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Home My WebLink About198-146 STATE OF ALASKA -'-$-(77 ALASr<A OIL AND GAS CONSERVATION COMM*(SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 0 2 2007 1. Operations Performed: Alaska Oil & Gas Gons. Commiss p o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Ent~_!~ged Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 198-146 ./ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20659-01-00 ( 7. KB Elevation (ft): 69.68'/ 9. Well Name and Number: 12-14A ,/ 8. Property Designation: ADL 028331 ¡ 10. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool .¡ 11. Present well condition summary Total depth: measured 14047J feet true vertical 8997 feet Plugs (measured) None Effective depth: measured 14004 feet Junk (measured) 14005 true vertical 9006 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2644' 13-3/8" 2644' 2644' 4930 2670 Intermediate 11471' 9-5/8" 11471' 8875' 6870 4760 Production Liner 879' 7" 10614' - 11910' 8348' - 8995' 7240 5410 Liner 249' 4-1/2" 11306' - 14047' 8775' - 8923' 8430 7500 Scab Liner 7952' 7" 2643' - 10595' 2643' - 8336' 7240 5410 iCANNED FEB 0 7 2007 Perforation Depth MD (ft): 11710' - 13995' Perforation Depth TVD (ft): 8983' - 9008' 4-1/2", 12.6# 13Cr80 11309' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2" x 7" Baker 'S-3' packer; 10742' 4-1/2" x 7" Baker '8-3' packer 11254' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut & pull tubing f/11218' and 9-5/8" casing f/1648'. Run new 9-5/8" casing to surface. Cement w/11 0 Bbls of Class 'G' (618 cu ft /528 sx, 1.17 Yield). Run 7" scab linerf/2643' to 10595'. Cement w/215 Bbls Class 'G' (1207 cu ft /1032 sx, 1.17 Yield). Run new 4-1/2" Chrome completion. 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: NIA Subsequent to operation: 506 3,033 3,173 1,500 333 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o 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 David Reem, 564-5743 306-289 Printed Name Terrie Hubble Title Technical Assistant ~~~ œtO\ 107 Prepared By Name/Number: Signature 11 JV\n. Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 flRnMS tJt"L FEB 0 6 Z007 ÞJ;, Submit Original Only ~ 11 Digital Welltile Well Events for SurfaceWell - 12'* Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> 12 -> 12-14 Date Range: 28/Sep/2006 to 16/Dec/2006 Data Source(s): AWGRS Events Source Well Date AWGRS 12-14AL1 12/07/2006 AWGRS 12-14AL1 12/05/2006 A\^LGRS 12-14ALl 12/04/2006 A WGRS 12-14ALl 12/03/2006 AWG.RS 12-14ALl 11/26/2006 AViGRS 12-14ALl 11/18/2006 rage 1 or 1 Description SET BPV , PRE RIG T/I/O= 10/Vac/100. Temp= 51. Bleed WHP's to 0 psi (pre-RWO, post eire-out). OA FL near surface. Bled OAP to slop trailer from 100 psi to 0+ psi in 1 hour. Monitored for 30 minutes. No change pressures. Final WHP's= O/Vac/O+. ***Continued from 12-3-06 WSR*** Circ-Out. Pumped 81 bbls of diesel down tubing, U- tube to freeze protect tubing & IA. Freeze protect flowline. FWP's = 100/100/50 T/I/O=600/510/340 Circ out (pre-RWO) Pumped 5 bbls meth, 1080 bbls 1% KCL, 90 bbls diesel down tubing taking returns up the IA into jumper line and down the flowline, ****Continued on 12-4-06 WSR**** 400/540/300. Temp.= 51. ALP= Spool piece is removed. Picture of wellhead, (specifically interested in 20"x 13 5/8" starting head). Took pictures and turned in to WIE for eval. WELL SHUT IN ON ARRIVAL. SSV OPEN ON ARRIVAL. SIMOPS WITH RIG AND MOVE PIPE IN ORDER TO MAKE ROOM FOR RIG UP ON WELL. INITIAL T/I/O= 650/650/350 POWERJET CUT TUBING AT 11223' IN THE MIDDLE OF THE FIRST FULL JOINT ABOVE THE PACKER CORRELATED TO TUBING TALLY DATED 11/11/1998. TUBING AND IA PRESSURE 650 PSI BEFORE AND AFTER CUTTING THE TUBING. WELL SHUT IN ON DEPARTURE. SSV LEFT OPEN. FINAL T/I/O=650/650/350 AWGRS 12-14ALl 10/29/2006 T/I/O=650/640/340 CMIT Tx IA to 3500 psi (PASSED) (Pre-RWO) CMIT Tx IA pressured up to 3500 psi with 13.3 bbls crude. T/I lost 40/0 psi in 15 minutes and 20/0 psi in 2nd 15 minutes. For a total of 60/0 psi in 30 minutes. Bled pressure down. FWHP's=350/560/340 AWGRS 12-14ALl 10/12/2006 T/IA/OA = 51/650/340 (Pre Rig Workover Inspection / Inoperable Lockdown Screws) PPPOT-IC - Passed / Functioned Frozen Lockdown Bled inner casing packoff void to 0+ psi. Torqued lockdowns to 550 ft/lbs. Rigged up test equipment and pumped semi-clean fluid returns. Pressured up void to 1,000 psi., shut in pump and pressured source to 3,800 psi., and shocked void with pressure. Void then steadily pressured up to 3,800 psi. for 30 mins. - Passed. Packoff had prior "Seal- Tite applications in the past. Tubing Head had (1) lockdown pin backed out, that is unfunctional. Used "High- Torque" to break free (1) frozen lockdown on same flange, pin was functional. AWGR$ 12-14ALl 10/06/2006 ***** CONTINUE FROM 06/05/06 ***** «rwo prep) CMIT T*IA TO 1675/1640/400 T/IA/OA. RUN 3.5" * 10' DUMP BAILER, KNUCKLE JAR, 2.77 BLIND BOX AND DUMP BAIL 100 LBS. SLUGGITS FROM 11285' SLM TO 11275' SLM. DRIFT WITH 3.805 G.RING, 4.5 B.L.B. TO 11275' SLM (no tight spots noted) ***WELL LEFT 5/1*** DSO NOTIFIED AWGRS 12-14ALl 10/05/2006 ***WELL 5/1 ON ARRIVAL *** (pre-rwo) BRUSH X NIP. @ 11281' SLM WITH 4.5 B.L.B. AND 3.805 G. RING. SET 4 1/2 XX-PLUG @ 11,284' SLM, (4 EACH 1/8" AND 4 EACH 3/16" EQ PORTS). *** CONTINUE TO 10/06/06 *** AWG.RS 12-14ALl 10/04/2006 T/I/O=0/400/400 Load TBG & IA (RWO Prep) Pumped 675 bbls crude down lA, 170 bbls crude down TBG FWP's=200/200/700 AWGRS 12-14AL1 09/28/2006 T/I/O= 280/490/310. Temp.= 51. WHP's. IA FL, Self TIFL if possible. (WC). ALP= spool piece removed. IA FL @10361'. (555 bbls). Insufficient TBG psi to do selfTIFL. http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 2/1/2007 ""-" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/16/2006 00:00 - 03:00 3.00 MOB P PRE Move in on DS12-14, Set #2 Pump, and #4 Motor Mod, Rig Up, Bermed and Set Slop Tank, Rig Up Circulating Manifold, 03:00 - 05:00 2.00 PULL P DECOMP Pull BPV, Take on Sea Water In Pits, Pressure Test Lines to 3,500 psi. 05:00 - 05:30 0.50 PULL P DECOMP Pre-Spud Meeting in Dog House w/Rig Crew, Pre-Job With Rig Crew and Truck Drivers on Displacing Well. 05:30 - 06:00 0.50 PULL P DECOMP Reverse Circulate Freeze Protection Out of Well, Displace Well to Clean Sea Water. 06:00 - 09:00 3.00 PULL P DECaMP Pump Hi-Vis Safe Surf-O Pill, Displace Well w/Clean Sea Water. 09:00 - 11 :00 2.00 WHSUR P DECOMP Monitor Well, Set TWC, Test flBelow to 1,000 psi and Test to 3,500 psi flAbove, held for 10 minutes on Chart. 11 :00 - 13:30 2.50 WHSUR P DECaMP Blow Down Surface Lines and Nipple Down Production Tree and Adapter Flange, Bled Down Void Space on Hanger, Checked M/U of XO to Top of Hanger, Threads in Good Shape, 9 rds to M/U. 13:30 - 16:00 2.50 WHSUR P DECOMP Function Lock Down Screws, 3 Bad Ones, One had to be Ground Down. No Repairs as Spool is to Be Changed Out. 16:00 - 17:00 1.00 BOPSU P DECOMP N/U BOPE. 17:00 - 17:30 0.50 BOPSU P DECOMP RlU to Test BOPE. 17:30 - 22:00 4.50 BOPSU P DECQMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Lou Grimaldi. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Hydril, Kill HCR, TIW, Choke Valves 1,12,13,14. Test #2- Dart Valve, Manual Kill, Choke Valves 9,11. Test #3- Upper IBOP, Choke Valves 5,8,10. Test #4- Lower IBOP, Choke Valves 4,6,7. Test #5- Choke Valve #2. Test #6- HCR Choke Test #7- Manual Choke Test #8- Blind Rams, Choke Valve #3 Test #9- 4" VBR Rams Test #10- 4.5" VBR Rams Accumulater Test- 2,900 psi Starting Pressure, 1,750 psi After Actuation, First 200 psi in 23 seconds, Full Pressure in 1 Minute 27 Seconds. 5 Nitrogen Bottles at 2,150 psi. 22:00 - 22:30 0.50 BOPSU P DECOMP RID and BID Test Equipment. 22:30 - 00:00 1.50 BOPSU P DECOMP RlU DSM Lubricator and Pull TWC, RID DSC. 12/17/2006 00:00 - 01:00 1.00 PULL P DECOMP Pick Up Jt Drill Pipe, Make Up XO, Screw into Hanger 10 turns. Pull On Hanger, Unseated Hanger at 125,000 Ibs Up Weight, Tubing Broke Over at 150,000 Ibs Up Weight, String Weight = 145,000 Ibs. 01 :00 - 02:00 1.00 PULL P DECOMP CBU at 14 bpm w/930 psi. No Sign of Gas on B/U. 02:00 - 11 :00 9.00 PULL P DECOMP Lay Down Hanger, Blow Down Top Drive, POOH UD 4.5" 12.6#, 13Cr80, NSCT tubing. Tubing Condition Good, Slight Amount of Corrosion On Pin End. Clean Tubing Cut, OD 4 7/8" 11 :00 - 11 :30 0.50 PULL P DECOMP RID Tubing Handling Equipment. 11 :30 - 12:00 0.50 PULL P DECOMP Set Wear Ring. 12:00 - 12:30 0.50 PULL P DECOMP Clear and Clean Rig Floor. Printed: 1/8/2007 6:53:02 AM .",-, ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rjg Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/17/2006 12:30 - 16:00 3.50 PULL P DECaMP P/U M/U Dress Off Assemby. BHA Consist of Wash Pipe Shoe, Wash Pipe Ext, Wash Over Boot Basket, XO, 7" Scraper, Bit Sub, XO, 21 jts Drill Pipe, XO, XO, 9 5/8" Scraper, Boot Basket, Boot Basket, Bit Sub, LBS, Oil Jar, XO, 9-Drill Collars, XO,XO. BHA Lenght = 1013.13' 16:00 - 00:00 8.00 PULL P DECaMP RIH w/4" HT-38 Drill Pipe. 12/18/2006 00:00 - 01 :30 1 .50 CLEAN P CLEAN RIH, Pick Up Drill Pipe From Shed, f/9,989,to 10,614 at Top of the 7" Liner Top. Rotate Through Liner Top, Up Weight = 185,000 Ibs, Down Weight = 155,000 Ibs, Rotating Weight = 170,000 Ibs, 20 rpm, 4,000 ft-Ibs Free Torque, Continue to RIH. 01 :30 - 04:30 3.00 CLEAN P CLEAN Tight Spot and Began Taking Weight 10,000 Ibs, M/U Top Drive and Reamed f/10,800' to 11,223', 55 rpm, 10,000 ft-Ibs to 15,000 ft-Ibs Torque, 8 bpm @ 1,390 psi. With 25,000 Ibs Over Pull Through this Section. 04:30 - 05:00 0.50 CLEAN P CLEAN Tagged Tubing Stub at 11,218', Up Weight = 195,000 Ibs, Down Weight = 155,000 Ibs, Rotating Weight = 175,000 Ibs, 60 rpm, 7,000 ft-Ibs Free Torque. Washed Over Fish to 11,226', Dressed Off Top of Tubing Stub, Worked Over Shot Over Stub 3 Times. 05:00 - 06:30 1.50 CLEAN P CLEAN Circulate Hi-Vis Sweep around at 10 bpm w/2750 psi. 06:30 - 12:00 5.50 CLEAN P CLEAN Monitor Well, UD 2 jts DP, POOH SlowlyThrough 7" Liner, Had Drag Shoe at 10,850' 7" Scraperat 10,830', 95/8" Scraper at 10,150', Maximum Depth 9 5/8" Scraper is 10,526', Continue to POOH wI Wash Over Assembly to 1 ,013.30'. 12:00 - 13:00 1.00 CLEAN P CLEAN UD 95/8" Casing Scraper, Stand Back 7 Stands Of Drill Pipe UD 7" Dress Off Assembly. 13:00 - 13:30 0.50 CLEAN P CLEAN R/U Test Equipment, Test Casing to 1,000 psi f/15 minutes. 13:30 - 16:00 2.50 CLEAN P CLEAN R/U SWS E-line Tools. 16:00 - 17:30 1.50 CLEAN N DFAL CLEAN RIH w/CBL, USIT,Corrosion Log tI700' POOH Trouble Shoot Tools. 17:30 - 18:30 1.00 CLEAN N DFAL CLEAN RIH t/1,000', POOH UD Tools. 18:30 - 19:30 1.00 CLEAN N WAIT CLEAN Waiting On New String of Tools to Come From W-Pad. 19:30 - 20:30 1.00 CLEAN N DFAL CLEAN P/U New Tools, 20:30 - 00:00 3.50 CLEAN P CLEAN Log f/10,580' to 7,800'. 12/19/2006 00:00 - 02:30 2.50 CLEAN P CLEAN Run USIT Logs f/7,800' to 60'. 02:30 - 03:30 1.00 CLEAN P CLEAN Rig Down USIT Tools. 03:30 - 04:30 1.00 CLEAN P CLEAN PJSM with SLB, PDS, and Rig Crew. R/U PDS Caliper Tools 04:30 - 06:00 1.50 CLEAN P CLEAN RIH w/PDS Caliper Tools 06:00 - 10:00 4.00 CLEAN P CLEAN Log while POOH wI PDS CaliperTool 10:00 - 11 :30 1.50 CLEAN P CLEAN Download PDS Caliper Tool and test SWS circuits 11 :30 - 12:00 0.50 CLEAN P CLEAN RU shooting nipple, pump in sub, wireline BOPE and line wiper. 12:00 - 14:00 2.00 CLEAN P CLEAN PJSM. MU 3 strand string shot and RIH to 1,700'. Gammaray CCL quit. POOH and CIO Gamaray and CCL. 14:00 - 15:00 1.00 CLEAN P CLEAN RIH wI string shot to 1,638'. Fire shot across 9 5/8" casing collar f/1 ,642' to 1,654' and POOH 15:00 - 16:00 1.00 CLEAN P CLEAN RD E-Line and Equipment 16:00 - 18:30 2.50 CLEAN P CLEAN MU HES RBP Assembly and RIH to 4,000' 18:30 - 19:30 1.00 CLEAN P CLEAN Set HES RBP @ 4,000'. Element set @ 4,005', POOH to 3,943'. RU and test RBP 2,000 psi for 15 minutes. Good Test. RD test equipment. 19:30 - 21 :30 2.00 CLEAN P CLEAN POOH to 3,913'. Dump 2,200# River Sand down Drill Pipe. 21 :30 - 22:00 0.50 CLEAN P CLEAN RIH and tag top and Sand @ 3,945' Printed: 1/8/2007 6:53:02 AM ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rjg Number: Spud Date: 7/5/1992 End: 1/4/2007 12/19/2006 22:00 - 23:00 1.00 CLEAN P CLEAN POOH, standing back 4" Drill pipe. 23:00 - 00:00 1.00 CLEAN P CLEAN UD HES RBP Retrieveing Tool. P/U 9-5/8" Multi string Casing Cutter. 12/20/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN RIH w/9-5/8" Multi String Casing Cutter to 3,900'. 01 :30 - 05:00 3.50 CLEAN N CLEAN Wait on Trucks to haul Brine, no Trucks available. Inspect and service Top Drive, remove Shooting Flange from Cellar, and clean Pits. 05:00 - 06:00 1.00 CLEAN P CLEAN 290 bbls of 120 degree, 9.8 ppg Brine arrived on location. Load Brine into Pits. 06:00 - 10:30 4.50 CLEAN P CLEAN Safety Stand Down with drilling crew, all Co men, both Toolpushers, RLG rep, and BP Safety Manager. Discuss ways to improve safety and individuals commitment to safety. 10:30 - 15:00 4.50 CLEAN N CLEAN Continue waiting on Vac Truck to haul 9.8 ppg NaCI Brine to location due to no availability of Trucks. 15:00 - 16:30 1.50 CLEAN P CLEAN PJSM with Drilling Crew and Vac Truck Drivers. Displace well to 9.8 ppg NaCI Brine w/ 20 bbl HiVis Spacer Pill in front of Brine @ 5 BPM/ 980 psi. 16:30 - 17:30 1.00 CLEAN P CLEAN POOH to 1600' 17:30 - 18:30 1.00 CLEAN P CLEAN Establish Parameters of 60K up and down wt, 63K rotating wt w/ 1.5K TQ. Locate collars @ 1600' and 1644'. Circulate one pipe volume @ 2-1/2 BPM/200 psi. 18:30 - 19:00 0.50 CLEAN P CLEAN PJSM. RU and tie into Tiger Tank from wellhead. 19:00 - 19:30 0.50 CLEAN P CLEAN Cut 9-5/8",47#, L-80 CSG @ 1624' w/ 65 RPM and 2-4K TO, 3.5 - 4 BPM w/490 - 730 psi. 19:30 - 23:00 3.50 CLEAN P CLEAN Test LRHOS lines to rig to 3000 psi. Displace Drillstring w/ 16 bbls of 160 deg F hot Diesel @ 2 BPM/ 600 psi. Close Annular Preventer taking returns to the 9-5/8" x 13-3/8" Annulus. Pump 24 bbls hot Diesel @ 1/4-1/2 BPM w/ 2200 psi. Pump pressure too high to increase pump rate. Stop pumping, let soak for 10 minutes. Continue pumping 26 bbls of hot Diesel @ 1/4-1/2 BPM w/ 2200 psi. Let soak for 25 minutes. Continue pumping 20 bbls hot Diesel @ 3/4 BPM w/ 2100 psi. Let soak for 30 minutes. RD LRHOS. 23:00 - 00:00 1.00 CLEAN P CLEAN Pump 16 bbls of 120 deg 9.8 ppg NaCI Brine down the Kill Line and returns through the 9-5/8" x 13-3/8" Annulus @ 1/2- 1 BPM w/ 2200 - 2480 psi. 12/21/2006 00:00 - 03:30 3.50 CLEAN P CLEAN Continue circuating hot 120 deg 9.8 ppg NaCI Brine down the Kill Line taking returns through the 9-5/8" x 13-3/8" Annulus to the Tiger Tank @ 1/2 - 1 BPM w/2200 - 2490 psi. Stopping circulating intermittently to allow diesel to soak into and help dilute Arctic Pac. Pumped 95 bbls. 03:30 - 04:00 0.50 CLEAN P CLEAN Bleed pressure and monitor Well. 04:00 - 05:00 1.00 CLEAN P CLEAN CBU down Drill Pipe returning up the 4" DP x 9-5/8" Annulus @ 6 BPM w/ 1070 psi. Monitor Well. Arctic Pac breaking out at surface. CBU one more Annular Volume. Annular Volume of 9-5/8" x 133/8" - 95 bbls. Pumped a total of 70 bbls of 160 deg Diesel followed by 283 bbls of 120 deg 9.8 NaCI Brine. 05:00 - 06:00 1.00 CLEAN P CLEAN POOH w/ 9-5/8" CSG Cutter. Cutter took 65K overpull to pull cutter back into CSG. 06:00 - 06:30 0.50 CLEAN P CLEAN Pull Wear Ring 06:30 - 07:30 1.00 CLEAN P CLEAN PU and MU 9-5/8" CSG Spear, RIH on joint of Drill Pipe. Spear casing hanger at wellhead. 07:30 - 08:30 1.00 CLEAN P CLEAN BOLDS, Sting into hanger, Pull hanger to floor w/1 05K. UD Printed: 1/8/2007 6:53:02 AM '~' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rjg Release: 1/4/2007 Rjg Number: Spud Date: 7/5/1992 End: 1/4/2007 12/21/2006 07:30 - 08:30 1.00 CLEAN P CLEAN Spear. 08:30 - 10:30 2.00 CLEAN P CLEAN RU and circulate one 9-5/8" x 13-3/8" annular volume @ 6 BPM wI 280 psi. Mixed and pumped 20 bbl SafeSurf 0 Sweep, followed by 20 bbl HiVis Sweep. Circulate surface to surface @ 11 BPM wI 930 psi. Initial circulation brought the heaviest amounts of Arctic Pac to surface (5-10 bbls total) then cleaned up. 10:30 - 11 :00 0.50 CLEAN P CLEAN RD circulating head and RU casing tools to pull 9-5/8" casing. 11 :00 - 18:00 7.00 CLEAN P CLEAN POOH wI 9-5/8" casing and LD same. Average breakout torque 35K. Total Joints POOH- 39 and one 20.98' Cutoff Joint. Average length of casing joints- 41 .10'. Central izers recovered- 11 Bowspring including one Centralizer on the joint above the Cutoff joint. casing condition: Pipe inside and outside condition was excellent no visible signs of wear or corrosion. Pin end was used, but in excellent condition. Box end was same, used but in excellent condition with no signs of wear or galling. Cut of Cutoff Jt was ratty with 1/2 of the lip rolled over. Appears to have been in compression and dropped on cut. 18:00 - 19:30 1.50 CLEAN P CLEAN Clear rig floor and RU to PU Scraper and Washpipe BHA. 19:30 - 21 :30 2.00 CLEAN P CLEAN MU Washpipel Scraper Assy consisting of Drag Tooth Shoe, Washpipe, Boot Basket, Scraper, Bitsub, Bumper Sub, Oil Jars, 9 DC. 21 :30 - 22:30 1.00 CLEAN P CLEAN RIH wI Washpipe & Scraper to 1596'. 22:30 - 23:00 0.50 CLEAN P CLEAN Establish Parameters of 80K up and down wt, 78K rotating wt, 50 RPM wI 2K TO, 10 BPM wI 520 psi. Tag 9-5/8" casing stump @1624'. Wash down to 1659' @ 20 RPM wI 2K TO, 8.5 BPM wI 420 psi. 23:00 - 00:00 1.00 CLEAN P CLEAN Pump 2- 20 bbl HiVis Sweeps @ 10 BPM wI 600 psi. Trace amounts of Arctic Pac coming to surface while circulating. Sweeps brought back trace amounts of Arctic Pac. 12/22/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN POOH wI 11-3/4" Washover shoe, 13-3/8" Casing Scraper Assembly 01 :00 - 02:00 1.00 CLEAN P CLEAN LD Baker washpipe and scraper assembly. Rack back drill collars. 02:00 - 03:00 1.00 CLEAN P CLEAN Clear and Clean Rig Floor. Break out Bullnose Sub from Spear. 03:00 - 05:00 2.00 CLEAN P CLEAN PU Baker Back-Off BHA with Bullnose Sub, 9 DC, Blank Sub, Lower Anchor, Power Section, and Upper Anchor. RIH 05:00 - 06:30 1.50 CLEAN P CLEAN RIH wI 9-5/8" casing Back-Off Assy on 4" HT38 drill pipe to casing stub @ 1624'. Fill every 5 stand with fresh water. Collar to be backed off @ 1644'. 06:30 - 08:00 1.50 CLEAN P CLEAN Set upper and lower anchors on Baker back-off tool. Pressure up on backoff tool to 3500 psi to break connection. Back out stub a total of 5.5 turns. 08:00 - 09:00 1.00 CLEAN P CLEAN RD and POOH wet with Baker back-off assembly. 09:00 - 10:00 1.00 CLEAN P CLEAN Break and LD Baker backoff assembly. Rack back drill collars. 10:00 - 11 :00 1.00 CLEAN P CLEAN PU Baker Spear and fising assembly BHA. 11 :00 - 12:00 1.00 CLEAN P CLEAN RIH with Spear assembly on 4" HT38 drill pipe. Tag fish @ 1624'. 12:00 - 12:30 0.50 CLEAN P CLEAN Establish parameters of 60K pick up weight and 65K slack off weight. Tag 9-5/8" casing stump @ 1624' and swallow 8' down to no go. PU 5K over pick up weight and rotate 7 turns left to Printed: 1/8/2007 6:53:02 AM ~' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rjg Number: Spud Date: 7/5/1992 End: 1/4/2007 12/22/2006 12:00 - 12:30 0.50 CLEAN P CLEAN unscrew stub from 9-5/8" casing. 