to POP, NFT for TXIA waiver & watch for IAxOA comm really exists) Spear in to TBG w/10 bbls 60/40 meth water Followed by 274 bbls of 50* C-h20 caped w/35 bbls of 105* crude Final Whp's=100/1700/120 Page 1 . . 13-29L 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 1 Diesel --- PT Surface Equipment 10 60/40 Methanol Water 262 Crude 274 Sea Water 547 TOTAL Page 2 TREE = MCEVOY GEN 3 I WELLHEAD = MCEVOY ACTUA TOR = AXELSON KB, ELEV = 83' BF. ELEV = KOP = 3200' Max Angle = 91 @ 11930' Datum MD = Datum lV D = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.38" @ 11454' 3-3/16" X 2-7/8" XO 13-29L 1 2209' -14-1/2" CAM BAL-O SSSV NIP, 10 = 3.812" I . GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 2899 2898 7 CAMCO DOME RK 16 08/19/02 2 5218 4797 51 CAMCO DOME RK 16 10/15/04 3 7558 6262 49 MERLA DMY TG 0 4 8783 7071 47 CAMCO DOME RK 16 10/15/04 5 9596 7615 48 MERLA DMY TG 0 6 10116 7975 45 MERLA DMY TG 0 05/06/02 7 10355 8148 44 MERLA DMY TG 0 05/06/02 8 10631 8345 45 MERLA DMY TG 0 05/06/02 9 10744 8424 46 MERLA DMY TG 0 05/06/02 10 10854 8500 47 MERLA DMY TG 0 05/06/02 11 10964 8575 46 CAMCO SO RK 22 10103/04 9-518" X 4-1/2" BAKER SB-3 PKR AND SEAL BORE ASSY, ID = 4.750 3-3/8" BKR IBP SET (07/31/06) MID-ELEflAENT @ 11,028' -14" BKR DEA...OYMENT SL V. ID = 3.00" I -13-1/2" X 3-3/16" XO, ID = 2.80" I -14-1/2" OTIS XN NIP, ID = 3.725" (BEHIND CT LNR) 4-1/2" BOT SHEA ROUT SUB, 10 = 4.000" (BEHIND CT LNR) ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/02/83 ANGLEATTOPÆRF: 43 @ 11366' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11366 - 11394 C 11/09/89 3-3/8" 4 11412-11432 C 05/18/92 3-3/8" 4 11484·11513 C 05/18/92 3-1/8" 4 11522-11542 C 03/11/84 3-1/8" 4 11552 - 11562 C 03/11/84 3-1/8" 4 11574 - 11600 C 03/11/84 3-1/8" 4 11608 -11632 C 01/19/86 4-1/2" TBG-PC,12.6#, L-80, .0152 bpt, 10 = 3.958" I 9-5/8" CSG, 47#, L-80, 10 = 8.681" I I TOP OF FLOW-BY WHIPSTOCK IPBID I IT' LNR, 29#, L-80, .0371 bpf. 10 = 6.184" DATE 05/11/83 07/14/87 04/25/02 08/16/04 08/20/04 09/30104 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER JDM/KK CTD SIDETRACK DA V ITLP SSSV CORRECTION LDKlTLP SET IBP RWUTLP REMOVEIBP@ 11045' ELM 11113' 11113' -14-1/2" TUBING TAIL I 11097' H ELMD TT LOGGED 11/16/92 11378' -13-3/16" X 2-7/8" XO. ID = 2.38" I ...-::---1 11580' H TOP OF SLID LNR I '..... ....., ... ... ... ... ... ... ....., ........... ...... 'i______ 12-7/8" SLIDLNR, 6.16#, L-80, .0055 bPf,:~H 12501' 11603' -1 BAKER 3-1/2" PIP PKR (04/03/02) I 11836' 11870' DATE 08/20/05 09/24/05 05/31/06 06/15/06 07/31/06 RBI BY COMMENTS RPH/TLH WAIVER SFTY NOTE DELETED MORlTLH L TIP SET (08/06/05) DTM WELLHEAD CORRECTION RCT/PJC PULL L TIP @ 11037 RRDlPAG SET BKR IBP PRUDHOE BA Y UNIT WELL: 13-29L 1 ÆRMIT No: "2020690 API No: 50-029-20928-60 SEC 14, T10N, R14E. 761' SNL & 1234' WEL BP Exploration (Alaska) -- e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 13-29Ll (prD #2020690) Internal Waiver Cancellation ) ) Subject: 13-29Ll (PTD #2020690) Internal Waiver Cancellation From: "Dube, Anna T" <Anna.Dube@BP.com> Date: Fri, 12 Aug 2005 14:01 :22 -0800 ~ £jZ¡.{DS Tø: "AOGCC - Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. jini _regg@admin.state.ak.us CC: "NSU, ADW Well h1tegrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com> Winton and Jim, The internal BP waiver for TxlA communication on well 13-29L 1 (PTD #2020690) has been cancelled. The well has recently developed IAxOA communication and no longer meets waiver criteria. It has been secured and re-classified as a trouble well. Although there are no immediate plans for repair, the well will be evaluated for future utility. Please let me know if you have any questions. Thank you, }l.nna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 , . ..."" 'en C) 'ii, ~2' Op\-i K.::6'" !C'.ì~\N\\EJ,; It:':¡ [/ b ,1l..·...",I'.' ~~~(ì~\.., " ,) "." 1 of 1 8/22/20054:05 PM 13-29Ll (PTD #2020690) Classified as Problem Well ) ) Subject: 13-29LI (PTD #2020690) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Wed, 11 Aug 200406:01:55 -0800 . .. To::. "Luedke-Chan, Beverly (pRA)" <LuedkeB@BP.com>, ."GPB, BS3 TL" <GPBFS3TL@BP.com>, "R~ssberg, RSteven" <RossbeRS@BP.com>, "NSU, ADW. Well Operations Supervisor" : <NSUADWWellOperationsSupervisor@BP.com>,"GPB, Wells Opt Eng" ... . . <GPBWellsOptEng@BP.com>~ "AOGCC Jim Regg (E-mail)" <jim~regg@admin.state..ak.ùs>,. tfAOOCC.Wintòn Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. '~NSU, ADWWL&.. Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, FSJ DS . operators" <GPBFS3DSOperators@BP.com> . . .. . .. . . ........ . . . .. . . CC: "NSU, ADW WeHIIitegrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Reeves, Donald.F" <ReeveSDf@BP.com>, "Lyon, Scott W" <Lyonsw@BP.com> . .... .. All, Well 13-29Ll (PTD #2020690) has been found to have sustained casing pressure on the OA. The TIO's on 08/9/04 were 1980/1980/1170 after bleeding the OA pressure. This well is currently waivered for TxIA communication and recently passed a NFT and MITOA. The plan forward for this well is as follows: 1. SL: Set plug to secure well 2. Cameron: Attempt to service IC packoffs to mitigate communication 3. SL: c/o GLVs, pull plug 4. DHD: TIFL well to determine if TxIA still exists post GLV changout, bleed OA pressure & monitor build-up rate 5. WIE: Eval if communication still exists, waiver well if needed A wellbore schematic has been included for reference. . «13-29Ll.pdf» The well has been classified as a Problem well. Please questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 call if you have any Content-Description: 13-29L1.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED NO\! n 3 2004 1 of 1 9/2/2004 8: 11 AM ) TREE = rvcEV OY GEN 3 WELLHEA D = CIW ACTUA TOR= AXELSON -KB:--ElBt-;'~--"~-- -.--.---- 83 ' BF.8..EV .;;.... "Rop = 3200' ïViäXÄïï"gië "";; ··..9f·@ffi~i3Öï· --D:itum MD-= . Dätumï\/Ó";;" 13-29L 1 - l13-3/8" CSG, 72#, L-80, ID = 12.347" H 2624' r---.J Minimum ID = 2.38" @ 11454' 3-3/16" X 2-718" XO ITOPOF7" LNR 1-1 11071' 4-1/2" BOT SHEA ROUT SUB, D =4.000" -I 11111' (BEHND CT LNR) 4-1/2"TBG-FC,12.6#, -1 11113' 1 L-80, .0152 bpf, ID =3.958" L :g: , '1 :8:-1 - ~ j 1 19-5I8"CSG, 47#, L-80, D =8.681" 1-1 11378' ~ ITOPOFFLOW-BYWHIPSTOa< I-{ 11366' ÆRFORA 1l0N SUMJ'v\ð. RY REF LOG: BHCS ON 05/02/83 ANGLE AT TOP PERF: 43 @ 11366' Note: Refer to Production DB for hstorical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 4 11366 - 11394 0 11/09/89 3-318" 4 11412 -11432 0 05/18/92 3-318" 4 11484 - 11513 0 05/18/92 3-118" 4 11522-11542 0 03/11/84 3-118" 4 11552-11562 0 03/11/84 3-118" 4 11574 -11600 0 03/11/84 3-118" 4 11608 -11632 0 01/19/86 PBTD [-I 11836' 17" LNR, 29#, L-80, .0371 bpf, ID= 6.184" H 11870' DATE 05/11/83 07/14/87 04/25/02 08/31/02 06/14/03 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOV~ CT D SIDETRAC K GL V C/O WAIVER SAFElY NOTE JDM/KK DTRITP JAIKAK ~I tlh , -.. DA. TE COMrÆNTS REV BY ) SAFETY NOTES: *** T X IA COM M. OP~ TING LlM ITS: MAX lAP = 2000 PSI; MAX OAP = 1000 PSI. (06/14/03 W AIV~) *** 2209' H4-1/2" C'AMWRDP-2 SSSV NIP, ID=3.812" ~ GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LA TCH PORT DA.TE 1 2899 2898 7 CAMCO DOWE RK 16 08/19/02 2 5218 4797 51 CAMCO DOME RK 16 08119102 3 7558 6262 49 MERLA C1v1Y TG 0 4 8783 7071 47 CAMCO DOME RK 16 08/19/02 5 9596 7615 48 MERLA C1v1Y TG 0 6 10116 7975 45 MERLA C1v1Y TG 0 7 10355 8148 44 MERLA C1v1Y TG 0 8 10631 8345 45 MERLA C1v1Y TG 0 9 10744 8424 46 MERLA C1v1Y TG 0 10 10854 8500 47 MERLA C1v1Y TG 0 11 10964 8575 46 CAMCO SO RK 22/64 08119102 10991' 1- 9-5/8" X 4-lIZ' BAKER SB-3 PKR AND SEAL BOREASSY, ID= 4.750 11037 1-14" BKRDe>LOYMENT SLV, ID =3.00" 11072' H 3-1/2" x 3-3116" XO, ID = 2.80" I 11100' H4-1/2" OTIS XN NIP, D = 3.725" (BB-IIND cr LNR) 11113' 1-14-1/2" TUBING TAIL I 11097 1-1 ELMD TT LOGGED 11/16/92 I ~ 11454' 1-13-3/16" X 2-7/8" XO, ID = 2.38" I ~ 11580' I-iTOP OF SL TD LNR 1 "~~ 12-7/8" SLTD LNR, 6.16#, L-80, .0055 bpf, ID = 2.38" H 12501' 11603' H BAKER 3-112" PIP PKR (04103102) 1 PRUDHOE BA Y UNIT WELL: 13-29L 1 PERMff No: 2020690 A A No: 50-029-20928-60 SEC 14, T1 ON, R14E, 761' SNL & 1234' WEL BP Exploration (Alaska) Permit to Drill 2020690 ;1'1 ('to¡ Áöt] ~ DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Well Name/No. PRUDHOE BAY UNIT 13-29L1 Operator BP EXPLORATION (ALASKA) INC ;p ~~ ;t~() f1¡a ~ ~ API No. 50-029-20928-60-00 REQUIRED INFORMATION MD 12501 .- 1VD 9014 ./ Completion Date 4/24/2002 Completion Status 1-01L Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Fnnt Number ~g I 4-W C Lk.og I ~Og DATA INFORMATION ~97 Well Cores/Samples Infonnation: Name ADDITIONAL INFORMATION Y/~ Well Cored? Chips Received? 'Y IN" Analysis Received? ~ Comments: ------ --- Compliance Reviewed By: Mud Log No Samples No Name Induction/Resistivity "^ t) Gamma Ray Induction/Resistivity 14 i) Production Log Log Run Scale Media No 25 Blu 1 1 1 1 25 Blu Blu Interval Start Stop Sent Received Daily History Received? Formation Tops ~ Current Status 1-01L UIC N Directional Survey $' C-/ (data taken from Logs Portion of Master Well Data Maint) Interval OH I Start Stop CH Received 11360 12484 Open 6/11/2002 11388 12501 Open 6/11/2002 11360 12484 Open 6/11/2002 '~- Comments 0 11500 Case 5/23/2003 GRlCCUPRESSrremp/Gra Ii dio/PILS/PFCS Sample Set Number Comments 0N @N '-- Date: ~ '1 ~1A; JJJ-ó '-f Schlumbeflger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well NK-14 \ q tc . O~lð NK-08A 20' .02Cj NK-20 I '1'3 ~ i q , NK-21 {q't f)~';; ~ . 0(., ~ NK-07A ~ l . O(.,.~ 4-18/5-30 , ~ 8 . . 4 ¿::¡ 1-33B/L-24,q2>. ,^-5~ 3-45/M-29 i ~.Ô - ò~ i D.S.15-47 ~C5 -,.4 0.5.17-11 'ß4- -a.~~ D.S.18-14A C16. 0°1 0.5. 13-29L 1 1-0"")..' CCøC} D.S.18-03A \.'14 - LO?- 0-05 . \,0. DO (, 0.5. 9-20 l"" . C Co.\- l E-13A I q, . 00 ~ 0.5.1-28 \7")Íc? . 0'\ 5 p.S.4-18 t ~~ : ?> ~~ J-23 \ -?, 1 . 0 3 \ N-20A lqip - 1'8 i.\- 0.5.1-34 r8(c -114 Job# Log Description SBHP SURVEY SBHP SURVEY SBHP SURVEY SBHP SURVEY SBHP SURVEY PSP GLS LDL INJECTION PROFILE LDL GLS LDL PRODUCTION PROFILE LDL PRODUCTION PROFILE INJECTION PROFILE SBHP SURVEY CHFR FLOWING BHP & TEMP LDL CHFR CHFR PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: -5 t~3:D.3 05/13/03 NO. 2781 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk Color Date Blueline Prints CD 04/20/03 1 04/19/03 1 04/20103 1 04/19/03 1 04/21/03 1 04/18/03 1 04/19/03 1 03/27/03 1 03/21/03 1 04/27/03 1 04/03/03 1 04/06/03 1 03/27/03 1 04/13/03 1 04/15/03 1 04/24/03 1 03/31/03 1 04/13/03 1 04/25/03 1 04/10/03 1 03/29/03 1 -' '-' Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 A TTN: Beth Received by: cP. &A.q- Sc~luIIIb.PleP Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth .~~, Well D.S. 13-29L1 J-Olo~ D.S. 13-29L 1 D.S. 13-29L 1 C-198 doo - 005 P2-53 Jq In - Dc.} I E-29 J ~7-0 ~ ~ S-29A / ql¿,.. 0 JJ X-21A Iq£}-IO~ R-188 lq¡-- J') X-28 9 '5 - J1 L/ D.S.3-07 J 7lJJ -O~~~ F~ Job # Log Descñption Date 22247 OH EDIT GR,ROP5 22247 MD VISION RESISTIVITY 22247 TVD VISION RESISTIVITY 22224 MCNL PROD PROFIDEFT PROD PROFILE LEAK DETECTION LOG GAS LIFT SURVEY PROD LOG/GLS INJECTION PROFILE INJECTION PROFILE 04/23/02 04/23/02 04/23/02 04/21/02 05/17/02 OS/27/02 05/15/02 OS/22/02 OS/28/02 OS/26/02 OS/23/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2- 1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED JUN 11 2002 AlalkaOil&GasCons,ConmWloo Ancttorage Blueline 06/06/02 NO. 2135 Company: State of Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Pñnts CD Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received ~(Á 000 ~ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well a 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 . I~' ..'.~.~ -, - ~-.. -"~ ":" '" ,:~,"....L. '''~'...."o....<I' 4. Location of well at sUrface¡;.lOCA~JONI~. 1.' CDI~/¡P.¡J'::f.'i(~t~ 761' NSL, 1234' WEL, SEC. 14, T10N, R14E, UM '. Vm' ~ '~ J DJ\!.}! .. i."; At top of productive interval ~ .. ."",' ~ r 2.. it- Q fA 287' NSL, 1896' WEL, SEC. 15, T10N, R14E, UM ~$u", .~.' .,~.~;~ VEfJÚ=lsi' "'!'. At ,total depth , ~,~:~~.\;~.lL.~.f ~. 2{f.(.._~ ~ 612 SNL, 1812 WEL, SEC. 22, T10N, R14E, UM ' !).'-~-""","¡'f~,,","~~~!~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 83' ADL 028314 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/20/2002 4/23/2002 4/24/2002 17. Total Depth (MD+ TVD)' 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 12501 9014 FT 12501 9014 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES Multilateral Classification of Service Well 7. Permit Number 202-069 8. API Number 50- 029-20928-60 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 13-29L 1 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) 2209' MD 1900' (Approx.) 23. CASING SIZE 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16'" GRADE H-40 L-80 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 163' 3-3/4" 2265# Poleset Surface 2624' 17-1/2" 1953 sx CS III, 400 sx CS II, Top Job Surface 11378' 12-1/4" 500 sx Class 'G', 300 sx CS I 11071' 11369' 11870' 390 sx Class 'G' 11037' 12501' 3-3/4" Uncemented Slotted Liner x 2-7/8" WT. PER FT. 91.5# 72# 47# 29# 8.81# / 6.2# /6.16# 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 11580' - 12499' 8950' - 9014' TVD MD AMOUNT PULLED 97 sx CS II TUBING RECORD DEPTH SET (MD) 11113' PACKER SET (MD) 1 0991' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11367' Set Flow-By Whipstock on top of PIP packer 2500' Freeze Protected with 38 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 7,2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL 5/7/2002 18.1 TEST PERIOD 1097 Flow Tubing Casing Pressure CALCULATED OIL-BSL Press. 24-HoUR RATE 28. CORE DATA ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit èore.ch1ps.. GAs-McF 323 GAs-McF WATER-BsL 2533 WATER-BBL No core samples were taken. Form 10-407 Rev. 07-01-80 GAS-OIL RATIO 294 CHOKE SIZE 85 OIL GRAVITY-API (CORR) ~ I' ~ A " I: r\f jj ¡ I ¡ \.; ¡ ~ "'"- RBDMS BFL MAY 3 I 2002 r-' :J\-"" Submit In Duplicate ') ') 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. Shublik A 11387' 8873' Shublik B 11423' 8895' Shublik C 11467' 8915' Sadlerochit 11582' 8950' 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 TerrieHubble-Y~.~ Title Technical Assistant 13-29L 1 202-069 Well Number Permit No. / Approval No. Date DS-;J3.o-, " 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', Form 10-407 Rev. 07-01-80 ) ) Well: Field: API: Permit: 13-29L 1 Prudhoe Bay Unit 50-029-20928-60 202-069 Rig Accept: 04/17/02 Rig Spud: 04/20/02 Rig Release: 04/24/02 Drilling Ri~: Nabors 3S PRE-RIG WORK 03/15/02 MIT-OA TO 1000 PSI PASSED. (CTD PREP) PT MASTER, WING, AND SWAB, FAILED. PPPOT-T. 03/16/02 PT MASTER, WING AND SWAB VALVES, FAILED AFTER VALVE SHOP SERVICED TREE. (CTD PREP) 03/17/02 PPPOT-T PASSED 5000 PSI TEST (CTD PREP). 03/19/02 DRIFTrrAG W/3.65" DUMMY WHIPSTOCK. TAG BOTTOM @ 11,603' SLM. RUN PDS CALIPER OF TBG & LINER. 03/20/02 SET CATCHER SUB, PULL OGLV (TG) FROM GLM #11 AND LGLV'S (TG LATCHES) FROM GLM'S #2 AND #1. SET DGLV'S W/RK LATCHES IN GLM'S #2 AND #1. PUMPING CRUDE TO LOAD I/A IN PROGRESS. MIT IA WITH SLlCKLlNE. 03/21/02 CONTINUE MIT IA FILL IA 700 BBLS CRUDE ATTEMPT TO PRESSURE UP WITH 70 BBLS CRUDE. SET DGLV'S IN GLM'S #2 & #11. SET DGLV IN GLM # 1 AND ATTEMPT TO MITIA WI NO SUCCESS. SET 4- 1/2" PXN PLUG IN XN NIPPLE @ 11067' SLM (PRONG 94" LONG WI 1.75" FN). FLOW TESTED WELL FROM 1650# DOWN TO 950# TUBING PSI, HELD PRESSURE. PUMP TRUCK TO COME OUT FOR COMBO MIT AND FREEZE PROTECT FLOW LINE @ LATER TIME. WELL LEFT SHUT IN. MIT COMBO TBG AND lA, PUMPED 88 BBLS DOWN TUBING PRESSURED UP TO 1500 PSI, IA TRACKS WITH TUBING. FREEZE PROTECT FLOWLINE WITH 195 BBLS OF DEAD CRUDE AND 12 BBLS OF NEAT. 03/22/02 MIT COMBO TBG AND lA, PUMPED 88 BBLS OF DEAD CRUDE DOWN TBG, PRESSURED UP TO 1500 PSI, IA TRACKED WITH TBG. 03/24/02 CMIT TXIA PASSED TO 2500 PSI (PRE-CTD). 03/26/02 PULLED 4-1/2" PXN PLUG FROM 11067' SLM. LEFT WELL SHUT IN. 04/02/02 SET TOP OF 31/2" BAKER PIP PACKER (10' OAL) AT 11465'. SET DOWN ON PLUG TO CONFIRM POSITION. DEPTH CORRELATED TO DRESSER ATLAS CBUVDL LOG DATED MAY 6,1983. WILL SET WHIPSTOCK IN AM, LEAVE WELL SHUT IN. 13-29L 1, Coil Tubing Drilling, \J¡, ,ltera' Page 2 ') 04/03/02 SET 7" X 41/2" BAKER WHIPSTOCK @ 11366' WI RA TAG AT 11376' (ORIENTED 10 DEG LEFT OF HIGH SIDE). TAG WHIPSTOCK AND LOG OFF TO CONFIRM SETTING DEPTH. NOTE: BAKER 3 1/2" PIP PACKER ORIGINALLY SET @ 11465' HAS MOVED. TAGGED PBTD @ 11603' AND NEVER SID ON PIP. DEPTHS CORRELATED TO DRESSER ATLAS CBUVDL LOG DATED MAY 6,1983. NOTIFY PAD OPER OF WELL STATUS. LEAVE WELL SHUT IN. 04/07/02 MIRU CTU#8. MU MULESHOE, RIH TO 11,000'. PUMP WELL KILL. TAG WHIPSTOCK @ 11,382' (CTD). PU 11,378', PUMP 27.5 BBLS SLURRY (150-200K LSRV, 2% KCL, 20# MED/1 0# FINE CAC03). POOH TO TT. PREP SECOND BATCH OF SLURRY. PUMP 27 BBLS SAME CAC03 SLURRY, HOLDING SLIGHT POSITIVE PRESSURE. FREEZE PROTECT TOP 2500' WITH METH. WELL SI AND READY FOR TWC. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-29 13-29L 1 REENTER+COMPLETE NABORS NABORS 3S Start: 4/17/2002 Rig Release: 4/24/2002 Rig Number: Spud Date: 4/18/1983 End: 4/24/2002 /-fours<Activity 4/17/2002 17:00 - 18:00 1.00 RIGU P PRE 18:00 - 20:30 2.50 RIGU P PRE 20:30 - 22:00 1.50 RIGU P PRE 22:00 - 00:00 2.00 RIGU P PRE 00:00 - 04: 15 4.25 RIGU P PRE 04:15 - 05:00 0.75 RIGU P PRE 05:00 - 05:20 0.33 RIGU P PRE 05:20 - 08: 15 2,92 RIGU P PRE 08:15 - 09:00 0.75 RIGU P PRE 09:00 - 10:00 1.00 RIGU P PRE 10:00 - 11 :00 1.00 RIGU P PRE 11 :00 - 12:00 1,00 STWHIP P WEXIT 12:00 - 15:00 3.00 STWHIP N WAIT WEXIT 15:00 -16:30 1.50 STWHIP P WEXIT 16:30 -18:45 2.25 STWHIP P WEXIT 18:45 - 20:30 1,75 STWHIP P WEXIT 4/18/2002 20:30 - 21 :30 1.00 STWHIP P WEXIT 21 :30 - 00:00 2.50 STWHIP P WEXIT 4/19/2002 00:00 - 01 :35 1.58 STWHIP N DPRB WEXIT 01 :35 - 03:30 1.92 STWHIP N DPRB WEXIT 03:30 - 04:30 1.00 STWHIP N DPRB WEXIT 04:30 - 06:30 2.00 STWHIP N DPRB WEXIT 06:30 - 06:45 0.25 STWHIP N DPRB WEXIT 06:45 - 07:30 0.75 STWHIP N DPRB WEXIT 07:30 - 10:00 2.50 STWHIP N DPRB WEXIT 10:00 - 16:30 6.50 STWHIP P WEXIT 16:30 - 17:30 1.00 STWHIP P WEXIT 17:30 - 18:30 1.00 STWHIP P WEXIT 18:30 - 18:45 0.25 STWHIP P WEXIT 18:45 - 20:30 1.75 STWHIP P WEXIT 20:30 - 22:15 1.75 STWHIP P WEXIT 22:15 - 23:00 0.75 STWHIP N DPRB WEXIT Move from W-Pad to DS 13. Position rig over well. Accept rig 17:00 hrs. Rig up. Nipple UP BOP. Function test rams. Continue rigging up. Grease x-tree valves. Pull SPY. Set test plug. CTU on location. Start BOP test. Continue BOPE test. Witness by AOGCC's Lou Grimaldi. Pulltest plug. PJSM, Change pack off and brass. Rehead. Pull and PT CTC. RU divert tanks and hardline. Pump ball thru new coil (14200'; calc volume = 54.9 bbls). Bump at 55.8 bbls. Retrieve ball from coil. Rehead again. Fill well. Monitor losses. 5 BPH max. MU milling BHA: tapered diamond mill, string mill, BHI motor. Wait on getting divert tanks RU. Pressure test backside lines. Displace methanol out of coil to open top. RIH with milling BHA. Tag XN nipple. Correct depth to 11084' (-11'). Losses at 70%. Mill XN 2.5/07. Mostly crude in returns. Known communication to lA, and IA liquid packed with crude. lAP = 800 psi. Tougher than normal getting thru XN -- 13 stalls. Dry passes clean. RIH. Tag whipstock dry 11362.5'. Slight OP on PU. RIH with pumps, tagged deeper 11367.2', Stall here. Call this the pinch point. Continue diverting crude returns to tiger tank. Start milling window. Stalling out. Continue milling window. Stalling. Unable to made progress. Decide to POH to check motorlmill Mix LCM pill. 30 bbls pill. 15 ppb Mix II fine-15 ppb mix II med. Pump LCM pill. Shut in backside. Squeeze to 530 psi. Slow response. Monitor well. 2.5/2.2. POOH to check tools. Safety meeting. LD BHA. Diamond mill worn on gage -- 3.76" 00. String mill had some wear, but in gage. Put on new diamond mill and motor. RIH. Tag 11381' uncorrected. Mill 2.7/2.3 and 1700 psi. Good steady milling. Weight gain at 11388' uncorrected. Must have popped out. Drill 12' of formation at 15 FPH to 11400' uncorrected Ream and backream window several times. 2.7/2.3. Dry tag clean. Correct (-12') to get to ELMO: Window = 11369' - 11376'. TO = 11388'. Crew change safety meeting Clean pits, get ready for mud swap. Continue reaming window. Swap mud. Mud at surface. Losses more severe with mud in the ground: 2.7/1.4 (lost another 1.0 BPM due to increased ECD). Drop ball to open circ sub. Pump LCM pill. 15 bbls of 5 ppb MI seal fine-15 ppb MI Mix II Printed: 4/30/2002 3:13:23 PM ) ") Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-29 13-29L 1 REENTER+COMPLETE NABORS NABORS 3S Date Frdrrl.;.To I-Ipurs Activity Code. .NPT Phase 4/19/2002 22: 15 - 23:00 0.75 STWHIP N DPRB WEXIT 23:00 - 00:00 1.00 STWHIP N DPRB WEXIT 00:00 - 01 :20 1.33 STWHIP N DPRB WEXIT 01 :20 - 02:40 1.33 STWHIP N DPRB WEXIT 02:40 - 04:00 1.33 STWHIP N DPRB WEXIT 04:00 - 05:30 1.50 STWHIP N DPRB WEXIT 05:30 - 05:50 0.33 STWHIP N DPRB WEXIT 05:50 - 07:30 1.67 STWHIP P WEXIT 07:30 - 08:30 1.00 STWHIP P WEXIT 08:30 - 09:00 0,50 DRILL P PROD1 09:00 - 11 :00 2.00 DRILL P PROD1 11 :00 - 12:30 1.50 DRILL P PROD1 4/20/2002 12:30 - 12:50 0.33 DRILL P PROD1 12:50 - 15:00 2.17 DRILL P PROD1 15:00 - 15:45 0.75 DRILL N DFAL PROD1 15:45 - 16:00 0.25 DRILL P PROD1 16:00 - 16:30 0.50 DRILL N DFAL PROD1 16:30 - 16:40 0.17 DRILL P PROD1 16:40 - 17:45 1.08 DRILL N DFAL PROD1 17:45 - 20:20 2.58 DRILL N DFAL PROD1 20:20 - 20:30 0.17 DRILL N DFAL PROD1 20:30 - 00:00 3.50 DRILL N DFAL PROD1 4/21/2002 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 01 :30 - 02:15 0.75 DRILL P PROD1 02:15 - 02:30 0.25 DRILL P PROD1 02:30 - 08:50 6.33 DRILL P PROD1 08:50 - 09:20 0.50 DRILL N SFAL PROD1 09:20 - 10:40 1.33 DRILL P PROD1 Start: 4/17/2002 Rig Release: 4/24/2002 Rig Number: Spud Date: 4/18/1983 