12:30 - 13:30 1.00 CLEAN P CLEAN POOH wI spear assembly and fish. 13:30 - 14:00 0.50 CLEAN P CLEAN LD fish and spear assembly. Cut off casing joint was 20.70'. Cut off joint came out of the hole with the collar. The 9-5/8" casing is threads up. 14:00 - 17:00 3.00 CLEAN P CLEAN Nipple down BOPE and remove 15" tall flang by flang spacer spool to make room for wach's cutter and to set slips after new 9-5/8" casing is run. Nipple up BOPE. 17:00 - 18:00 1.00 CLEAN P CLEAN RU BOPE testing equipment. Pressure test the BOP body to 2000 psi for 15 minutes and chart the results. Good Test. 18:00 - 19:30 1.50 CLEAN P CLEAN RU rig floor and handling equipment to run 9-5/8" casing. 19:30 - 00:00 4.50 CLEAN P CLEAN RIH wI 9-5/8" 47#, L-80 casing wI TC-II connections to 720'. BHA consisted of Baker Guide shoe and triple connection, HES Baffle Plate, 10' pup, HES ES-Cementer, 24' BTC Pin x TC-II Box crossover pup. 12/23/2006 00:00 - 01 :00 1.00 CLEAN N CLEAN Repair Top Drive. Remove and replace broken Link Tilt hose. No spills or incidents with the broken hose. 01 :00 - 03:00 2.00 CLEAN P CLEAN RIH wI 9-5/8" 47#, L-80, TC-II casing from 720' to 1648'. Tag casing stump. MU pups and XIO to handle and work casing string. 03:00 - 04:30 1.50 CLEAN P CLEAN Establish parameters of 105K up wt, 11 OK down wt, 11 OK rotating wt with 1 K TQ @ 9 RPM. Work casing string onto casing stump and screw together with 10.5K TQ @ 1648'. Work torque down to casing stump by working casing string and right hand rotation. Slack off right hand rotation, and pull test connection to 250K. Good test. 04:30 - 05:00 0.50 CLEAN P CLEAN RD handling tools and equipment. RU HES cement head with plugs loaded. Line up to circulate. 05:00 - 06:30 1.50 CLEAN P CLEAN Pressure up on 9-5/8" casing to 2000 psi against the ES Cementer. Hold for 20 minute and chart results. Good Test. RD test equipment. 06:30 - 07:30 1.00 CLEAN P CLEAN Pressure up on 9-5/8" casing to 2800 psi. Shear ES Cementer open. Circulate 90 deg 9.8 ppg NaCI brine at 9.5 BPM with 350 psi until brine returns came back at 80 deg F. All personnel present, and rigged up for cement job. 07:30 - 09:30 2.00 CLEAN P CLEAN PJSM with all necessary personnel. Fill cementing lines and pressure test to 4500 psi, good test. Mix and pump 110 bbls of 15.8 ppg Class "G" cement (599 sacks with a yield of 1.170 cu ftIsx) @ 5 BPM with 700 psi. Drop closing plug and displace with 118.5 bbls of 9.8 ppg NaCI Brine with rig pumps. Start displacement @ 6 BPM and 575 psi, end @ 2 BPM, bump plug with 2000 psi. Close ES Cementer as per HES rep. Hold pressure, bleed and check for backflow. CIP @ 09:30 hrs 12/23/06. 15% excess cement pumped, 15 bbls cement returned to surface. 09:30 - 10:00 0.50 CLEAN P CLEAN Flush stack, lines, and side outlet valves on wellhead with SAPP water. Clean up cementing equipment. 10:00 - 12:00 2.00 CLEAN P CLEAN Nipple down BOPE, inspect and clean API ring groove in 15" spacer spool. 12:00 - 12:30 0.50 CLEAN P CLEAN Center 9-5/8" casing in casing head. RU and set emergency slip with 120K on slips as per FMC Wellhead Specialist recommendations. 12:30 - 14:00 1.50 CLEAN P CLEAN RU and prep 9-5/8" casing stump for cutting. Install Wack's Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/23/2006 12:30 - 14:00 1.50 CLEAN P CLEAN cutter and cut casing 6" above wellhead flange by FMC rep. LD cutoff joint of 9-5/8" casing and xIo pup. RD casing handling equipment. 14:00 - 15:00 1.00 CLEAN P CLEAN Dress 9-5/8" casing stump in wellhead and install 13-3/8" x 9-518" bushing. 15:00 - 18:30 3.50 CLEAN P CLEAN ND tubing spool. Install packoff and NU new tubing spool. RU and pressure up to test pack off void to 3800 psi. Hold test for 30 minutes. Good test. 18:30 - 20:00 1.50 CLEAN P CLEAN NU BOPE and all associated lines to rig. 20:00 - 20:30 0.50 CLEAN P CLEAN M/U flushing tool to top drive and flush out BOP stack. 20:30 - 21 :30 1.00 CLEAN P CLEAN RU testing equipment to test BOPE. 21 :30 - 00:00 2.50 CLEAN P CLEAN Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was held for 5 minutes. AOGCC witness of test was waived by John Spaulding. Test was witnessed by Doyon Toolpusher and BP WSL. Test #1- Hydril, HCR Kill, Lower IBOP, Choke valves 1, 12, 13, 14. Test #2- Upper IBOP Test #3- Manual Kill and Choke HCR Test #4- Manual Choke 12/24/2006 00:00 - 04:00 4.00 CLEAN P CLEAN Continue BOPE test to 250 psi Low Pressure and 3,500 psi High Pressure. Each test was held for 5 minutes. AOGCC withness of the test was waived by John Spaulding. Test was witnessed by the Doyon Toolpusher and BP WSL. Test #5- Choke Valves 9 and 11 Test #6- Choke Valves 5,8, 10 and Dart Valve Test #7- Choke Valves 4,6,7, and TIW Test #8- Choke Valve 2 Test #9-Pipe Rams with 4" pipe Test #10- Choke Valve 3 and Blind Rams Test #11- Pipe Rams with 4 1/2" pipe Accumulater Test 3000 psi Starting Pressure, 1750 psi after actuation, Fisrt 200 psi in 14 seconds, Full pressure in 1 minutes and 19 seconds. 5 nitrogen Bottles at 2,200 psi. (Cement UCA came back at 1000 psi @ 01 :00 hrs.) 04:00 - 04:30 0.50 CLEAN P CLEAN Rig down BOP testing equipment. 04:30 - 05:00 0.50 CLEAN P CLEAN R/U and install wear ring. Gather up tools and BHA to RIH with drill out assembly. 05:00 - 06:30 1.50 CLEAN P CLEAN P/U 9-5/8" casing drill out assembly consisting of 8-1/2" used bit with no jets, 2 boot baskets, 9-5/8" casing scraper, bit sub, bumper sub, oil jars, and 9 drill collars. RIH to 318'. 06:30 - 08:30 2.00 CLEAN P CLEAN RIH from 318' to 1563' with drill out assembly on 4" HT-38 drill pipe. 08:30 - 09:00 0.50 CLEAN P CLEAN Establish parameters of 75,000# pick up weight, 80,000# slack off weight, 78,000# rotating weight @ 80 RPM and 2000# Torque. Tag top of cement at 1608'. Drill out cement at 8 BPM with 220 psi and 5000# WOB. 09:00 - 10:30 1 .50 CLEAN P CLEAN Control drill out wiper plug and HES ES Cementer at 1626' at 8 BPM with 230 psi and 5000# WOB. Pump 20 bbl HiVis Sweep @ 12 BPM with 650 psi. Sweep brought good results and brough an increase in fine metal to the surface. 10:30 - 12:30 2.00 CLEAN P CLEAN Control drill 10' of cement, Baffle Plate to 1655' with 70 RPM, Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/24/2006 10:30 - 12:30 2.00 CLEAN P CLEAN 2000# Torque, 7 BPM with 200 psi, 4000# WOB. Pumped a 20 bbl HiVis sweep at 9 BPM with 430 psi with minimal result. A slight increase in rubber and fine metal was noted. Shakers cleaned up shortly after after sweep past. 12:30 - 13:30 1.00 CLEAN P CLEAN RID circulating lines and RIH from 1655' to 3955'. 13:30 - 14:30 1.00 CLEAN P CLEAN RlU circulating lines and pump a 20 bbl HiVis sweep at 12 BPM with 1400 psi. Followed HiVis sweep with 8.5 ppg seawater to displace well from 9.8 NaCI brine to seawater. Sweep brought back minimal amounts of rubber and sand back to surface. 14:30 - 15:30 1.00 CLEAN P CLEAN RlU test equipment and pressure test the 9-5/8" casing against the HES RBP to 3500 psi. Hold test for 30 minutes and charted results. Good test. Bleed off pressure and RD testing equipment. 15:30 - 16:30 1.00 CLEAN P CLEAN POOH with drilling out assembly from 3955' to the BHA at 318'. 16:30 - 18:00 1.50 CLEAN P CLEAN POOH with drill out BHA. Lay down bit, jars,· bumper sub, xlo subs, 9-5/8" casing scraper, and 2 boot baskets. Rack back 3 stands of 6-1/4" drill collars. Clean out boot baskets. Boot baskets contents were cement and small amout of metal. 18:00 - 19:00 1.00 CLEAN P CLEAN P/U clean out BHA assembly consisting of Reverse Circulating Junk Basket, bumper dub, jars, xlo subs, and 9 drill collars as per Baker Fishing Rep. RIH to 311'. 19:00 - 20:00 1.00 CLEAN P CLEAN RIH with clean out assembly on 4" HT-38 drill pipe from 311' to 3861'. 20:00 - 20:30 0.50 CLEAN P CLEAN Make up top drive and establish parameters of 113K pick up weight, 108,000# slack off weight, 110,000# rotating weight at 60 RPM with 2K torque. Pumping at 10 BPM with 2900 psi. RIH and tag sand at 3948'. Reverse out sand to 3957'. 20:30 - 21 :00 0.50 CLEAN P CLEAN Circulate bottoms up at 9.5 BPM with 2960 psi. Bottoms up returns came dirty without any extra debris. 21 :00 - 22:30 1.50 CLEAN P CLEAN POOH with 4" HT-38 drill pipe from 3957' to 311 '. 22:30 - 00:00 1.50 CLEAN P CLEAN POOH with RCJB BHA. Clean out junk basket. Recovered nose cone and baffle plate ring with chunks of cement. 12/25/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN M/U and RIH with Reverse Circulating Junk Basket for run number 2 to 3645'. 01:30 - 02:00 0.50 CLEAN P CLEAN M/U top drive and establish parameters of 105,000# pick up weight, 104,000# slack off weight, 105,000# rotating weight at 60 RPM and 2000ftllbs of torque. Pump at 8 BPM with 2940 psi. RIH and clean out to 3995'. (Top of HES 9-5/8" RBP at 4000') 02:00 - 03:00 1.00 CLEAN P CLEAN Pump a 20 bbl HiVis sweep though well bore at 8 BPM with 2960 psi. Sweep brought an increase in sand and small amounts of fine metal to surface. Sand strung out past the sweep. Circulate until clean. 03:00 - 04:30 1.50 CLEAN P CLEAN POOH with Reverse Circulating Junk Basket run number 2. 04:30 - 06:00 1.50 CLEAN P CLEAN Change out elevators, lay down 6 1/4" drill collars. Lay down RCJB, bumpers sub, oil jars, and xlo subs. No debris was recovered in this second junk basket run. 06:00 - 06:30 0.50 CLEAN P CLEAN Clear and clean rig floor for next operation. Pick up HES RBP retreiveing tool for 9-5/8" RBP. MU to specs as per HES rep. 06:30 - 08:00 1.50 CLEAN P CLEAN RIH with HES retrieving tool on 4" HT-38 drill pipe. 08:00 - 08:30 0.50 CLEAN P CLEAN Establish parameters of 95,000# pick up weight, 95,000# slack off weight. Tag top of sand at 3992'. Wash sand off RBP Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/25/2006 08:00 - 08:30 0.50 CLEAN P CLEAN latch. Latch up to RBP and pull 20,000# overpull. Relax and pull 20,000# overpull to confirm proper connection. 08:30 - 10:30 2.00 CLEAN P CLEAN Unsting from RBP, and pump 20 bbl HiVis sweep to assist hole cleaning at 10 BPM with 2790 psi. Sweep brought back good result. Sand continued to come back after sweep. Continued to circulate until well cleaned up. POOH one stand and install TIW safety valve. 10:30 - 12:00 1.50 CLEAN P CLEAN Stand down for Christmas dinner with both crews. 12:00 - 13:00 1.00 CLEAN P CLEAN Slip and cut 123' of drill line. 13:00 - 14:30 1.50 CLEAN P CLEAN RIH one stand. Latch up to 9-5/8" RBP and pull up to 10,000# overpull. Relax and set 25,000# on the elements and turn 1/2 turn to the right. Pick up to 15,000# overpull and the packer released. 14:30 - 15:30 1.00 CLEAN P CLEAN Circulate bottoms up at 8 BPM with 580 psi. Monitor well for 10 minutes. 15:30 - 17:00 1.50 CLEAN P CLEAN POOH with 9-5/8" HES RBP. 17:00 - 17:30 0.50 CLEAN P CLEAN Lay down 9-5/8" HES RBP, and pick up HES model3L 7" RBP on 4" HT-38 drill pipe. 17:30 - 22:00 4.50 CLEAN P CLEAN Pick up 4" HT-38 drill pipe from derrick and RIH with 7' HES RBP to 10,693'. 22:00 - 23:00 1.00 CLEAN P CLEAN Spot HES RBP as per HES rep. Top of packer depth at 10,693', packer elements set at 10,696'. Unsting from HES RBP and POOH to 10,650'. R/U and pressure iJp to test HES RBP to 2500 psi. Hold test for 15 minutes and chart results. Good test. 23:00 - 00:00 1.00 CLEAN P CLEAN Dump 1200# of 20 x 40 mesh river sand down the drill string on top of HES RBP. 12/26/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Dump 1200# of 20 x 40 Mesh River Sand down drill string to protect top of HES RBP. 01 :00 - 02:30 1.50 CLEAN P CLEAN POOH to 10,616' (top of 7" Liner at 10,614'). Pump 1 drill string volume at 2 BPM with 90 psi to clear sand from drill string. 02:30 - 03:00 0.50 CLEAN P CLEAN Shut down pumping and stand by for 15 minutes to allow river sand to settle on top of HES RBP. RIH and verify top of sand at 10,632' (top of HES RBP set at 10,693', sand depth- 61'). 03:00 - 07:30 4.50 CLEAN P CLEAN POOH with HES RBP retrieving tool. Lay down retrieving tool. 07:30 - 13:00 5.50 CLEAN P CLEAN P/U Baker Polish Mill assembly to polish 7" Casing Tie-Back Stem and RIH on 4" HT-38 drill pipe to 10,541'. 13:00 - 13:30 0.50 CLEAN P CLEAN Establish parameters of 175,000# pick up weight, 142,000# slack off weight, 161,000# rotating weight at 40 RPM with 4,000 ftllbs torque. Establish circulation at 3 BPM with 220 psi off bottom. Tag top of liner at 10,614'. Polish through PBR with 260 pump pressure. Made three passes through PBR. Torque ran 7,000 to 8,000 ftllbs while polishing PBR. 13:30 - 15:00 1.50 CLEAN P CLEAN POOH to 10,541'. Pump 20 bbl high-vis Sweep at 12 BPM with 2780 psi. Sweep only brought back small amounts of brass. 15:00 - 18:30 3.50 CLEAN P CLEAN POOH from 10,541'. Stand back 4" HT-38 drill pipe. 18:30 - 21 :00 2.50 CLEAN P CLEAN Clean and organize rig floor. R/U to run 7", 26#, L-80 BTC-M casing. 21 :00 - 00:00 3.00 CLEAN P CLEAN M/U Baker ported seal-stem assembly with 20' L-80 BTC-M, 26#, 7" casing pup jt with float collar inserted in box end; 1 jt 7", 26#, L-80 BTC-M casing; 1 jt 7" 26#, L-80 BTC-M casing with Printed: 118/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/26/2006 21 :00 - 00:00 3.00 CLEAN P CLEAN landing collar inserted in pin end. Baker-Loc shoe tract and RIH with 7",26#, L-80 BTC-M casing to 746'. Making up each joint to mark, using Best-O-Life 2000 pipe dope. Average make up torque 8,000 ftIlbs. 12/27/2006 00:00 - 10:00 10.00 CASE P TIEB2 RIH with 7", 26#, L-80 BTC-M casing from 746' using Best-O-Life 2000 pipe dope, and making up each joint to mark. Average make up torque 8,400 ftIlbs. 10:00 - 10:30 0.50 CASE P TIEB2 C/O Elevators and M/U 7" Liner Hanger and Liner Top Packer. P/U Wt = 220,000 Ibs, SIO Wt = 190,000 Ibs 10:30 - 12:00 1.50 CASE P TIEB2 C/O Elevators and Bails. RlU to Run Liner in hole on DP. 12:00 - 14:00 2.00 CASE P TIEB2 RIH with 7" Liner on DP from Derrick. Rabbit DP to 2-1/4" Prior to RIH. 14:00 - 14:30 0.50 CASE P TIEB2 M/U DP to Top Drive, Establish P/U Wt = 255,000 Ibs ; S/O Wt = 191,000 Ibs. Continue in hole wi Liner on DP. Tag Up High approx 25'. Set Down 10,000 Ibs with no change in depth. P/U and Break Circulation. Pump 2 bpm at 60 psi. S/O again to same depth. P/U and Repeat Twice. With Liner Stacked Out wi 10,000 Ibs, attempt to circ. Pressure Up to 500 psi, hold for 3 mins wi no bleed off. Bleed off Pressure and P/U 4 feet. Establish Circulation at 2 bpm and 60 psi. S/O and Stack Out again. Attempt to Circulate at 2 bpm. Pressure Up to 500 psi. Bleed Off Pressure and P/U 4 ft. Establish Circ again at same rate and pressure. Confirmed in Tie Back SLeeve. 14:30 - 15:30 1.00 CASE P TIEB2 B/O top drive and Set Back one Stand in Derrick. P/U 2 - 10' Pup Joints and 2 - 15' Pup Joints. M/U Baker Liner Cement Head to String. 15:30 - 16:00 0.50 CASE P TIEB2 WI Cement Head Made Up. SIO and Take Measurements where Liner Stacks Out and 4 ft lower for circulation holes. Confirm Circulation at 2 bpm and 60 psi again and liner pressures up 4 ft in. 16:00 - 16:30 0.50 CEMT P TIEB2 PJSM with SLB Pumping Services, Rig Crew, Baker Packer, and Veco Truck Drivers. 16:30 - 17:00 0.50 CEMT P TIEB2 SLB Pumpers to prime up pump unit. Pump 10 bbls fresh water and PT lines to 4500 psi. 17:00 - 18:00 1.00 CEMT P TIEB2 Pump 215 bbls of 15.8 ppg Class G Unislurry. Mix Cmt on the fly and Pump at 5 bpm and 240 psi for job. 18:00 - 19:30 1.50 CEMT P TIEB2 Drop Drill Pipe Wiper Dart from Baker Cement Head and Chase with 5 bbls water from SLB Pumpers. Rig displaced with 325 bbls of SW. Start displacement at 5 BPM with 170 psi. Bumped plug on strokes at 1.7 BPM with 2300 psi. CIP at 19:20 hrs. 19:30 - 20:00 0.50 CEMT P TIEB2 Bleed off pressure. Stab seal assembly into PBR and stack 50,000 Ibs on PBR. Pressure up to 3,500 Ibs to set liner hanger. Stack 75,000 Ibs on liner hanger and pressure up to 4,000 Ibs to energize liner packer. Bleed off pressure slack off 10,000 Ibs. Put 14 right hand revolutions in workstring to unlatch liner top from running tool. Pressure up to 1 ,000 Ibs and pull out of liner top. CBU at 10 BPM with 1050 psi. 2 bbls of CMT returned to surface. TOL- 2643' MD. 20:00 - 20:30 0.50 CEMT P TIEB2 POOH 17' and sweep well with SAPP water sweep at 10 BPM with 1030 psi. 20:30 - 22:30 2.00 CEMT P TIEB2 RID cementing lines and POOH with 7" casing liner running tool. Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rjg Number: Spud Date: 7/5/1992 End: 1/4/2007 12/27/2006 22:30 - 23:30 1.00 CEMT P TIEB2 Break down cement head and 7" liner running tool. 23:30 - 00:00 0.50 CEMT P TIEB2 Clear and clean rig floor. 12/28/2006 00:00 - 00:30 0.50 CEMT P TIEB2 Clear and clean rig floor. RlU and rinse BOPE with SAPP water. 00:30 - 03:00 2.50 CLEAN P CLEAN P/U drill out assembly consisting of 6.125" used bit, 2 boot baskets, 1 5-3/8" OD casing scraper, bumper sub, oil jars, and 12 drill collars 4-3/4". Total length of BHA - 405'. Recieved CMT 500 psi compressive strength at 02:00 hrs. 03:00 - 07:00 4.00 CLEAN P CLEAN RIH with drill out assembly on 4" HT-38 drill pipe. Did not see TOL at 2,643' while RIH. 07:00 - 08:00 1.00 CLEAN P CLEAN Tag up on Cement at 9,916'. P/U and Establish Parameters; Up Wt = 190,000 Ibs; Down Wt = 140,000 Ibs; Pump rate = 7.5 bpm at 1500 psi. Free Torque = 8,000 ft-Ibs at 80 rpm's. Drill Cement from 9,916', circulate intermitant High Vise sweeps while drilling. Drill up 7" wiper plug at 10,072'. Circulate around High Vise Sweep from surface to surface to confirm, found black rubber at bottoms up. 08:00 - 15:00 7.00 CLEAN P CLEAN Continue to drill cement from 10,072' to 10,544'. Tag Up on Landing Collar at 10,544'. Required 1 hr to drill through Landing Collar with 15,000 WOB, 80 RPM's, 8,000-12,000 ft-Ibs Torque. 15:00 - 16:30 1.50 CLEAN P CLEAN Continue to Drill Cement from Landing Collar at 10,544' to Float Collar at 10,590'. Required.5 hrs to Drill FLoat Collar with 15,000 Ibs WOB. Once through Float Collar drill cement to 10,620'. Drilled a total of 704' of cement. A total of 472' of cement between Wiper Plug and Landing Collar = 18 bbls in 7" 26# casing. 16:30 - 17:00 0.50 CLEAN P CLEAN Wash down to Top of Sand at 10,632' and Clean Out 8 ft to 10,640'. Circulate Bottoms Up at 11 BPM and 3,000 psi. 17:00 - 19:00 2.00 CLEAN P CLEAN Continue to circulate well clean at 10 BPM with 3,180 psi while waiting on clean seawater to arrive on location. Clean Out Cuttings Box of Cement Cuttings. Clean and Drain Pit #4 for clean seawater. 19:00 - 20:30 1.50 CLEAN P CLEAN Displace well to clean Seawater by pumping 20 bbl HiVis (FloVis) spacer followed by 450 bbls of Seawater. 20:30 - 21 :00 0.50 CLEAN P CLEAN POOH 1 stand and RlU to test Casing. 21 :00 - 22:00 1.00 CLEAN P CLEAN Test Casing integrity of 7" Liner to 3,500 psi for 30 minutes. Good Test. Charted results. Bleed pressure and RID testing equipment. 22:00 - 00:00 2.00 CLEAN P CLEAN POOH from 10,562' to 7,305' with drill out assembly. Rack back 4" Ht-38 drill pipe. 12/29/2006 00:00 - 02:30 2.50 CLEAN P CLEAN POOH w/ Drill Out Assembly on 4" HT-38 Drill Pipe from 7,305'. Rack back Drill Pipe. 02:30 - 03:00 0.50 CLEAN P CLEAN Break down Drill Out BHA. Lay down Boot Baskets, and scraper. Boot Baskets were full of cement with small amounts of metal. Rack back 4 stands of Drill Collars. 