End: 4/24/2002 med-15 ppb Mix II fine, Close returns to reduce rate, Monitor returns. Improvement, but still losing 0.4 - 0.6 bpm. Mix another pill. Wait on mud Pump LCM pill. 15 bbls 15 ppb MX F-15 ppb MXM 3 ppb MI seal Fine -5 ppb MI seal medium. Erratic response. Losses stabilizes in 0.5 bpm. Order 3rd pill of the night. Mixing third LCM pill: 15 bbls of 15 ppb Mix II fine, 15 ppb Mix II medium, 5 ppb MI seal fine, 8 ppb MI seal medium. Pump LCM. Close returns, Once pill out of coil pump 3 bbls through backside. Pressure up to 920 psi. Monitor well. Have 1: 1 returns. POH. Flag pipe at 11000' EOP. LD milling BHA. MU drilling BHA: M09 bit, 2.8 deg motor, MWD GR, TORC orienter, Shallow test good. RIH, Lots of LCM over shakers. Correct depth at flag (-16'). RIH. Can't get thru window at 50R TF. PUH and send TORC commands. Struggle executing commands to get TF to move to the left at 90% modulationg. Send commands to move to right at 93% modulation. Worked. RIH at highside TF. Tag TD 11385'. Orient 40L. Drill 2.6/2.5 on MM. Losing lots of mud over shakers (LCM plugging shaker screen). Able to make TF changes while on bottom drilling. Drill to 11436' Pump up survey. Not getting the survey. Suspect surface software problem. Drill a little more while trying to fugure out surface problem. Drill to 11440', Try pumping up survey again -- didn't get anything. May not be surface problem. Originally we could see survey getting sent, but they weren't getting decoded. Now we're not seeing anything. Drill to 11446' while rebooting everything. Try the survey again. Nope. But able to get survey frame up in cased hole. Try open hole. No survey. Diagnostics suggest downhole failure. POOH for MWD failure. OOH. Change out MWD. Pull test CT connector. PT MHA. OK. RIH wI new MWD. SHT. OK. Continue RIH Contiue RIH. Stop at flag. Correct depth (-12'). RIH to TD. Tag bottom at 11447'. Drill ahead, 2.6/2670/66L. Drill to 11457 Survey. Good. Drill. 2.6/2660/66L, near full returns. Orient on the fly to 90L. Typical Shublik drilling at about 20 FPH. Losses about 0.1 - 0.2 BPM. Drilling break 11560' -- might be 24. Drill to 11568' Pump up survey so that Anadril can continue to get continuous surveys after rebooting their computer in order to print a log -- interesting. Drill to 11643'. Losing 10 - 15 BPH. Probably still losing to 7" completion, Printed: 4/30/2002 3:13:23 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 13-29 13-29L 1 REENTER+COMPLETE NABORS NABORS 3S From.:-..To I-Iqufs.ActivitYGode NPT Phase 4/21/2002 10:40 -11:00 11:00-11:15 11:15 - 12:00 12:00 - 14:15 14:15 - 16:30 16:30 - 17:00 17:00 - 19:45 19:45 - 20:00 20:00 - 20:30 20:30 - 22:30 22:30 - 00:00 4/22/2002 00:00 - 02:50 02:50 - 03:20 03:20 - 05:00 05:00 - 05:45 05:45 - 06: 15 06:15 - 08:00 08:00 - 08:30 08:30 - 08:50 08:50 - 09: 1 0 09:10 - 09:50 09:50 - 11 :10 4/23/2002 11: 10 - 11 :50 11 :50 - 12:50 12:50 - 13:10 13:10 -14:00 14:00 - 14:45 14:45 -17:15 17:15 - 17:40 17:40 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 21 :30 21 :30 - 22:10 22:10 - 22:45 22:45 - 23:30 23:30 - 00:00 00:00 - 02:30 0.33 DRILL P 0.25 DRILL P 0.75 DRILL P PROD1 PROD1 PROD1 2.25 DRILL P 2.25 DRILL P 0.50 DRILL P 2.75 DRILL N PROD1 PROD1 PROD1 DPRB PROD1 0.25 DRILL N DPRB PROD1 0.50 DRILL N 2,00 DRILL P 1.50 DRILL P DPRB PROD1 PROD1 PROD1 2.83 DRILL 0.50 DRILL 1.67 DRILL 0,75 DRILL 0.50 DRILL 1,75 DRILL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 P P P P P P 0.50 DRILL P PROD1 0.33 DRILL P 0.33 DRILL P 0.67 DRILL P PROD1 PROD1 PROD1 1.33 DRILL P PROD1 0.67 DRILL 1.00 DRILL 0.33 DRILL 0.83 DRILL 0.75 DRILL 2.50 DRILL 0.42 DRILL 0.33 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 0.67 DRILL 0.58 DRILL 0.75 DRILL 0.50 DRILL 2.50 DRILL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 P P P P P P P P P P P P P P P P P P Start: 4/17/2002 Rig Release: 4/24/2002 Rig Number: Spud Date: 4/18/1983 End: 4/24/2002 Wiper to window. Survey Drill. Top Sad coming in 10' - 15' shallow. Geo says to land shallower than plan. Nose it up for a few feet, then back to 90L. Took three command attempts while drilling to get TF change. Drill to 11670', Landed. POOH for planned motor change. LD BHA. MU DS49, 1.1 deg motor, resistivitiy. RIH at minimum rate. Bring pumps up to do shallow hole test at 3500'. Can't circulate thru coil. something plugged. POOH. Check BHA. Some fine LCM material on MWD probe cause of plugging. RIH SHT. OK RIH. Correct -26' @flag. RIH to TD MAD pass. Made pass on real time mode as per town geologist request. Loosing 10 bph. MAD pass. Tie in w/GR. +20' correction. Drill ahead 2.6 and 88TF. Drill to 11776'. Drill to 11794'. Stacking. Wiper to window. Drill 2.6/2.4 and 2950 psi FS to 11890'. Drilling with negative weight, lots of stacking. Start mixing lubetex pill. Wiper trip to window. Pyrite in samples suggest near top of Sad, Will need to nose it down some. Pump up survey. Drill to 11918'. Pump 10 bbllubetex pill (1 drum in 30 bbls). Send command to change from continuous rotation to 180 TF. Need to send it a command to stop first. Drill 175R for a few feet, then back to continuous rotating. Losses at 12 BPH. Still have poor slide (110' long anchor), requiring lubetex pills to get us moving. Note: continuous rotating does not seem to help our slide. Drill to 12000'. Stacking. Wiper trip to window, Drill 2.6/2.5 with continuous rotation to 12060'. 100' wiper, Drill to 12120'. Stacking. Wiper to window. Drill to 12235'. Pump up survey. Drill 12253'. Stall here. Wiper trip to window. DriIl2.6/3320/86R. ROP 80 ftlhr. Drill to 12292', Pump survey. Short trip 100'. Stacking out. Stalling out. Short trip 100'. Continie rotating TORC. Drill ahead. 2.5/3330/82L. Drill to 12345'. Pump survey. Got stuck. Work pipe free. drill to 12372' Wiper trip to the window. Drill ahead. 2.5/3400. Drill to 12447'. Printed: 4/30/2002 3: 13:23 PM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-29 13-29L 1 REENTER+COMPLETE NABORS NABORS 38 Date From-To HQUrs Activity Code NPT Phase 4/23/2002 PROD1 PROD1 02:30 - 03:20 0.83 DRILL P 03:20 - 04:10 0.83 DRILL P 04: 1 0 - 05:00 0.83 DRILL P 05:00 - 06: 15 1,25 DRILL P 06:15 - 08:30 2.25 DRILL N 08:30 - 09: 15 0.75 DRILL P 09:15-12:00 2.75 DRILL P 12:00 - 13:00 1,00 DRILL P 13:00-13:15 0.25 CASE P 13:15 - 15:30 2.25 CASE P 15:30 - 16:30 1.00 CASE P 16:30 - 18:30 2.00 CASE P 18:30 - 19:00 0.50 CASE P 19:00 - 19:30 0.50 CASE P PROD1 PROD1 SFAL PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP 19:30 - 20:00 0,50 CASE P 20:00 - 21 :30 1.50 CASE P 21 :30 - 22:30 1.00 CASE P 22:30 - 00:00 1.50 CASE N 4/24/2002 00:00 - 02:00 2.00 CASE N 02:00 - 03:00 1.00 CASE P 03:00 - 05:00 2.00 CASE P 05:00 - 08:30 3.50 CASE P COMP COMP COMP WAIT COMP WAIT COMP COMP COMP COMP Start: 4/17/2002 Rig Release: 4/24/2002 Rig Number: Spud Date: 4/18/1983 End: 4/24/2002 pescti ption ()fOperations Short trip 200' Drill ahead. Hard drilling. Shift on resistivity, Call TD @ 12494'. Wiper trip to the window. Log tie-in. Not definitive. Nabors pump washing out. Switch to Dowell pump. Log tie-in. Correct depth (+8'). RIH and tag TD 12501' corrected. POOH, laying in new mud in open hole, Flags at 10890' and 9800' EOP. LD drilling BHA. Safety meeting. P/U liner M/U CTLRT. P/U injector and stab on well. RIH wI liner. Pumping at 0.33 bpm @1200 psi. RIH to 11300', Wt up 43K, wt dwn 15k. Pass through window wlo problems. Tag TD. P/U 50k#, Set down 10k. Drop 5/8" steel ball. Displace ball wlmud @2.5 bpm/2500 psi. At 40 bbls slow rate to 1,2 bpm/1660 psi. At 43 bbls slow rate to 0.75 bpm/1400 psi. 45.4 bbls away. Ball on seat. Pressure up to 3150 psi. P/U wt 38k. Liner released. Displace well to KCI. POH to 400 '. Found out methaol tank manifold frozen. Ask for more methanol. POH to 200' to FP,Wait on methanol. Wait on methanol. POH. OOH. LID liner running tools. FP to 2000'. Set BBV. RID CTU #4 road to Deadhorse for routine maint. NID BOPE. Install tree cap and PT to 3500 psi. Nabors 3S released at 0830 hrs 4-24-2002 Printed: 413012002 3: 13:23 PM ANADRILL SCRLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay Well.....................: DS 13-29L1 API number...............: 50-029-20928-60 Engineer. . . . . . . . . . . . . . . . .: M. Aburto RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 3S / SLB Unit # 4 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference....... . . .: GR Tie-In @ 11376 ft GL above permanent.......: 0.00 ft KB above permanent.......: N/A - GR Tie In DF above permanent.......: N/A - GR Tie In ----- Vertical section origin---------------- La tit ude ( + N / S -) . . . . . . . . . : 0 . 00 f t Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : - 999 . 25 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 192.54 degrees [(c)2002 Anadrill IDEAL ID6_1C_10J 23-Apr-2002 10:28:35 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 2 20-Apr-02 23-Apr-02 28 11300.00 ft 12501.00 ft °--° ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date............: 18-Apr-2002 Magnetic field strength..: 1150.17 RCNT Magnetic dec (+E/W-).....: 26.42 degrees Magnetic dip.............: 80.77 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: R. . . . . . . . . . . . . . : Dip. . . . . . . . . . . . : of G...........: of R...........: of Dip. . . . . . . . . : Criteria --------- 1002.67 mGal 1150.16 RCNT 80.77 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees .~,' ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.43 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.43 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 1 2 3 4 5 11300.00 11366.00 11421.34 11466.00 11497.49 ------ ------ Incl angle (deg) ------ ------ 43.78 43.53 58.40 66.59 70.93 73.08 74.84 79.05 83.83 88.01 87.08 86.19 85.47 88.53 90.10 90.72 89.42 88.46 87.74 89.49 87.91 87.73 87.63 87.08 85.64 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 281.67 282.00 270.53 256.21 245.31 232.31 223.57 201.76 188.23 175.68 174.13 172.21 171.47 165.41 168.16 176.87 167.76 164.60 162.25 167.09 171.36 168.18 171.75 175.45 180.88 81.47 179.54 78.33 180.46 74.00 180.00 ------ ------ 0.00 66.00 55.34 44.66 31.49 27.33 39.17 40.54 35.30 36.17 38.31 45.33 41.87 28.13 41.75 58.88 44.35 48.80 40.58 37.06 34.02 47.48 48.94 52.25 57.75 53.00 40.50 66.00 [(c)2002 Anadrill IDEAL ID6_1C_10J 6 7 8 9 10 11524.82 11563.99 11604.53 11639.83 11676.00 11 12 13 14 15 11714.31 11759.64 11801.51 11829.64 11871.39 16 17 18 19 20 11930.27 11974.62 12023.42 12064.00 12101.06 21 22 23 24 25 12135.08 12182.56 12231.50 12283.75 12341.50 26 12394.50 27 12435.00 28 12501.00 -------- -------- TVD depth (ft) -------- -------- 8728.86 8776.61 8811.44 8832.13 8843.56 8852.04 8862.89 8872.15 8877.43 8880.01 8881.66 8884.32 8887.37 8888.84 8889.34 8888.92 8888.87 8889.77 8891.11 8892.01 8892.78 8894.59 8896.58 8899.00 8902.67 8908.62 8915.72 8931.50 23-Apr-2002 10:28:35 -------- -------- Vertical section (ft) -------- -------- 1651.67 1652.23 1657.35 1670.48 1685.94 1703.87 1734.53 1771.38 1806.16 1841.54 1878.01 1920.70 1959.77 1985.39 2022.98 2078.25 2119.82 2163.54 2198.96 2231.71 2262.93 2306.67 2351.82 2401.18 2456.98 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Page 2 of 2 --------------- --------------- Total displ (ft) ---------------- ---------------- -418.00 -408.66 -404.44 -409.18 -418.87 -432.31 -457.51 -490.57 -524.20 -560.18 -598.30 -643.23 -684.56 -712.07 -752.70 -811.02 -854.93 -902.30 -941.17 -976.89 -1010.29 -1056.98 -1105.12 -1156.98 -1214.56 -5727.89 -5772.48 -5815.01 -5854.16 -5881.80 -5903.96 -5931.87 -5952.98 -5961.96 -5963.17 -5959.77 -5954.39 -5948.46 -5942.83 -5933.29 -5925.63 -5919.70 -5908.05 -5896.48 -5886.69 -5880.33 -5871.91 -5863.39 -5857.57 -5855.72 At Az i m ( deg ) DLS (deg/ 100f) --------------- --------------- 5743.12 5786.93 5829.06 5868.44 5896.69 5919.77 5949.49 5973.16 5984.96 5989.43 5989.73 5989.03 5987.73 5985.34 5980.84 5980.87 5981.12 5976.55 5971.12 5967.19 5966.49 5966.28 5966.62 5970.74 5980.35 265.83 265.95 266.02 266.00 265.93 265.81 265.59 265.29 264.98 264.63 264.27 263.83 263.44 263.17 262.77 262.21 261.78 261.32 260.93 260.58 260.25 259.80 259.33 258.83 258.28 2508.42 -1267.21 -5855.92 5991.46 257.79 2547.34 -1307.08 -5855.91 6000.01 257.42 2609.93 -1371.15 -5856.17 6014.54 256.82 0.00 0.51 31.25 33.79 35.07 45.93 21.89 53.42 40.20 36.51 4.71 4.65 2.46 24.14 7.60 14.83 20.75 6.77 6.05 13.88 13.38 6.70 7.29 7.15 9.70 ------ ------ Srvy tool type Tool qual type ------ ------ TIP MWD SP MWD MWD SP MWD SP SP MWD .~ SP MWD MWD SP MWD MWD MWD MWD MWD MWD ---. MWD SP SP SP MWD 8.26 MWD 8.06 MWD 6.59 Proj. bp DS13-29L 1 Schlumbepgep Survey Report - Geodetic Report Date: 30-Apr-2002 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 192,540° Field: Prudhoe Bay Unit - EOA (Drill Sites) Vertical Section Origin: N 0,000 ft, E 0.000 ft Structure I Slot: OS-13/13-29 TVD Reference Datum: MSL Well: 13-29 TVD Reference Elevation: 0.000 ft relative to MSL Borehole: 13-29L 1 UWUAPI#: 500292092860 Magnetic Declination: +26.413° Survey Name I Date: 13-29L 1 I April 30, 2002 Total Field Strength: 57508.484 nT Tort I AHD I DDII ERD ratio: 285.907° /6930.17 ft 16.443 I 0,776 Magnetic Dip: 80.772° Grid Coordinate System: NA027 Alaska State Planes, Zone 4, US Feet Declination Date: April 30, 2002 ~ Location Lat/Long: N 701257,232, W 1482958,295 Magnetic Declination Model: BGGM 2001 Location Grid N/E Y/X: N 5930797.810 ftUS, E 686012.050 ftUS North Reference: True North Grid Convergence Angle: + 1.41194489° Total Corr Mag North -> True North: +26.413° Grid Scale Factor: 0,99993931 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) n (°) (ft) (ft) (ft) (ft) (" 11 OOft) (ftUS) (ftUS) 0,00 0,00 180,00 -83,00 0.00 0.00 0,00 5930797,81 686012.05 N 70 1257.232 W 1482958.295 100,00 0.10 251.60 17.00 0.04 -0.03 -0.08 0.10 5930797.78 686011.97 N 70 12 57.232 W 148 29 58.297 200,00 0.23 201.90 117.00 0.29 -0.24 -0,24 0.18 5930797.56 686011.82 N 701257.230 W 1482958.302 300,00 0.35 223.48 217.00 0.75 -0.65 -0,53 0.16 5930797,15 686011.54 N 70 1257.226 W 1482958,310 400,00 0.27 230.00 317.00 1.20 -1.02 -0.92 0.09 5930796.77 686011.16 N 70 1257.222 W 1482958,321 500,00 0.23 216.10 417.00 1.57 -1.34 -1,21 0.07 5930796.44 686010.87 N 701257,219 W 1482958,330 600,00 0.22 181.90 517.00 1.94 -1.69 -1.34 0.13 5930796.09 686010.75 N 70 1257.216 W 1482958.334 700,00 0.12 158.35 616.99 2.22 -1.98 -1.31 0.12 5930795.80 686010.79 N 70 1257.213 W 1482958,33' 800,00 0,12 198.77 716.99 2.41 -2.18 -1,30 0.08 5930795.60 686010.80 N 701257.211 W 148 29 58.33~ 900,00 0.18 210.67 816.99 2.66 -2.41 -1.42 0,07 5930795,37 68601 0.69 N 701257.209 W 1482958.336 1000.00 0.13 258.43 916.99 2.86 -2,57 -1.61 0.13 5930795.20 686010.51 N 70 1257.207 W 1482958.341 1100,00 0.23 308.05 1016.99 2.82 -2.47 -1.88 0.18 5930795.30 686010.23 N 701257.208 W 1482958,349 1200.00 0.38 320.60 1116.99 2.52 -2.09 -2.25 0.16 5930795.67 686009.86 N 70 1257.212 W 1482958,360 1300.00 0.38 318,83 1216.99 2.12 -1.58 -2.67 0.01 5930796.16 686009.42 N 70 1257.217 W 1482958.372 1400,00 0.47 264.97 1316.99 2.05 -1.37 -3,30 0.39 5930796.36 686008,78 N 701257.219 W 1482958.390 1500.00 0,52 247.22 1416.98 2.44 -1.58 -4.13 0.16 5930796.13 686007.96 N 701257.217 W 1482958.414 1600,00 0.48 244.12 1516.98 2.96 -1,94 -4.92 0.05 5930795.75 686007.18 N 70 1257.213 W 1482958.438 1700.00 0,52 217,27 1616.98 3.63 -2.48 -5.57 0.24 5930795.19 686006.54 N 701257.208 W 1482958.456 DS13-29L 1 ASP Final Survey,xls Page 1 of 5 5/13/2002-10:41 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S Ef-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (° /1 OOft) (ftUS) (ftUS) 1800.00 0.55 207.12 1716.97 4.51 -3.27 -6.07 0.10 5930794.39 686006,06 N 70 1257,200 W 1482958.471 1900.00 0,75 204.72 1816.97 5.61 -4.29 -6.56 0.20 5930793.36 686005,60 N 701257.190 W 1482958.485 2000.00 0,95 228,02 1916.95 6.93 -5.44 -7.45 0.40 5930792.19 686004.74 N 70 1257.179 W 1482958,511 2100,00 0.95 252,98 2016.94 8.01 -6.24 -8.86 0.41 5930791,36 686003.35 N 701257,171 W 1482958.552 2200.00 0.85 270,80 2116.93 8,57 -6.47 -10.39 0.30 5930791.09 686001.82 N 701257.169 W 1482958,596 2300,00 0.33 307,93 2216.92 8.60 -6.28 -11.36 0,62 5930791,25 686000.85 N 701257.170 W 1482958.625 2400,00 0.63 68,63 2316.92 8.17 -5.91 -11.08 0.85 5930791 .63 686001.12 N 701257.174 W 1482958,616 2500.00 0,95 96.97 2416,91 7.78 -5.81 -9.74 0.50 5930791.77 686002.45 N 701257.175 W 1482958.578 2600.00 1,00 127.97 2516.90 8.08 -6.44 -8,23 0.52 5930791.17 686003.98 N 701257.169 W 1482958.53- 2700.00 1.93 177,10 2616.87 10.07 -8.66 -7.46 1.48 5930788.97 686004.81 N 701257.147 W 148 29 58.51~. 2800.00 4,83 206.38 2716.69 15.79 -14.12 -9.25 3,28 5930783.47 686003,16 N 701257.093 W 1482958.563 2900.00 6,65 243,78 2816.22 23.50 -20.45 -16,31 4.06 5930776,97 685996.25 N 70 1257.031 W 1482958.768 3000,00 7,83 248.20 2915.42 30,97 -25.54 -27,83 1.30 5930771.60 685984.86 N 70 1256.981 W 1482959.103 3100,00 8.48 249,57 3014.41 38.83 -30.64 -41.07 0.68 5930766.17 685971.75 N 70 1256.931 W 1482959.487 3200,00 10,77 256.48 3113.00 46.94 -35.40 -57,06 2.56 5930761.02 685955,88 N 70 1256.884 W 1482959.951 3300,00 13.43 261 .28 3210,77 55.26 -39.35 -77.63 2.84 5930756,57 685935.42 N 70 1256.845 W 148300.549 3400,00 16,38 259.55 3307.39 64.98 -43.66 -102,98 2.98 5930751.62 685910.18 N 70 1256.803 W 148301,285 3500,00 18.48 260.10 3402.80 76.54 -48.95 -132.46 2.11 5930745.62 685880.84 N 70 1256,751 W 148302,141 3600,00 20.52 260.88 3497.06 89.06 -54.45 -165.39 2.06 5930739.30 685848.07 N 70 1256.697 W 148303.096 3700,00 22.93 261.37 3589.95 102.57 -60.15 -201,96 2.42 5930732.70 685811.65 N 701256.641 W 148304.158 3800,00 25,07 261.85 3681.30 117.09 -66.08 -242.19 2.15 5930725.79 685771.57 N 70 1256,582 W 148305,326 3900.00 27,67 262.02 3770.88 132.72 -72.31 -286,17 2.60 5930718.48 685727.77 N 70 1256.521 W 148306,603 4000.00 31.12 262.22 3858.00 149.83 -79,03 -334.78 3.45 5930710.56 685679.34 N 70 12 56.455 W 148308.015 4100.00 33.72 262.52 3942.40 168.31 -86,14 -387.91 2.60 5930702.14 685626.40 N 70 12 56.385 W 148309.557 4200.00 36.03 262.82 4024.44 187.74 -93.43 -444,62 2.32 5930693.45 685569.89 N 70 1256.313 W 14830 11.2C 4300.00 39,25 262,62 4103.61 208.45 -101.18 -505.19 3.22 5930684.22 685509.54 N 70 1256.237 W 14830 12,962-"' 4400,00 42.00 262.37 4179.50 230.77 -109,68 -569.74 2.75 5930674.13 685445.23 N 70 1256.153 W 1483014.836 4500,00 44.33 262.40 4252.44 254.34 -118,75 -637.54 2,33 5930663.40 685377.67 N 70 12 56.064 W 148 30 16.805 4600.00 47.50 262.27 4322.00 279.15 -128.33 -708,72 3.17 5930652.07 685306.75 N 701255.970 W 1483018.871 4700.00 50.37 262,38 4387.69 305.19 -138.40 -783.43 2.87 5930640.16 685232.32 N 70 12 55,871 W 1483021.040 4800,00 50.85 262.50 4451.15 331,75 -148.56 -860.04 0.49 5930628.11 685155.98 N 70 12 55.771 W 148 30 23.265 4900.00 51.28 263.42 4513.99 357,82 -158.10 -937.24 0.83 5930616.68 685079.05 N 70 1255.677 W 1483025,506 5000,00 51.02 263.95 4576.72 382.99 -166.66 -1014.65 0.49 5930606.21 685001.88 N 70 1255.592 W 1483027.753 5100.00 51.12 264.22 4639.56 407,61 -174.68 -1092,02 0.23 5930596.29 684924.73 N 70 1255,514 W 1483030.000 5200.00 51,08 263.77 4702.35 432,36 -182.82 -1169.42 0.35 5930586.24 684847.56 N 70 12 55.433 W 148 30 32.247 DS13-29L 1 ASP Final Survey.xls Page 2 of 5 5/13/2002-10:41 AM Grid Coordinates Geographic Coordinates Station 10 MO Inc! Azim TVO vSec N/-S EI-W OLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (° 11 OOft) (ftUS) (ftUS) 5300.00 50.50 264.43 4765.57 456.88 -190.79 -1246.49 0.77 5930576.38 684770,71 N 701255.355 W 1483034.484 5400.00 50,90 264,73 4828.91 480.74 -198.10 -1323.53 0.46 5930567,18 684693.89 N 701255.283 W 1483036,721 5500.00 50,95 265,25 4891.94 504.14 -204.87 -1400.87 0.41 5930558.49 684616.75 N 701255.216 W 1483038.966 5600.00 51 .40 265.75 4954.64 526.97 -210.99 -1478.53 0,60 5930550.47 684539.26 N 70 1255.156 W 1483041.221 5700.00 51 .48 265.90 5016,97 549.46 -216.68 -1556,52 0.14 5930542.86 684461.44 N 701255.100 W 1483043.485 5800.00 51.48 266.15 5079.25 571,70 -222.10 -1634,57 0.20 5930535.51 684383.55 N 70 1255.046 W 1483045.751 5900.00 51,23 266.17 5141.70 593.73 -227.33 -1712,50 0.25 5930528.37 684305.78 N 70 1254.995 W 1483048.014 6000.00 51.83 267.28 5203.91 615.06 -231,80 -1790.66 1.06 5930521.97 684227.76 N 701254.950 W 1483050.283 6100.00 52.40 267.77 5265.32 635.51 -235.21 -1869,51 0.69 5930516.62 684149.02 N 70 1254.917 W 14830 52.5T 6200,00 52.67 267,65 5326,14 655.82 -238.38 -1948,82 0,29 5930511,50 684069.82 N 70 1254.885 W 148 30 54,87~ 6300.00 51.97 267.27 5387.27 676.41 -241.89 -2027,89 0.76 5930506.05 683990.87 N 70 1254.851 W 1483057.170 6400.00 51.95 267.42 5448.89 697.06 -245.54 -2106,56 0.12 5930500.46 683912.31 N 70 1254.815 W 1483059.455 6500.00 51.92 267.37 5510,55 717.63 -249.11 -2185.21 0.05 5930494.95 683833.78 N 70 1254.779 W 14831 1,738 6600.00 51.53 266.88 5572.49 738.49 -253,05 -2263.61 0,55 5930489.08 683755.50 N 70 1254,740 W 14831 4.014 6700.00 51.68 266.28 5634.60 760.04 -257.73 -2341.85 0.49 5930482.48 683677.41 N 70 1254.694 W 14831 6,286 6800.00 51 .40 266.38 5696.79 781.90 -262.74 -2419.99 0.29 5930475.54 683599,42 N 70 1254.644 W 14831 8,554 6900.00 51,13 266.55 5759.37 803.50 -267,55 -2497.85 0.30 5930468.81 683521.71 N 70 1254.597 W 14831 10.815 7000.00 51.03 266.35 5822.19 825.06 -272,37 -2575.50 0.18 5930462.09 683444.20 N 70 1254.549 W 14831 13.069 7100.00 51.03 266.38 5885.08 846.72 -277,30 -2653.09 0.02 5930455.25 683366.76 N 701254.500 W 14831 15.322 7200.00 50.55 266.32 5948.30 868,33 -282.23 -2730.42 0.48 5930448.41 683289.59 N 70 1254.452 W 14831 17.567 7300.00 50.12 266.02 6012.13 890.02 -287,37 -2807.23 0.49 5930441.38 683212.93 N 70 1254.401 W 14831 19.797 7400.00 49.93 266.32 6076.37 911,62 -292.49 -2883,69 0.30 5930434.38 683136.63 N 701254.350 W 14831 22.016 7500.00 49.62 266.13 6140.95 933.07 -297.51 -2959.87 0.34 5930427.48 683060.59 N 701254.300 W 14831 24.228 7600.00 49.27 265.95 6205.97 954.65 -302.76 -3035.67 0.38 5930420,36 682984,95 N 70 1254.249 W 14831 26.429 7700.00 49.08 266,02 6271.34 976.21 -308.06 -3111.15 0.20 5930413.21 682909.63 N 70 1254.196 W 14831 28.62 7800.00 49.40 265.78 6336.63 997,90 -313.48 -3186.70 0,37 5930405,93 682834,24 N 70 1254.143 W 14831 30.814-'" 7900.00 49.50 265.50 6401.64 1019.99 -319.25 -3262.47 0.24 5930398.29 682758.64 N 701254,085 W 14831 33.013 8000,00 49.25 265.08 6466.75 1042.49 -325.48 -3338.11 0.41 5930390.20 682683,18 N 70 1254.024 W 14831 35.209 8100.00 49.07 264.75 6532.15 1065.40 -332.19 -3413.47 0.31 5930381.64 682608.02 N 701253,958 W 14831 37.397 8200.00 48.77 264.38 6597.86 1088,66 -339.33 -3488.51 0.41 5930372,65 682533.18 N 70 1253.887 W 14831 39.576 8300.00 48.57 264.12 6663.90 1112.23 -346.85 -3563.22 0.28 5930363.29 682458.68 N 701253.813 W 14831 41,745 8400.00 48.30 264.08 6730.25 1135.89 -354.54 -3637.64 0.27 5930353.77 682384.47 N 70 1253,737 W 14831 43.905 8500,00 48.07 264.30 6796,92 1159.36 -362.09 -3711.79 0.28 5930344.40 682310.54 N 70 1253,662 W 14831 46.058 8600.00 47.48 264.53 6864.12 1182.39 -369.29 -3785.49 0.61 5930335,38 682237.04 N 70 1253.591 W 14831 48.197 8700.00 47.22 264.37 6931,88 1205.23 -376.41 -3858.70 0.29 5930326.47 682164.04 N 701253,521 W 14831 50.323 DS13-29L1 ASP Final Survey.xls Page 3 of 5 5/13/2002-10:41 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 8800.00 47.40 263.92 6999.68 1228.43 -383,91 -3931.82 0.38 5930317.17 682091.13 N 701253.446 W 14831 52.445 8900.00 47.43 263.72 7067.35 1252.06 -391.83 -4005.02 0.15 5930307.44 682018.16 N 70 1253,368 W 14831 54.570 9000.00 47.80 263.93 7134,76 1275.76 -399.78 -4078.45 0.40 5930297.69 681944,94 N 70 1253.290 W 14831 56.702 9100.00 47.85 264,13 7201,90 1299.29 -407.49 -4152.16 0.16 5930288.17 681871.45 N 701253.213 W 14831 58.842 9200.00 48.20 264.33 7268.78 1322.64 -414.96 -4226.12 0.38 5930278.88 681797,70 N 70 1253.139 W 148 32 0,989 9300.00 48.27 264.67 7335,39 1345.74 -422,11 -4300.37 0.26 5930269.90 681723.66 N 70 1253.069 W 148323.145 9400.00 48.33 265.08 7401.91 1368.40 -428.78 -4374.73 0.31 5930261.40 681649.48 N 70 1253,003 W 148325.304 9500,00 48.67 265.17 7468.17 1390.81 -435,14 -4449.36 0,35 5930253,20 681575.04 N 701252,940 W 148327.470 9600.00 47.50 265.05 7534.97 1413.10 -441.48 -4523.50 1,17 5930245,03 681501.08 N 70 12 52.877 W 14832 9.62r 9700.00 47.30 265,12 7602.66 1435.18 -447.79 -4596,84 0.21 5930236.92 681427,93 N 701252.814 W 148 3211.7t.~ 9800.00 46.72 265,73 7670.85 1456.71 -453.63 -4669.75 0.73 5930229.29 681355,19 N 701252.757 W 14832 13.868 9900.00 45.92 265.85 7739.91 1477.55 -458.94 -4741.88 0.80 5930222,21 681283.22 N 701252.704 W 14832 15,962 10000.00 45.30 266,13 7809.86 1497.91 -463.94 -4813.16 0,65 5930215.45 681212.08 N 701252.654 W 1483218.032 10100.00 44,55 267.10 7880.67 1517.29 -468.11 -4883.65 1,02 5930209.54 681141 .72 N 701252,613 W 1483220.078 10200.00 43.65 266,88 7952.48 1535.94 -471.76 -4953. 15 0.91 5930204,18 681072.34 N 70 1252.576 W 1483222.096 10300,00 43.53 266,95 8024.91 1554.51 -475.47 -5022.00 0,13 5930198.77 681003,61 N 70 12 52.540 W 148 32 24.094 10400.00 43,80 268.47 8097.25 1572.18 -478.23 -5090,98 1.08 5930194.32 680934,72 N 701252.512 W 1483226.097 10500.00 44.22 270.20 8169.17 1588.05 -479,03 -5160.45 1.27 5930191.81 680865,29 N 701252.504 W 1483228.114 10600.00 44,92 272.05 8240.42 1601.93 -477.65 -5230.61 1.47 5930191.46 680795.13 N 70 1252.517 W 1483230.151 10700.00 46.03 273.77 8310.54 1613.84 -474.02 -5301.80 1.65 5930193.34 680723.87 N 70 1252,552 W 1483232.218 10800.00 46,32 275.32 8379,79 1623.87 -468.30 -5373.72 1.16 5930197.28 680651.84 N 70 12 52.608 W 148 32 34.306 10900,00 46,82 276.52 8448.54 1632.24 -460.81 -5445.95 1.00 5930202.99 680579.45 N 701252.681 W 1483236.403 11000,00 46,33 277.07 8517.28 1639,51 -452.21 -5518,07 0.63 5930209.80 680507,15 N 70 12 52.765 W 148 32 38.497 11100.00 45.45 278.52 8586.88 1645.46 -442.48 -5589.20 1.36 5930217,78 680435.80 N 701252.860 W 1483240.562 11200.00 44.93 279.95 8657.36 1649.55 -431 , 1 0 -5659,22 1.14 5930227.43 680365,52 N 701252.972 W 14832 42.5r 11300.00 43.78 281,67 8728,86 1651.67 -418.00 -5727.89 1.66 5930238.83 680296.56 N 701253.100 W 1483244,589-' 11366,00 43.53 282.00 8776.61 1652.24 -408.66 -5772.48 0.51 5930247.07 680251.75 N 701253.191 W 1483245,884 11421.34 58.40 270.53 8811.44 1657.36 -404.45 -5815.01 31.25 5930250.24 680209, 14 N 701253,233 W 1483247,119 11466.00 66.59 256.21 8832.13 1670.48 -409.18 -5854.16 33.79 5930244.54 680170.12 N 70 1253.186 W 1483248.255 11497.49 70.93 245.31 8843.57 1685.94 -418,87 -5881.79 35.07 5930234.17 680142.73 N 701253.090 W 1483249.058 11524.82 73.08 232,31 8852.04 1703.87 -432,31 -5903.96 45.91 5930220.19 680120.90 N 70 1252.958 W 1483249,701 11563.99 74.84 223.57 8862.88 1734.53 -457.51 -5931,87 21.91 5930194.31 680093.62 N 70 1252.710 W 1483250,510 11604.53 79.05 201.76 8872.15 1771.38 -490.56 -5952.99 53.40 5930160.75 680073.33 N 701252.384 W 1483251.123 11639,83 83.83 188,23 8877.42 1806.16 -524,20 -5961.97 40.24 5930126.91 680065.18 N 701252.054 W 1483251.383 11676.00 88.01 175.68 8880.00 1841.54 -560.17 -5963,19 36.48 5930090.91 680064.85 N 70 1251.700 W 1483251.417 DS13-29L 1 ASP Final Survey.xls Page 4 of 5 5/13/2002-10:41 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec N/-S El-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 11714.31 87.08 174,13 8881.65 1878.02 -598.30 -5959.79 4.72 5930052,89 680069.19 N 701251.325 W 1483251.318 11759.64 86.19 172.21 8884.31 1920.71 -643.22 -5954.41 4.66 5930008,11 680075.67 N 701250.883 W 1483251.160 11801.51 85.47 171.47 8887.35 1959.77 -684.56 -5948.48 2.46 5929966.94 680082.62 N 70 1250.477 W 1483250,987 11829,64 88.53 165.41 8888,82 1985.40 -712.07 -5942.85 24,10 5929939.58 680088.92 N 701250.206 W 1483250,823 11871.39 90.10 168.16 8889.32 2022.99 -752.70 -5933.31 7.58 5929899,19 680099.46 N 701249.806 W 1483250.545 11930.27 90,72 176,87 8888.90 2078.26 -811.02 -5925.65 14.83 5929841.08 680108.56 N 70 1249.233 W 1483250.322 11974.62 89.42 167.76 8888.85 2119.83 -854.93 -5919.72 20.75 5929797.34 680115.56 N 701248.801 W 1483250.149 12023.42 88.46 164.60 8889.75 2163.54 -902.30 -5908.07 6.77 5929750.27 680128.38 N 701248.335 W 1483249.809 12064.00 87,74 162.25 8891.10 2198.97 -941.17 -5896.50 6.05 5929711.70 680140.90 N 701247.953 W 14832 49.4T 12101.06 89.49 167,09 8891.99 2231.71 -976.89 -5886.71 13,88 5929676.24 680151.57 N 701247.602 W 148 32 49.1ó~ 12135.08 87.91 171.36 8892.76 2262.94 -1010.29 -5880,35 13.38 5929643.00 680158.75 N 70 1247.273 W 1483249.002 12182.56 87,73 168,18 8894,57 2306.68 -1056.98 -5871.93 6.70 5929596.54 680168.32 N 70 1246,814 W 1483248.757 12231.50 87,63 171.75 8896,55 2351.83 -1105.12 -5863.41 7.29 5929548.63 680178.02 N 701246.341 W 1483248.508 12283,75 87.08 175.45 8898.97 2401.19 -1156.98 -5857,59 7.15 5929496,93 680185.11 N 701245.831 W 1483248.338 12341 ,50 85.64 180.88 8902.63 2456,99 -1214.56 -5855.74 9.71 5929439.41 680188.38 N 70 12 45.265 W 148 32 48.283 12394.50 81.47 179.54 8908.58 2508.43 -1267.21 -5855.94 8.26 5929386.78 680189.48 N 70 1244.747 W 1483248.288 12435.00 78.33 180.46 8915.68 2547.34 -1307.08 -5855,94 8.07 5929346,93 680190.46 N 70 12 44.355 W 148 32 48.287 12501,00 78.33 180.46 8929,03 2610.55 -1371.71 -5856.45 0,00 5929282.30 680191.54 N 701243.719 W 1483248.300 '--- DS13-29L1 ASP Final Survey.xls Page 5 of 5 5/13/2002-10:41 AM ) MWD/L WD Log Product Delivery ) Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No DS 13-29L 1 Date Dispatched: 29-Apr-02 Installation/Rig Nabors 3S / SLB CTU # 4 Dispatched By: Nate Rose Data No Of Prints No of Floppies Su rveys Received By: döJl-o<cc:¡ ~~ (~.. ) LWD Log Delivery V1.1, Dec '97 2 ~ECEIVED MAY 2 LOO2 AlaskE 0iJ& Gas Cons. ~ornn_n Anchorage Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd. Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 MEMORANDUM ) TO: Camille O. Taylor ep< Chair ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 18, 2002 THRU: Tom Maunder A.(;J?y{\ P.I. 8upervisorfjþ 5b5)D?- FROM: Lou Grimaldi Petroleum Inspector SUBJECT: Blowout Preventer Test Nabors 38 BPX D8-13 .13~29L1 202-069 Prudhoe Bay Field Operator Rep.: John McMullins Contractor Rep.: Graham Olsen Test Pressures Rams: 250/3500 MISC. INSPECTIONS: P/F Location Gen.: P Housekeeping: P* PTD On Location P Standing Order: P BOP STACK: Quantity Size 1 1 2 1 1 1 2 1 Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve NON- CONFIDENTIAL Op. phone: 659-5515 Rig phone: 659-5514 P/F Sign:~ Rig cond: ~ Hazard: P P/F P P P P P P P P Op. E-Mail: Rig E-Mail: Annular: 250/3500 Choke: 250/3500 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 0 Lower Kelly 0 Ball Type 2 Inside BOP 0 P P CHOKE MANIFOLD: Quantity P/F No. Valves 12 P Man. Chokes 1 P Hyd.Chokes 1 P MUD SYSTEM: Visual Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm P P P P P ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 2950 P After Closure 1950 P 200 psi Attained: 18 P Full Pressure :46 P Blind Covers (All Stations): P N2 Bottles (avg): 4/2000 P Test's Details I arrived to find the rig crew holding pressure on their first test. The test proceeded smoothly with no failures observed. . Thie rig condition was fair, cosmetically it could use some improvement but the BOP equipment all functioned well and held its respective pressure tests. Total Test Time: 5 hours Number of failures: None Attatchments: None cc: BOP Test (for inspectors) BFL 11/02/01 BOP Nabors 384-18-02 LG.xls @C"':3~~-e @ ~ J\., ~ 1: ) : F !Æ~!Æ~~~!Æ ) AlASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 13-29-Ll BP Exploration (Alaska), Inc. Permit No: 202-069 Sur Loc: 761' NSL, 1234' WEL, Sec. 14, TI0N, RI4E, UM Btmhole Loc. 600' SNL, 1892' WEL, Sec,. 22, TI0N, RI4E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting determinations are made. The permit is for a new wellbore segment of existing well PBU 13-29, Permit No, 183-043 API 50-029- 20908. Production should continue to be reported as a function of the original API number stated above. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 13-29-Ll. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ ~./v~. tL fJ./ camm~hsli Tay¡;';-Õ' Chair . BY ORDER OF THE COM:MISSION DATED this~ day of March, 2002 jjcÆnc10sures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA STATE OF ALASKA )AND GAS CONSERVATION COMM' PERMIT TO DRILL 20 AAC 25.005 VJGA- "2)/ ¡4! f) -L. ti ~ ~~-cD )ION 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 761' NSL, 1234' WEL, SEC. 14, T10N, R14E, UM At top of productive interval 367' NSL, 18121 WEL, SEC. 15, T10N, R14E, UM At total depth 600' SNL, 1892' WEL, SEC. 22, T10N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028315,1892' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11375' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Hole Cas'ing Weiaht Grade Couplina LenÇJth 3-3/411 3.3116" x 2.7/8" 6.2#/6.16# L-80 ST-L 1395' 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 RKB = 83' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028314 7. Unit or Property Name , Prudhoe Bay Unit 8. Well Number , 13-29L 1 .l 9. Approximate spud date 03/17/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12500' MD / 89301 TVD 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 92 Maximum surface 2364 psig, At total depth (TVD) 8800' / 3420 psig Setting Depth TQD Botom Quantitv of Cement MD TVD MD TVD (include stage data) 111051 85901 125001 8930' Uncemented Slotted Liner .,/ 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 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 feet feet feet feet Junk (measured) Plugs (measured) Fill tagged at 11617' (02/96) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemènted RECEI'VED MD TVD MAr-{ 1. ~ 2002 Alaska Oil & Gas Cons. Commission Anchorage true vertical 11366'-11394', 114121_114321, 11484'-11513', 11522'-11542', 11552'-11562', 11574'- 11600', 11608' - 116321 8860' - 88801, 8893' - 8908', 8946' - 8967', 8974' - 8989', 89961 - 9004', 90131 - 90321, 9038' - 90561 Perforation depth: measured 20. Attachments II Filing Fee 0 Property Plat II Drilling Fluid Program 0 Time vs Depth Plot Contact Engineer Name/Number: Thomas McCarty, 564-5697 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ThomasMcca~ / ¿:;::¿~4'f"'~.. ..' .. T. itle. CT Dri.lling.Engineer .. /.' Commission Use Only . Permit Number API Number ~iJJ7~e"J See cover letter 20 2..- (J h t 50- 029-20928-60 ;' ¡- ,t7'\ for other requirements Conditions of Approval: Samples Required 0 Yes .ŒI No Mud Log equ ed 0 Yes ta'No Hydrogen Sulfide Measures Ð Yes 0 No Directional Survey Required ;gJ Yes 0 No Required Working Pressure for BOPE D2K 0 3K D4K 0 5K 0 10K 0 15K ~.5K psi ~<'<:.\~ Other: Original Signed By i ~ . by order of Approved By Cammy Oechsh nom~~i~&r the commission Date g I ) lJ '/1,9-. Form 10-401 Rev. 12-01-85 0 t\ \J \ \ A L Sl!It(ml ~ triplicate II BOP Sketch 0 Diverter Sketch II Drilling Program 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Prepared By NamelNumber: Terrie Hubble, 564-4628 Date 1/;0'- ') BPX 13-29L 1 Sidetrack -) Summary of Operations: A sidetrack from production well 13-29 will be drilled using coil tubing. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Screen & Prep Well: Screen - Install dummy GlV's, fluid pack lA, and MIT-IA. PPPOT-tbg I hanger seals. MIT-OA and pressure test tree valves. Prep - detailed below is planned to start March 1ih 02 . Set a PIP, (permanent isolation packer) with modified check valve at 11 ,465'MD (-8,849' tvdss). Set a 4Y2"x7" thru tbg whipstock at 11,375' md, (-8,783' tvdss). . Note: The PIP with check will prevent fluid losses to the open Z4 perfs while drilling and yet allow production from these perfs after placing the well back on production. /' Phase 2: Drill and Complete CrD sidetrack: Planned for March 22th 02../ 2%" coil will be used to drill a -1125ft of 3%" OH sidetrack from a window cut in the 7" liner - as per the attached plan. The sidetrack will then be completed with an uncemented solid & slotted liner. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: ./' . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 3-3/16", l-80, liner will be run from approximately 11,105'md (TOl, 8,590' TVDss) to approx. 11,475' md, (100' outside of the window). Above the window a perforated pup joint will be included to faciltate production from the existing Z4 perfs via the standing valve. From 11 ,475'md, 2%" ~otted liner will be run to TD. Well Control: . BOP diagram for Nabors 38 rig / 8chlumberger CT Unit 4 is attached. .,/ . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . Real time MWD, Gamma Ray & Resistivity logs will be run while drilling the open hole section. Hazards . H2S is a minor hazard. last tested on the 12/2/01, 13-29 had a 30ppm concentration. . The wells directional trajectory does not cross any mapped faults. Therefore, there is a low risk of los/sing circulation. Reservoir Pressure Reservoir pressure is estimated to be 3,420 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,364 psi. / TREE = MCEVOY GEN 3 . WELLHEAD = Cr1V .... ...". .. 'P' "". ... .........., ACTUA TOR = AXELSON KB. äE\i ~ . ... .83" BF. ELEV = 'KÖp~...'.". ... ""...."""". ....... .........,... Max Angle = . . . , Datum MD = . .. . . Datum lVD = ') 3200' ... ... ..n...",.." "..""" ... 53 @ 6200' .'. .11348' 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2624' Minimum 10 = 3.725" @ 11100' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR 1-1 11071' 1 4-1/2"TBG-PC,12.6#,L-80,,0152bpf,ID=3.958" IJ 11113' 1 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 11378' 1 PERFORA TION SUMrv1A RY REF LOG: BHCS ON 05/02/83 ANGLE AT TOP PERF: 43 @ 11366' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11366-11394 0 11/09/89 3-3/8" 4 11412-11432 0 05/18/92 3-3/8" 4 11484-11513 0 05/18/92 3-1/8" 4 11552-11562 0 03/11/84 3-1/8" 4 11574-11600 0 03/11/84 3-1/8" 4 11608-11632 0 01/19/86 3-1/8" 4 11522-11542 0 03/11/84 I PBTD 1-1 11836' 1 I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 11870' 1 DATE 05/11/83 07/14/87 01/09/01 02/21/01 06/19/01 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SIS-SL T CONVERTED TO CANVAS SIS-LG REV ISION RN/TP CORRECTIONS DA TE REV BY 13-29 ~ , "I ... 8> L I I ~ COMMENTS f I I ~ ) SAFETY NOTES 2209' 1-14-1/2" CAM WRDP-2 SSSV NIP, ID = 3.812" 1 STA 1 2 3 4 5 6 7 8 9 10 11 GAS LIFT MANDRELS MD lVD DEV 1YÆMAN LATCH VLV 2899 2898 7 MERIA TG 1-1/2" 5218 4797 51 MERIA TG 1-1/2" 7558 6262 49 MERIA TG 1-1/2" 8783 7071 47 MERIA TG 1-1/2" 9596 7615 48 MERIA TG 1-1/2" 10116 7975 45 MERIA TG 1-1/2" 10355 8148 44 MERIA TG 1-1/2" 10631 8345 45 MERIA TG 1-1/2" 10744 8424 46 MERIA TG 1-1/2" 10854 8500 47 MERIA TG 1-1/2" 10964 8575 46 MERIA TG 1-1/2" I 10991' 1- 9-5/8" X 4-1/2" BAKER SB-3 PKR AND SEAL BORE ASSY, ID = 4.750 I 11100' 1-14-1/2" OTIS XN NIP, ID = 3.725" 1 I 11111' 1-14-1/2" BOT SHEA ROUT SUB, ID=4.000" 1 I 11113' 1-14-1/2" TUBING TAIL 1 I 11097' 1-1 ELM TT LOGGED 11/16/92 1 .. PRUDHOE BA Y UNIT WELL: 13-29 ÆRMIT No: 83-043 API No: 50-029-20928-00 Sec. 14, T10N, R14E, 2055.12 Fe.. 4858.8 FNL BP Exploration (Alaska) I) SAFETY NOTES TREE = MCEVOY GEN 3 !, WELLHEAD = crvv """". ...",,,,..,,,..,,,....... ........ ,., "'''n..,..".".....",,,,,...,, ACTUA TOR = AXELSON 'KB':"ELÊV;;^""""'"'''' """'''''83;' """.. n,.....,,,... "." .......... BF. ELEV = KC)'p';;'M"WW'ww',www" ""32ÖÖì' MaxAngië;;' '.'''S'3@62ÓÖi 'Öatu'mrvîÖ';;"'''''''''''''''''''''1''1'348i . bäium ,.yO;;' , ""8'8ÓO' 55 13-29 L 1 Proposed CTD Sidetrack ') 2209' 1-14-1/2" CAM WRDP-2 SSSV NIP, ID = 3.812" 1 8 GAS LIFT MA NDRELS MD ND DEV TYPE MAN 2899 2898 7 MERIA 5218 4797 51 MERIA 7558 6262 49 MERIA 8783 7071 47 MERIA 9596 7615 48 MERIA 10116 7975 45 MERIA 10355 8148 44 MERIA 10631 8345 45 MERIA 10744 8424 46 MERIA 10854 8500 47 MERIA 10964 8575 46 MERIA ~ ~ STA 1 2 3 4 5 6 7 8 9 10 11 LATCH VLV TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" TG 1-1/2" 113-3/8" CSG, 72#, L-80, ID = 12,347" 1-1 2624' Minimum ID = 3.725" @ 11100' 4-1/2" OTIS XN NIPPLE L 1 10991' 1- 9-5/8" X 4-1/2" BAKER SB-3 PKR AND SEAL BORE ASSY, ID = 4.750 , "I f I TOPOF 7" LNR 1-1 11071' I I 11100' -4-1/2"OTISXNNIP,ID=3.725" 1 11105' - Top of Proposed 3-3116" Liner I I 11111' 1-14-1/2" BOT SHEAROUT SUB, ID = 4.000" I ~ 11113' 1-14-1/2" TUBING TAIL I 1 11097' 1-1 ELM IT LOGGED 11/16/92 1 4-1/2"TBG-PC,12.6#,L-80,,0152bpf,ID=3.958" 1-1 11113' 1 \. 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 11378' 1 ... ~ PERFORA TION SUMMARY REF LOG: BHCS ON 05/02/83 ANGLE AT TOP PERF: 43 @ 11366' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11366-11394 0 11/09/89 3-3/8" 4 11412-11432 0 05/18/92 3-3/8" 4 11484-11513 0 05/18/92 3-1/8" 4 11552-11562 0 03/11/84 3-1/8" 4 11574-11600 0 03/11/84 3-1/8" 4 11608-11632 0 01/19/86 3-1/8" 4 11522-11542 0 03/11/84 1,1375' 1-1 Mechanical Flow -by Whipstock ./ Ih 0 0 -111450'1-1 3-3/16" X 2-7/8" XO 1 13-3/4" Open Hole I 0 - 0 0 0 0 0 0 0 0 0 0 0 0 01 v -T~ 12-7/8" L-80 Pre-drilled Liner H 12500'1 - ""i 11465' l---i Standing Valve (proposed) I 1 PBTD 1-1 11836' 1 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 11870' I -.. DATE 05/11/83 07/14/87 01/09/01 02/21/01 06/19/01 COMMENTS ORIGINA L COMPLETION LAST WORKOVER SIS-SL T CONVERTED TO CANVAS SIS-LG REVISION RNlTP CORRECTIONS REV BY DA TE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 13-29 PERMIT No: 83-043 API No: 50-029-20928-00 Sec. 14, T10N, R14E, 2055.12 FEL 4858.8 FNL BP Exploration (Alaska) ,.,..t W.IIp.Uu Tie 08 MDI ..... It.,. D.tuMl' Y.s.Ä.~: o.~ ------ BP Amoco MLLPATH DETAILS PI.... 1 :J.2tL 1 ID02t2012110 13-2. 11375.oD ND"UC 1 4A 121 4I17J1I.3 OG:OO ~~; :;::~D REFERENCE INFORMATION Co-~e~7;':r ~~¡ ~:¡:;:~: ~y~:e~:n~:~~ ~~;. ~~:I North Seelion (VS) Reference: Slot - 29 (O.OON.O.OOE) Measured Depth Reference: 44: 294/17/198300:00 83.00 Calculation Method: Minimum Curvature 1 11300..00 43.78 281.'7 872"" Z 11375.00 43.48 282.0.4 87n.14 :Ii 11385.00 45.23 280.'3 .nO.D 4 11425.00 51.'. 272.40 8115.18 S 11555.44 11.45 227.38 '''1.00 1 1170.5.44 .2.40 174.18 ...5.21 7 11715.44 82.00 114.18 11".12 : ~~~:::: ::::: ~::::: :::::~~ ~~ ~=::: ;:::~ ~~:::: :=~ - .5 8550 fi 8600 II) - .c 8650 .. Do ~ 8700 Q ëi 8750 U :e 8800 ~ > 8850 ~ 2 8900 I- ANNOTATIONS MD .....tatlo8 872.'" 113DO.00 TIP 87.3.1.11371.00 KOP '710.21 11311.00 1 1115.11 11~I.OO 2 1117.00 11555.... J 1111.21 117OS.... . ..11.11 1171''''' . 111S.3. 11110"" . '.".57 1221G.... 7 1103.13 1ZUO.... . 1'30.0.4 12100.00 TD 8350 8400 8450 8500 8950 9000 9050 9100 .ICTION DITAIL8 .~ DL8. TFU8 Vhc T8I'J1tt ~ -600 æ -70G 0 ~ -800 - '+ -900 :c 1:: -1000 0 Z ;;;::::. -11 00 . :c -1200 .. ~ ~ -1300 bp LEGEND nmnn 13-29 (13-29) 13-31 (13-31) Plan#6 13-29l1 Plan #6 T ^M Azimuths to True North Plan: Plan #6 (13-29/Plan#613-29L1) Magnetic North: 26.4 r Created By; Brij Polnis Date: 2/28/2002 ¡~ Magnetic Field Strength: 57508nT Dip Angle: 80.77. Date: 2/2812002 Model; BGGM2001 8aker Hughes i~~i~:{~f#~~i~~Q~~" ~17." -5127.81 ....o1.H .511'.51 ....05.... -511-5.31 -402.... .5818.31 -445.77 -Se24.GZ .57..18 -5873.11 "'51.1' -5"5..0 .778.40 -5831.12 .1074.0.1 -S821.81 .1202.51 -583'.34 -1358.10. -S8n.1I 0.00 0.00 1..5..7. 0.52 138.77 115...10 20.00 330.00 11581.01 3S.OO 330.0.0 1700-72 ~.OO 215.00 17&6... 3!.OO 270..00 18-01.78 12.00 0..00 1.1130 12.00 2M.GO 20M" 12.00 81.00 237".' 12.00 2aO.OO 2507.51 12...00 1&0.00 28S8.84 Cr:n~act h1forrnatiof:. e- INTEQ 'ij".,,-.~~.~ -100 - 13.29l1 T61 13.29L1 162 13.2'9l1163 1).19L1 T6.t 13-2'9t.1T65 '3-2911P~ U.~L1 Boo.ndrtFwt 119500 -51892 --591348 Pont U9'500 -91568 -590615 por.r 890300 -"17.00 -593U.t Pont ¡907oo -1262 06 -593129 FoR 1930 00 -13S9 os -593167 Pont 000 ~93M -.6016..t1 Pc:I¥;on 000 .1$83 01' -õ293 33 Po.\¡;on -200 -300 -400 -500 -1400 -1500 -160G -1700 -1800 . . . . -7000 -6900 -6800 -6700 -6600 -6500 -6400 -6300 -6200 -61 00 -6000 -5900 -5800 -5700 -5600 -5500 -5400 -5300 -5200 -5100 -5000 -4900 -4800 -4700 -4600 -4500 -4400 West(-)/East{+) [100ft/in] ~ 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 31'00 3150 3200 3250 3300 3350 3400 Vertical Section at 193.00' [50ft/in] - -----~- :TIP--; .:KOpn: ::.: ~1- I' I I I ! :-1:>-29 (13-29)i ¡ - .- . \J .T /r~J m +- / l 13="29[1 m; - -------- 2/28/2002 1 : 13 PM bp ') ) ..... BADa HUGHES ,..",....",,,.........,,......,,,,,.....,,,,,,,,,, .. IN'IEQ BP Amoco Baker Hughes INTEQ Planning Report ~""""'-"'~-"-"~""""'''~''''-~'''''~''''''''''''~''~''''~'''''''~,_.-. "'~'_'_"""".",,,.~....,,,,,._........,,,......c-._-_.,,..........,...",........"....~.........._.._..--.."._... -..,,--..- ""-"'~"-""~""-'-""""-"-'-'''''---''''-'''-'''''''"--""-'''''','-_._-'.~_...-.--' n_." ~...__.._". ,,,--,"-',-,,., ....-......-...... ..-...--. . .-"_u_. .---"---..- Company: BP Amoco Date: 2/28/2002 Time: 13: 14:26 Field: . Prudhoe Bay Co-ordinate(NE) Reference: WeIJ:13~29, True North Site: . PBDS 13 Vedical(TVD) Reference: System: Mean Sea Level Well: 13-29 Section (VS) Reference: Well (0.00N,O,OOE,193.00Azi) Well path: Plan#6 13-29L 1 Survey CalCulation Method: Minimum Curvature Db: Oracle ~-~---------'-~"-~--'~-' --"'---"~-'-'--"'~~""~~~~~-~~-'----'~"'~"w.""-"-'..-.",..' ...- "'~~-~"'.'~"'-~~'''~''~-'.'''''-~-'-'-~.'~-~._~-'-~''."~-'-'-'-~-'~~.'-""'~-""~~'~'"-,-,~,,,-,-,,--,-.__.._._...~~~._...¥.-._-----.~~....~-_.~~_..__.._~~ .------'-'---'--------'----'----'-"---'----'--"'----'" ""-'----'--"-------'--"-'--"----------'-"----'-----'-'-.'-----'-'" ._-_._._._-----~----_.-..._-.._.....__._---- ----..-.- --. -- .--..-- ..-.-.- -. .._-----.. .----.-- Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Page: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 Site: -- ..--..--------'-----"---'--"--'-'---,,,------,,,,----,, - ----- ..--........--.--...-.. ---..-....-.-.- .-.---.. - -. n --~.,--.. ..,.. .--..... .,-..-."...-.- ..-.-----....-. - --. -.....- .. _._,--_. .----..-.--- -------'---'-""'---.-.-----.----..-----------.-.,,----'-"'---"'---"""---'''-,--,----- --.-..-"....-.-..-.-. . --.--..-.- ---.". '.-"'''--- ..-., -- ,...-..-.---...-..-.-.-. - ---- -- ...-----,-----------.,..-..--,-.-".---..-.. .-...--. "-""..........--.--..-.----.-.".-....".... "-"._"-"'-"~~--"'-'-'-"-'-' -.-,..-.-,...--.. ._..~-------------_._,.._._._._....- '---'--'....---.-... -- ~~_._---_.._-- PB DS 13 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5932645.45 ft Latitude: 685828.44 ft Longitude: North Reference: Grid Convergence: ._.._-_._--_.__._---~---_..._--_.,,_._-~._,..__..._..._.-....,,-..---.--.-. 70 13 15.444 N 148 30 2.303 W True 1.41 deg Well: ---"'-----"-"--"--'------------~-"- 29 "--~_..__._---- --------'----"'--'-'--------'----~'-"--'-"--'-'---'-'--...----- .._--_._--~~-_....._._. -- -- -"----'-"""----""~'---"'-_._'_._-"'-'--"'-'---'----"-'------"-"--"-----'---'----"----'-'--,----.,-----.--.---..-.-------.-----.---- 13-29 13-29 Well Position: -. ---..-----,-...-.-, .---.--- Slot Name: +N/-S -1851.74 ft Northing: 5930797.79 ft +E/-W 138.07 ft Easting: 686012.05 ft Position Uncertainty: 0.00 ft 70 12 57.232 N 148 29 58.295 W Latitude: Longitude: -'''--'''-'-----'-'--'---'-----'-'--'''-'------'--''---'----.-.--.-.-- ------.-.---..--.. "-~.'-""---'-'---- -_._.,-,- .---.---..,.-.- .--------...-..---------.-.-....-.,,--,-- -'-----------'-.----.-----.-- -....--.--.--., '-'--'-----'-"-'---'------'--'-- ~--.._----~---_._------_...- -'-~'- '-'-"-''''-''----'--'--",-_w,-,--,,--.--.,,-.--------.------'-----"----'-----'-'-----""'---"-"-,,,-.-,.---,,,-~'--'-'----'-- --._-----_...~ Wellpath: Plan#6 13-29L 1 500292092860 Current Datum: 44 : 294/17/1983 00:00 Magnetic Data: 2/28/2002 Field Strength: 57508 nT Vertical Section: Depth From (TVD) ft ....... '-"'-'--'---'---'u_----''''''-''-'-''u_,,,-.,,-,--,,------"""-""-'--'-' --"-"'---' .'-""-'..- .- 0.00 -.,. .-'---"---"",--,-,'."-'.' -----"-.-..---...-- --''''''~'''''-'---'-'-'''-'--~--,-,_._, -".~_.- --... .- -.--.. ----'-'- --.-"-..-..---- Plan #6 Identical to Lamar's Plan #6 Principal: Yes Plan: -- ----'--'''-"'-'---'''----'---'-''----- Targets Drilled From: Tie-on Depth: Height 83.00 ft Above System Datum: Declination: Mag Dip Angle: +N/-S +E/-W ft ft ...---.---.-....,-...-------....-..--.,-.------....-----.......,--- 0.00 0.00 13-29 11375.00 ft Mean Sea Level 26.4 7 deg 80.77 deg Direction deg ......_--_...._.__..__._---,-~_.-_.__._---_._---_..-.._--"..- -.--.. 193.00 ~. -... .----.-- ---.- ---....._-.__._,-----~-_._._---------,--- -----_.'~.'--"-----'----'~'-----~--'''-'---'''--'-'----.- .. --.------ - ~--_._---,-_. --.. "-'--'-~~---"--.-,-,,,----------~~,---,,.,,,",,.,'h -.-..--.--. ...-. -.-.---. --- --.-.--..,,-....-----.-- - "-.- ---~ --~ Date Composed: Version: Tied-to: 2/28/2002 1 From: Definitive Path .".-.--.-.---- -.--._-..---~..,-._.._._.._-- . . ---- ..,,--..-. ---"--"-'-"-'--- --,-,.,,_., ,_. .---..-. --.----.,--. ...-...",,--- Name Description 13-29L 1 T6.1 13-29L 1 T6.2 13-29L 1 T6.3 13-29L 1 T6.4 13-29L 1 T6.5 13-29L 1 Polygon6.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 13-29L 1 Boundary Fault -Polygon 1 -Polygon 2 Annotation MD ft I 11300.00 11375.00 , 11385.00 TVD ft 8728.86 8783.14 8790.29 TIP KOP 1 - .-.- .- ----'-------'-- _._".~..._- Map Map <--- . Latitude ---> <-- Longitude ---> TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft ft ft ft ft --..-.- 8895.00 -578,92 -5973.48 5930071.90 680055,01 701251,515N 148 32 51,716 W 8895.00 -915.68 -5906.75 5929736.90 680130.02 70 12 48.203 N 148 32 49.771 W 8903.00 -1187.00 -5938.44 5929464.90 680105.02 70 12 45,535 N 148 32 50.685 W 8907.00 -1262,06 -5937.29 5929389.90 680108,02 70 12 44.797 N 148 32 50,650 W 8930.00 -1359.08 -5937.67 5929292,90 680110.03 70 12 43.842 N 148 32 50,659 W 0.00 -493,35 -6076.41 5930154.89 679950.01 70 12 52.356 N 148 32 54.706 W 0.00 -493.35 -6076.41 5930154.89 679950.01 70 12 52.356 N 148 32 54.706 W 0.00 -479.76 -5815.98 5930174.90 680210.01 70 12 52.491 N 148 32 47.146 W 0.00 -1440.51 -5799.63 5929214,90 680250.03 70 12 43.043 N 148 32 46.650 W I 0.00 -1434.35 -6049.57 5929214.90 680000.03 70 12 43.101 N 148 32 53.905 W I I 0,00 -1583.41 -6293.33 5929059.89 679760.03 70 12 41.633 N 148 33 0.977 W i 0.00 -1583.41 -6293.33 5929059.89 679760.03 70 12 41.633 N 148 33 0.977 W 0.00 -1603.97 -5458.53 5929059.91 680595.03 70 12 41.437 N 148 32 36.744 W I -,------_....- -.-. ..--.-.-...... '-',-,.-.-.-----.".-- .- .-.-...-- -.---.... '-"-"'--------'-'----.'-'.--- - -.- .,. --".- -.---....---- .-...--.---- -- ...--- - - ._---~-_...._....__.._. ..~-_.~--.._.._------ ') ) BP Amoco Baker Hughes INTEQ Planning Report ".u,'"....,',,',................................ IN1"ßQ ...-.., -,,~...w_~._, '._'-"'--"~'" -""'- ,"._~".__..-.,""_~_'"'' ..."~'" ..".n ,~"_,-",,,,-'-;'''''-'''W..''L. . . '~"'_._...... -'--"''''''-'''''''~~' --. ...._-.....~...- . 'm .- _....._.~_....-.--.._,.w,-- -'-'-~- ~""~""""-''''-- ~.._-.__...m....._.-........,,~~....._._..w... -"-~"-"'-"'" .... -.....--...--- n_._"_----,-, - - -. --.__.. Company: BP Amoco Date: 2/28/2002 Time: 13:14:26 Field: Prudhoe Bay Co-ordlnate(NE) Reference: Well: 13-29, True North Site: PB DS 13 Vertical (TVD) Reference: System: Mean Sea Level Well: . 13~29 Section (VS) Reference: .Well (O.00N,O.00E,193.00Azi) Wellpath: Plan#6 13-29L 1 Survey Calculation Method: Minimum Curvature Db: Oracle -'~-'-'-~-"""'-"'-~'---~'-"---"-~--"----'--'-~~,-~,,-~,-""~-~--'---~""U_"-~~'--'-~"-~~-'-'_._-''''''-~.'..__...__.~~...~~.-.__.~~-~~--,-~..~----.--_.~.._-_..~.-......._._...._.~_...._.u_~~..~_._-~-- - -- -..... - ..~._- _._----_.__._-_.._.~._._.- Page: 2 Annotation --""'-'--"'-'--''''''--''-'~--- --~_.__.._.._---_.__.__. "..'--'-.---'-- _.~~--_..__.~-_.~- . .- ,-~,-~-- _.,-_.,,-y~-_... ......._-~._.._-,_...~-~- _..~. --.. .._~.._..__._.- .,--,_... ..-.._._~...._._--.._.__..-~...._._,- MD ft 11425,00 11555.44 11705.44 11785.44 11910.44 1221 0.44 12340.44 12500.00 TVD ft 8815,19 8867.00 8895.21 8899,11 8895.38 8899,57 8903.13 8930.04 2 3 4 5 6 7 8 TD ~-,---_.-.._.._.-.._--_...~._--_.._--_._---_.__._-'.'-,---~.. ---'''---''----.'-----------''''--'.--'---.--.--"...--.-.- ---.,-.-----,--.--- .---------.---.-'-'-"-'-"-.-"'--'-.'-..,_.'_h._- ,. ~----- -... -....-.---- -...,-"~-"'---_._--_._~ 'h-'_...__..._---_.__.__._--~--~------_..- -. Plan Section Information r""----""~D._._..._._.~~~___m.......,"._~~;.._..m..__..."_..--"T~D"'c--.....:,"m"'+N~S-"'.'-"-'-"'+Eï~w--'--"-:~~1SOOftd~~~~~~~-'~~~~~~'~~--"""Trf--"-T;~g;¡-'-----'''''-''''.m ---.----.-----..---.--.--..--.----..---.........-...--'L.".'''~_..~..--..-~,..~,...__._.__._.._..._-._......._~'-"-'-"-'-".~-_.'~.'-_."'."~'-'~'.""--~""~"'''''~'..._...._,-~._--...._......_.,_........__... "-"-""~~--"'~_."-- .._~~._.__....." .L_.-'..._.._-_..._--_.._..__._-....._....,..._..~......-~.~_.-..- 11300.00 43.78 281,67 8728.86 -417.99 -5727.86 0.00 0.00 0.00 0,00 11375.00 43.49 282,04 8783.14 -407,36 -5778,51 0.52 -0,39 0.49 138.77 11385.00 45.23 280.63 8790,29 -405.99 -5785.36 20,00 17.41 -14.08 330.00 11425.00 57.68 272.40 8815,19 -402.64 -5816.36 35.00 31,13 -20.57 330.00 11555.44 77.45 227.36 8867.00 -445.77 -5924,02 35.00 15.16 -34,53 285.00 11705.44 82.40 174.19 8895,21 -578.76 -5973.88 35.00 3.30 -35.44 270,00 11785.44 92.00 174,19 8899,12 -658.16 -5965.80 12,00 12.00 0,00 0.00 11910.44 91.41 159.19 8895.37 -779.40 -5937.12 12.00 -0.47 -12.00 268.00 12210.44 87.04 194.94 8899.55 -1074.07 -5921.97 12,00 -1.46 11,92 97.00 12340.44 89,82 179,58 8903.13 -1202.58 -5938.34 12,00 2.14 -11.81 280.00 12500,00 70.67 179,58 8930.04 -1359.10 -5937.19 12.00 -12.00 0.00 180.00 ------- ---.--,--~,..."_..__..._, "--'----"'-'-.- .-..--..--,-''"--.-.--...-----------..--,.,..------", ._--~-~_._."._"_.,_._-_._-,-,._--,----_.",._-,..,- ---~_._.__.'-'---'--'-,,- """~'_"_',.....__._._.._---_.__.-------".,---,---,._."-. - - .-.. - --,_..."._- -. ---~,,_......- -."..--....,.--" - ...."' Survey MD Incl Azim SSTVD N/S E/W MapN DLS VS TFO Tool ft deg deg ft ft ft ft deg/100ft ft deg . - - -.--.-... -,------- ...._~,.- -. ---.-"-.--.. ~---~_..~-'~--~~~--'_...wh~__'~_--- -~-~------~-~- ----~--'_._'.__~~'_h"'_~-----"-,,_.'_.' 