03:00 - 04:00 1.00 CLEAN P CLEAN P/U RCJB with Bumper Sub, Oil Jars, and 12 Drill Collars. Total length of BHA= 402'. 04:00 - 08:00 4.00 CLEAN P CLEAN RIH with RCJB on 4" HT-38 Drill Pipe to 10,592' MD. Establish parameters of 210,000 Ibs pick up weight, 135,000 Ibs slack off weight, 168,000 Ibs rotating weight at 40 RPM with 8,000 ft-Ibs Torque off bottom, pumping at 5.5 BPM with 2150 psi. 08:00 - 08:30 0.50 CLEAN P CLEAN RIH to top of sand at 10,640'. Wash sand to 10,670' at 8.5 Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rjg Number: Spud Date: 7/5/1992 End: 1/4/2007 12/29/2006 08:00 - 08:30 0.50 CLEAN P CLEAN BPM with 2150 psi, keeping 5,000 Ibs WOB, at 50 RPM and 12,000 ft-Ibs Torque. 08:30 - 09:30 1.00 CLEAN P CLEAN Pump a High Vise sweep at 8.5 BPM with 2500 psi. Sweep only brought a slight increase in cuttings to surface. 09:30 - 13:30 4.00 CLEAN P CLEAN POOH wI RCJB standing back 4" HT-38 drill pipe. 13:30 - 14:00 0.50 CLEAN P CLEAN POOH with RCJB BHA. Rack back 4 stands of 4-3/4" drill collars and empty RCJB. Large fist size chucks of cement and small metal pieces in Junk Basket. Recovered approx 1 gallon of debris. Decission to make 2nd RCJB run. 14:00 - 15:00 1.00 CLEAN P CLEAN M/U RCJB and RIH with 4 stands of 4-3/4" drill collars from derrick. 15:00 - 18:30 3.50 CLEAN P CLEAN RIH with RCJB on 4" HT-38 drill pipe from derrick to 10,465' MD. Notify AOGCC of 24 hours notice of upcoming BOP test at 1600 hrs. 18:30 - 19:30 1 .00 CLEAN P CLEAN Slip and cut 104' of drill line. 19:30 - 20:00 0.50 CLEAN P CLEAN RIH from 10,465' to top of sand at 10,670' MD. Establish parameters of 215,000 Ibs up weight, 135,000 Ibs down weight, 166,000 Ibs rotating weight with 40 RPM and 9,000 ft-Ibs torque off bottom. Pump at 5 BPM with 800 psi off bottom. Wash sand to 10,685' with 8 BPM with 2070 psi and 10-15 RPM with 10,000 ft-Ibs torque on bottom. 20:00 - 21:30 1.50 CLEAN P CLEAN Pump 20 bbl High Vise sweep at 8 BPM with 2940 psi. A noticeable increase of sand was brought to surface by the sweep which cleaned up shortly afterwards. 21 :30 - 00:00 2.50 CLEAN P CLEAN POOH with RCJB from 10,685' to 5386'. Stand back 4" HT-38 drill pipe. 12/30/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN POOH with RCJB from 5386' to 402'. Stand back 4" HT-38 drill pipe. 01 :00 - 02:00 1.00 CLEAN P CLEAN POOH and lay down RCJB assembly. Stand back 4-3/4" drill collars. Junk Basket was empty. 02:00 - 02:30 0.50 CLEAN P CLEAN Pick up HES RBP retrieving tool and 4 stands of 4-3/4" drill collars. 02:30 - 06:00 3.50 CLEAN P CLEAN RIH w/ HES RBP retrieving tool assembly on 4" HT-38 drill pipe from derrick to 10,600' MD. 06:00 - 06:00 24.00 CLEAN P CLEAN Establish parameters of 215,000 Ibs up weigh, 135,000 Ibs down weight. Wash down and tag top of PBR at 10,693' MD. Rotate 3 turns right to engage HES RBP. Slack off 15,000 Ibs and pull up 10,000 Ibs overpull on HES RBP. Repeated 3 times. On the third time with 20,000 Ibs overpull, the RSP unseated. Rotate 1 turn right and RIH below RBP set depth of 10,693' MD to confirm release. 06:00 - 07:00 1.00 CLEAN P CLEAN Circulate bottoms up at 10 BPM with 2750 psi. Bottoms up returns were clean. 07:00 - 11 :30 4.50 CLEAN P CLEAN POOH with HES RBP from 10,693' to 378'. Rack back 4" HT -38 drill pipe in derrick. 11 :30 - 12:00 0.50 CLEAN P CLEAN POOH with HES RBP retrieving tool BHA. Stand back 4-3/4" drill collars. Lay down HES RBP and running tool. HES RBP missing 1 full rubber element and 1/2 rubber spacer ring. 12:00 - 12:30 0.50 CLEAN P CLEAN Break down Baker RCJB and send to Baker shop for modifications to fish RBP rubber elements. 12:30 - 13:00 0.50 CLEAN P CLEAN Pull wear ring and set BOP test plug. R/U to test BOPE. 13:00 - 18:30 5.50 CLEAN P CLEAN Test BOPE to 250 psi low pressure and 3,500 psi high pressure. Each test was held for 5 minutes. AOGCC witness Printed: 1/8/2007 6:53:02 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/30/2006 13:00 - 18:30 5.50 CLEAN P CLEAN of test was waived by Chuck Sheve. Test was witnessed by Doyon Toolpusher and BP WSL. Test #1- Annular Preventer, HCR Choke, HCR Kill, Upper IBOP Test #2- Lower IBOP, Manual Choke, Manual Kill Test #3- Variable Pipe Rams on 4" Test Joint Test #4- Blind Rams, and Choke Valves 9 and 11 Test #5- Choke Valves 5,8, and 10 Test #6- TIW Valve, and Choke Valves 4,6, and 7 Test #7- Dart Valve, and Choke Valve 2 Test #8- Choke Valve 3 Test #9- Choke Valves 12, 13, 14, and 1 Test #10- Variable Pipe Rams on 4-1/2" Test Joint Accumulater Test- 2950 psi starting pressure, 1800 psi after actuation. First 200 psi in 14 seconds. Full pressure in 1 minute and 18 seconds. 5 Nitrogen bottles at 2,200 psi RID test lines and testing equipment. 18:30 - 19:00 0.50 CLEAN P CLEAN M/U Baker RCJB BHA consiting of 18.68' RCJB, bumper sub, oil jars, and 12 drill collars (4-3/4") and RIH. Total length of BHA= 408.87'. 19:00 - 00:00 5.00 CLEAN P CLEAN RIH with RCJB assembly on 4" HT-38 drill pipe from 408' to 10,567'. Wash through the top of the liner at 2643 at 7.5 BPM with 1250 psi. 12/31/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Establish parameters at 10,567' MD of 215,000 Ibs pick up weight, 135,000 Ibs slack off weight, 160,000 free rotating weight at 40 RPM and 8,000 ft-Ibs torque, pumping at 7.5 bpm with 2250 psi. Wash from 10,567' to 11,141' MD. Reestablished parameters of 218,000 Ibs pick up weight, 135,000 Ibs slack off weight, and 165,000 free rotating weight at 40 RPM and 8,000 ft-Ibs torque. Pumping at 6.5 bpm and 1935 psi pump pressure. Wash from 11,141'. Tagged top of 4-1/2" tubing stump at 11,218' and continue washing over tubing to 11,225' MD. There were no indictation of tight casing through this section. Logs showed possible damaged casing at 11,800' to 11,806'. No problems were noticed while washing through. 01 :00 - 02:00 1.00 CLEAN P CLEAN POOH to 11,217'. Pump 20 bbl high viscosity sweep at 8 bpm and 2250 psi. CBU and sweep brought rubber to surface. 02:00 - 07:00 5.00 CLEAN P CLEAN POOH with RCJB from 11,217' to 408'. Rack back 4" HT-38 drill pipe. 07:00 - 07:30 0.50 CLEAN P CLEAN POOH from 408' with RCJB BHA. Stand back 4 stands of 4-3/4" drill collars. UD RCJB. No recovery in RCJB. 07:30 - 08:00 0.50 CLEAN P CLEAN P/U and RIH with Baker GS Spear BHA assembly consisting of bit sub, 3 joints of 2-7/8" Pac pipe, bumper sub, oil jars, pump out sub, and 4 stand stands of 4-3/4" drill collars. Total length of BHA= 494.86'. 08:00 - 12:30 4.50 CLEAN P CLEAN RIH with Baker GS Spear BHA assembly on 4" HT-38 drill pipe from derrick to 11,132'. 12:30 - 13:30 1.00 CLEAN P CLEAN M/U top drive and establish parameters of 220,000 Ibs pick up weight, 140,000 Ibs slack off weight, 175,000 Ibs free rotating weight at 40 RPM and 8,000 ft-Ibs torque, pumped at 1.5 bpm and 1120 psi. Continue to RIH just to top of 4-1/2" Tbg Stub at Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/31/2006 12:30 - 13:30 1.00 CLEAN P CLEAN 11218'. Pump 40 bbl High Vise Sweep at 2.0 bpm and 2360 psi. 13:30 - 14:30 1.00 CLEAN P CLEAN With Sweep near end of DP. Continue in hole. Tag Up and Take Wt at 11248'. P/U and Establish Rotation at 40 RPM and 8,000 torque. SIO and Clean Out Tbg. Required to Work Pipe in and out of 4-1/2" Tbg Stub to get down to Top of XX Plug at 11287'. Once Down on Top of Plug, Shut Down Rotation and Pumps, and SIO to Latch "XX" plug wI GS Spear. Never Saw Plug when S/O. Continue to SIO to 11301' wI no Wt Gain. -- Did See Loss in Return. A small decrease in returns was noticed when Washing Down above plug -11285'. Loss Rate Slowly increase to Full Losses over about 10 mins. 14:30 - 15:00 0.50 CLEAN P CLEAN P/U out of 4-1/2" Tbg Stub and Break Connection. Drop Dart for Pump Out Sub. Pump Down Dart at 2 bpm and 500 psi. Required 15 mins and 3500 psi to Shear Open Sub. 15:00 - 16:00 1.00 CLEAN P CLEAN POOH standing back 2 stands of 4" HT-38 drill pipe. Monitor well and establish loss rate. Fill Hole with Rig Pump at 6.5 bpm and Hole Fill Pump On, Total Rate - 12 bpm. Received returns after pumping 50 bbls. Able to keep small % returns at 7 bpm. Loss rate= 350 bph at 7 bpm and 100 psi. Pump a total of 100 bbls prior to POOH. 16:00 - 00:00 8.00 CLEAN P CLEAN POOH laying down 4" HT -38 drill pipe from 11,132' to 2282' MD. Using double displacement while POOH. 1/1/2007 00:00 - 01 :00 1.00 CLEAN P CLEAN POOH from 2283' to 494'. Lay down 4" HT-38 drill pipe. Using double displacement while POOH. 01 :00 - 02:30 1.50 CLEAN P CLEAN POOH from 494'. Lay down 12,4-3/4" drill collars, oil jars, bumper sub, 3 joints 2-7/8" Pac pipe, and subs. POOH wI GS Spear. "XX" Plug not recovered with GS Spear. 02:30 - 04:30 2.00 CLEAN N CLEAN Discuss options with Anchorage. Decision made to RIH with GS Spear to recover "XX" plug. Load BHA in pipe shed and send to coil shop for new GS Spear. 04:30 - 06:00 1.50 CLEAN N CLEAN PI U GS Spear assembly with 5 joints of 2-7/8" Pac pipe, bumper sub, oil jars, pump out sub, xlo subs, and 12 drill collars. 06:00 - 09:00 3.00 CLEAN N CLEAN PI U DP 1x1 from Shed and RIH. Pump 15 bbls every 15 mins while RIH. 09:00 - 09:30 0.50 CLEAN N CLEAN Consult with Town Again and Decide Slickline is Best Option. Change Plans to POOH and Rack Back the 3000' of DP in hole and R/U SLickline to Fish Plug. 09:30 - 11 :30 2.00 CLEAN N CLEAN POOH, Rack Back DP and DC's. Lay Down 5 Joints of 2-7/8" Pac DP and GS Spear. Continue to fill hole wI 15 bbls I 15 mins. 11 :30 - 13:00 1.50 CLEAN N CLEAN N I D Flow Riser and N I U 7" Otis Shooting Flange. 13:00 - 13:30 0.50 CLEAN N CLEAN PJSM wI Slickline Crew and Rig Crew 13:30 - 15:30 2.00 CLEAN N CLEAN R/U Slickline Riser Section, Pump In Sub, BOP's, and Lub. 15:30 - 18:00 2.50 CLEAN N CLEAN M I U Slickline Tools and Rope Socket. Bring Slickline Tools and Equipment to Rig Floor. Pressure Test Slick Line Surface Equipment. 18:00 - 20:00 2.00 CLEAN N CLEAN RIH with 5.98" Wireline Gauge Ring and Junk Basket to 11,229' SLM. Tag 4.5" Tubing Stump and POOH. Lay down Gauge Ring and Junk Baskets. No recovery in Junk Baskets. 20:00 - 22:30 2.50 CLEAN N CLEAN PI U and RIH with 8' Pump Bailer with Equalizer Prong to 11,309'. POOH. One Gallon of Sand and pieces of rubber Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 111/2007 20:00 - 22:30 2.50 CLEAN N CLEAN recovered from Bailer. 22:30 - 00:00 1.50 CLEAN N CLEAN RIH with same Bailer with Equalizer Prong 1/2/2007 00:00 - 01 :00 1.00 CLEAN N CLEAN RIH with Pump Bailer and Equalizer Prong to 11,315' SLM. POOH. Small amounts of Junk in Bailer. 01 :00 - 03:00 2.00 CLEAN N CLEAN RIH with GR Pulling Tool to 11,316'. Latch up and Jar "XX" Plug. Pull up to "X" Nipple. Pulling Tool sheard off at 11,294' SLM. POOH with sheared GR Pulling Tool. 03:00 - 04:00 1.00 CLEAN N CLEAN RIH with Equalizer Prong with 3.5 Centralizer to 11,339' SLM . Tapped down and POOH. Prong showed marks from plug. 04:00 - 05:00 1.00 CLEAN N CLEAN RIH with GR Pulling Tool to 11,250'. POOH with GR Pulling Tool without Plug. Tool sheared off. 05:00 - 06:00 1.00 CLEAN N CLEAN PI U and RIH with GS Pulling Tool to 11,249'. Latch up to Plug and POOH. "XX" Plug OOH at 06:00 hrs. 06:00 - 07:00 1.00 CLEAN N CLEAN UD Slickline Tools and Plug. UD Slickline BOP's and Lubricator. 07:00 - 08:00 1.00 CLEAN N CLEAN N I D Shooting Flange and N I U Flow Riser. 08:00 - 09:30 1.50 CLEAN N CLEAN P/U Baker Hydraulic GS Spear BHA. RIH wI BHA. POOH, B/O and UD BHA. 09:30 - 10:30 1.00 CLEAN N CLEAN RIHw/4 Stands of DC's from Derrick and 19 Stands of DP. 10:30 - 13:00 2.50 CLEAN N CLEAN POOH and UD DP and DC's. 13:00 - 14:00 1.00 CLEAN N CLEAN RIH wI Remaining 5 Stands of DP from Derrick. Slip and Cut 80' for Drilling Line. 14:00 - 15:00 1.00 CLEAN N CLEAN POOH wI DP and UD. 15:00 - 16:00 1.00 RUNCO RUNCMP Rig Up to Run 4-1/2" 13Cr80 Tbg Completion. Lay Out Completion in Pipe Shed. 16:00 - 16:30 RUNCMP PJSM on Running Tbg Completion. 16:30 - 00:00 RUNCMP Run 4-1/2", 12.6#, 13Cr80 Tbg Completion. Average M/U Torque for Vam Top Tubing 4,450 ft-Ibs. Average M/U for JFE Bear Tubing 4,500 ft-Ibs Torque. Using Jet Lube Seal Guard Pipe Dope. Torque Turning All Connections. 1/3/2007 00:00 - 12:00 12.00 RUNCO P RUNCMP Continue to Run 4-1/2", 12.6#, 13Cr80 Tbg Completion. Average M/U Torque for Vam Top Tubing 4,450 ft-Ibs. Average M/U for JFE Bear Tubing 4,500 ft-Ibs Torque. Using Jet Lube Seal Guard Pipe Dope. Torque Turning All Connections. 12:00 - 13:00 1.00 RUNCO P RUNCMP M/U Joints #270 and #271. M/U Circulating Head to Jt #271. P/U Wt = 167,000 Ibs, S/O Wt = 119,000 Ibs. Establish Pump Rate at 2.0 bpm and 60 psi. S/O to confirm space out. Tag up on Shear Pins at 11233', Shear Out Pins wI 5,000 Ibs. Continue in hole, start taking wt at 11237'. Stack 15,000 Ibs at 11238'. P/U and reconfirm depths, did not see anything at 11233' but stacked 15,000 Ibs at 11238' again. P/U and make -1/2 turn and S/O. Stacked 10,000 Ibs at 11228'. P/U and make another -1/2 turn. S/O, begin taking wt at 11237' and stack 15,000 Ibs at 11238'. 13:00 - 14:00 1.00 RUNCO P RUNCMP LID circulating head, Jt #271 and Jt#270. M/U 2.03' Pup Jt and M/U Jt#270 again. 14:00 - 14:30 0.50 RUNCO P RUNCMP M I U FMC Tbg Hanger and TC-II Landing Joint to string. S/O and Land Hanger. Thaw Out Inner Annulus Valve, found ice inside when confirming if hanger at proper seating depth. 14:30 - 15:00 0.50 RUNCO RUNCMP PJSM wI Rig Crew and Vac Trucks on Pumping Seawater Displacement and Corrosion Inhibitor. 15:00 - 15:30 0.50 RUNCO RUNCMP With Inner Annulus Valve Thawed out able to confirm Hanger at proper depth. RILDS, Printed: 1/8/2007 6:53:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/16/2006 Rig Release: 1/4/2007 Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 20:30 - 21 :30 Pump 180 bbls of 120 degree SW followed by 300 bbls of 120 degree SW wI corrosion inhibitor at 3 bpm and 290 psi. Partial returns at surface seen after pumping 245 bbls. RUNCMP RID Circ Equipment, Drop Ball and Rod, UD Landing Jt, Linue Up and Fill Tubing. RUNCMP Pressure up and Set Packer, Continue to Pressure up to 3,500 psi and Tested Tubing to 3,500 psi for 30 Charted Minutes, Good Test Bled Tubing Pressure Down to 1,750 psi. Lined up and Pressured up on Annulus at 3,000 psi Tubing Pressure Equilized with Annulus Pressure. Continued to Pressure up to 3,500 psi and Held Test for 30 Charted Minutes. Sled off Annulus Pressure and Tubing Pressure Followed Annulus Pressure to 0 psi. It is Believed DCK Shear Valve Opened Prematurely. RUNCMP Lined up and Pumped from Annulus Side at 1.7 bpm with 410 psi, Return Observed at Surface. Lined up on Tubing Side and Pumped at 1.7 bpm with 410 psi Returns Observed to Confirm DCK Valve Communication for Freeze Protecting Well Lined up and Retested Annulus Side for 30 Charted Minutes at 3,500 psi, Tubing Side Tracked Annulus Pressures-CMIT. GOOD Test Set TWC. Pressure Test to 1000 psi from below and 3500 psi above. Blow Down Lines and Drain BOP Stack. N/D BOPE and Set Back on pedestal. N/U Adapter Flange. Pressure Test Hanger and Neck Seal to 5,000 psi for 30 minutes. Good Test. N/U Production Tree. N/D Adapter Flange Re-Orient, FMC Initial Orientation Incorrect. N/U Adapter and Retest Void and Neck Seals to 5,000 psi for 30 minutes. Fill Tree wI Diesel and Test to 5,000 psi for 30 minutes- charted. Good Test. PI U DSM Lubricator, Pull TWC R I U Little Red and PJSM. PT Lines to 2500 psi. Displace IA with 160 bbls of 80 degree diesel. Pump at 2 bpm 950 psi. Allow Freeze Protect to U-Tube. Wait on DSM to arrive. Set BPV in well head and PT with Little Red to 1000 psi. Hold for 5 mins. Bleed down Pressure. Rig Down Little Red. Secure Well and Cellar, UD DSM Lubricator, Install all Gauges. Rig Released at 14:00 hrs. 18:00 - 19:00 19:00 - 20:30 21 :30 - 22:30 RUNCMP 22:30 - 00:00 RUNCMP 1/4/2007 00:00 - 01 :30 1.50 BOPSU P WHDTRE 01 :30 - 03:00 1.50 WHSUR P WHDTRE 03:00 - 03:30 0.50 WHSUR P WHDTRE 03:30 - 04:00 0.50 WHSUR P WHDTRE 04:00 - 06:00 2.00 WHSUR N HMAN WHDTRE 06:00 - 08:00 2.00 WHSUR P WHDTRE 08:00 - 08:30 0.50 WHSUR P WHDTRE 08:30 - 10:30 2.00 WHSUR P WHDTRE 10:30 - 12:00 1.50 WHSUR P WHDTRE 12:00 - 12:30 0.50 WHSUR N WHDTRE 12:30 - 13:30 1.00 WHSUR P WHDTRE 13:30 - 14:00 0.50 WHSUR P WHDTRE Printed: 1/8/2007 6:53:02 AM W-29i RWO (Sundry # 306-304) and 12-14.WO (Sundry... qf - . "",,- Subject: W-29i RWO (Sundry # 306-304) an 12-14AL 1 RWO (Sundry # 306-281 and 306-289) From: "Reem, David C" <ReemDC@BP.eom> Date: Thu, 21 Dee 2006 08:52:40 -0900 To: Wintôn Aubert <winton_aube drnin.state.ak.Üs> CC:"McLellan,Bryan J"<Bryan. eHan@BP.com> Winton, as you requested, here is a synapsis of the reason for scope changes on the two subject wells: W-29i: This well bore passes within -200' of a planned Schrader Bluff injector. As such we ran a bond log across the Schrader Bluff interval and the cement bond looked to be poor to absent across the Schrader. The asset folks for the Schrader development have requested that we repair the 9-5/8" casing primary cement job across the Schrader bluff boundaries in W-29. Thus we are planning on a circulation squeeze thru perfs shot in the 9-5/8" at 5112'-5114'md and 5480'-5482'md. After the cement job, a second bond log will be run to confirm adequate bonding across the Schrader. Following this activity, a 7" 26#/ft, L-80 scab liner will be fully cemented in place from -3000' md down to the top of the existing 7" production liner. 12-14AL 1: This well bore was logged in the 9-5/8" with a US IT and a 40-arm caliper. These diagnostic tools indicated severe drill-pipe wear on the 10 of the 9-5/8" casing in several areas just above the existing 7" production liner. Therefore we have elected to install a fully cemented 7", 26#/ft, L-80 scab liner in this well with the top at -3000'md and the bottom tied into the existing 7" production liner. This operation will follow the planned 9-5/8" casing repair work as outlined in the original Sundry applications. Do not hesitate to call with any questions. Thanks. Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) 1 of 1 12/21/20068:55 AM . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AIVD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 12-14A Sundry Number: 306-289 SCANNED AUG 2 9 20DB Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~.s;ay of August, 2006 Encl. '.<1 ~- 140 . 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension v o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 198-146/ 3. Address: D Stratigraphic D Service 6, API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20659-01-00 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: 12-14A / Spacing Exception Required? DYes 181 No 9. Property Designation: \10. KB Elevation (ft): 11. Field / Pool(s): ADL 028331 69.68' Prudhoe Bay Field / Prudhoe Bay Pool 12';;.:;.. ........ ........... 'WI=II / .......··...·..X /.:)·X.·.·/··;·;·· .... ..../........:... ............... .... ...... . .: Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14047 8997 14004 / 9006 None 14005 Casino Lenath Size MD , TVD Burst CollaDse Structural Conductnr 80' 20" 80' 80' Surface 2644' 13-3/8" 2644' 2644' 4930 2670 Intermediate 11471' 9-5/8" 11471' 8875' 6870 4760 Production Liner 879' 7" 10614' -11910' 8348' - 8995' 7240 5410 Liner 249' 4-1/2" 11306' - 14047' 8775' - 8923' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11710' - 13995' / 8983' - 9008' 4-112", 12.6# 13Cr80 11309' / Packers and SSSV Type: 4-112" x 7" Baker 'S-3' packer I Packers and SSSV MD (ft): 11254' ./ 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service o Detailed Operations Program r-.. 15. Estimated Date for octo~ 1 2006 16. Well Status after proposed work: CommencinQ Operations: 181 Oil DGas o Plugged D Abandoned 17. Verbal Approval: ~teJ o WAG OGINJ OWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Name ~vid Reem Title Drilling Engineer Bryan McLellan, 564-5516 f}{y #/1 A~ Prepared By Name/Number: Signature Phone 564-5743 Date 3'-23 06 Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: 3D(~ -:;:)Ç:q Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: T ~ t- 13 0 fJ L:' f-o ~soo rUt -?1Jâ RBDMS Bfl AUG 2 8 2006 Subsequent Form Required: 1° APPROVED BY Date &1J£ít6 Approved Bv: COMMlSSIONER THE COMMISSION Form 10-403 Revised 06/2006 V ~JO KrG" NA /Subrv1't In Duplicate .~~N 1)~~ ~J~ATEOFALASKA ¡{P¿ .;Z<¡/~ ALA~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 l ~~efVEtŸ AUG 2 4 2006 Alaska Oil & Gas Cons. COfMIÍssio . . 12-14A Rig Workover Scope of Work: PuIl4-Y2" 13Cr completion, cut and pull 9-5/8" casing above the surface casing shoe, run new 9-5/8" premium threaded casing and fully cement the 9-5/8" x 13-3/8" annulus to surface, run 4- %" ",- Chrome completion. Note that this is the same scope of work as requested in a separate Sundry Application for RWO on the lateral 12-14AL 1 . MASP: 2470 Well Type: Producer Estimated Start Date: October, 2006 Pre-riQ prep work: Pre-Ri : 0 1 S 2 F 3 E 4 F 5 0 6 0 7 Troubleshoot the two non-functionallockdown screws on the tubin han er. Set non-equalizing plug (XX plug) in the X-nipple at 11287' md. Dump sluggitz on top of lu . Drift 4-1/2" tub in for the 'et cutter. MITIA to 3500 psi. Monitor OAP for signs of communication - note that this well has slow IA x OA communication to gas. MIT-T to 1000 psi to verify TTP is a competent barrier. Jet cut tubing at 11,223' md, referenced to the tubing tally dated 11/11/98. Note that this is in the middle of the first full 'oint above the roduction acker. Circulate well with seawater and diesel freeze rotection thru the cut. Set a BPV in the tubin han er. Remove the wellhouse & flow line. Level the Proposed Procedure: /' 1. MIRU. ND tree. NU and test BOPE to ~oq.þsi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. ,Æ, 2. Pull and LD 4-1/2" tubing string to the cut. 3. Run a cement evaluation log to determine top of cement in 9-5/8" x 13-3/8" annulus. 4. Cut and pull 9-5/8" casing above top of cement in the surface casing. 5. Run new 9-5/8" premium threaded casing tieback from top of casing stub to surface. 6. Cement 9-5/8" tieback to surface. 7. Run new 4-1/2" Chrome tubing completion with packer at -11,160. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. ./ TREE = WB..LHEAD <= ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = DatumlVD= FMC GEN 2 FMC OTIS 76' . 3700' 94 @ 12027' 11461' 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12,347" I 12-14AL 1 ~NOTES: CHROME4-1/2"TBG. EXISTING COMPLETION 2024' -14-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRB..S ST MD lVD DEV 1YÆ VLV LATCH 1 3349 3349 2 MMG DOME RK 2 5455 5192 48 MMG DOME RK 3 7471 6402 53 MMG DMY RK 4 8515 7014 53 MMG DOME RK 5 9392 7586 49 MMG DMY RK 6 10486 8272 54 MMG DMY RK 7 11099 8646 52 KBG2LS SO INT PORT DA 1£ 16 05/17/04 16 05/17/04 o 16 o o 20 Minimum ID = 2.205" @ 11327' 2-7/8" HES XN NIPPLE TOP OF 7" LNR , 10614' 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 11258' ITOPOF 7" LNR H 11258' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I I TOP OF 4-1/2" LNR I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 11471' 17" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" ÆRFORA TION SUMMARY REF LOG: GR/CCL ANGLEATTOPÆRF: 75 @ 11710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA1£ 3-3/8" 4 11710 -11790 0 11/10/98 3-3/8" 4 11810 - 12030 0 11/10/98 33/8" 4 12190-12265 0 11/10/98 3 3/8" 4 12335 - 12355 0 11/10/98 33/8" 4 12435-12455 0 11/10/98 33/8" 4 12855-12915 0 11/10/98 33/8" 4 12965-13015 0 11/10/98 33/8" 4 13250 - 13320 0 11/10/98 3 3/8" 4 13440 - 13500 0 11/10/98 33/8" 4 13725-13750 0 11/10/98 3-3/8" 4 13895-13995 0 11/10/98 PREDRILLED (12-14AL 1) 3-3/8" 4 12072 - 12884 0 08/20/02 05/17/04 08/02/02 08/02/02 08/21/05 11254' -14-1/2" X 7" BAKER S-3 PKR I 11287' -14-1/2"HESXNIP,ID=3.813" I 11309' -14-1/2" WLEG I 11320' -1TIW DEA...OYMENT SLV, ID - 2.375" 11328' -12-7/8" HES XN NIP, ID = 2.205" I H B..MD TT NOT LOGGED I DA1£ 1981 11/12/98 08/21/02 08/24/02 09/29/02 03/22/03 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK (12-14A) JDM/KK CTD SIDETRACK (12-14AL 1) DTR/TP GL V C/O BM/TP WAIVER SAFETY NOTE JMP/KK WAIVER SAFETY NOTE DATE 05/17/04 08/16/05 08/21/05 10/28/05 05/31/06 MILLOlIT WINDOW 11555' - 11562' 11555' HMEeHANICAL FLOW-BY WHIPSTOCK I H2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.440"1 .. 2-7/8" PRE-DRLD LNR, 6.16#, L-80, .0058 bpf, ID = 2.440" .. .. , .... ' , -1 BAKER MODB.. "D" PKR -1 PBTD I 4-1/2" LNR, 12,6#, L-80, .0152 bpf, ID = 3.958" -1 14047' REV BY COMMENTS JLJ/KAK GL V C/O KSBrrLH GL V C/O KSBfTLH GL V C/O EZL/PAG WAIVER SFTY NOTE REVISED DTM WB..LHEAD CORRECTION PRUDHOE BAY UNIT WB..L: 12-14AL 1 ÆRMIT No: "202122 API No: 50-029-20659-60 SEe 18, T10N, R15E BP Exploration (Alaska) TREE FMC GEN 2 . 12-14AL 1 ~ NOTES: CHROME4-1/2" TBG. I WELLHEAD !: FMC ACTUATOR = KB. ELEV = 76' PROPOSED BF. ELEV = "" KOP= 3700' Max Angle = 94 @ 12027' I I - ---1 2200' -14-1/2" HES X NIP, ID = 3.813" I Datum MD = 11461 ' Datum1VD= 8800' SS 19-5/8" CSG, 40#, L-80, ID = 8.835" I -2200' t-- GAS LIFT MANDRELS a ST MD 1VD DEV TYÆ VLV LATCH PORT DATE 113-3/8" CSG, 72#, L-80, ID= 12.347" I 2644' 5 3350 ~ 4 6173 3 8729 Minimum ID = 2.205" @ 11327' 2 10112 2-7/8" HES XN NIPPLE 1 -1108C TOPOF 7" LNR I 10614' I . I I 11150' -14-1/2" HES X NIP, ID = 3.813" I I 11160' 14-1/2" x 7" BAKER S-3 PKR I . . 11214' -14-1/2"HESXNIP, ID=3.813" I 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 11224' r I( 11224' -I UNIQUE MACHINE OVERSHOT I I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 11258' I ~ 11254' -14-1/2"X7"BAKERS-3PKR I , TOPOF7" LNR H 11258' I I I 11287' -14-1/2" HES X NIP, ID = 3.813" I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I 11309' 1--- --f4-1/2" WLEG I ~ 11309' TOPOF4-1/2" LNR 11309' i 11\I I 11320' -1TIW DEPLOYMENT SLV, ID = 2.375" I . I I 11328' -12-7/8" HES XN NIP, ID = 2.205" I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 11471' ..01 ~ I 7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" I 11493' I MILLOUT WINDOW I I ./ 11555' - 11562' ÆRFORA TION SUMMARY REF LOG: GRlCCL ..... ANGLEATTOPÆRF: 75@ 11710' ¡ I I 11555' HMECHANICAL FLOW-BY WHIPSTOCK I Note: Refer to Production DB for historical perf data Ih~ ~ 12047' SIZE SPF INTERV AL Opn/Sqz DATE H2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.440"1 3-3/8" 4 11710 - 11790 0 11/10/98 ........(" 3-3/8" 4 11810 -12030 0 11/10/98 33/8" 4 12190 - 12265 0 11/10/98 ' , , ~ 2-718" FRE-DRLD LN!<, 6.16#, I 33/8" 4 12335 - 12355 0 11/10/98 ... ... ... L-80, .0058 bpf, ID = 2.440" 33/8" 4 12435 - 12455 0 11/10/98 ~,,~ ...... ~~~ " " 33/8" 4 12855 - 12915 0 11/10/98 I ...... ... ... 33/8" 4 12965 - 13015 0 11/10/98 ... ... , 33/8" 4 13250 - 13320 0 11/10/98 [ ",' 3 3/8" 4 13440 - 13500 0 11/10/98 I 3 3/8" 4 13725 - 13750 0 11/10/98 ., 11610' H BAKER MODEL "D" PKR 3-3/8" 4 13895 - 13995 0 11/10/98 r 14005' 1-\ PBTD I PREDRILL ED (12·14AL 1) 3-3/8" 4 12072 - 12884 0 08/20/02 \ r 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 14047' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 1981 ORIGINAL COM PlETION 05/17/04 JLJ/KAK GL V C/O WELL: 12-14AL 1 11/12/98 SIDETRACK (12-14A) 08/16/05 KSBrrLH GL V C/O ÆRMrr No: '202122 08/21/02 JDM/KK CTD SIDETRACK (12-14Al1) 08/21/05 KSBrrLH GL V C/O API No: 50-029-20659-60 08/24/02 DTRlTP GL V C/O 10/28/05 EZUPAG WAIVER SFTY NOTE REVISED SEC 18, T10N, R15E 09/29/02 BIINTP WAIVER SAFETY NOTE 05/31/06 DTM WELLHEAD CORRECTION 03/22/03 JMP/KK WAIVER SAFETY NOTE 08/08/06 BJM PROPOSED RWO BP Exploration (Alaska) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 2656830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kuparuk Team Leader RT/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Disoosal durin : the fourth quarter of 2001: · h(1) !~(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2'-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 'October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November" December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 oct2001 Nov 2001 1C-109 2P-438 30331 100 0 30431 212 0 30643 Oct 2001 Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 ~ 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 200! CD2-34 Total Volumes into Annuli ~ which Dis ~osal Authori ation Ex ~ired durin 20~)1: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 1D-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CDI-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only 1D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, 1D-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... 1D-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 Annular Dis ¢osal durin the third 'uarter ~:2001' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, 1C-117, 1C-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May2001 July2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 ,. 1C-16 19579 100 0 19679 0 19679 Sept2001 Sept2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 ~ CD2~.14 276 100 0 376 0 376 Sept2001 Sept2001 Freeze protect volume fromCD2-14 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2001: ' Total Voiume ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-3 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor' DATE: May 7, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, M. av 7, 200!: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition~ Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Ah/gka Oil and Gas Conservation Commi~sron Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Pmdhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 Well Permit Separ Set L/P Test Test Test Date oil WAG, GIN J, Number Number PSI PSI TAp Code Code Code Passed GAS or CYCL~ , 12-01 1790230 12-02 1790320 12-03 1790410 160 150] 150 P P OIL 12~04A 1811870 ' '160 150 150: P P OIL 12'05 1790550 12-06A i520540 ' 160 150 150' 'e e ' " OIL 12-07A 1811750 160 150 140 P P OIL , 12208B 1811670 160 150 140 P P OIL 12-09 1800930 160 150 125 P P OIL 12-10A 1920890 160 150 150' P P OIL 12-11 1810730 ,, 12-12 1810830 160 150 90 P 4 OIL 12-13B " 1960170: 160 " 150 '150 P " P ~IL ,, 12-14A 1981460' 160 150 150 P P OIL , 12-15 1830320 160 150 150 P P OIL ,, 12-16A 1931480' 160 150 150 P P OIL ,, 12-17 1830040'! 160 150 150 P P OIL i12'18 ' i825060 160 150 150 P P " OIL , , , 12-19 1821980 12-20 18219101 12-21 1840486 '- 12-22 18406001 160 150 125 P P oiL 12-23 1840580 ,, ,, 12-25 1831660 12-26 1840140 ' '160' i50 ' 125 e " P, 'OiL 12-27A 1990390 , , 12-28A 1990330 160 150 170 P P OIL , , 12.29 1840320 12-30 1881420 12-31 1890010 12-32 1896i'10 160 150 150 e P 0IL , 12-33 1890100 12-34 'i941370 'i60 '150 150 ' e' e " OIL 12-35 1951300 160 150 100 12-36 1951580 lg0 150 150 " P P ' ' OIL; RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p_IA~C_S Well Permit ~ Separ Set L/P Test Number Number / PSI PSI Trip Code Wells: 21 Components: 42 Failures: Test Code 1 i Code ] Passed I GAS or CYCLE Failure Rate: 2.:38% [-'] 90 Day Remarks: Surface Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS 198-146-0 PRUDHOE BAY UNIT 12-14A 50- 029-20659-01 BP EXPLORATION (A~ASV, A) I~C Roll #1: Start: Stop Roll #2: Start Stop MD 14047 TVI) 08999 Completion Date: 11/12/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 9147 I//2,3 SPERRY GR/EWR4/SLD OH L DGR/EWR4~MD ,/FINAL 11493-14047 OH L DGRfEWR4-TVD //t~iNAL 8903-8991 OH L DGR/SLD-MD ,d/FINAL 11493-14047 OH ,. L DGR/SLD-TVD t/~FINAL 8903-8991 OH R SRVY RPT v/ SPERRY 11462.49-14047. OH 5/20/99 5/21/99 5/20/99 5/21/99 5/20/99 5/21/99 5/20/99 5/21/99 5/20/99 5/21/99 12/11/98 12/17/98 Tuesday, January 09, 2001 Page 1 of 1 0 I:! I I--I-- I IM G S E I~1~1C I::: S WELL LOG TRANSMITrAL To: State of Alaska May 20, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 12-14A, AK-MW-80409 The technical data listed below is being submitted herewiffr Please acknowledge recdpt by returning a signed copy of this transmittal letter to the attention off Jan Galvin, Sperry-Sun Ddlling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20659-01. RECF_ ED 211999 Alaska Oil & Gas C~ns. Commission 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 F:i I I--I-- I I~1 [3 SEFI~/ICE S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 qg. 14qo May 20. 1999 RE: MWD Formation Evaluafion Logs · 12-14A, AK-MW-80409 The technical data listed .below is being submilted herewitk Please address.any problems or ~ to the attention off Ylm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 D.S. 12-14A: 2"x 5"MD Resistivity & Gamma Ray'Logs: 50-029-20659-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20659-01 2" x 5" MD Density Logs: 50-029-20659-01 2"x 5" TVD Density Logs: 50-029-20659-01 1 Btueline- 1 Folded Sepia 1 Bluetine 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil E~] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 98-146 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20659-01 4. Location of well at surface. _ . ..-~ 9. Unit or Lease Name 527' NSL, 717' WEb, SEC. 18, T10N, R15E, UM · : ~'" .~:"i !.~frj;)~._ ~I: Prudhoe Bay Unit At top of productive interval : :':i~ 10. Well Number 3064' SNL, 3846' EWL, SEC. 20, T10N, R15E, UM ..... 12-14A At total depth :.,~, r , 1 1. Field and Pool 3485' SNL, 845' EWL, SEC. 21 T10N, R15E, UM ..... Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease DeSignatiOn and Serial No. Pool KBE = 69.68'I ADb 028331 12. Date Spudded10/31/98 I 13' Date I'D' Reached [ 14' Date C°mp" Susp" °r Aband'l15' Water depth' if Offsh°re I 16' NO' °f C°mpleti°nsl 1/5/98 11/12/98 N/A MSL, One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14047 8999 FTI 14004 9008 FTI [~]Yes E~]NoI (Nipple) 2024' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, 4-Phase RES, DEN 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Weld Surface 80' 30" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2644' 17-1/2" 3250 sx Fondu, 400 sx Arcticset III 9-5/8" 47# L-80 Surface 11471' 12-1/4" 500 sx Class 'G' 7" 26# L-80 / 13Cr80 10614' 11493' 8-1/2" 270 sx Class 'G' 4-1/2" 12.6# L-80 11306' 14047' 6" 340 sx Class 'G' .... 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIzE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr-80 11309' 11254' MD TVD MD TVD 11710' - 11790' 8985' - 8997' 13725' - 13750' 9033' - 9032' 2~. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11810' - 12030' 8998' - 8995' 13895' - 13995' 9025' - 9010' 12190' - 12265' 8993' - 8993' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12335' - 12355' 8993' - 8993' 12435' - 12455' 8994' - 8995' Freeze Protect with 151 Bbls of Diesel 12855' - 12915' 9027' - 9030' 12965, - 13015, 9030' - 9031, . 13250' 13320' 9039' 9042' 13440' - 13500' 9041' - 9040' 27. PRODUCTION TESTORi^,NAL Date First Production I Method of Operation (Flowing, gas lift, etc.) November 19, 1998I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE GAS-OIL'S, lO.m, ' TEST PERIOD ............. ::'-* Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 11486' 8886' Shublik 11535' 8914' Sadlerochit 11705' 8984' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certi~t¢ that the forego)lng is true and correct to the best of my knowledge Signed .~2_~4A~1~ ~__~ ~.~ Ja .... Title Senior Drilling Engineer Date 98-146 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 Progress Report Facility PB DS 12 Well 12-14A Rig Nabors 22E Page 1 Date 02 December 98 Date/Time 15 Oct 98 06:00-07:00 07:00-12:00 12:00-12:30 12:30-16:30 16:30-00:00 16 Oct 98 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-17:00 17:00-17:30 17:30-19:00 19:00-00:00 17 Oct 98 00:00-00:30 00:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-00:00 18 Oct 98 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 19 Oct 98 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-15:00 15:00-16:30 16:30-22:00 22:00-00:00 20 Oct 98 00:00-00:30 00:30-02:30 02:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-15:30 15:30-20:00 20:00-21:30 21:30-00:00 21 Oct 98 00:00-00:30 00:30-04:00 04:00-06:00 06:00-12:00 12:00-12:30 12:30-17:00 17:00-19:00 19:00-20:00 20:00-00:00 22 Oct 98 00:00-00:30 Duration lhr 5 hr 1/2 hr 4 hr 7-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 5hr 1/2 hr 5-1/2 hr 3hr 3hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 2-1/2 hr 1-1/2 hr 5-1/2 hr 2hr 1/2 hr 2 hr 3-1/2 hr 3hr 3hr 1/2 hr lhr 1-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 2-1/2 hr 1/2hr 3-1/2 hr 2hr 6 hr 1/2hr 4-1/2 hr 2hr lhr 4hr 1/2 hr Activity Held safety meeting Rigged down Top drive Held safety meeting Rigged down Top drive Rigged down Swivel Held safety meeting Rig moved 40.00 % Rigged down Drillfloor / Derrick Held safety meeting Rig waited: Weather Held safety meeting Removed Drillstring handling equipment Rigged down Drillfloor / Derrick Held safety meeting Rigged down Drillfloor / Derrick Rigged down Drillfloor / Derrick Rig moved 100.00 % Held safety meeting Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Installed Top drive Held safety meeting Installed Production swab valve - manual Removed Accessories Circulated at 11272.3 ft Installed Accessories Held safety meeting Removed Xmas tree Installed BOP stack Installed BOP stack Tested BOP stack Held safety meeting Tested BOP stack Retrieved Accessories Held safety meeting Circulated at 11270.0 ft Rigged up Completion string handling equipment Laid down 1000.0 ft of Tubing Held safety meeting Laid down 2200.0 ft of Tubing Laid down 3305.0 ft of Tubing Laid down 8300.0 ft of Tubing Held safety meeting Laid down 11270.0 ft of Tubing Rigged down Completion string handling equipment Serviced Top drive Ran Drillpipe to 1000.0 ft (4in OD) Held safety meeting Facility Date/Time 23 Oct 98 24 Oct 98 25 Oct 98 26 Oct 98 PB DS 12 Progress Report Well 12-14A Rig Nabors 22E Page Date Duration Activity 00:30-06:00 06:00-09:00 09:00-10:00 10:00-12:00 12:00-12:30 12:30-20:30 20:30-21:30 21:30-00:00 00:00-00:30 00:30-06:00 06:00-07:00 07:00-08:30 08:30-13:00 13:00-15:00 15:00-15:30 15:30-19:30 19:30-20:30 20:30-00:00 00:00-00:30 00:30-03:30 03:30-04:30 04:30-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-16:30 16:30-19:00 19:00-20:00 20:00-00:00 00:00-00:30 00:30-01:00 O1:00-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-11:00 11:00-13:30 13:30-14:00 14:00-17:00 17:00-18:00 18:00-00:00 00:00-00:30 00:30-06:00 06:00-07:30 07:30-08:30 08:30-13:30 13:30-14:00 14:00-15:30 15:30-18:00 18:00-19:00 19:00-20:30 20:30-22:00 22:00-23:00 23:00-04:00 5-1/2 hr 3 hr lhr 2hr 1/2 hr 8hr lhr 2-1/2 hr 1/2 hr 5-1/2 hr lhr 1-1/2 hr 4-1/2 hr 2hr 1/2 hr 4 hr lhr 3-1/2 hr 1/2 hr 3hr lhr 1-1/2 hr 5hr lhr 1/2 hr 4hr 2-1/2 hr lhr 4hr 1/2 hr 1/2 hr 3hr lhr lhr lhr 4hr 2-1/2 hr 1/2 hr 3hr lhr 6hr 1/2hr 5-1/2 hr 1-1/2 hr lhr 5hr 1/2 hr 1-1/2 hr 2-1/2 hr lhr 1-1/2 hr 1-1/2 hr lhr 5 hr Ran Drillpipe to 4000.0 ft (5in OD) Ran Drillpipe to 11281.0 ft (4in OD) Worked toolstring at 11281.0 ft Circulated at 11280.0 ft Held safety meeting Pulled out of hole to 0.0 ft Serviced Top drive Ran Drillpipe in stands to 2000.0 ft Held safety meeting Ran Drillpipe in stands to 10750.0 ft Ran Drillpipe in stands to 10862.0 ft Circulated at 10862.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 3228.0 ft Held safety meeting Ran Drillpipe in stands to 11281.0 ft Serviced Top drive Worked toolstring at 11295.0 ft Held safety meeting Worked toolstring at 11295.0 ft Circulated at 11295.0 ft Pulled out of hole to 7000.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 300.0 ft Held safety meeting Ran Drillpipe in stands to 11295.0 ft Worked toolstring at 11295.0 ft Circulated at 10290.0 ft Pulled out of hole to 0.0 ft Held safety meeting Pulled out of hole to 0.0 ft Ran Drillpipe to 10550.0 ft (5in OD) Serviced Block line Serviced Top drive Ran Drillpipe in stands to 11295.0 ft Worked toolstring at 11295.0 ft Circulated at 11391.0 ft Singled in drill pipe to 11423.0 ft Worked toolstring at 11430.0 ft Circulated at 11430.0 ft Pulled out of hole to 0.0 ft Held safety meeting Ran Drillpipe in stands to 11430.0 ft Worked toolstring at 11430.0 ft Circulated at 11430.0 ft Pulled out of hole to 5.0 ft Serviced Downhole tools Serviced Downhole tools Ran Drillpipe in stands to 7100.0 ft Serviced Top drive Ran Drillpipe in stands to 11430.0 ft Worked toolstring at 11463.0 ft Circulated at 11430.0 ft Pulled out of hole to 80.0 ft 2 02 December 98 Facility Date/Time 27 Oct 98 28 Oct 98 29 Oct 98 30 Oct 98 31 Oct 98 Progress Report PB DS 12 Well 12-14A Rig Nabors 22E Page 3 Date 02 December 98 04:00-05:00 05:00-06:00 06:00-06:30 06:30-11:30 11:30-14:30 14:30-16:00 16:00-19:30 19:30-21:30 21:30-22:00 22:00-22:15 22:15-22:30 22:30-01:30 01:30-01:45 01:45-02:00 02:00-04:00 04:00-06:00 06:00-08:00 08:00-09:00 09:00-09:30 09:30-12:00 12:00-14:00 14:00-18:30 18:30-20:30 20:30-22:30 22:30-02:30 02:30-06:00 06:00-10:00 10:00-12:30 12:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-20:00 20:00-20:15 20:15-22:00 22:00-02:30 02:30-02:45 02:45-04:30 04:30-05:00 05:00-06:00 06:00-11:30 11:30-12:00 12:00-14:00 14:00-15:00 15:00-15:30 15:30-21:00 21:00-03:00 03:00-05:00 05:00-06:00 06:00-09:30 09:30-12:00 12:00-12:15 Duration lhr lhr 1/2 hr 5 hr 3 hr 1-1/2 hr 3-1/2 hr 2 hr 1/2 hr 1/4 hr 1/4 hr 3hr 1/4 hr 1/4 hr 2hr 2hr 2hr lhr 1/2 hr 2-1/2 hr 2hr 4-1/2 hr 2hr 2hr 4hr 3-1/2 hr 4hr 2-1/2 hr 4hr lhr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 3/4 hr 1/4 hr 1-3/4 hr 4-1/2 hr 1/4 hr 1-3/4 hr 1/2 hr lhr 5-1/2 hr 1/2 hr 2hr lhr 1/2 hr 5-1/2 hr 6hr 2 hr lhr 3-1/2 hr 2-1/2 hr 1/4 hr Activity Serviced Downhole tools Serviced Downhole tools Serviced Downhole tools Ran Drillpipe in stands to 11430.0 ft Worked toolstring at 11656.0 ft Circulated at 11656.0 ft Pulled out of hole to 145.0 ft Retrieved Downhole tools Rigged up Drillfloor / Derrick Retrieved Wear bushing Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Installed Wear bushing Installed Downhole tools Ran Drillpipe in stands to 4000.0 ft Ran Drillpipe in stands to 10600.0 ft Serviced Block line Serviced Top drive Worked toolstring at 11559.0 ft Circulated at 11559.0 ft Pulled out of hole to 365.0 ft Serviced Downhole tools Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Ran Drillpipe in stands to 11260.0 ft Serviced Top drive Singled in drill pipe to 11513.0 ft Injectivity test - 15.000 bbl injected at 1200.0 psi Held safety meeting Mixed and pumped slurry - 17.000 bbl Displaced slurry - 155.000 bbl Displaced slurry - 11.000 bbl Circulated at 11513.0 ft Pulled Drillpipe in stands to 0.0 ft Held safety meeting Made up BHA no. 1 Tested MWD - Via string R.I.H. to 950.0 ft R.I.H. to 9700.0 ft Serviced Top drive Singled in drill pipe to 11503.0 ft Set tool face Circulated at 11493.0 ft Milled Casing at 11493.0 ft Drilled to 11522.0 ft Circulated at 11493.0 ft Pulled out of hole to 9600.0 ft Pulled out of hole to 852.0 ft Pulled BHA Held safety meeting Facility Date/Time 01 Nov 98 02 Nov 98 03 Nov 98 04 Nov 98 05 Nov 98 06 Nov 98 Progress Report PB DS 12 Well 12-14A Page 4 Rig Nabors 22E 'Date 02 December 98 12:15-13:00 13:00-16:30 16:30-17:00 17:00-17:45 17:45-18:00 18:00-22:00 22:00-23:00 23:00-00:00 00:00-00:15 00:15-06:00 06:00-12:00 12:00-12:15 12:15-00:00 00:00-00:15 00:15-06:00 06:00-12:00 12:00-12:15 12:15-17:00 17:00-19:30 19:30-02:00 02:00-04:00 04:00-05:30 05:30-05:45 05:45-06:00 06:00-09:30 09:30-09:45 09:45-10:00 10:00-12:00 12:00-12:30 12:30-15:00 15:00-15:15 15:15-18:30 18:30-19:30 19:30-21:00 21:00-21:30 21:30-00:30 00:30-02:00 02:00-06:00 06:00-12:00 12:00-12:15 12:15-00:00 00:00-00:15 00:15-06:00 06:00-12:00 12:00-12:15 12:15-17:30 17:30-20:00 20:00-21:30 21:30-22:30 22:30-23:30 23:30-03:00 03:00-06:00 06:00-10:30 Duration 3/4 hr 3-1/2 hr 1/2 hr 3/4 hr 1/4 hr 4hr lhr lhr 1/4 hr 5-3/4 hr 6hr 1/4 hr 11-3/4 hr 1/4 hr 5-3/4 hr 6hr 1/4 hr 4-3/4 hr 2-1/2 hr 6-1/2 hr 2hr 1-1/2 hr 1/4 hr 1/4 hr 3-1/2 hr 1/4 hr 1/4 hr 2hr 1/2 hr 2-1/2 hr 1/4 hr 3-1/4 hr 1 hr 1-1/2 hr 1/2 hr 3hr 1-1/2 hr 4hr 6hr 1/4 hr 11-3/4 hr 1/4 hr 5-3/4 hr 6hr 1/4 hr 5-1/4 hr 2-1/2 hr 1-1/2 hr lhr lhr 3-1/2 hr 3hr 4-1/2 hr Activity Serviced BOP stack Made up BHA no. 2 Singled in drill pipe to 650.0 ft Serviced Top drive Tested M.W.D. tool - Via string R.I.H. to 11489.0 ft R.I.H. to 11522.0 ft Drilled to 11524.0 ft Held safety meeting Drilled to 11610.0 ft Drilled to 11680.0 ft Held safety meeting Drilled to 12076.0 ft Held safety meeting Drilled to 12325.0 ft Drilled to 12415.0 ft Held safety meeting Drilled to 12601.0 ft Circulated at 12601.0 ft Pulled out of hole to 230.0 ft Pulled BHA Serviced Mud motor Retrieved Wear bushing Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Installed Wear bushing Serviced Drillfloor / Derrick Held safety meeting Made up BHA no. 3 Tested MWD - Via string R.I.H. to 11480.0 ft Serviced Top drive Serviced Block line R.I.H. to 12340.0 ft Washed to 12435.0 ft Logged hole with LWD: Formation evaluation (FE) from 12435.0 ft to 12601.0 ft Drilled to 12740.0 ft Drilled to 13005.0 ft Held safety meeting Drilled to 13543.0 ft Held safety meeting Drilled to 13675.0 ft Drilled to 13856.0 ft Held safety meeting Drilled to 14047.0 ft Circulated at 14047.0 ft Pulled out of hole to 11480.0 ft R.I.H. to 13670.0 ft Washed to 14047.0 ft Circulated at 14047.0 ft Pulled out of hole to 9760.0 ft Pulled out of hole to 221.0 ft Facility Date/Time 07 Nov 98 08 Nov 98 09 Nov 98 10 Nov 98 Progress Report i' PB DS 12 Well 12-14A Rig Nabors 22E Page 5 Date 02 December 98 10:30-12:30 12:30-14:00 14:00-15:00 15:00-15:30 15:30-18:30 18:30-01:00 01:00-02:00 02:00-06:00 06:00-08:00 08:00-09:00 09:00-11:00 11:00-14:30 14:30-14:45 14:45-15:15 15:15-15:30 15:30-16:15 16:15-16:30 16:30-19:30 19:30-21:00 21:00-21:30 21:30-22:00 22:00-03:30 03:30-04:00 04:00-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-11:00 11:00-12:00 12:00-12:15 12:15-13:30 13:30-15:30 15:30-17:00 17:00-18:00 18:00-22:30 22:30-00:00 00:00-00:15 00:15-01:00 01:00-02:30 02:30-04:00 04:00-06:00 06:00-10:30 10:30-12:00 12:00-12:30 12:30-20:30 20:30-22:30 22:30-00:00 00:00-00:30 00:30-03:30 03:30-05:30 05:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 Duration 2hr 1-1/2 hr 1 hr 1/2 hr 3hr 6-1/2 hr lhr 4hr 2hr 1 hr 2 hr 3-1/2 hr 1/4 hr 1/2 hr 1/4 hr 3/4 hr 1/4 hr 3 hr 1-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 2hr lhr 1/2 hr 1/2 hr 3hr lhr 1/4 hr 1-1/4 hr 2hr 1-1/2 hr lhr 4-1/2 hr 1-1/2 hr 1/4hr 3/4 hr 1-1/2 hr 1-1/2 hr 2hr 4-1/2 hr 1-1/2 hr 1/2 hr 8hr 2 hr 1-1/2 hr 1/2 hr 3 hr 2hr 1/2 hr 6hr 1/2 hr 11-1/2 hr Activity Pulled BHA Serviced Drillfloor / Derrick Rigged up Casing handling equipment Held safety meeting Ran Liner to 2716.0 ft (4-1/2in OD) Installed Tubing Installed Liner hanger Ran Drillpipe in stands to 8375.0 ft Ran Drillpipe in stands to 11400.0 ft Circulated at 11400.0 ft Ran Drillpipe in stands to 14047.0 ft Circulated at 14047.0 ft Held safety meeting Pumped Water based mud spacers - volume 70.000 bbl Mixed and pumped slurry - 68.000 bbl Displaced slurry - 185.000 bbl Functioned Liner hanger Circulated at 13994.0 ft Reverse circulated at 13994.0 ft Tested Liner Rigged down Cement head Pulled Drillpipe in stands to 2700.0 ft Retrieved Setting tools Laid down 1000.0 ft of Tubing Laid down 1600.0 ft of Tubing Rigged up Drillfloor / Derrick Held safety meeting Installed Gun assembly Ran Tubing in stands to 2770.0 ft Held safety meeting Installed Retrievable packer Ran Drillpipe in stands to 6100.0 ft Serviced Block line Serviced Top drive Ran Drillpipe in stands to 13996.0 ft Rigged up Surface lines Held safety meeting Perforated Reverse circulated at 11000.0 ft Pulled out of hole to 11300.0 ft Laid down 1400.0 ft of 5in OD drill pipe Pulled out of hole to 2800.0 ft Laid down 560.0 ft of Tubing Held safety meeting Laid down 2500.0 ft of Tubing Ran Drillpipe in stands to 5225.0 ft Laid down 1465.0 ft of Drillpipe Held safety meeting Laid down 3760.0 ft of Drillpipe Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 2372.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 9143.0 ft (4-1/2in OD) Facility Date/Time 11 Nov 98 12 Nov 98 PB DS 12 Progress Report Well 12-14A Rig Nabors 22E Page Date Duration Activity 00:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 06:00-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-14:30 14:30-18:00 18:00-21:00 21:00-23:00 23:00-00:00 00:00-00:30 00:30-03:00 03:00-06:00 06:00-09:00 1/2 hr 3-1/2 hr lhr lhr 3 hr 2hr lhr 1/2 hr lhr 1 hr 3-1/2 hr 3hr 2hr lhr 1/2hr 2-1/2 hr 3hr 3hr Held safety meeting Ran Tubing to 11305.0 ft (4-1/2in OD) Space out tubulars Circulated at 11295.0 ft Circulated at 11295.0 ft Installed Tubing hanger Set packer at 11254.0 ft with 4000.0 psi Held safety meeting Tested Permanent packer - Via annulus Installed Hanger plug Rigged down BOP stack Installed Xmas tree Removed Hanger plug Rigged up High pressure lines Held safety meeting Circulated at 3349.0 ft Monitor pressures Installed Hanger plug 6 02 December 98 D F! I I_1_ I I~ I~ S E F:t~./I I-- E S 11-Dec-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 12-14A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 11,462.49' MD Window / Kickoff Survey: 11,493.00' MD Projected Survey: 14,047.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEC 17 1998 r.,.,~ Co;~s. Commission a~ch0ra~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS '/2, Slot ~ 2- ~4A 12-14A Job No. AKMMS0409, Surveyed: 5 November, ~998 S UR VEY REPORT 10 December, 1998 Your Ref: API-500292065901 KBE- 69.68' Surface Coordinates: 5930839.99 N, 696891.~7 E (70° 12' 54.9333"N, ~48° 24'42.4863" W) SERVICES Survey Ref: svy3941 Sperry-Sun Drilling Services Survey Report for 12-14A Your Ref: API-500292065901 Job No. AKMM80409, Surveyed: 5 November, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 11462.49 52.600 125.970 8802.43 8872.11 11493.00 54.110 124.210 8820.64 8890.32 11517.14 55.330 122.880 8834.58 8904.26 11548.90 59.090 121.980 8851.78 8921.46 11579.97 62.070 121.160 8867.04 8936.72 11610.92 64.970 120.380 8880.84 8950.52 11645.76 68.010 119.550 8894,74 8964.42 11677.66 71.190 118.840 8905.85 8975.53 11707.64 74.630 116.930 8914.66 8984.34 11740.89 79.430 115:630 8922.12 8991,80 11772.91 84,720 116.370 8926.54 8996.22 11802.05 89.350 116.220 8928.04 8997.72 11836.70 90.520 115.750 8928.08 8997.76 11868.11 90.340 115.660 8927.85 8997.53 11898.60 90.460 114.470 8927.64 8997.32 11931.56 90.710 114.440 8927.30 8996.98 11964.26 90.490 114.890 8926.96 8996.64 11991.28 91.290 112.580 8926.54 8996.22 12025.13 90.920 112.090 8925.88 8995.56 12057.32 91.420 111.210 8925.23 8994.91 12087.93 91.390 110.160 8924.48 8994.16 12124.39 90.710 109.210 8923.81 8993.49 12156.44 90.250 108.490 8923.54 8993.22 12182.83 90.310 109.390 8923.41 8993.09 12217.19 90.250 108.290 8923.24 8992.92 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3480.84S 4380,67 E 5927474.59 N 701361.13 E 3494.91S 4400.70 E 5927461,04 N 701381.52 E 3505,80 S 4417.13 E 5927450.59 N 701398.23 E 3520.11S 4439.66 E 5927436.87 N 701421,13 E 3534.27 S 4462.72 E 5927423.31N 701444.54E 3548.44 S 4486.52 E 5927409.77 N 701468.71 E 3564.39 S 4514.19 E 5927394.54N 701496.79 E 3578.97 S 4540.29 E 5927380.65 N 701523.26 E 3592.37 S 4565.62 E 5927367.92 N 701548.93 E 3606.71S 4594,66 E 5927354.34 N 701578.33 E 3620.61S 4623,15 E 5927341.19 N 701607,18 E 3633.49 S 4649.24 E 5927328.99 N 701633,59 E 3648.68 S 4680.38 E 5927314.62 N 701665.12 E 3662.30 S 4708.68 E 5927301,74 N 701693.77 E 3675.22 S 4736.30 E 5927289.55 N 701721.71E 3688.86 S 4766.30 E 5927276.69 N 701752.06 E 3702.51S 4796.02 E 5927263.83 N 701782.12 E 3713.38 S 4820.75 E 5927253.60 N 701807.13 E 3726.24 S 4852.05 E 5927241.56 N 701838.76 E 3738.11S 4881,97 E 5927230.47 N 701868,97 E 3748.92 S 4910.59 E 5927220.42 N 701897.87 E 3761.20 S 4944.92 E 5927209.04 N 701932.50 E 3771.56 S 4975.25 E 5927199.48 N 701963.09 E 3780.12 S 5000.21E 5927191.56 N 701988.26 E 3791.22 S 5032.72 E 5927181.32 N 702021.06 E Alaska State Plane Zone 4 PBU EOA DS 12 Dogleg Rate (°/100ft) Vertical Section (ft) Comment 6.776 6.765 12.076 9.863 9.638 8.995 10.185 12.990 14.930 16.679 15.897 3.639 0.641 3.923 0.764 1,532 9.046 1.814 3.144 3.431 3.204 2.666 3.418 3.206 5378.73 5402.62 5421.96 5448.25 5474.97 5502.39 5534.06 5563.75 5592.27 5624.59 5656.23 5685.26 5719.85 5751.21 5781.66 5814.60 5847.28 5874.29 5908.13 5940.31 5970.89 6007.30 6039.29 6065.63 6099.92 Tie-on Survey Window Point Continued... 10 December, 1998 - 15:33 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 12-14A Your Ref: AP1-500292065901 Job No. AKMM80409, Surveyed: 5 November, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12246.88 89.750 106.430 8923.24 8992.92 12276.72 89.600 105.490 8923.41 8993.09 12315.86 90.090 104.490 8923.52 8993.20 12347.84 90.370 103.210 8923.39 8993.07 12374.02 90.000 100.420 8923.31 8992.99 12407.83 88.580 100.050 8923.72 8993.40 12439.40 87.190 98.120 8924.89 8994.57 12469.39 87.320 97.470 8926.33 8996.01 12504.18 87.250 97.540 8927.97 8997.65 12534.84 86.830 97.870 8929.56 8999.24 12556.49 86.210 97.210 8930.87 9000.55 12594.11 85.410 97.640 8933.62 9003.30 12626.16 85.100 98.020 8936.27 9005.95 12652.71 85.130 98.760 8938.53 9008.21 12689.83 84.670 98.780 8941.83 9011.51 12722.11 84.110 98.630 8944.99 9014.67 12746.36 84.080 97.780 8947.48 9017.16 12784.45 84.270 94.400 8951.35 9021.03 12812,06 84.390 91.370 8954.08 9023.76 12841.68 84.860 91.340 8956,85 9026.53 12878.88 88.280 90.440 8959.08 9028.76 12911.00 88.860 91.370 8959.88 9029.56 12937.25 89.260 91.150 8960.31 9029.99 12972.36 89.660 91.490 8960.64 9030.32 13003.94 89.660 91.970 8960.83 9030.51 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft). (ft) (ft) 3800.08 S 5061.06 E 5927173.20 N 702049.62 E 3808.28 S 5089.75 E 5927165.75 N 702078.51E 3818.40 $ 5127.56 E 5927156.62 N 702116.57 E 3826.06 S 5158.61E 5927149.77 N 702147.81E 3831.42 $ 5184.23 E 5927145.08 N 702173.56 E 3837.43 S 5217.50 E 5927139.95 N 702206.98 E 3842.41S 5248.65 E 5927135.78 N 702238.25 E 3846.47 $ 5278.33 E 5927132.49 N 702268.02 E 3851.01S 5312.78 E 5927128.85 N 702302.58 E 3855.11 $ 5343.12 E 5927125.54N 702333.02 E 3857.95 S 5364.55 E 5927123.26 N 702354.51E 3862.80 S 5401.75 E 5927119.39 N 702391.83 E 3867.15 S 5433.39 E 5927115.86 N 702423.57 E 3871.01 $ 5459.56 E 5927112.69 N 702449.83 E 3876.65 S 5496.10 E 5927108.01N 702486.51E 3881.51S 5527.86 E 5927103.97 N 702518.38 E 3884.95 S 5551.73 E 5927101.15 N 702542.34 E 3888.97 S 5589.41E 5927098.12 N 702580.10 E 3890.35 S 5616.64E 5927097.45 N 702607.57 E 3891.05 S 5646.32 E 5927097.52 N 702637.06 E 3891.63 S 5683.45 E 5927097.92 N 702674.18 E 3892.13 S 5715.55 E 5927098.25 N 702706.29 E 3892.71S 5741.79 E 5927098.35 N 702732.54E 3893.52 S 5776.89 E 5927098.46 N 702767.64E 3894.47 S 5808.46 E 5927098.33 N 702799.22 E Alaska State Plane Zone 4 PBU EOADS 12 Dogleg Rate (°/'tOOft) Vertical Section (ft) Comment 6.487 3.190 2.845 4.097 10.750 4,340 7.530 2.208 0.284 1.741 4.179 2.413 1.527 2.779 1.240 1.795 3.489 8.842 10.929 1.590 9.505 3.412 1.739 1.495 1.520 6129.49 6159.13 6197.94 6229.56 6255.28 6288.32 6319.01 6347.98 6381.55 6411.16 6432.04 6468.27 6499.17 6524.83 6560.75 6591.95 6615.33 6651.67 6677.56 6705.06 6739.59 6769.45 6793.91 6826.65 6856.18 Continued... 10 December, 1998 - 15:33 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 12-14A Your Ref: API-500292065901 Job No. AKMM80409, Surveyed: 5 November, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 13033.76 86.580 93.130 8961.81 9031.49 13067.37 86.700 93.950 8963.78 9033.46 13099.94 87.540 94.430 8965.41 9035.09 13128.58 88.800 93.590 8966.33 9036.01 13163.36 89.230 94.590 8966.92 9036.60' 13194.34 88.550 94.670 8967.52 9037.20 13223.41 88.120 96.110 8968.37 9038.05 13257.53 87.540 95.730 8969.66 9039.34 13288.25 87.720 96.470 8970.93 9040.61 13317.89 87.970 96.980 8972.05 9041.73 13350.01 89.660 96.690 8972.71 9042.39 13382.05 90.310 97.710 8972.72 9042.40 13412.67 91.420 97.790 8972.26 9041.94 13445.23 91.330 98.390 8971.48 9041.16 13479.00 91.230 98.900 8970.72 9040.40 13505.98 90.920 98.940 8970.21 9039.89 13542.81 91.260 99.090 8969.51 9039.19 13574.90 91.350 97.800 8968.78 9038.46 13600.66 91.570 97.230 8968.13 9037.81 13639.00 91.570 96.710 8967.08 9036.76 13669.51 92.810 95.740 8965.91 9035.59 13696.56 93.110 96.360 8964.51 9034.19 13731.78 92.030 95.960 8962.93 9032.61 13765.44 91.170 96.790 8961.99 9031.67 13792.16 91.510 97.910 8961.37 9031.05 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3895.80 S 5838.23 E 5927097.78 N 702829.02 E 3897.87 S 5871.72 E 5927096.59 N 702862.55 E 3900.25 S 5904.16 E 5927095.06 N 702895.04 E 3902.25 S 5932.7t E 5927093.80 N 702923.64E 3904.73 $ 5967.40 E 5927092.22 N 702958.38 E 3907.23 $ 5998.27 E 5927090.53 N 702989.30 E 3909.96 $ 6027.20 E 5927088.56 N 703018.29 E 3913.47 $ 6061.11E 5927085.93 N 703052.29 E 3916.74 S 6091.63 E 5927083.46 N 703082.88 E 3920.20 S 6121.05 E 5927080.76 N 703112.38 E 3924.03 S 6152.93 E 5927077.77 N 703144.35 E 3928.04 S 6184.72 E 5927074.59 N 703176.23 E 3932.17 S 6215.05 E 5927071.25 N 703206.66 E 3936.75 $ 6247.28 E 5927067.51 N 703239.00 E 3941.83 $ 6280.66 E 5927063.31 N 703272.50 E 3946.01S 6307.31E 5927059.82 N 703299.25 E 3951.78 S 6343.68 E 5927055.00 N 703335.75 E 3956.49 S 6375.41 E 5927051.12 N 703367.60 E 3959.86 S 6400.94 E 5927048.42 N 703393.21 E 3964.51 $ 6438.98 E 5927044.76 N 703431.36 E 3967.81 $ 6469.29 E 5927042.25 N 703461.74 E 3970.66 S 6496.15 E 5927040.10 N 703488.67 E 3974.44 $ 6531.13 E 5927037.24 N 703523.74 E 3978.17 S 6564.57 E 5927034.38 N 703557.26 E 3981.59 S 6591.06 E 5927031.65 N 703583.83 E Alaska State Plane Zone 4 PBU EOADS 12 Dogleg Vertical Rate Section (°/'lOOft) (ft) Comment 11.036 6884.20 2.462 6915.94 2.970 6946.82 5.287 6973.97 3.129 7006.97 2.210 7036.45 5.168 7064.23 2.032 7096.91 2.477 7126.35 1.915 7164.86 5.338 7185.78 3.775 7216.69 3.634 7246.30 1.863 7277.83 1.539 7310.61 1.159 7336.83 1.009 7372.65 4.029 7403.77 2.371 7428.65 1.356 7465.58 5.159 7494.64 2.544 7520.76 3.270 7554.52 3.550 7586.85 4.379 7612.63 Continued... 10 December, 1998 - 15:33 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 12-14A Your Ref: API-50029206590'1 Job No. AKMMS0409, Surveyed: 5 November, 1998 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northlngs Eastings Northings Eastings (ft) (ft) (ft) (ft) 13826.80 93,790 96.850 8959.77 9029.45 3986.04 S 6625.38 E 5927028.11 N 703618.25 E 13856.97 93.700 96.590 8957.80 9027.48 3989.56 S 6655.28 E 5927025.36 N 703648.23 E 13885.95 94.320 97.640 8955.77 9025.45 3993.14 $ 6683.96 E 5927022.53 N 703677.00 E 13918.44 97.230 97.270 8952.50 9022.18 3997.33 $ 6716.01 E 5927019.18 N 703709.15 E 13950.19 98.170 97.210 8948.25 9017.93 4001.30 S 6747.22 E 5927016.03 N 703740.45 E 13981.87 101.820 96.180 8942.75 9012.43 4004.94 S 6778.20 E 5927013.20 N 703771.52 E 14047.00 101.820 96.180 8929.41 8999.09 4011.80 S 6841.58 E 5927007.99 N 703835.06 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.970° (24-Oct-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 112.480° (True). :".. Based upon Minimum Curvature type calculations, at a Measured Depth of 14047.00ft., The Bottom Hole Displacement is 7931.06ft., in the Direction of 120.387° (True). Alaska State Plane Zone 4 PBU EOADS 12 Dogleg Rate (°/'lOOft) Vertical Section (ft) Comment 7.257 0.910 4.200 9.028 2.967 11.958 0.000 7646.04 7675.01 7702.89 7734.10 7764.46 7794.48 7855.67 Projected Survey Continued... 10 December, 1998 - 15:33 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 12-14A Your Ref: API-500292065901 Job No. AKMMS0409, Surveyed: 5 November, 1998 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOADS 12 Comments Measured Depth (ft) 11462.49 11493.00 14047.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8872.11 3480.84 S 4380.67 E 8890.32 3494.91 S 4400.70 E 8999.09 4011.80 S 6841.58 E Comment Tie-on Survey Window Point Projected Survey 10 December, 1998 - 15:33 - 6 - DrillQuest ~ALAS .eare-d rvIces rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: December 18, 1998 From: Subject: Terrie Hubble Technical Assistant Permit To Drill ~/98-146, 12-14A We have just discovered that the location of this well at surface was listed incorrectly on the Permit To Drill (50-029-20659-01). It was also listed incorrectly on the Application for Sundry Approval (Approval #398-207) for the Plug Back for Sidetrack on the original well, 12-14 (50-029-20659). We discovered this while calculating the new below surface locations. Originally Permitted (Incorrectly) Should Have Been Permitted Location of well at surface Location of well at surface 527' SNL, 717' WEL, SEC. 18, T10N, R15E 527' NSL, 717' WEL, SEC. 18, T10N, R15E I apologize for any inconvenience this may have caused. Please let me know if there is any further action required. Thank you for your assistance and patience in this matter. /tlh ~ALASKA~ are. d rvlc~s rillin9 BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: December 18, 1998 From: Terrie Hubble Technical Assistant Subject: Permit To Drill ¢f98-146, 12-14A We have just discovered that the location of this well at surface was listed incorrectly on the Permit To Drill (50-029-20659-01). It was also listed incorrectly on the Application for Sundry Approval (Approval #398-207) for the Plug Back for Sidetrack on the original well, 12-14 (50-029-20659). We discovered this while calculating the new below surface locations. Originally Permitted (Incorrectly) Should Have Been Permitted Location of well at surface Location of well at surface 527' SNL, 717' WEL, SEC. 18, T10N, R15E 527' NSL, 717' WEL, SEC. 18, T10N, R15E I apologize for any inconvenience this may have caused. Please let me know if there is any further action required. Thank you for your assistance and patience in this matter. /tlh 11/05/98 16:24 FAX 907 564 5193 BP EXPLORATION ~ AOGGG ~ 0OZ a_ ka ared rvices rilling To; Blair Wondzeil, AOGCC From: Chris Brown Subject: DS 12-14A AFE #4J0389 Horizontal Sidetrack BP Exploration / ARCO Alaska Inc. Date: 5/11/g8 Mr Wondzell, I am writing to advise you of our intent to extend the wellbore on the DS 12-14a Horizontal sidetrack past the original depth specified on our application for Drilling Permit. The original depth specified in the application was a TD of 13,465'. However, due to the Iow oil saturation encountered in this well, our asset geologists and reservoir engineers have requested that we extend the wellbore in an attempt to expose more producing formation, to improve the economics of this well. Their requested extension brings the proposed TD of the well to 14,050' and will be drilled as a linear extension of the planned path. There are no other wells in close proximity to the extension. We therefore advise you of our intent to drill to this depth and request your approval of the matter. Sincerely, Chris Brown, Operations Engineer, Nabors 22E a pro?~ . · ' 11/05/98 16:23 FAX 907 564 5193 BP EXPLORATION ~ AOGCC ~001 A~~~ka~eared r.v!ces nll~ng TO: ~ L.~-,,r... tO ekS~.~ DATE: COMPANY: FAX: ~ ;~,. PHONE: FROM: FAX: / (/_¢07/)J6,¢ J/93 PHONE: Number of attachments not including fax cover: ALASKA OIL AND GAS CONSERVATION CO~IISSION -ONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 14. 1998 Dan Stone Enginccring Supcrvisor ARCO Alaska. Inc. PO Box 196612 Anchoragc, AK 99519-6612 ac: Prudhoc Bay Unit 12-14A ARCO Alaska. Inc. Permit No. 98-146 Sur. Loc. 527'SNL. 717'WEL. SEC 18. T10N. RISE. UM Btmnholc Loc. 2061'NSL. 5017'WEL. SEC 21. T10N, RISE. UM Dcar Mr. Stone: Encloscd is the approved application for permit to rcdrill thc abovc rcfcrcnccd w-ell. Thc permit to rcdrill docs not cxcmpt you from obtaining additional permits required by law from other governmental agcncics, and docs not authorize conducting drilling operations until all other rcquircd pcrmitting dctcrminations arc made. Blowout prevention equipment (BOPE) must be tested in accordancc with 20 AAC 25 035. Sufficient noticc (approximately 24 hours) must be givcn to alloxv a rcprcscntative of the Commission to witness a test of BOPE installcd prior to drilling ncw holc. Notice may be given by contacting tl~~on~!cum ficld inspcctor on thc North Slope pager at 659-3607. · '-N.x ~] David kV~-stoll N ~ ~ Chai~an '""., ~ ~ '-~ BY ORDER OF TIlE COMMISSION dlf/Enclosurcs CC: Department of Fish &Gamc. Habitat Scction v,'/o cncl. Department of Environmcntal Conservation xv/o cncl. STATE OF ALASKA ALASKA'OIL AND GAS CONSERVATION COI~i--MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oili [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 70.38' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designatiqn . Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028331/~.~¢,.,~0 4. Location of well at surface 7. Unit or Property Rame 11. Type Bond (See 20 AAC 25.025) 527' SNL, 717' WEL, SEC. 18, T1 ON, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 2136' NSL, 1260' WEL, SEC. 20, T10N, R15E, UM 12-14-~ At total depth 9. Approximate spud date Amount $200,000.00 2061' NSL, 5017' WEL, SEC. 21, T10N, R15E, UM 08/21/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028330, 263'I No Close Approach 2560 13465' MD / 9060' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11070' Maximum HoleAngle 9o° Maximurnsurface 3130 psig, At total depth (TVD) 8920'/3478 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-M 2117' 11348' 8796' 13465' 9060' 263 sx Class 'G' .... iVF ;19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Totaldepth: measured 11911 feet Plugs(measured) Fill at11674' Ma (03/04/95) JUL. 29 1.998 true vertical 9137 feet Effective depth: measured 11674 feet Junk (measured) ~a$~-,~ 0il & Gas Cons. C0mm true vertical 8996 feet Anchorage Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2568' 13-3/8" 3250 sx Fondu, 400 sx AS II 2644' 2644' Intermediate Production 11395' 9-5/8" 500 sx Class 'G' 11471' 8877' Liner 1296' 7" 270 sx Class 'G' 11258' - 11910' 8743' - 9136' Perforation depth: measured 11498'-11520', 11658'-11674', 11675'-11677',,./ , ~ ~i ,~t t~., r~P' ~l~\I~/ true vertical 8893' - 8906', 8986' - 8996', 8997' - 8999' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: C. Michael Jackson, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is~true and correct to the best of my knowledge Signed -~__~__ ~, _.~--'~=~ / Dan Stone Title Engineering Supervisor Date Commission Use Only Permit Number . I APl Number I A~:~rovaI,Date ISee cover letter ¢~_' ~ /~'¢/ 50-029-20659-0' ~ L~IS~ for other requirements Conditions of Approval: Samples Required []Yes [~ No Mud Log Requir ~ []Yes 1-1-1~No Hydrogen Sulfide Measures [~Yes [] No Directional Survey Required J~Yes'E]No Required Working Pressure for BOPE 1--12M; f~]3M; 1--15M; I--I10M; []15M Other: Original Signed By David W. J0hnst0n by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit T' llcate Alaska hared ervices rilling WELL NAME DS 12-14B DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) ['~ DRILLING PERMIT ~] Permit Documentation Prepared: ODE:~~ Date:~Q/~:~ ~] Permit Application ~ed: [~TA.~ ~9~Permit~Applicatioo~Sul¢rgi~ted: Date._7/~,~.Tf~; ['~ PRE-RIG WORK Pm-Rig Memo Reviewed: SDE/ES: Date:~ Pm-Rig Memo Sent to Slope: ODE: Date: Pm-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date:~ Pm-Rig Sundry Application Submitted: TA: Date: Sundry Documentation Prepared: ODE: Date: Sundry Application Reviewed: SDE/ES: Date: Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply,), Abandon Change Approved Program Alter Casing Operation Shutdown Suspend Re-enter Suspended Well Repair Well Time Extension ~ Plugging Perforate Pull Tubing Stimulate Variance Other(Explain): f~ ~a ? ~ ?' APPROVAL TO PROCEED II Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: I Well Name: I PBU DS 12-14B I Redrill Plan Summary I Type of Redrill (producer or injector): I Producer ISurface Location: Target Location. Bottom Hole Location' 527 FSL 717 FEL, S18 T10N R15E Umiat 2136 FSL 1260 FEL, S20 T10N R15E Umiat 2061 FSL 5017 FEL, S21 TION R15E Umiat I AFE Number: 14J0387 I I Estimated Start Date: 18/21/98 I MD: 1~3,465' I I'TVD: 19°6°' I I Rig: I Nabors 22E Operating days to complete: 122 I BF/MSL: 141.0e'1 I RKB: 170.38' I I Well Design (conventional, slimhole, etc.)' I Horizontal Sidetrack I Objective: I Development production targeting Zone 4 sands. Mud Program'. Production Mud Properties: Quickdril-n 16" hole section Density (ppg) Funnel vis LSRV LSR YP pH 8.6 - 8.8 45-65 >45,000 cP 10-20 8.5-9.0 Directional: KOP: I 11,070' MD Maximum Hole Angle: Close Approach Well' 90 From 11,836' to 12,058'. None Logging Program: IProduction Hole(Horizontal) Drilling: JUL 2 7 ~998 Dir / GR / 4 Phase Resis~i~Oil&GasCons. Co~rnis~io~ Platform Express + Sonic Anchorage | " Open Hole: Formation Markers: Formation Tops MD TVD Sag River 11,498' 8883' Open perforations during sidetrack around whipstock. Estimated 3442 psi BHP or 7.5 ppg. Shublik 11,524' 8901' Sad(Z4) 11,732' 8985' Target sands. Estimated 3478 psi BHP or 7.5 ppg HOT 9056' Not penetrated on sidetrack COWC 9094' Not penetrated on sidetrack DS 12-14B Permit to Drill I Casinq/Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 6" 4 1/2" 12.6# L-80 IBT-M 2117' 11,348'/8796' 13,465'/9060' Tubing 4 1/2" 12.6# 13Cr-80 NSCT 11,348' 0/0 11,348'/8796' Cement Calculations: Liner Size 14 1/2" Basis: Tail - Based on 80' shoe track volume, 1967' of open hole with 50% excess, 150' of 7" x 4.5" liner lap and 200' of 7" x 4" drill pipe annular volume. Total Cement Volume: Tail 54 bbl/303 ft~ / 263 sk of acid resistant Premium(G) at 15.8 ppg and 1.15 cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: · Maximum surface pressure: · Planned completion fluid. 3478 psi @ 8920' TVDss - Zone 4 3130 psi @ 8920' TVDss - Zone 4 8.5 ppg Seawater / diesel freeze protection. Drilling Hazards/Contingencies · None DRILLING CLOSE APPROACH: H2S: · Drill Site 12 is not considered to be an H2S Drill Site. Crew H2S drills Will be performed routinely along with the other require drills. PRODUCTION SECTION: · Loss circulation on Drill Site 12 has been documented in the past sidetrack development programs from 1992 to 1994. High losses can occur in the Shublik and at formation interfaces around the Sag River, Shublik and Sadlerochit. · Stuck pipe has not been recorded in the production interval but differential sticking will be a problem if loss circulation is occurring. DS 12-14B Permit to Drill 2 The kick tolerance for the 7" window would be an infinite influx(annular volume) assuming an influx at the 13,465' TD. This is a worst case scenario based on a 7.5 ppg pore pressure and a minimum fracture gradient of 10.0 ppg with a 8.6 ppg mud weight. Disposal No annular injection in this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. SUMMARY SIDETRACK PROCEDURES Pre-Rig Work 1. Pull the 4-1/2" SSSV. Valve is set at 2196' MD. 2. Lay an LCM pill in the 7" liner across the perfs from PBTD to the tubing tail at 11,396'. Ensure the well is static with no fluid losses. 3. Test 4-1/2" tubing x casing annulus from the production packer at 11,292' to surface to 3000 psi for 30 minutes. Note: If the casing is successfully tested to 3000 psi then an RTTS run will not be needed in the rig abandonment operations. 4. Chemically cut the 4-1/2" tubing at ,..11,275', in the middle of the second pup joint above the 7" permanent packer. 5. Circulate with seawater to ensure the well is dead and freeze protect the well to ~2200'. Bleed tubing and annuli pressures to CI psi. 6. Test the FMC 9-5/8" mandrel packoff to 5000 psi for 30 minutes and tubing hanger to 5000 psi for 30 minutes. 7. Set a BPV in the tubing hanger and secure the well. Rig Abandonment Operations * Notify the AOGCC for witnessing rig operations on BOPE testing and with intent to plug and abandon * 1. MIRU Nabors22E 2. Circulate out freeze protection. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4-1/2" tubing cut at ~11,275'. 5. Washover and latch the tubing with an overshot. Rotate to release the tubing anchor and POOH. 6. Mill and recover the Otis production packer at 11,292'. 7. RIH with a 7" RTTS and test the 7" x 9-5/8" casing from 11,450' to surface to 3000 psi for 30 minutes. Note: This step may be deleted if a casing test was performed during pre-rig operations. DS 12-14B Permit to Drill 3 8. RIH with a 7" Halliburton cement retainer on e-line with GR/CCL tie-in to the top of the Sag River(~11,498') and set the cement retainer top at -.11,518' and 20' below TSag. · The top of the cement retainer will be set with open Sag River perforations above. The planned 4.5" liner top packer will lap the highest perforation by 150' minimum and will be fully cemented. 9. RIH with cementing string. Sting into the retainer and establish an injection rate with seawater. Pump 17 barrels of 15.6 ppg Premium cement to fill the casing volume between PBTD at 11,866' and the cement retainer plus squeeze 5 barrels to the perforations. Unsting and circulate out any excess cement. Ric~ Sidetrack Operations 10. 11. 12. 1. RIH with 7" whipstock and set 20° right of high side. KOP should be 11,498'(Top Sag). 2. Displace the well with 4% Quickdril and mill the window through the existing perforations. Monitor torque / drag closely due to the perforations. 3. Directionally drill building from 52-90° angle. Drill the ~1950' of 6" horizontal section with MWD / GR / 4 Phase resistivity to a planned TD of 13,465'. 4. Run drill pipe conveyed 'Platform Express' + Sonic logs from TD to 7" window. 5. Run and fully cement a 4.5" L-80 production liner. The production liner will have a RA tag in a coupling spaced at TSag. Displace the cement with clean seawater. Land the liner top packer at 11,348' or shallower, a minimum of 150' liner lap is required. 6. Test the 4-1/2" x 7" x 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 7. Run a DPC 2.75" perforating assembly shooting locations determined from LWD and DPC logs. 8. Run a 4-1/2" 13Cr completion spacing the WLEG into the 4-1/2" liner tieback sleeve. 9. Test the tubing to 3500 psi for 30 minutes. Test the annulus to 3000 psi for 30 minutes. Nipple down BOPE. Nipple up the adapter flange/tree and test to 5000 psi. Freeze protect the well to ~2100' and secure. Rig down and move off. Estimated Start Date: August 21, 1998 C. Michael Jackson 564-5486 7/23/98 DS 12-14B Permit to Drill 4 Anadrill Schl~-nberger Alaska District 1111 East 80th Avenue Anchorage, Al{ 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for Shared Services Drilling Well ......... : DS12-14B {PO9A) Field ........ : Prudhoe Bay Computation..: Minimu~ Curvature Units ........ : FEET Surface Lat..: 70.21525926 N Surface Long.: 148.41180176 W Legal Description Surface ...... : 527 FSL 717 FEL S18 TiON R15E UM Tie-in survey: 2316 FSL 1603 FEL S20 TION R15EUM BSL .......... : 2136 FSL 1260 FEL S20 TION R15E UM Tgt MidPoint.: 2015 FSL 947 FEL S20 TION R15E UM BHL .......... : 2061FSL 5017 FEL S21 TiON R15E UM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 696891.17 5930839.99 701387.50 5927466.32 701735.00 5927296.00 702052.00 5927183.00 703260.00 5927262.00 Prepared ..... : 20 Jul 1998 Vert sect az.: 113.24 KB elevation.: 70.38 ft Magnetic Dcln: +28.358 Scale Factor.: 0.99994404 Convergence..: +t.49449236 PRELIMINARY PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZII~JTH SAG RIVER TIE-IN SURVEY 11494.38 52.90 123.57 ~OP OF ~IPSTOCK 11498.00 52.93 123.57 11500.00 53.21 123.81 BASE OF ~IPSTOCK 11510.00 54.61 125.00 SHUBLIK 11524.81 54.61 125.00 CURVE 12/100 11527.00 54.61 125.00 11600.00 62.86 I21.54 11700.00 74.27 117.55 SAD ZONE 4 11732.95 78.05 116.34 11800.00 85.75 113.98 VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 8883.18 8812.80 8884.03 8813.65 5426.64 8886.21 8815.83 5429.48 8887.41 8817.03 5431.05 8893.30 8822.92 5438.98 8901.88 8831.50 8903.15 8832.77 8941,01 8870.63 8977.50 8907.12 8985.38 8915.00 8994.82 8924.44 5450.80 5452.55 5513.94 5606.30 5638.22 5704.51 COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 3489.98 S 4407.05 E 701387.50 5927466.32 5L <TIE 3491.57 S 4409.46 E 701389.94 5927464.79 35R 0.94 3492.46 S 4410.79 E 701391.30 5927463.94 35R 17.00 3497.03 S 4417.46 E 701398.08 5927459.55 HS 17.00 3503.95 S 4427.35 E 3504.98S 4428.81E 3539.11S 4480.97 E 3584.81S 4561.86 E 3599.30 S 4590.37 E 701408.15 5927452.88 HE 0.00 701409.64 5927451.90 21L 0.00 701462.66 5927419.14 lgL 12.00 701544.71 5927375.57 17L 12.00 701573.60 5927361.83 lTL 12.00 3627.48S 4650.42 E 701634.35 5927335.22 17L 12.00 (Anadrill (c)98 1214BP09 3.2C 3:23 PM P) DS12-14B (PO9A) 20 Jul 1998 Page 2 STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE LOW POINT 11836.99 90.00 END 12/100 11843.30 90.73 CURVE 10/100 11900.82 90.73 TGT BSL / END 10/100 11908.07 90.00 12058.07 90.00 CURVE 8/100 END 8/100 CURVE CURVE 8/100 TARGET INTER 1 END 8/100 CURVE 4-1/2" LINER POINT TD HOT ONC PROPOSED WELL PROFILE 12098.07 88.31 12098.86 88.28 12244.79 88.28 12244.79 88.28 12300.00 88.03 12400.00 87.61 12500.00 87.23 12559.66 87.03 13465.05 87.03 13465.05 8?.03 DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 112.70 8996.19 8925.81 112.48 8996.15 8925.77 112.48 8995.43 8925.05 112.48 8995.38 8925.00 112.48 8995.38 8925.00 SECTION DEPART 5741.47 5747.78 5805.29 5812.54 5962.52 109.76 8995.97 8925.59 6002.49 109.71 8995.99 8925.61 6003.27 109.?1 9000.38 8930.00 6148.86 109.71 9000.38 8930.00 6148.86 105.30 9002.16 8931.78 6203.75 97.30 9005.98 8935.60 6301.44 89.30 9010.49 8940.11 6395.27 84.53 9013.48 8943.10 6448.66 84.53 9060.38 8990.00 7241.66 84.53 9060.38 8990.00 7241.66 9056.38 8986.00 9094.88 9024.50 COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 3642.12 S 4684.34 E 701668.65 3644.55 S 4690.17 E 701674.53 3666.54 S 4743.31E 701728.23 3669.31S 4750.02 E 701735.00 3726.67 S 4888.61E 701875.04 TOOL FACE 100 5927321.47 17L 12.00 5927319.20 HS 12.00 5927298.60 LS 0.00 5927296.00 HS 10.00 5927242.28 122L 0.00 3741.09 S 4925.92 E 701912.71 3741.35 S 4926.66 E 701913.45 3790.55 S 5063.98 E 702052.00 3790.55 S 5063.98 E 702052.00 3807.14 S 5116.59 E 702105.03 5927228.84 122L 8.00 5927228.60 HS 8.00 5927183.00 93L 0.00 5927183.00 93L 0.00 5927167.78 93L 8.00 3826.71S 5214.50 E 702203.41 3832.47 S 5314.15 E 702303.17 3829.26 S 5373.63 E 702362.54 3743.08 S 6273.69 E 703260.00 3743.08 S 6273.69E 703260.00 5927150.78 93L 8.00 5927147.62 93L 8.00 5927152.38 HS 8.00 5927262.00 0.00 5927262.00 0.00 PRELIMINARY (Anadrill (c)98 1214BP09 3.2C 3:23 PM P) ii ii i i ii i i Shared Hnrker Identl?l~otlon ND BNB SECTN INCLN A) TIE-IN SURVEY 11494 B~4 54~ 52. gO B) TOP ~ WHIPSTOCK 11498 8~6 54~ ~.~ C) BASE OF YHII~*TOCK 11510 ~9 54~ 54. 6I D) CURVE 12/100 11527 8903 54~ 54.61 E) LOW POI~ 11897 8996 5741 gO. DO F) END 12/100 11849 (t996 57~ ~.~ G) CURVE 10/100 11~1 ~5 5805 gD.~ H) TGT ~L / ENO lO/lDO 11gOB ~5 ~13 ~.00 I) CJJRVE 8/100 l~gB 8~6 ~ 88. 91 J) END B/lDO CU~E 120~ 8996 6003 BB.~ K) CURVE B/lDO 12245 gOOD 6149 ~.~ L) TARG~ INTER I 12245 gOOD 6149 ~.~ H) END 8/100 CU~E 12560 ~19 6449 87.03 N) 4-1/2' LINER POINT 13465 9060 7242 87. ~ O) TO 13465 g~O 7242 8%~ ii Serv l'Ces "0r i 1 1''1 n~ , PI)fLIMINARY , , ~m m~m mI I l, mm~FmCh!~~S~rmmm I, DS 12-148 (POgA) VERTICAL SECTIDN VIEW Section at: 113. 24 TVD Scale.: 1 lnch= 250 feet Oep Scale.: 1 1rich = 250 feet Dro,n ..... -. 20 Jul 1998 9~:-'~ .......................................... -N 5000 5125 5250 5375 5500 5625 5750 5875 6000 6125 6250 63?5 6500 6625 6750 8875 7000 7125 7250 Departure ............... SeOtll°n, ................................................... ,~nnd~ z 1 ~. Sch ! u~b~.~r ~ii i ' ii '' i i i ii ii i . i DS 12-14B (POgA) PLAN VIEH CLOSURE. · 7305 ¢~et at Azimuth 12& 82 ',1 DE S A) B) C) D) ~E) F) G) H) I) J) K) L) M) N) O) Shared SerVices I Dr I 1 1~1n9, PRELIMINARY ECLINATION.: +28.358 (E) CALE ....... : 1 inch : 400 fe~t RAWN ....... : 20 Jul lgg8 -- mrker~lentlfloatlon ~ N/S E/W .......... ) TIE-IN'~m. LIRVEY 11494 34gD 5 4407 E ) TOP DF W~ST~K 114~ 3492 S 4~g E ) BASE DF W~STOCK 11510 ~g7 S 4417 E ) CU~E 12/1~ 11527 3505 S 442g E -- , LOW POINT ~ ~m~ S~ S 4m4 E ) TGT BSL / END 10/10~ l lgm ~Bg S 4750 E , )CURVE 8/%00 ~m 3741 S 4g~6 E ) END 8/]~ CURVE 1~ 3?4] S 4~? E ) C~VE 8/X~ ]~ 379] S ~4 E ) TARGET INTER 1 1~ 3'791 S 5~4 E , ) 4-1/~ LI~R POINT ~ ~4~ S ~74 E ) TD ]34~ 3~S 8~74 E .... ~ .............. ............ ~ ..... ...... , ,, I ................................... _}~ ............ ~ ...... , ......... 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 EAST -> i i ii nl I ii I i n i t J I I iiiiij ii I i . i . il i i i i i .~ i i i i i iii i W®ll:12-1~ST1 Spud Date:10-8-81 Original RKBE:76' Top of Formation: 0' Annular Fluid:6.8 Diesel/8.5 SW Reference LoG:GR/CCL Date:7-31-92 ARCO Al&ska, Inc. - Prudh~_~ Bay API %: 50-029-20659-00 Completion: 7-23-92 Hanger Type: FMC Max Hole Angle: 56° @ MD: 6700' Tie In: GR/CCL Type:PRODUCER Status:Sidetrack Hanger:21' Angle @ TS:53° Angle @ TD:54° Date: 7-31-92 ALL DEPTHS ARE 1~ DRILLING MD TO TOP OF EQUIPMENT F~XCEPT WHE~ NOTED. Jewelry (J) Depth Description 2196 4-1/2" Camco TRSVSSSVNipple ID=3.812" 10621 7"X 9-5/8" External Baker Type H Liner Top Packer 11270 4-1/2" Parker SWS Nipple ID=3.813" 11292 7" x 4-1/2" Otis MHR Permanent Packer 11323 4-1/2" Parker SWS Nipple ID=3.813" 11383 4-1/2" Parker SWNNipple ID=3.725" 11396 4-1/2" Tubing Tail 11398 ELM Tubing Tail (Logged 07/31/92) ID: 4-1/2" Parker SWN Nipple ID--3.725" Casing and Tubing (C) Size Weight Grade 1 13-3/8" 72% L-80 2 9-5/8" 479 L-80 9-5/8" Window @ 10800' - 10860' 3 7" 26# L-80 Top Bottom Description 0' 2644' Casing 0' 11471' Casing 10614' 11258' Liner Problems getting by 10843' w/3-3/8" long toolstrings (dog leg) 7" 26# 13CR-80 11258' 11910' CR Liner 4-1/2" 12.69 13CR-80 0' 11396' CR Tubing J-3 Gas Lift Information (G) J-4 MD TVD Stn Mandrel Valve J-5 3389' (3389') i TE-TGPD MC J-6 6421' (5796') 2 TE-TGPD MC 0-2 8088' (6764') 3 TE-TGPD TE 9701' (7790') 4 TE-TGPD TE 10502' (8281') 5 TE-TGPD CA Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF 11498-11520 SAG 22 6 11658-11674 4 16 4 11675-11676 4 1 4 11676-11677 4 1 5 11678-11686 4 8 0 11696-11706 4 10 0 Ty~e Latch Port TRO Date VR-STD RK 1/4" 1748 05-06-93 VR-STD RK 1/4" 1738 05-06-93 D-14R RK 07-23-92 D-14R RK 07-23-92 RDO TG 3/8" ORIF 05-29-93 Date Comments 03-04-95 APERF 05-01-93 RPERF 05-01-93 APERF 05-01-93 RPERF 04-17-93 SQZ 04-17-93 SQZ FRAC ZN4 05/04/93 Datum 8700' SS=11308' MD 8800' SS=11472' MD PBTD=l1866' TD=ll911' Revision Date: 02-01-96 by ENH/BMJ Reason: Perf Data Correction Previous Reason: 10-25-95 Well 12-14ST1 0-3 DS 12-14B Pre-Rig Status (3.812"1D) -- GLMS~flons: 1) 3389' 2) 5796' 3} 6764' 4) 7790' 5) 8281' J9~/8", 47# L~ Bu~ess 9~/8', 47# S~-95 Buffress Section From 10,800- 10,8~' -- 7 ', 2~L-~NSCC 10,614'to 11,208' 7", 2~13Cr~0 Fox tl,258'to 1t,910' DATE REV, BY COMME~S 7/18/90 CH Proposed Pre-~lg Condition APl NO: 50-029- 20659-O~ ARCO Alaska Inc. DS 12-14B Rig Abandonment 9-518", 47~ L*80 Buttress EI to 9630' 9-5/8", 47# S00-95 Buttress 9630' to 10,800' Section From 10,800 - 10,860' -- -- 7", 26,9 Liner 7", 26# L-80 NSCC 10,614' to 11,258' ?", 26~ 13Cr-80 Fox Cement Retainer PBTD ~ __ 7",26#,13Cr~0 ~ -- DATE REV. BY COMMENTS 7/14/98 CMJ Proposed Rig Abandonment Condition APl NO: 50-02a- 20ss9-01 ARCO Alaska Inc. Nabora 22E KB. Elevation = 70.38' -- - - 4-1/2" BaI-O SSSV @ 2000' ~ 4-1/2", 12.6~, 13Cr Tubing ~1 ii: i~ 9~5/8" Milled section from 10,800' - 10,860' H 7" x 4.5" Baker Packer ~ 'x' Completion(CT Access) I~ 4-112" Liner Top (Minimum 150' lap above perfs) ~r~,,~" ~ ~ Perforat ons j 11,658 - 11,706 PBTD DATE REV. BY COMMENTS PRUDHOE BAY UNIT 7/23/98 CMJ Proposed Completion APl NO: 50-029-20659-02 SEC 18: T10N: R15E Arco Alaska Inc Alaska hared ervices rilling WELL NAME DS 12-14B DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET [~ Pe .~~/pplicatig~ Su]~rgitted: TA. (0~._~ ,, ~g..~~~__ Date?~).~.[~ The attached work cannot commence without obtaining the requi.red signatures in ] the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVA,,L TO PROCEED" will signify AOGCC approval has b,een received.I _ _ . Thzs cover sh.eet ~s applicable to: (only one category per cover sheet) ~ Permit Documentation Prepared: . I I~ Sundry Documentation Prepared: --.-- ODE:~_~~~._ Date:'V/:g~J ,.-.. ODE:~ - Date: D(.,! Permit Application Re~ed: / i I [ Sundry Application Reviewed: SDE/ES' <2~--- -~.%~o~ ,=-~- Date"~l~.llot~ SDE/ES' Date' · : ' ~ ~ r-! Sundry'Applicafio----~-~ Submitted'--~: ' TA: Date: ["'] PRE-RIG WORK D Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date:~ ~-I Pre-Rig Sundry Documentation Prepared: ODE: Date:~ ~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date: I Pre-Rig Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE.RIG WORK~ USE PRE.RIG WORK.SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate APPROVAL TO PROCEED I I I I Approved AOGCC Permit/Sundry Received TA: Date: I Approval to Commence Operations SDE/ES: Date: I ., .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coM~i'ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of Well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry E] Deepenl [] Service [] Development Gas []Single Zone [] Multiple Zone :2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 70.38' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 02833y.,~-?..~¢) 4. Location of Well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 527' SNL, 717' WEL, SEC. 18, T10N, R15E, UM Prudhoe Bay Unit - At top of productive interval 8. Well Number Number U-630610 2136' NSL, 1260' WEL, SEC. 20, T10N, R15E, UM 12-14i!~ At total depth 9. Approximate spud date Amount $200,000.00 2061' NSL, 5017' WEL, SEC. 21, T10N, R15E, UM 08/21/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028330, 263'I . No Close Approach 2560 13465' MD / 9060' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) Kick Off Depth 11070' Maximum Hole Angle 90 ° Maximum surface 3130 psig, At total depth (TVD) 8920'/.3478 psig , 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole' Casing Weight Grade Coupling Length MD i TVD 'MD TV• (include stagedata) 6" 4-1/2" 12.6# L-80 IBT-M 2117' 11348' 8796' 13465' 9060' 263 sx Class 'G' .......... 19. To be' compl'eted for Redrill, Re_entry, and DeePen Operations' ''" [~ECEiv~ Present well condition summary Total depth: measured 11911 feet Plugs (measured) Fill at 11674' MD (03/04/95) true vertical 9137 feet JUL 29 !99 Effective depth: measured 11674 feet Junk (measured) true vertical 8996 feet ~aska 0il & Gas 00ns. Casing Length Size Cemented MD Al~.~rage Structural Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2568' 13-3/8" 3250 sx Fondu, 400 sx AS II 2644' 2644' Intermediate Production 11395' 9-5/8" 500 sx Class 'G' 11471' 8877' Liner 1296' 7" 270 sx Class 'G' 11258' - 11910' 8743' ~ 9136' Dr ,D, IC-ATE Perforation depth: measured 11498' - 11520', 11658'- 11674', 11675' - 11677' '~JI' L. true vertical 8893' - 8906', 8986' - 8996', 8997' - 8999' ....... 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements , , Contact Engineer Name/Number: C. Michael Jackson, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is ~true and correct to the best of my knowledge Signed ~__~_~__ ~-,-~. / ) DanStone Title Engineering Supervisor Date Commission Use Only Perm¢ I~umber , I APl Number' I APe~-q~u!r°yal Datee~ I See c°ver letter ,~' ~. / ¢Z/-.p 50-029-20659-0.~ ~- J O~q~ for other requirements Conditions of Approval: Samples Required I-lYes [~No Mud Log R r []Yes J~i'No Hydrogen Sulfide Measures J~Yesi~No Directional Survey Required [~'Yes []No Required Working Pressure for B'OPE []2M; ~I3M; I--ISM; [-I10M; ~15M Other: 0ii~01rlal Sigrle0 dy/'\ by order of Approved By D~¥id W. J0ht'lSt0R Commissioner the commission Date '~1 ~ I~/L;~ c...,,., ~n_ztnl Rc.v. 12-01-85 Submit plicate IWell Name: I PBU DS 12-14B I Redrill Plan Summary [Type of Redrill (producer or injector): I Producer ISurface Location: Target Location: Bottom Hole Location: 527FSL 717FEL, S18 T10N R15E Umiat 2136FSL 1260FEL, S20 T10N R15E Umiat 2061 FSL 5017 FEL, S21 T10N R15E Umiat I AFE Number: 14J0387 I I Rig: J Nabors 22E Estimated Start Date: ] 8/21/98 ! Operating days to complete: 122 lED= 113,465' I ITvD: !9060, I I BF/MSL: 141.oe'1 .. I RKB: 170.38' I Well Design (conventional, slimhole, etc.):...I Horizontal Sidetrack I Objective: I Development production targeting Zone 4 sands. Mud Program: Production Mud Properties: Quickdril-n J6" hole section , , Density (ppg) Funnel vis LSRV LSR YP pH 8.6 - 8.8 45-65 >45,000 cP 10-20 8.5-9.0 Directional: KOP: 111,070' MD Maximum Hole Angle:. Close Approach Well: 90 From 11,836' to 12,058'. None Logging Program: Production Hole(Horizontal) IDrilling: Dir / GR / 4 Phase Resistivity Open Hole: Platform Express + Sonic Formation Markers: Formation Tops MD' TVD Sag River 11,498' 8883' Open perforations during sidetrack around whipstock. Estimated 3442 psi BHP or 7.5 ppg. Shublik 11,524' 8901' ~ad(Z4) 11,732' 8985' Target sands. Estimated 3478 psi BHP or 7.5 ppg HOT 9056' Not penetrated on sidetrack C0WC 9094' Not pe .n. etrated on sidetrack DS 12-14B Permit to Drill Casinc/Tubing Proqram: 'Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 6" 4 1/2" 12.6# L-80 IBT-M 2117' 11,34878796' 13,465'/9060' Tubing 4 1/2" 12.6~ 13Cr-80 NSCT 11,348' 0/0 11,348'/8796' , , Cement Calculations: LinerSize 14 1/2" I Basis: Tail - Based on 80' shoe track volume, 1967' of open hole with 50% excess, 150' of 7" x 4.5" liner lap and 200' of 7"x 4' drill pipe annular volume. Total Cement Volume: Tail 54 bbl/303 ft3 / 263 sk of acid resistant Premium(G) at 15.8 ppg and 1.15 cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: · Maximum surface pressure: · Planned completion fluid: 3478 psi @ 8920' TVDss - Zone 4 3130 psi @ 8920' TVDss - Zone 4 8.5 ppg Seawater / diesel freeze protection. Drillin Hazards/Contingencies · None DRILLING CLOSE APPROACH: H2S: · Drill Site 12 is not considered to be an H2S Drill Site. Crew H2S drills Will be performed routinely along with the other require drills. PRODUCTION SECTION: · Loss circulation on Drill Site 12 has been documented in the past sidetrack development programs from 1992 to 1994. High losses can occur in the Shublik and at formation interfaces around the Sag River, Shublik and Sadlerochit. · Stuck pipe has not been recorded in the production interval but differential sticking will be a problem if loss circulation is occurring. DS 12-14B Permit to Drill 2 · The kick tolerance for the 7" window would be an infinite influx(annular volume) assuming an influx at the 13,465' TD. This is a worst case scenario based on a 7.5 ppg pore pressure and a minimum fracture gradient of 10.0 ppg with a 8.6 ppg mud weight. Disposal No annular injection in this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. SUMMARY SIDETRACK PROCEDURES Pre-Riq Work 1. Pull the 4-1/2" SSSV. Valve is set at 2196' MD. 2. Lay an LCM pill in the 7" liner across the perfs from PBTD to the tubing tail at 11,396'. Ensure the well is static with no fluid losses. 3. Test 4-1/2" tubing x casing annulus from the production packer at 11,292' to surface to 3000 psi for 30 minutes. Note: If the casing is successfully tested to 3000 psi then an RTTS run will not be needed in the rig abandonment operations. 4. Chemically cut the 4-1/2" tubing at ~11,275', in the middle of the second pup joint above the 7" permanent packer. 5. Circulate with seawater to ensure the well is dead and freeze protect the well to ~2200'. Bleed tubing and annuli pressures to ~l psi. 6. Test the FMC 9-5/8" mandrel packoff to 5000 psi for 30 minutes and tubing hanger to 5000 psi for 30 minutes. 7. Set a BPV in the tubing hanger and secure the well. Rig Abandonment Operations * Notify the AOGCC for witnessing rig operations on BOPE testing and with intent to plug and abandon * 1. MIRU Nabors22E 2. Circulate out freeze protection. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4-1/2" tubing cut at ~11,275'. 5. Washover and latch the tubing with an overshot. Rotate to release the tubing anchor and POOH. 6. Mill and recover the Otis production packer at 11,292'. 7. RIH with a 7" RTTS and test the 7" x 9-5/8" casing from 11,450' to surface to 3000 psi for 30 minutes. Note: This step may be deleted if a casing test was performed during pre-rig operations. DS 12-14B Permit to Drill 3 8. RIH with a 7" Halliburton cement retainer on e-line with GR/CCL tie-in to the top of the Sag River(~11,498') and set the cement retainer top at ~11,518' and 20' below TSag. · The top of the cement retainer will be set with open Sag River perforations above. The planned 4.5" liner top packer will lap the highest perforation by 150' minimum and will be fully cemented. 9. RIH with cementing string. Sting into the retainer and establish an injection-rate with seawater. Pump 17 barrels of 15.6 ppg Premium cement to fill the casing volume between PBTD at 11,866' and the cement retainer plus squeeze 5 barrels to the perforations. Unsting and circulate out any excess cement. Ri.q Sidetrack OPerations 1. RIH with 7' whipstock and set 20° right of high side. KOP should be 11,498'(Top Sag). 2. Displace the well with 4% Quickdril and mill the window through the existing perforations. Monitor torque / drag closely due to the perforations. 3. Directionally drill building from 52-90° angle. Drill the ~1950' of 6" horizontal section with MWD / GR / 4 Phase resistivity to a planned TD of 13,465'. 4. Run drill pipe conveyed 'Platform Express' + Sonic logs from TD to 7" window. 5. Run and fully cement a 4.5" L-80 production liner. The production liner will have a RA tag in a coupling spaced at TSag. Displace the cement with clean seawater. Land the liner top packer at 11,348' or shallower, a minimum of 150' liner lap is required. 6. Test the 4-1/2" x 7" x 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 7. Run a DPC 2.75" perforating assembly shooting locations determined from LWD and DPC logs. 8. Run a 4-1/2" 13Cr completion spacing the WLEG into the 4-1/2" liner tieback sleeve. 9. Test the tubing to 3500 psi for 30 minutes. Test the annulus to 3000 psi for 30 minutes. 10. Nipple down BOPE. Nipple up the adapter flange/tree and test to 5000 psi. 11. Freeze protect the well to ~2100' and secure. 12. Rig down and move off. Estimated Start Date: August 21, 1998 C. Michael Jackson 564-5486 7/23/98 DS 12-14B Permit to Drill 4 Anadrill Schltmuberger Alaska District 1111 East 80th Avenue ~nchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for Shared Services Drilling Well ......... : DS12-14B (POgA) Field ........ : Prudhoe Bay Computation..: Minimm Curvature Units ........ : FEET Surface Lat..: 70.21525926 N Surface Long.: 148.41180176 W Legal Description Surface ...... : 527 FSL 717 FEL S18 TiON R15E UM Tie-in survey: 2316 FSL 1603 FEL S20 TION R15E UM BSL .......... : 2136 FSL 1260 FEL S20 TION R15E UM Tgt MidPoint.: 2015 FSL 94? FEL S20 TION R15E UM BHL .......... : 2061FSL 5017 FEL S21 TION R15E UM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 696891.17 5930839.99 701387.50 5927466.32 701735.00 5927296.00 702052.00 5927183.00 703260.00 5927262.00 Prepared ..... : 20 Jul 1998 Vert sect az.: 113.24 KB elevation.: 70.38 ft Magnetic Dcln: +28.358 (E) Scale Factor.: 0.99994404 Convergence..: +1.49449236 PRIELI INARV PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH VERTICAL-DEPTHS TVD SUB-SEA SECTION DEPART COORDINATES-FROM ALASKA Zone 4 WELLHEAD X ¥ TOOL DL/ FACE 100 SAG RIVER TIE-IN SURVEY TOP OF WHIPSTOCK BASE OF WHIPSTOCK 11494.38 52.90 123.57 11498.00 52.93 123.57 11500.00 53.21 123.81 11510.00 54.61 125.00 SHUBLIK 11524.81 54.61 125.00 CURVE 12/100 11527.00 54.61 125.00 11600.00 62.86 121.54 11700.00 74.27 117.55 SAD ZONE 4 11732.95 78.05 116.34 11800.00 85.75 113.98 8883.18 8812.80 8884.03 8813.65 8886.21 8815.83 8887.41 8817.03 8893.30 8822.92 8901.88 8831.50 8903.15 8832.77 8941.01 8870.63 8977.50 8907.12 8985.38 8915.00 8994.82 8924.44 5426.64 5429.48 5431.05 5438.98 5450.8O 5452.55 5513.94 5606.30 5638.22 5704.51 3489.98 S 4407.05 E 701387.50 5927466.32 5L <TIE 3491.57 S 4409.46 E 701389.94 5927464.79 35R 0.94 3492.46 S 4410.79 E 701391.30 5927463.94 35R 17.00 3497.03 S 4417.46 E 701398.08 5927459.55 }IS 17.00 3503.95 S 4427.35 E 701408.15 5927452.88 HS 0.00 3504.98 S 4428.81E 701409.64 5927451.90 216 0.00 3539.11S 4480.97 E 701462.66 5927419.14 lgL 12.00 3584.81S 4561.86E 701544.71 5927375.57 lTL 12.00 3599.30 S 4590.37 E 701573.60 5927361.83 17L 12.00 3627.48.S 4650.42 g 701634.35 5927335.22 I?L 12.00 (Anadrill (c)98 1214BP09 3.2C 3:23 PM P) DS12-14B (PO9A) 20 Jul 1998 Page 2 PROPOSED WELL PROFILE STATION MEASURED INCLIq IDENTIFICATION DEPTH ANGLE LOW POINT 11836.99 90.00 END 12/100 11843.30 90.73 CURVE 10/100 11900.82 90.73 TGT BSL / END 10/100 11908.07 90.00 12058.07 90.00 CURVE 8/100 END 8/100 CURVE CURVE 8 / 100 TARGET INTER 1 END 8/100 CURVE 4-1/2" LINER POINT TD OWC 12098.07 88.31 12098.86 88.28 12244.79 88.28 12244.79 88.28 12300.00 88.03 12400.00 87.61 12500.00 87.23 12559.66 87.03 13465.05 87.03 13465.05 87.03 DIRECTION AZIMUTH 112.70 112.48 112.48 112.48 112.48 109.76 109.71 109.71 109.71 105.30 97.30 89.30 84.53 84.53 84.53 VERTICAL-DEPTHS TVD SUB-SEA SECTION DEPART COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 8996.19 8925.81 8996.15 8925.77 8995.43 8925.05 8995.38 8925.00 8995.38 8925.00 5741.47 5747.78 5805.29 5812.54 5962.52 3642.12 3644.55 3666.54 3669.31 3726.67 S 4684.34 E 701668.65 5927321.47 17L 12.00 S 4690.17 E 701674.53 5927319.20 HS 12.00 S 4743.31E 701728.23 5927298.60 LS 0.00 S 4750.02 E 701735.00 5927296.00 HS 10.00 S 4888.61E 701875.04 5927242.28 122L 0.00 8995.97 8925.59 8995.99 8925.61 9000.38 8930.00 9000.38 8930.00 9002.16 8931.78 6002.49 3741.09 S 4925.92 E 701912.71 5927228.84 122L 8.00 6003.27 3741.35 S 4926.66 E 701913.45 5927228.60 HS 8.00 6148.86 3790.55 S 5063.98 E 702052.00 5927183.00 93L 0.00 6148.86 3790.55 S 5063.98 E 702052.00 5927183.00 93L 0.00 6203.75 3807.14 S 5116.59 E 702105.03 5927167.78 93L 8.00 9005.98 8935.60 9010.49 8940.11 9013.48 8943.10 9060.38 8990.00 9060.38 8990.00 6301.44 6395.27 6448.66 7241.66 7241.66 3826.71 3832.47 3829.26 3743.08 3743.08 S 5214.50 E 702203.41 5927150.78 S 5314.15 E 702303.17 5927147.62 S 5373.63 E 702362.54 5927152.38 S 6273.69 E 703260.00 5927262.00 S 6273.69 E 703260.00 5927262.00 93L 8.00 93L 8.00 HS 8.00 0,00 0,00 9056.38 8986.00 9094.88 9024.50 P ELIHINAi Y (knadrill (c)98 1214BP09 3.2C 3:23 PM P) Shored S~K'v1c~s Morker Identification MD B~B SECTN INCLN A) TIE-IN SURVEY 11494 BBB4 5427 52. go B) TDP DF VHIPSTDCK 11498 BBB6 5429 52. EB C) BASE DF YHIPSTDCK 11510 BBg9 5499 54. 61 D) CURVE 12/100 11527 BgD3 5453 54.61 E) LOW POINT 11897 Bgg8 5741 90. DO F) END 12/100 11849 Bgg6 5748 90. 73 G) CURVE 1D/lDO 11901 BBg5 5805 90.73 H) TGT BSL / END 10/100 l lgDB Bgg5 5819 g(~DO I) CURVE B/1DD 12i]98 BBg6 6002 BB. 91 J) END B/IOO CURVE 12099 Bgg6 6003 BB. ~B K) CURVE B/IOD 12245 gODO 6149 BB. 28 L) TARGET INTER 1 12245 gOOD 6149 BB. 2B M) END 8/100 CURVE 12560 g019 6449 87. 09 N) 4-1/2' LINER PDINT 13465 g06D 724~ 87.03 D) ll] 13465 9060 ?242 B?.D9 Ori 1 1 in P I LIMINARY AnOdr~ 11 DS 12-148 (PDgA) VERTICAL SECTIDN VIEW Soctlon ~t: 113.24 TVD Scole.: 1 lnch= 250 feet Oep Scole.: 1 inch TM 250 feet Drown ..... : 2D Jul 1998 , ~ ~ ...... ~ ...... --____ --,,-_--- .... 5000 5125 5250 5375 5500 5625 5750 5875 6000 § 125 8gO 83?5 8500 6825 6750 6875 ?fflo 7125 7250 Sectlon De (Anodrlll (c>g8 12148P09 3.2C 3:26 PM P) Anadr ~ ],~ Scl~ ! umb~r§~r -- iiii II I I II I DS 12-14B (POg^) PLAN VIE CLOSURE ..... : 2305 ?eet at Azimuth 120. 82 il mil 'Shar d BE SC/ OR/ B) C) E) F) G) H) I) K) L) N) N) O) S~vlc~s i J i O,rl!lln9 RELIMINARY I I --CLINATIDN.: +28.358 (E) ; .'ALE ....... : 1 inch : 400 ?eet J ~rker ~mnt ! ? 1 cat ! on MD N/S E/W ~ TIE-IN~i~JRVEY 11494 34~ S 4~? E~ ~ OF ~~ 114~ 34~ S 4~g E ~~STOCK 1151a ~g~ s 441~ E ~2/~ 11527 3505 S 442g E ~OW POlm ~ 118~ 3642 S 4m4 E ~ 1~/1~ ~ 11843 3845 S 4~D E ~ 1~~1g01 3887 S 4?43 E ~ EN~IO~ 11g~ ~6g S 4~D E ~U~E BYrD ~ 3741 S 4~8 E ~~ CURVE 1~ 3741 S 4~7 E ) C~VE B/1~ ~~1 S ~4 E ~ INTER 1 1~ 9791 S 5~4 E ,, ~ ~ CURVE 1~ ~ B~g S 59~4 E ~' LIaR ~~~ ~4BS ~4E ) TD 194~ 3~S 6~4 E .... _ ~ ~ , , ~ ~t Ntd~olnt (P( 1 ............. ~ m"' ..... , , .... .......... m 3200 3400 9600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 EAST -> (^.njr"ll! (C:~gJ~ 121'4BPOg 3.2C 3,'J]5- PJJ P~ ............................ 6400 6600 8800 ,, , ,, ~O0 Well:12-1~ST1 Spud Date:10-8-81 Original RKBE:76' Top of Formation: 0' Annular Fluid:6.8 Diesel/8.5 SW Reference Log:GR/CCL Date:7-31-92 "--'~tRCO Al&ska, Inc. - Pr%1dhoe-~ay API %:50-029-20659-00 Completion:7-23-92 Hanger Type:FMC Max Hole Angle:56° @ MD: 6700' Tie In: GR/CCL Type:PRODUCER Status:Sidetrack Hanger:21' Angle @ TS:53° Angle @ TD:54° Date: 7-31-92 ALL DEPTHS ~ RF~B DRILLING MI) TO TOP OF EQUIPMEt~T EXCEPT W'iiE~ NOTED. Jewelry (J) Depth Description i 2196 4-1/2" Camco TRSVSSSVNipple ID=3.812" 2 10621 7" X 9-5/8" External Baker Type H Liner Top Packer 3 11270 4-1/2" Parker SWS Nipple ID=3.813" 4 11292 7" x 4-1/2" 0tisMHR Permanent Packer J-1 5 11323 4-1/2" Parker SWS Nipple ID=3.813" 6 11383 4-1/2" Parker SWNNipple ID=3.725" 'O-1 7 11396 4-1/2" Tubing Tail 11398 ELM Tubing Tail (Logged 07/31/92) ID: 4-1/2" Parker SWN Nipple ID=3.72§' G-1 Casing and Tubing (C) Size Weight arade 1 13-3/8" 72% L-80 2 9-5/8" 479 L-80 9-5/8" Window @ 10800' - 10860' 3 7" 26% L-80 10614' 11258' Liner Problems getting by 10843' w/3-3/8" long toolstrings (dog leg) g-2 4 7" 26# 13CR-80 11258' 11910' CR Liner 4-1/2" 12.6# 13CR-80 0' 11396' CRTubing Top Bottom Description 0' 2644' Casing 0' 11471' Casing J-$ aas Lift Information (G) J-4 MD TVD Stn Mandrel J-5 3389' (3389') 1 TE-TGPD J-6 6421' (5796') 2 TE-TGPD 0-2 8088' (6764') 3 TE-TGPD 9701' (7790') 4 TE-TGPD 10502' (8281') 5 TE-TGPD Valve Ty~e Latch Port TRO Date MC VR-STD RK 1/4" 1748 05-06-93 MC VR-STD RK 1/4" 1738 05-06-93 TE D-14R RK 07-23-92 TE D-14R RK 07-23-92 CA RDO TG 3/8" ORIF 05-29-93 Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF 11498-11520 SAG 22 6 11658-11674 4 16 4 11675-11676 4 1 4 11676-11677 4 1 5 11678-11686 4 8 0 11696-11706 4 10 0 Date Comments 03-04-95 APERF 05-01-93 RPERF 05-01-93 APERF 05-01-93 RPERF 04-17-93 SQZ 04-17-93 SQZ FRAC ZN4 05/04/93 Datum 8700' SS=11308' MD 8800' SS=11472' MD PBTD=l1866' TD=ll911' Revision Date: 02-01-96 by ENH/BMJ Reason: Perf Data Correction Previous Reason: 10-25-95 Well 12-14ST1 0-3 2-14BP Status Freeze Protection Camco ~RSV' S$$V Nipple IGLM Stations: 1) 33S0' 3} 6764' 4} 7790' $) 828t' Fox Tubing 9-5/8", 47# L-80 Buttress O' to 9630' 9-5/8", 47# $00-95 Buttress 9630' to t0,800' 7", 26~ Liner ~ Chemical Cut ~ 7" Otis 'MHR' Packer 7", 26~ L.~0 NSCC 7", 26# 13Cr-80 Fox 1tA58' to 1t,0~10' 11,498' - 11,520' P~oposed K.O.P. for t2-14B ~[~ 11,658' - tl,674' 11,~8' - 11,~ 11,678' - 11,686' 1t ,6~' - 11,7~' DATE DS 12-14B Ria Abandonment 13-3/8", 72#, L-80 ~ ~ 9-5/8", 47# L-80 Buttress ~ to 9630' 9-5/8", 47# S00-95 Buttress 9630' to t0,800' 9-5/8', 47 ~t, L-80 Section From 10,800-10,860' 7", 26~Liner ~ 7", 26f~ L-80 NSCC 10,614' to 11,258' 7", 26~ 13Cr-80 Fox 11,258' to 11,916. Cement Retainer Otmn Perforations: 11,498' - 11,520' Proposed K.O.P. for 12-14B (~ tt,658' - 11,674' 11,675' - 11,676' 11,676' - 11,677' 11,678' - 11,686' 1t,696' - 11,706' Previous~ySaz_ dPa~:fs: 11,678' - 11,686' 1 t ,696' - 1 t,706. PBTD ~ ?", 26~, 13Cr-80 ~ ' DATE REV~ BY CMJ COMMENTS Proposed Rig Abandom~ent Condition PRUDHOE BAY_UNIT WELL:DS 1~4A AP! NO: $O-O29-20659-O1 ARCO Alaska Inc. i"' Nabors 22E KB. Elevation = 70.38' ~ 4-1/2" BaI-O SSSV @ 2000' ~ ~- 13-3/8", 72#, L-80 . . x ~" GLM's 4-1/2", ~2.~, t3Cr Tubing 7" Liner Top ~ 9-518" Milled se~ion ~m J0,800' - J0,860' 7" x 4.5" Baker Packer ~ 'x' ~mHeflon(CT Accel) 4-1/2" Liner Top ~ 11'~'1 (Minimum t50' lap above pe~) - ISag in ~1~" Perorations: ~ J~,~8' - ~ J,520' TD at ~ Sqz'd Perforations: ~ 658' - 1~,706' ~ PBTD DATE R~. BY COMME~ 7~3/98 CMJ Proposed Completion ~Pl NO: Arco Alaska Inc VENDOR /~L/~S~i/~ST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET O&O19~ CKO&O19@D 100. O0 100. O0 HANDL NO INST: S/H TERRIE HUBBL)-'. X 4628 ........... ..r. ,_~ I# P*YMENT FOR iTEMS DESCRIBED ABOVE. ~ ~ 1 OO_ OO 1 OO. OO · WELL PERMIT CHECKLIST FIELD & POOL COMPANY INIT CLASS WELL NAME/,~-~'~'.. /2-"',,/'Z//,i~ PROGRAM: exp [] dev/~redrll~ serv [] wellbore seg IJ ann. disposal para req Ii /'--',¢,?'/ GEOL AREA ~' '~'4::~ UNIT# ,/,,,2~. ,~'~O ON/OFF SHORE _,,_,,~,~ 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 ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~ C~c:~C) ps~g. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... APPR., DATE 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. N N f N f N Y N Y N ~' N N GEOLOGY 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N /" 31. Data presented on potential overpressure zones ....... Y/,N 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. /Y N / ' 34. Contact name/phone for weekly progress reports ....... /~ Y N [exploratory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain w~ suitable receiving zone; ....... Y N (B) will not contaminate~'s~ater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integn'ty,o.~the well used for disposal; Y N (D) will not dama~ng forr~atio~ir recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLgGY: ENGINEERING: UlC/Annular COMMISSION' co (-.,3 Commentsllnstructions: M:chel~list rev 05/29198 dlf:C:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri May 14 14:09:29 1999 Reel Header Service name ............. LISTPE Date ..................... 99/05/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/05/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPER3~TOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MW-80409 T. PIEPER P. WILSON 12-14A 500292065901 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 14 -M_AY- 99 MWD RUN 3 MWD RUN 3 AK-MW-80409 AK-MW-80409 B. ZIEMKE B. ZIEMKE P. WILSON P. WILSON 18 I0N 15E 527 717 .00 69.70 41.10 1999 AJas 0i! & Cons. mmis$iOa WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: File Header OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 11505.0 6.000 14047.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMFLA P~AY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PH3kSE-4 (EWR-4) AND STABILIZED LITHO-DENSITY (SLD) . 4. A MEASUREMENT AFTER DRILLING (MAD) PASS WAS PERFORMED WHILE TRIPPING INTO THE HOLE FOR MWD RUN 3. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 5. MWD DATA HAS BEEN DEPTH CORRECTED/SHIFTED USING THE MWD GAMMA RAY DATA LOGGED ON 31 JULY, 1992 BY CAMCO. THIS DATA WAS PROVIDED BY DEDE SCHWARTZ OF ARCO ALASKA, INC . 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14047'MD, 8991'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD). ENVIRONMENTAL PARAMETERS USED IN PROCESSING DENSITY LOG DATA: HOLE SIZE = MUD FILTRATE SALINITY = FORMATION WATER SALINITY = MUD WEIGHT = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ 6 I! 19000 - 20000 PPM. 11500 PPM. 8.5 - 8.6 PPG. 1.o G/CC 2.65 G/CC SANDSTONE Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START GR 11439 ROP 11490 PEF 11503 DRHO 11503 RHOB 11503 FET 11503 RPD 11503 RPM 11503 RPS 11503 RPX 11503 $ BASELINE CURVE FOR SHIFTS: Comment Record FILE HEADER FILE NIIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH 5 5 0 0 0 0 0 0 0 0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 11439.5 11480 11483 11484 11485 11487 11490 11491 11492 11493 11496 14045 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: GR 11441 5 11482 5 11485 5 11486 5 11488 0 11490 0 11492 5 11493 5 11495 5 11497 0 11498 5 14047 0 STOP DEPTH 13995 0 14045 0 13966 0 13965 5 13965 5 14002 0 14002 0 14002.0 14002.0 14002.0 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 11493.0 12601.0 3 12601.0 14047.0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD FT/H 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 lO 40 11 Name DEPT ROP GR RPX RPS RPM RPD FET RHOB DRHO PEF Min 11439.5 5 0954 17 3618 0 4133 0 5401 0 5134 0 5068 0 5556 2.129 -0.256 0.9449 First Max Mean Nsam Reading 14045 12742.2 5212 11439.5 3951.56 109.247 5110 11490.5 754.062 79.4209 5112 11439.5 2000 23.8181 4999 11503 2000 26.5878 4999 11503 947.147 17.3743 4999 11503 2000 20.7992 4999 11503 34.3477 1.92665 4999 11503 3.2019 2.40595 4926 11503 0.3351 0.0356327 4926 11503 12.3495 2.22137 4927 11503 Last Reading 14045 14045 13995 14002 14002 14002 14002 14002 13965.5 13965.5 13966 First Reading For Entire File .......... 11439.5 Last Reading For Entire File ........... 14045 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE DRHO RHOB PEF GR RPD RPM RPS FET RPX RAT $ MERGED DATA SOURCE Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 12355.0 12355.0 12355.5 12384 5 12391 0 12391 0 12391 0 12391 5 12391 5 12435 0 STOP DEPTH 12520 0 12520 0 12520 0 12549 0 12556 0 12556 0 12556 0 12556 0 12556 0 12599 0 PBU TOOL CODE MWD $ REMARKS: MAD RUN NO. MAD PASS NO. MERGE TOP 3 12601.0 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 14047.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR ~ API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 PEF MAD BARN 4 1 -68 20 24 28 32 36 4O 6 7 8 9 10 11 Name Min Max Mean DEPT 12355 12599 12477 P~AT 87.4584 224.089 157.589 GR 42.8415 749.243 237.722 RPX 2.414 2000 18.5481 RPS 3.0947 2000 24.2369 RPM 3.9307 88.2653 16.5119 RPD 4.8405 2000 32.4516 FET 33.8123 38.0739 35.1474 RHOB 2.2217 2.8859 2.5092 DRHO -0.154 0.3153 0.0377746 PEF 1.4173 4.88 2.64358 Nsam 489 329 330 330 331 331 331 330 331 331 330 First Reading 12355 12435 12384.5 12391.5 12391 12391 12391 12391.5 12355 12355 12355.5 Last Reading 12599 12599 12549 12556 12556 12556 12556 12556 12520 12520 12520 First Reading For Entire File .......... 12355 Last Reading For Entire File ........... 12599 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR ROP PEF DRH0 RHOB FET RPD RPM RPS RPX $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11441 5 11493 0 11505 0 11505 0 11505 0 11505 0 11505 0 11505 0 11505 0 11505 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12551 0 12601 0 12522 0 12522 0 12522 0 12558 0 12558 0 12558 0 12558 0 12558 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA PAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 02-NOV-98 5.07 SP4 5.16/DEPII 2.22A MEMORY 12601.0 11493.0 12601.0 55.3 91.4 TOOL NUMBER Plll5GR4 Plll5GR4 Plll5GR4 6.000 6.0 QUIKDRILL-N 8.50 63.0 8.5 19000 12.0 2.200 1.430 1.500 3.500 61.1 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 FT/H 4 1 68 28 8 RHOB MWD 2 G/CC 4 1 68 32 9 DRHO MWD 2 G/CC 4 1 68 36 10 PEF MWD 2 BARN 4 1 68 40 11 Name DEPT ROP GR RPX RPM RPD FET RHOB DRHO PEF Min 11441.5 5 0954 20 8419 1 6025 1 8594 1 6098 0 5068 0 5556 2 1952 -0.182 1.0236 First Max Mean Nsam Reading 12601 12021.2 2320 11441.5 3951.56 103.269 2217 11493 754.062 129.776 2220 11441.5 2000 48.9847 2107 11505 2000 54.821 2107 11505 947.147 32.8878 2107 11505 2000 40.7725 2107 11505 33.8142 1.63977 2107 11505 3.1493 2.50141 2035 11505 0.2606 0.0317924 2035 11505 12.3495 2.7588 2035 11505 Last Reading 12601 12601 12551 12558 12558 12558 12558 12558 12522 12522 12522 First Reading For Entire File .......... 11441.5 Last Reading For Entire File ........... 12601 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 12522.5 13968 0 DRHO 12522.5 13967 5 RHOB 12522.5 13967 5 GR 12551.5 13997 0 FET 12558.5 14004 0 RPD 12558.5 14004 0 RPM 12558.5 14004 0 RPS 12558.5 14004 0 RPX 12558.5 14004 0 ROP 12601.5 14047.0 $ LOG HEADER DATA DATE LOGGED: 05-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.1 MAXIMUM ANGLE: 101.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY Plll5GR4 5.07 SP4 5.16/DEPII 2.22A MEMORY 14047.0 12601.0 14047.0 EWR4 SLD $ ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MLTD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP_ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Plll5GR4 Plll5GR4 6.000 6.0 QUIKDRILL-N 8.60 63.0 8.6 20000 9.4 2.200 1.360 1.500 3.500 65.6 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 FT/H 4 1 68 28 8 RHOB MWD 3 G/CC 4 1 68 32 9 DRHO MWD 3 G/CC 4 1 68 36 10 PEF MWD 3 BARN 4 1 68 40 11 Name Min Max Mean Nsam DEPT 12522.5 14047 13284.8 3050 GR 17.3618 201.721 40.762 2892 RPX 0.4133 16.7374 5.48266 2892 RPS 0.5401 19.7381 6.01806 2892 RPM 0.5134 21.0986 6.07177 2892 RPD 0.6028 44.4774 6.24735 2892 ROP 5.8217 2436.33 113.76 2892 FET 0.5609 34.3477 2.13566 2892 RHOB 2.129 3.2019 2.33875 2891 DRHO -0.256 0.3351 0.0383359 2891 PEF 0.9449 5.9984 1.84321 2892 First Reading 12522 5 12551 5 12558 5 12558 5 12558 5 12558 5 12601 5 12558 5 12522 5 12522 5 12522 5 Last Reading 14047 13997 14004 14004 14004 14004 14047 14004 13967.5 13967.5 13968 First Reading For Entire File .......... 12522.5 Last Reading For Entire File ........... 14047 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 3 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DRHO 12357.0 12522.0 RHOB 12357 . 0 12522 . 0 PEF 12357 . 5 12522 . 0 GR 12386 5 RPD 12393 0 RPM 12393 0 RPS 12393 0 FET 12393 5 RPX 12393 5 P~AT 12437 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12551 0 12558 0 12558 0 12558 0 12558 0 12558 0 12601 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA ILAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 05-NOV-98 5.07 SP4 5.16/DEPII 2.22A MEMORY 14047.0 12601.0 14047.0 84.1 101.8 TOOL NUMBER Plll5GR4 Plll5GR4 Plll5GR4 6.000 6.0 QUIKDRILL-N 8.60 63.0 8.6 20000 9.4 2.200 1.360 1.500 3.500 65.6 .0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD 3 FT/H 4 1 68 GR MAD 3 API 4 1 68 RPX MAD 3 OHMM 4 1 68 RPS MAD 3 OHMM 4 1 68 RPM MAD 3 OHMM 4 1 68 RPD MAD 3 OHMM 4 1 68 FET MAD 3 FT/H 4 1 68 RHOB MAD 3 G/CC 4 1 68 DRHO MAD 3 G/CC 4 1 68 PEF MAD 3 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 Name Min Max DEPT 12357 12601 RAT 87.4584 224.089 GR 42.8415 749.243 RPX 2.414 2000 RPS 3.0947 2000 RPM 3.9307 88.2653 RPD 4.8405 2000 FET 33.8123 38.0739 RHOB 2.2217 2.8859 DRHO -0.154 0.3153 PEF 1.4173 4.88 Mean 12479 157.589 237.722 18 5481 24 2369 16 5119 32 4516 35 1474 2 5092 0.0377746 2.64358 Nsam 489 329 330 330 331 331 331 330 331 331 330 First Reading 12357 12437 12386.5 12393.5 12393 12393 12393 12393.5 12357 12357 12357.5 Last Reading 12601 12601 12551 12558 12558 12558 12558 12558 12522 12522 12522 First Reading For Entire File .......... 12357 Last Reading For Entire File ........... 12601 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/05/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/05/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File