11300.00 43.78 281.67 8728.86 -417,99 -5727.86 5930238.82 680296.58 0,00 1695.76 0.00 TIP 11325.00 43.68 281,79 8746.92 -414.48 -5744.78 5930241.91 680279.57 0.52 1696.15 138.77 MWD 11350,00 43.59 281,92 8765.02 -410.93 -5761.66 5930245.04 680262.61 0.52 1696.49 138.68 MWD 11375.00 43.49 282.04 8783.14 -407.36 -5778.51 5930248.19 680245.68 0,52 1696.80 138.59 KOP 11385,00 45.23 280,63 8790.29 -405.99 -5785.36 5930249.40 680238.80 20.00 1697.01 329.96 1 11400.00 49.83 277.20 8800.42 -404.29 -5796.29 5930250.83 680227.84 35.00 1697.81 330.00 MWD 11425.00 57.68 272.40 8815.19 -402.64 -5816.36 5930251,98 680207.73 34.99 1700.72 332.31 2 11450.00 60.32 262.66 8828,09 -403.59 -5837.73 5930250.51 680186.39 35.00 1706.45 285,00 MWD 11475.00 63.63 253.48 8839,85 -408.17 -5859.28 5930245.40 680164.96 35.00 1715.76 290.03 MWD 11500.00 67.49 244,86 8850.21 -416,27 -5880,51 5930236.77 680143.94 35.00 1728.43 294.35 MWD 11525.00 71,79 236.72 8858,92 -427.72 -5900.93 5930224.83 680123.81 35.00 1744.17 297.92 MWD 11550.00 76.41 228.99 8865.77 -442.23 -5920.06 5930209.85 680105.04 35.00 1762,62 300,76 MWD 11555.44 77.45 227.36 8867.00 -445.77 -5924,02 5930206.21 680101.17 34.91 /1766.96 302.99 3 11575.00 77.54 220.35 8871.24 -459.53 -5937,24 5930192.13 680088.29 35.00 1783.34 270.00 MWD 11600.00 77.92 211.40 8876.56 -479.30 -5951,54 5930172,01 680074.49 35.00 1805.83 271.52 MWD 11625.00 78,58 202.49 8881.66 -501,10 -5962.62 5930149.95 680063.95 35.00 1829.55 273.43 MWD 11650.00 79.51 193.63 8886.42 -524.41 -5970.21 5930126.46 680056.93 35.00 1853.98 275.24 MWD 11675.00 80,68 184.82 8890.73 -548,70 -5974.15 5930102.09 680053.59 35.00 1878.53 276.93 MWD 11700.00 82.07 176.09 8894.49 -573.39 -5974.35 5930077.40 680054.01 35.00 1902.63 278.45 MWD 11705.44 82.40 174,19 8895.21 -578.76 -5973.88 5930072.04 680054.61 35.06 1907.76 279.78 4 11725.00 84.75 174.19 8897.40 -598.10 -5971.91 5930052,76 680057.05 12.00 1926.15 0,00 MWD 11750.00 87.75 174.19 8899.04 -622.91 -5969.39 5930028.02 680060.19 12,00 1949.77 0.00 MWD 11775.00 90.75 174.19 8899,36 -647.78 -5966.86 5930003.22 680063.33 12.00 1973.43 0.00 MWD 11785.44 92.00 174.19 8899.12 -658.16 -5965.80 5929992.87 680064.64 12.00 1983.30 0.00 5 11800.00 91.94 172.44 8898.62 -672.61 -5964.11 5929978.47 680066.69 12.00 1997.00 268.00 MWD 11825.00 91.83 169.44 8897:80 -697.28 -5960.17 5929953.90 680071.23 12.00 2020.16 267.94 MWD 11850.00 91.71 166.44 8897.03 -721.72 -5954.95 5929929.60 680077.05 12.00 2042.79 267.84 MWD 11875.00 91.59 163.45 8896.30 -745.85 -5948.46 5929905.64 680084.13 12.00 2064.84 267.75 MWD 11900.00 91.47 160.45 8895.64 -769.61 -5940.72 5929882,08 680092.46 12.00 2086.25 267.66 MWD 11910.44 91.41 159.19 8895.37 -779.40 -5937.12 5929872.38 680096.30 12.05 2094.99 267.39 6 } ) BP Amoco Baker Hughes INTEQ Planning Report .~" '" ,..._m...'_' .~..'" -""... .,,~.._... ~ ,.-.-"... . .. .. .. -. .-,..-... ~.. . ,-,-.,-,..' -.-.- - . ,. ._......_.~~. ....-. "_Y. '" ..... ""'~'--'" ,-,~,,,'.m.. ',.--.._...__m..,.." ...--,,_...~-...~...._. .....-.-- "-"""".-'" ......,....._.._~_._. -.~.,,-.. ...-,,-. .~- '" ...,-.-......-. - "..-"..---. . ......~...._......_..~......._--.._._..~_..._-_..."..-... ..-.._~.... _.._n_..._- . 3 Company: BP Amoco Field: Prudhoe Bay Site: PB OS 13 Well: 13-29 - .Wellpa!_~~_~I~_~~~~~~~-----_m__._-_._..._--_..._--_..._. Bii. IS """....,."......"",.",."..."'.............,,,.............. INTEQ Date: 2/28/2002 Time: 13:14:26 Co-ordinate(NE)Reference: Well: 13-29, True North Vertical (TVD)Reference: System: Mean Sea Level Section (VS) Rdenmce: Well (0.00N,0.00E,193,OOAzi) Survey Calculation Method: Minimum Curvature. Db: Oracle -"---'~-'~"~---"-"'----"-"~'~----"""~O~"~"-'-_._-_..~.~_.~~_.~._-~~_..~......._-~.....~-~...~-~._---_o'~-""'._~.y,-~,,-~,-,-,,---------,----,-,--~,,~-,.-----. Survey ~''''-'''''''''''''''''''''''''-'-'~'''''--'''''~''-'''''''''-'''.''~'''''~'-''''''''-'''''''''''''.''''''''..-, ,....., "'-''''-'~''o..' "'""""'~'m..~..,, ....~,-_.._.._--_._,~.......--._-_...- Page: MD ft DLS VS deg/100ft ft -""-'~~~''''''-~-'-'-~--~'~~--~~''~~-~--''--'--'._~'._'''',-~_~._r~'_'_'-"''''''_._'-'''''-'',-,-,-""""---,~--,,~-~,,_..._.._.~~-_._. Tool Incl deg SSTVD ft Azim deg N/S ft E/W ft MapN ft MapE ft -.- -- --. 11925.00 91.20 160.92 8895.04 11950.00 90.83 163.90 8894.60 11975.00 90.46 166.88 8894.32 12000.00 90.08 169.86 8894.20 12025.00 89.71 172.83 8894.24 -793.08 -5932.16 5929858.83 680101,60 12.00 2107.20 -816.91 -5924.60 5929835,20 680109.73 12.00 2128.72 -841.10 -5918.30 5929811.17 680116.63 12.00 2150.87 -865.58 -5913.26 5929786.82 680122.27 12,00 2173,59 -890.29 -5909.50 5929762.21 680126.64 12.00 2196.82 12050.00 89.34 175.81 8894.45 -915.16 -5907,02 5929737.41 680129.73 12.00 2220.50 12075,00 88.97 178.79 8894.82 -940.13 -5905.85 5929712.48 680131.52 12.00 2244.56 12100.00 88.60 181.77 8895.35 -965.12 -5905.97 5929687.49 680132,02 12,00 2268.94 12125.00 88,24 184.74 8896.04 -990.07 -5907.39 5929662.52 680131.21 12.00 2293.57 12150.00 87.88 187.72 8896,89 -1014,91 -5910,10 5929637,63 680129,11 12.00 2318.38 TFO 97.00 MWD 97.04 MWD 97.09 MWD 97.13 MWD 97.14 MWD 97.13 MWD 97,11 MWD 97.07 MWD 97.00 MWD 96,92 MWD 12175.00 87.53 190.71 8897.89 -1039.56 -5914.10 5929612.88 680125.72 12.00 2343.30 96.82 MWD 12200.00 87.18 193.69 8899.05 -1063.97 -5919.37 5929588.36 680121.05 12,00 2368.27 96.70 MWD 12210.44 87.04 194,94 8899,55 -1074.07 -5921.97 5929578.19 680118.70 12,04 2378.69 96,37 7 12225.00 87.34 193.22 8900.26 -1088.18 -5925.51 5929564.01 680115.51 12.00 2393.23 280.00 MWD 12250.00 87.87 190,26 8901,31 -1112,63 -5930.59 5929539.44 680111.04 12.00 2418.20 280.08 MWD 12275.00 88.41 187.31 8902.12 -1137.32 -5934.40 5929514.66 680107.83 12,00 2443,12 280,21 MWD 12300,00 88.95 184.36 8902.70 -1162.18 -5936.94 5929489.75 680105.90 12.00 2467.92 280.30 MWD 12325.00 89.49 181.41 8903.04 -1187.14 -5938,20 5929464,76 680105,26 12.00 2492.52 280,37 MWD 12340.44 89.82 179.58 8903.13 -1202.58 -5938.34 5929449.33 680105.50 12.02 2507.59 280.33 8 12350.00 88,67 179.58 8903.26 -1212.14 -5938.27 5929439.77 680105.81 12.00 2516.89 180.00 MWD 12375.00 85.67 179.58 8904.49 -1237.10 -5938.09 5929414.82 680106.61 12.00 2541.18 180.00 MWD 12400.00 82.67 179.58 8907.03 -1261.97 -5937.90 5929389,97 680107.40 12.00 2565.37 180.00 MWD 12425.00 79,67 179.58 8910.86 -1286,67 -5937.72 5929365,28 680108.19 12.00 2589.39 180,00 MWD 12450,00 76.67 179,58 8915.99 -1311,14 -5937.54 5929340,83 680108.97 12.00 2613.19 180.00 MWD 12475.00 73.67 179.58 8922.38 -1335.30 -5937.37 5929316,68 680109.75 12.00 2636.70 180,00 MWD 12499.89 70.69 179,58 8930.00 -1359.00 -5937.19 5929292.99 680110,50 12.00 2659.74 180.00 13-29L 12500.00 70.67 179.58 8930.04 -1359.10 -5937.19 5929292.89 680110.51 12.00 2659.84 180.00 TD ---~._-----~--~--~------_._-_..__._-------_. . . -.--'----'----'--.'-'--"---"'-'-'----.-------",--,--.""""""'-'--"-'-"----"-'----'''-'''''''-'-- --------.--,-.--..--.-- -""'.--'___._.0.._._- --. ....-.-. .-... _.__n -.------..- .......,.-..-- -'- ~..__._-_._---_. ) ) All Measurements are from top of Riser 3/11/2002 24.71 from top of floor to rig mats 21.81 of room under floor to rig mats L- ID en a: Flanae to Flanae Heiahts 711 otis x-a .70. top of bag BAG 2.80. bttm of bag middle of slips Blind/Shears -""""'............... TOTs /' 1.90. ,...- ... middle of pipes 2-3/811 pipe/slips ......... ..." ... ~. ~ Mud Cross Mud Cross 1.70. middle of flow cross -- ~ 3-1/211 pipe/slips ........ .................. middle of blind/shears /' TOTs 1.90. ...,- ... 2-3/8 X 3.5 Var. pipe ... ... middle of pipe/slips ,........... middle of master - Tubing spool adapter .. Lock down screws Tubing Spool Rig mats H 205541 DATE 02/i5i02 CHECK NO. üú20554i DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ÃLÃSKÄOïLA NET 100.00 H 00 021302 CK021302J PYMT COMMENTS: HANDLING INST: Permit tü Drill ~ee S/H - Sonåra Steillman X4750 R: _E.- è <~~ J:: ~.V i= f"') . ,- ,(;~J ,- ~ ',<'='" \3-;;t.0¡ L\ 13. ;~ Alaska OH & Gas C( ,os, Commission ,~\1chor 3ge -- HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 205541 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00205541 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 02/15/02 AMOUNT $100.00 Tü The ORDER Of ALASKÄ OIL ÄND GÄS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS -~/ AK 99501 ç¿- "'1..4- ,: ,¡ ..-It . ... .. cr-,Pßß ~', .. ~ '----_....~..._..,,~~.. . "-~ III 20 5 5 L. ~ III I: 0 L. ¡. 20 j 8 ~ 51: 00 a L. L. ¡. ~ II' CHECK 1 STANDARD LEITER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITIAL LETTER WELL NAME /lf4 Is ~.29¿ / CHECK WHAT APPLIES ADD-ONS (OPTIONS) "CLUE" MULTI LATERAL. The permit is for jI new well bore segment of existing well /#4'I.J~PermitNc(,11-0'X;'APINo. $d "'ð~~';"':'2.0 ?2..r (If api number last two (2) Production should continue to be reported as a function of digits are between 60-69) the original API number stated above. . v PILOT HOLE (PH) . In accordance with ~O MC 25.005(1), all r~ords, data and logs acquired for the pilot hole must be clearly . differentiated in botb name (name on permit plus PH) and API number (50 ..70/80) from records, data and logs acquired for wel~ (n~me on permit). ANNUL~ Dß'POSAL . ~NO Annular disposal bas ~ot been requested... ANNULAR DISPOSAL Annular Disposal. of drilling wastes will not be approved. . . L..J YES ANNULAR DISPOSAL THIS WELL' Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS L-> YES + SP ACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,sùbJect to full compliance with 20 MC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception tbat may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY Iff ~ WELL NAME/At¡ ./?-2.7l J j. FIELD & POOL c: Lj èJ /.50 INIT CLASS /)~I./ / - 0,1 I ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . .. . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . AjÁ'~ (.~Pf\T~., 12. Permit can be issued without administrative approval.. . . . . ~ )/ IJ/ ð ~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided... . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reSE!rve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to ~50o psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . APfR - 9~TJ= 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . //,¿ "if! 31 ð2- 34. Contact name/phone for weekly progress reports [exploratory oni ANNULAR DISPOSAL 35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . Y N : ¡ .. / 1 ~ ...j. - j (B) will not contaminate freshwater; or cause drilling waste. .. Y N ju,o tiLl iLu..to\"v ~ ~f-Á] >~ ( re t, utJc;f:-f ' to surface; U (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impé:1ir recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ TE~.~'&;I¡'-\ COT SFD- WGA WGPr DTSD~/J4/0 2- JMH APPR DA TF \ú4A- 3/1'-//0'l- ê.c.;fM 'S It....-o~ GEOLOGY APPR DATE G:\geology\templates\checklist.doc PROGRAM: Exp - Dev X Redrll - Serv - Wellbore seg A Ann. disposal para req - GEOLAREA ??d UNIT# //G:ç~ ON/OFF SHORE rJ¡J ~JN Y N Y N Y N I Y N Y N Y N Y N Y N Y N Y N \ X.N \.!J N -¥-N-~ -¥~ I . t::. tJ./A 5ir/lled titLe,,-- , .~ ~ ~ C-TDu ~¥:-* Al/A. plow.. b 1 wtu'p $. fc?£íC. . &?N .-¥-N' Ai/A ~N &S ~ MS-P -= Z5~lj ff.A'. ~~ . ~ N 50 ffHA- J¿Iz.{OL Y N Y~ Y /L<A. N Y N ( \, Commentsllnstructions: