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Home My WebLink About202-122 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7f 3o( 3 DATE: 7/26/13 P. I. Supervisor (7 FROM: Jeff Turkington SUBJECT: No Flow Test Petroleum Inspector Prudhoe Bay Unit DS12-14A BP Ex. 'ratio SCANNED j �� _ i PTD # 1 ' 80, 2021220 7/26/13: No Flow Test Summary: Upon arrival at Drill Site 12 the operator, Kevin Parks, handed me the latest no-flow test procedure. I reviewed the schematic in the procedure with what was installed in the field. The layout 'as-built' was different from the planned rig-up in that 1) " there was no neighboring well used to depressure the inner annulus (IA), 2) there was no second "metering tank", and 3) instead of two Crystal gauges for tubing and IA there was one nVision dual port reference pressure data recorder used, which had been calibrated by CH2MHill on 3/11/13. The tubing was rigged with 2" Chicksan hard line from the top of the swab, through a valve manifold, and to the top of the tank. The tank used was marked as Tank #73012-B. The tank had no level measuring or sensing equipment so I had the operators provide a strapping table which showed that 1 foot equaled 2.397 barrels. The IA was routed to the other end of the dual port recorder - using a '/2" hydraulic hose. See attached photos. The operators had depressured the tubing along with the flow line to zero PSIG. The well tree was then isolated from the flow line by shutting the wing valve. The flow line pressure was checked throughout the test and remained at zero PSIG. The gas lift line (A/L line) was shut in at the well with valve CV1, as identified on the schematic, and the - pressure on the line remained at 1982 PSIG throughout the test. The outer annulus pressure (OA) was recorded, although the OA had previously been cemented to surface, on 1/7/06. After gathering initial readings the tubing and IA were isolated at the tank (marked "NFT Tank" in the procedure), and remained shut in for a continuous 3 hours, during which - time readings were taken every 30 minutes. At the end of the 3 hour shut in period the tubing was opened to the tank and the pressure recorded as it dwindled to zero and until no flow could be heard at the outlet inside the open-top tank. As a point of reference, an operator commented that the tubing had depressured from 41 to zero PSIG in 4 minutes, during their pre-test. 2013-0726_No-Flow_PBU_12-14A_jt.docx Page—1 of 4 The test continued as follows: Time Tubing IA OA Tank Level Initial 10:15:00 0* 241 35 2 1/2" 30 min 10:45:00 9 240 27 2 1/2" 1 hr 11:15:00 13 240 28 2 1/2" 1.5 hr 11:45:00 16 239 28 2 1/2" 2 hr 12:15:00 18 239 27 2 1/2" 2.5 hr 12:45:00 21 238 26 2 1/2" 3 hr 13:15:00 . 23 ' 238 26 2 1/2" Tubing open to tank 13:15:30 " 2 ' 238 26 2 1/2" 13:16:00 1 238 26 2 1/2" Time to zero 13:17:10 ' 0 . 238 26 2 1/2" Small whisper of flow 13:18:00 0 238 26 2 1/2" / Dead - no flow 18:30:00 / 0 238 26 2 1/2" *Note: The data recorder display did not indicate in fractions of a PSIG. p Y Attachments: Rig-up Schematic ' Photos (3) ' I1 201 3-0726 No-Flow_PBU_12-14Ajt.docx Page 2 of 4 No Flow Test— PBU 12-14A Photos by AOGCC Inspector J. Turkington 7/26-2013 NFT Riq-Up Schematic ee - -. No-Flow' A =Need;e PG' 1L 'aise Need'e t "Check Test WeIY evi�g( Ic. Y- Deprmsuezed it va've Vskre Coe-Op•Well _ 2'name Neighboring _ 1-AChoke �;_nvA9 E/lane Well X V Hose II"( ►' eGV o LFH ,(:) SSV 1'-------- '25C p<_i MV g �i ALLY • "1 \ CV> '••�,§j L Attune ►1 I - .}{ + r - Opai ;' - ■1 BaBVaNesL T� J( i ee'ao'.r.Si,i PG 2'Hard w orarC PRi e^I ! Needle Line s J 748VZ: Valve z = Closed -L. s 1__t. -,.b./., Vent -.;k,,.1:. - gy�pp(( l>>� Anonym geV �I �� BV4 p,.tod pLB�•/ Vent l----÷ a. ■V • ALLY.AIL Latera!Vave • Bs,Black Valve Metering Tank • CG•Crysta'PressureGatge (<10k BBL • N=Casire Vane NOT Tank w/Gas Buster) • !GV=In'et Gate Valve f 50 BBL Open-top w/Gas Buster) • LV=LateralValve • MV.Master valx • PG.Pressure Gauge • Q"V•Quarter-turn Va'e • SSV-SueaceSMeryVa e • SWAB•Swat Valve • WV=Wing Valve --If the o verso a smarm/nanyvevict et youwou d!keto make any chenem contact WSL L SC- x (1 Q1 5cter ") .0 / r, - 2 l'+ � �� /1 c x "7,47 - r,,k S SS j ''. j "V/ 201 3-0726_No-Flow_PBU_12-14Ayj t.docx Page 3 of 4 Photo of tubing from top of swab Photo of IA connection ..... i ,,. rli _, sue► ' ''' _ lk iii , . 4 , 3 .- ". e a or ; 7 ter 1 Photo of valve manifold with dual port recorder and tank / w j !, 777 A i,:Y A y^ kiikw11,,.", ' *pee:, r , - i gIVW*.„,...71 ..'•.- • -.." Z. _. 'L A 4 a '0"1",,,, sw s---•., - '' . . , . s ' :11111rNellr % - . `* "—. `'j e 7 4 - T x AN' ''' 1,74,1 .1 . * r. d .1v. • 2I!3-0726_No-Flow_PBU_12-14A,j t.docx Page 4of4 !-d ~ ~~ ~~ v~ ~b if~l)Il ~ ~7 ~t~lt,~ 04!21/10 Scl~lum6~r~er d~amr~, „y,„ NO.5511 ~ !..,..r _w ~. Y,m US:T .. Alaska Data & Consulting Services Company: State of Alaska ~,~y ~ ~~'~ 2525 Dambell street, Suite 40o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATiN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD F-30 12-14AL7 12-15 BBUO-00014 AYKP-00079 B3S0-00049 PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE 03/17/10 03/18/10 - 03/18/10 i 1 1 1 1 1 17-11 17-OS J-23A 07-18 83S0-00053 B3S0-00052 BCUE-00010 BC72-00006 PRODUCTION PROFILE PRODUCTION PROFILE - MEM PRODUCTION PROFIL C .~ FL DETERMINATIOWPERF 03/30/10 03!29/10 04/14/10 04/17/10 1 1 1 1 1 1 1 1 LE 04/14/10 1 1 OM77/10 1 1 P2-31A 83S0-OOD46 _ CH EDIT PDC JUNK BASKET - py27/2g 1 C-15A AWJI-00069 MCNL - L 01/27/10 1 1 K-07E 82NJ-00054 MCNL 02/18/10 1 1 Ot-28A BAUJ-00004 MCNL 12/18/09 1 1 PLEASE ACKNOWLEDGE wt=r Ftar pv struw r eun ocrrroru.~~ .,.,e ...,~.. ~...., ~... BP Exploration (Alaska) Inc. Pelrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street. Sude 400 Anchorage, AK 99503-2935 • • r. n rl p} t F1 "' ~' - yCyy~a~ 0 ~t 2 to I t / ~ .. Y ~j ~ . STATE OF ALASKA ~-.:s-07 ED ALAZ OIL AND GAS CONSERVATION COMrmlON RECEIV REPORT OF SUNDRY WELL OPERATIONS FIB 0 2 Z007 1. Operations Performed: Alaska Oil & Gm: Gons. LiìmrmSEiOn o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re~ended Well o Alter Casing ~ 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. ~ Development' 0 Exploratory 202-122/ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20659-60-00 .; 7. KB Elevation (ft): 69.68' / 9. Well Name and Number: 12-14AL 1 ./ 8. Property Designation: 10. Field 1 Pool(s): ADL 028330- Prudhoe Bay Field 1 Prudhoe Bay Pool , 11. Present well condition summary Total depth: measured 12844 ( feet true vertical 9035 . feet Plugs (measured) None Effective depth: measured 12844 I feet Junk (measured) None true vertical 9035 ( 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' 9-518" 11471' 8875' 6870 4760 Production Liner 879' 7" 10614'-11493' 8348' - 8889' 7240 5410 Liner 249' 4-1/2" 11306' - 11555' 8775' - 8923' 8430 7500 Liner 1564' 2-7/8" 11320' - 12884' 8783' - 9035' 13450 13890 Scab Liner 7952' 7" 2643' - 10595' 2643' - 8336' 7240 5410 Perforation Depth MD (ft): 12072' - 12862' 5GMNED FEB 07 Z007 Perforation Depth TVD (ft): 9012' - 9035' 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 'S-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/ 110 Bbls of Class 'G' (618 cu ft / 528 sx, 1.17 Yield). Run 7" scab liner f/ 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 Daily Averaae Production or Iniection 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: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ 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 Doug Cismoski, 564-4303 306-281 Printed Name Terrie Hubble Title Technical Assistant .---r:: . ~ 0Z/DI!o7 Prepared By Name/Number: Signature {ß f\1\u. Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 llit'll-JUS tsN FFB 0 6 ZOD7 /rJ¡,- Submit Original Only 5> · Page 1 of 1 Digital Wellfile ~ell Events for SurfaceWell - 114 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 12-14ALl 12/07/2006 AwGRS 12-14ALl 12/05/2006 AWG_RS 12-14ALl 12/04/2006 AWGRS 12-14ALl 12/03/2006 AwGRS 12-14ALl 11/26/2006 AwGRS 12-14ALl 11/18/2006 Description SET BPV , PRE RIG T/I/O= 10/Vac/100. Temp= S1. 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.= S1. 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. AWGRS 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 S/I*** 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 41/2 XX-PLUG @ 11,284' SLM, (4 EACH 1/8" AND 4 EACH 3/16" EQ PORTS). *** CONTINUE TO 10/06/06 *** AWGRS 12-14AL1 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 AW£>RS 12-14ALl 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/HomelDefaul t.aspx 2/112007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 12/1 6/2006 1/4/2007 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 DECOMP 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 f/Below to 1,000 psi and Test to 3,500 psi f/Above, held for 10 minutes on Chart. 11 :00 - 13:30 2.50 WHSUR P DECOMP 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 B/D 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,OOOlbs. 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, NSCTtubing. 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: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 Spud Date: 7/5/1992 End: 1/4/2007 12/17/2006 12:30 - 16:00 3.50 PULL P DECOMP PIU 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 DECOMP 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 9 5/8" 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 wICBL, USIT,Corrosion Log t/700' 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 fl 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: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 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. PIU 9-5/8" Multi string Casing Cutter. 12/20/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN RIH wI 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 wI 20 bbl HiVis Spacer Pill in front of Brine @ 5 BPMI 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 wI 1.5K TO. 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' wI 65 RPM and 2-4K TO, 3.5 - 4 BPM wI 490 - 730 psi. 19:30 - 23:00 3.50 CLEAN P CLEAN Test LRHOS lines to rig to 3000 psi. Displace Drillstring wI 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 wI 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 wI 2200 psi. Let soak for 25 minutes. Continue pumping 20 bbls hot Diesel @ 3/4 BPM wI 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 retums through the 9-5/8" x 13-3/8" Annulus @ 1/2- 1 BPM wI 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 wI 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 retuming up the 4" DP x 9-5/8" Annulus @ 6 BPM wI 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 wI 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 wI 105K. UD Printed: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 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'. Centralizers 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: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 12/16/2006 1/4/2007 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 9-518" 47#, L-80, TC-II casing from 720' to 1648'. Tag casing stump. MU pups and XlO 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 TO @ 9 RPM. Work casing string onto casing stump and screw together with 10.5K TO @ 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 ft/sx) @ 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: 11812007 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: Rig Release: Rig Number: 12/1 6/2006 1/4/2007 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 xlo 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 9-5/8" 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 MIU 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: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 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, X/O 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, x/o 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 MIU top drive and establish parameters of 105,000# pick up weight, 104,000# slack off weight, 105,000# rotating weight at 60 RPM and 2000ft/lbs 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 X/O 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: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 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" RSP 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 up 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 ft/lbs 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 ft/lbs 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 it with float collar inserted in box end; 1 it 7", 26#, L-80 BTC-M casing; 1 it 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 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 ft/lbs. 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 ftlbs. 10:00 - 10:30 0.50 CASE P TIEB2 CIO 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 cIa 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 ; SIO 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. SIO 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. SIO 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 BIO 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,OOOlbs. 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 retumed 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: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 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 Visc 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 wI 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: Rig Name: 12-14 12-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 12/16/2006 1/4/2007 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 Visc 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 wI 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 RBP 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: 1/812007 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: Rig Release: Rig Number: Spud Date: 7/5/1992 End: 1/4/2007 12/16/2006 1/4/2007 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. 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'. 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. 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. POOH to 11,217'. Pump 20 bbl high viscosity sweep at 8 bpm and 2250 psi. CBU and sweep brought rubber to surface. POOH with RCJB from 11,217' to 408'. Rack back 4" HT-38 drill pipe. POOH from 408' with RCJB BHA. Stand back 4 stands of 4-3/4" drill collars. UD RCJB. No recovery in RCJB. 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'. CLEAN RIH with Baker GS Spear BHA assembly on 4" HT-38 drill pipe from derrick to 11,132'. 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 12/30/2006 13:00 - 18:30 5.50 CLEAN P 18:30 - 19:00 0.50 CLEAN P CLEAN 19:00 - 00:00 5.00 CLEAN P CLEAN 12/31/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN 01 :00 - 02:00 1.00 CLEAN P CLEAN 02:00 - 07:00 5.00 CLEAN P CLEAN 07:00 - 07:30 0.50 CLEAN P CLEAN 07:30 - 08:00 0.50 CLEAN P CLEAN 08:00 - 12:30 4.50 CLEAN P 12:30 - 13:30 1.00 CLEAN P Printed: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 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'. PIU 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 % retums 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, x/o 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 RIU 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 115 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 RIU 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 P I U and RIH with 8' Pump Bailer with Equalizer Prong to 11,309'. POOH. One Gallon of Sand and pieces of rubber Printed: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 Spud Date: 7/5/1992 End: 1/4/2007 1/1/2007 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 PIU Baker Hydraulic GS Spear BHA. RIH wI BHA. POOH, BIO and UD BHA. 09:30 - 10:30 1.00 CLEAN N CLEAN RIH wI 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 0.50 RUNCO RUNCMP PJSM on Running Tbg Completion. 16:30 - 00:00 7.50 RUNCO 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 Tuming All Connections. 1/3/2007 00:00 - 12:00 12.00 RUNCO 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 RUNCMP M/U Joints #270 and #271. M/U Circulating Head to Jt #271. PIU Wt = 167,000 Ibs, SIO Wt = 119,000 Ibs. Establish Pump Rate at 2.0 bpm and 60 psi. SIO 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'. PIU 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'. PIU and make another -112 tum. SIO, begin taking wt at 11237' and stack 15,000 Ibs at 11238'. 13:00 - 14:00 1.00 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 RUNCMP M I U FMC Tbg Hanger and TC-II Landing Joint to string. SIO 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 RUNCMP PJSM wI Rig Crew and Vac Trucks on Pumping Seawater Displacement and Corrosion Inhibitor. 15:00 - 15:30 0.50 RUNCMP With Inner Annulus Valve Thawed out able to confirm Hanger at proper depth. RILDS. Printed: 1/812007 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: Rig Release: Rig Number: 12/16/2006 1/4/2007 Spud Date: 7/5/1992 End: 1/4/2007 Pump 180 bbls of 120 degree SW followed by 300 bbls of 120 degree SW w/ corrosion inhibitor at 3 bpm and 290 psi. Partial returns at surface seen after pumping 245 bbls. 18:00 - 19:00 1.00 RUNCMP RID Circ Equipment, Drop Ball and Rod, UD Landing Jt, Linue Up and Fill Tubing. 19:00 - 20:30 1.50 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. Bled off Annulus Pressure and Tubing Pressure Followed Annulus Pressure to 0 psi. It is Believed DCK Shear Valve Opened Prematurely. 20:30 - 21 :30 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 Retums Observed to Confirm DCK Valve Communication for Freeze Protecting Well 21 :30 - 22:30 RUNCMP Lined up and Retested Annulus Side for 30 Charted Minutes at 3,500 psi, Tubing Side Tracked Annulus Pressures-CMIT. GOOD Test 22:30 - 00:00 1.50 RUNCMP Set TWC. Pressure Test to 1000 psi from below and 3500 psi above. Blow Down Lines and Drain BOP Stack. 1/4/2007 00:00 - 01 :30 1.50 BOPSU P WHDTRE NID BOPE and Set Back on pedestal. 01 :30 - 03:00 1.50 WHSUR P WHDTRE NIU Adapter Flange. 03:00 - 03:30 0.50 WHSUR P WHDTRE Pressure Test Hanger and Neck Seal to 5,000 psi for 30 minutes. Good Test. 03:30 - 04:00 0.50 WHSUR P WHDTRE NIU Production Tree. 04:00 - 06:00 2.00 WHSUR N HMAN WHDTRE N/D Adapter Flange Re-Orient, FMC Initial Orientation Incorrect. NIU Adapter and Retest Void and Neck Seals to 5,000 psi for 30 minutes. 06:00 - 08:00 2.00 WHSUR P WHDTRE Fill Tree wI Diesel and Test to 5,000 psi for 30 minutes - charted. Good Test. 08:00 - 08:30 0.50 WHSUR P WHDTRE PI U DSM Lubricator, Pull TWC 08:30 - 10:30 2.00 WHSUR P WHDTRE R / 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. 10:30 - 12:00 1.50 WHSUR P WHDTRE Allow Freeze Protect to U-Tube. 12:00 - 12:30 0.50 WHSUR N WHDTRE Wait on DSM to arrive. 12:30 - 13:30 1.00 WHSUR P WHDTRE Set BPV in well head and PT with Little Red to 1000 psi. Hold for 5 mins. Bleed down Pressure. Rig Down Little Red. 13:30 - 14:00 0.50 WHSUR P WHDTRE Secure Well and Cellar, UD DSM Lubricator, Install all Gauges. Rig Released at 14:00 hrs. Printed: 1/8/2007 6:53:02 AM . . WELL LOG TRANS MITT AL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Librarian 333 West 7th A venue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 12-14 Ll Ll PBl, 14-17A, 14-30A, 15-38A PBI. - - The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 12-14A LI Ll PBl: ,QOd. -tdd ~ ¡4¿¡S-( Digital Log Images: 50-029-20659-60, 71 I CD Rom 14-17A: UIC- c903-DC¡&t /'-/'-/'115 Digital Log Images: 50-029-20562-01 14-30A: doS--Oq~1 t1: /'-./(../5-0 Digital Log Images: 50-029-20679-01 1 CD Rom I CD Rom 15-38A_PBl: ;;'03-01(0 tL fL/LjLIC¡ Digital Log Images: 50-029-20679-01 I CD Rom SCANNEID FEB 0 1 2007 :> Scblumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well MPS-10A 15-08CL 1 Z-12 L3-11 AGI-10A GNI-02A GNI-02A 12-18 NGI-07 A DS 12-14AL 1 01-23 WGI-09 Job# 11076475 10942196 11513657 11533392 11485869 11485873 11485874 N/A 11212892 11540230 11549351 11486172 ()()8 -Idd Log Description CH EDIT SCMT (PDC-GR) CH EDIT JEWELRY (PDC-GR) RST RST USIT USIT MDT USIT USIT CORROSION & CBL USIT US IT Date 10/17/05 03/01/05 12/06/06 12/31/06 11/09/06 11/15/06 12/03/06 11/17/06 10/13/06 12/18/06 12/16/06 12/03/06 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: SCANNED JAN 2 3 2007 01/22/2007 NO.4112 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color CD 1 1 1 1 (' 1 1 1 1 1 1 1 1 1 1 Alaska Data & 2525 Gambell Stl Ei, Anchorage, AK 99503-2838 ATTN: Beth Received by: W-29i RWO (Sundry # 306-304) and 12-14AL 1 RWO (Sundry... ?Æ7-12-<-- Subject: W-29i RWO (Sundry # 306-304) and 12-14AL 1 RWO (Sundry # 306-281 and 306-289) From: "Reem, David C" <ReemDC@BP.com> Date: Thu, 21 Dee 2006 08:52:40 -0900 To: .WintonAubert <winton_aubert@admirt.statè.äk.us> CC: "McLellan, Bryan J"<Bryan.McLeUa.n@BP.com> Winton, as you requested, here is a synapsis of the reason for scope changes on the two subject wells: W-29i: This wellbore 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 wellbore was logged in the 9-5/8" with a USIT 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) ,-.~" J:i. !uM:<";r) \,,<~,~o:·~ß:~17J~~-) ? 1 of 1 12/21/20069:03 AM _C<. . . FRANK H. MURKOWSKI, GOVERNOR ~ AI~SIiA. OIL AlO) GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 12-14AL1 Sundry Number: 306-281 SCANNED AUG 2 S 200B Dear Mr. Cismoski: 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~YOfAUguSt, 2006 Enc!. r9ö'd -t g'd ~è~~~ .~ '\~ ~ ~1/~~%OFAlASKA ~ß. Al~_ Oil AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No 9. Property Designation: 110. KB Elevation (ft): ADL 028330 69.68' 12.. ...) Total Depth MD (ft): 12844 Casino Structural Conductor Surface Intermediate Production Liner o Suspend / 181 Repair Well 181 Pull Tubing AUG 1 6 2006 Comrmssian o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver Alaska Oil & Gas Cons. o Time ExtensionAnchorage o Re-Enter Suspended Well o Other 4. Current Well Class: / 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 202-122 // 6. API Number: 50-029-20659-60-00 8. Well Name and Number: ~. 12-14AL1 / < . .... ". .< IIV.... I Total Depth TVD (ft):IEffective Depth MD (ft): 9035 I 12844 Lenoth Size MD 11. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool . . . '. Effective Depth TVD (ft): Plugs (measured): Junk (measured): ./ 9035 None None "TVD Burst CollaDse 80' 20" 80' 80' 2644' 13-3/8" 2644' 2644' 4930 2670 11471 ' 9-5/8" 11471' 8875' 6870 4760 879' 7" 10614' - 11493' 8348' - 8889' 7240 5410 249' 4-112" 11306' - 11555' 8775' - 8923' 8430 7500 1564' 2-7/8" 11320' - 12884' 8783' - 9035' 13450 13890 Liner Liner Perforation Depth MD¡(ft): I Perforation Depth TVD (ft): I 12072' - 1286~:/ 9012' - 9035' Packers and SSSVType: 4-112" x 7" Baker 'S-3' packer 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencina Ocerations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Doug Cismoski Title Drilling Engineer Signature ~ hL ~..<J~ ~ . Phone 564-4303 tY October ( ~06 DateK Tubing Size: 4-112", 12.6# Tubing MD (ft): 11309' / Tubing Grade: ,/ 13Cr80 I Packers and SSSV MD (ft): 11254' 14. Well Class after proposed work: / o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Date Contact Doug Cismoski, 564-4303 Bryan McLeìlan, 564-5516 Prepared By Name/Number: Terrie Hubble, 564-4628 Commission Use On Iv . I Sundry Number: ¿f') (p. ¡;.A I Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance Other: T .e.-S+ }50 P f to 31:,;00 'f!1Î' Subsequent Form Required: to' Approved BV: Form 10-403 Revised 06/2006 (lJ0 l\- . t . -A1 V \../ ORIG\NAL RBDMS BFl AUG .2 8 2006 éQMMISSIONËR '--""'" APPROVED BY THE COMMISSION Date ~is; Oh rbmiyf! Duplicate . . 12-14AL 1 Rig Workover c pe of Work: Pull 4- W' 13Cr completion, cut and pull 9-5/8" casing above the surface casing shoe,.run " . .' I ' cement annulus to surface, run 4-%" Chrome completion. /' n. ~. C4~~ 4+tÒ \.d6* :::::MASP: 247 Well Ty ,~ : Producer EstimatedStart Date: October, 2006 Pre-ria prep work: Pre-Rig: 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" tubin 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 3'500 ~si. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 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)18" 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 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 = WæLHEAD =, ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = FMC GEN 2 FMC OTIS 76' . 12-14AL 1 ~NOTES: CHROME4-1/2"TBG. EXISTING COMPLETION 3700' 94 @ 12027' 11461' 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.205" @ 11327' 2-7/8" HES XN NIPPLE TOP OF 7" LNR I 10614' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I I TOP OF 7" LNR , 14-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I ¡TOP OF 4-1/2" LNR I 19-5/8" CSG, 47#, L-80, ID = 8.681" , 11471' 17" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" PERFORA TlON SUMMARY REF LOG: GRlCCL ANGLEAT TOP ÆRF: 75 @ 11710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 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 33/8" 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 33/8" 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 (12ft4f'", L 1) 3-3/8" 4 12072 - 12~8f I 0 08/20/02 DATE 1981 11/12/98 08/21/02 08/24/02 09/29/02 03/22/03 11493' 2024' -14-1/2" HES X NIP, ID = 3.813" I ST MD lVD 1 3349 3349 2 5455 5192 3 7471 6402 4 8515 7014 5 9392 7586 6 10486 8272 7 11099 8646 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 2 MMG DOME RK 48 MMG DOME RK 53 MMG DMY RK 53 MMG DOME RK 49 MMG DMY RK 54 MMG DMY RK 52 KBG2LS SO INT 05/17/04 08/02/02 08/02102 08/21/05 PORT DA TE 16 05/17/04 16 05/17/04 o 16 o o 20 11254' -14-1/2" X 7" BAKER S-3 A<R I 11287' -14-1/2" HES X NIP, ID = 3.813" I 11309' -14-1/2" WLEG , 11320' --TIVV DEPLOYMENT SLV, ID = 2.375" 11328' -f2-7/8" HES XN NIP, ID = 2.205" 1 H ELMD IT NOT LOGGED I MILL OUT WINDOW 11555' - 11562' 11555' HMECHANICAL FLOW-BY WHIPSTOCK I --2-7/8" 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" .. .. , I , -1 BAKER MODEL "D" A<R 14005' -1PBTD I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" -1 14047' REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (12-14A) JDM/KK CTD SIDETRACK (12-14AL 1) DTRlTP GL V C/O BMITP WAIVER SAFETY NOTE JMP/KK WAIVER SAFETY NOTE DATE 05/17/04 08/16/05 08/21/05 10/28/05 05/31/06 REV BY COMMENTS JLJ/KAK GL V C/O KSBITLH GL V C/O KSBITLH GL V C/O ElL/PAG WAIVER SFTY NOTE REVISED DTM WELLHEAD CORRECTION PRUDHOE BA Y UNIT WELL: 12-14AL 1 ÆRMIT No: "202122 API No: 50-029-20659-60 SEe 18, T10N, R15E BP Exploration (Alaska) 1REE = FMC GEN 2 . 12-14AL 1 ~NOTES: CHROME4-1/2"TBG. I W~LHEAD =A FMC ACTUATOR = KB. 8.EV = 76' PROPOSED BF. 8.EV = ~ KOP= 3700' Max Angle = 94 @ 12027' I I - f----1 2200' -f4-1/2" HES X NIP, ID = 3.813" I Datum MD = 11461 ' DatumlVD= 8800' SS I 9-5/8" CSG, 40#, L-80, ID = 8.835" I 11471' -- GAS LIFT MANDRELS ~ ST MD lVD 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 I TOP OF 7" LNR I 10614' I . I I 11150' -f4-1/2" HES X NIP, ID = 3.813" I III 11160' Î4-1/2" x 7" BAKER S-3 PKR I I . 11214' -14-1/2" HES X NIP, ID=3.813" I 4-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 11224' I ~ UNIQUE MACHINE OVERSHOT I ;; 11224 ' I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 11258' I 11254' .,4-1/2" x 7" BAKER S-3 PKR , TOPOF7" LNR H 11258' I . . 11287' H4-1/2" HES X NIP, ID = 3.813" I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I 11309' 1---_ 11309' H4-1/2" WLEG I I TOP OF 4-112" LNR I 11309' . I,: 11IIII I 11320' -1TIW DEA...OYMENT SLY, ID - 2.375" I I 11328' -12-7/8" HES XN NIP, ID = 2.205" I I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 11471' ~ 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 11555' HMECHANICAL FLOW-BY WHIPSTOCK I Note: Refer to Production DB for historical perf data Ilh~ ~ 1204T SIZE SPF INTERVAL 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 .......(" 3-318" 4 11810 -12030 0 11/10/98 " 3 3/8" 4 12190 - 12265 0 11/10/98 " 12844' 2-7/8" PRE-DRLD LNR, 6.16#, I " 33/8" 4 12335 - 12355 0 11/10/98 " L-80, .0058 bpf, ID = 2.440" " " ~,,~ " " 3318" 4 12435 - 12455 0 11/10/98 " " I'="" ...... ~ " " 33/8" 4 12855 - 12915 0 11/10/98 [ " " " " 33/8" 4 12965 - 13015 0 11/10/98 " " , [ " , 3 3/8" 4 13250 - 13320 0 11/10/98 " , 3 3/8" 4 13440 - 13500 0 11/10/98 I 11610' H BAKER MODB.. "D" PKR I 33/8" 4 13725 - 13750 0 11/10/98 ., 3-3/8" 4 13895 - 13995 0 11/10/98 14005' HPBTD I PREDRILLED (12-14AL 1) 3- 3/8" 4 12072 - 12884 0 08/20/02 '\ 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 14047' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNrT 1981 ORIGINAL COM PLETION 05/17/04 JLJ/KAK GL V C/O W8.L: 12-14AL 1 11/12/98 SIDETRACK (12.14A) 08/16/05 KSBITLH GL V C/O ÆRMrT No: "202122 08/21/02 JDM/KK CTD SIDETRACK (12-14AL 1) 08/21/05 KSBfTLH GL V C/O API No: 50-029-20659-60 08/24/02 DTRITP GL V C/O 10/28/05 EZLlPAG WArvER SFTY NOTE REVISED SEC 18, T10N, R15E 09/29/02 BMlTP WArvER SAFETY NOTE 05/31/06 DTM W8.LHEAD CORRECTION 03/22/03 JMP/KK WArvER SAFETY NOTE 08/08/06 BJM PROPOSED RWO BP Exploration (Alas ka) . . WELL LOG TRANSMITTAL 13:55} I 3 5!:J~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950] October 14,2003 RE: MWD Formation Evaluation Logs 12-14A Ll & 12-14A Ll PBl, AK-MW-22138 12-14A Ll+PBl: Digital Log Images: 50-029-20659-60,61 ;) 0 [) - I'd Ä 1 CD Rom 4 1 tD eO~1\ 1~'I4-ALl PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: (}) aa DCe Signed er-~ " e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs _ Inserts\Microfilm __ Marker.doc 12-14 (PTD #2021220) Classified as Problem Well l z.- '4 L ( ) ) Su bject: J..2::1'2r (PTD #2021220) Classified as Problem W ell,.ø{).;"..', ' \ ~ 'Y From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> ('}iJ Date: Sun, 31 Ju12005 18:15:44 -0800 To: "Gerik, Bob G" <GerikBG@BP.com>, "GPB, FSl/SIP/STP Area Mgr" <GPBFSl TL@BP.com>, "OPB, FSl DS Ops Lead" <GPBFSIDSOpsLead@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "OPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC JiIll Regg (E-mail)" <jim_regg@adtnin.state.ak.lls>, "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL& Completion 'Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB,' FSI DS12 Operator" <GPBFSIDS120perator@BP.com> , cc: "NSU, ADWWell Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com> .,....-0-' I >J:4 'f OA All, \ 7-\4- u ( Well )..2::'T4 (PTO #2021220) has been found to have sustained casing pressure on the IA. The TIO's on 07/29/05 were 1920/2060/1420. The well is currently waivered for IAxOA communication and failed a TIFL on 7/29/05. The plan forward for this well is as follows: 1. OHO: TIFL - FAILED 2. SL: Change out OGL V 3. OHD: Re-TIFL v The well has been classified as a Problem well. Please call if you have any questions. «12-14AL 1.pdf» Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907 -659-5102 907 -659-5100 #1923 pgr r~ q 70(1) S(;ANNED l~UG ~,! ",-, ., Content-Description: 12-14AL1.pdf 12-14AL1.pdf Content-Type: application/octet-stream Content-Encoding: base64 -r~r '1 ~S5~ l qzo p;/ !JJyP ~~(p ]:A r, 2Œ>o PSI 6 C¿70fs~ 30% r(~/~S ?t~"eJ~ pres~s cJ/~ cdl<9u)-t<t's t-'-\. Cv L¡Clz~ SK'1[ 'lIz/os- OA ~420 f~ 63ßof~- 2G:,Á\ '--7 k)õ-te :' 2oc/J f -:, ll\.~~~ ( .g P ') Wet( ~Ì' pfeS5W€- woLt.Œd t,'é' 3 7 ~o (,-Ç" ~~:p~-( p 1 of 1 8/2/2005 1 :45 PM lREE = WELLHE'A D = ACTUATOR = "kS. '"EL"i=V '~.." 'BF. EiEV =. KOP= IVIax A n~le = D3turn MD = D3turn TVD = FMC GEN 2 rv1CEVOY OTIS "7f/ 3700' 94 ~ 12027' 11461' 8800' SS ) 12-14AL 1 SAFETY NOTES: CHROME 7" LNRANJ 4-1/2" TOO. ***IA X OA COMM. OPERATING PRESSURE OFTHE 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (09130102 WAIVER) *** I I 2024' 1-14-1/2" HES X NIP, 10 = 3.813" I GAS LFT I'v\4.NDRELS ~ ST MD TVD DEV TYÆ VLV LATCH PORT DA.TE 1 3349 3349 2 MIVIG DOME RK 16 05/17/04 2 5455 5192 48 MIVIG DOME RK 16 05/17/04 3 7471 6402 53 MIVIG (]IJY RK 0 4 8515 7013 53 MIVIG DOME RK 16 05/17/04 5 9392 7586 49 MIVIG (]IJY RK 0 08/02/02 6 10486 8272 54 MIVIG (]IJY RK 0 08/02/02 7 11099 8646 52 KBG2LS SO INT 20 05/17/04 113-3/8" CSG, 72#, L-80, 10 = 12.347" H 2196' ~ Min irn urn ID = 2.205" @ 11327' 2-7/8" HES XN NIPPLE ITOP OF 7" LNR 1-1 10614' 17" LNR 26#, L-80, .0383 bpf, 10 = 6.276" 1--1 11258' ITOPOF 7" LNR l-i 11258' 14-1/2" 1BG, 12.6#, 13-CR .0152 bpf, 10= 3.958" 1-1 ITOP OF 4-1/2" LNR 1-1 11309' 11309' l 'I II g " &. / I 11254' 1--19-5/8" BAKER 5-3 A<R I I 11287' 1-14-1/2" HES X NIP, 10= 3.813" I ~ i 11309' 1--14-1/2" WLEG I I 11320' 1-1 TIW DEPL OY MENf SL V, 10 = 2.375" I 11328' 1-12-7/8" HES XN NIP, 10 = 2.205" 1 ... I 1-I8.MDTTNOT LOGGED I 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 11471' -...t 17" LNR, 26#, 13-CR-80, .0383 bpf, 10= 6.276" 1-1 11493' ÆRFORA 1l0N SUVlI'v\4. RY REF LOG: GR/CCL ANGLEATTOPPERF:75@ 11710' Note: Refer to Production DB for historical perf data SIZE SFf' INTERVAL Opn/Sqz DATE 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 33/8" 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 33/8" 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 PREDRlLLED (12-14AL 1) 3-3/8" 4 12072 - 12884 0 08/20/02 DA.TE 1981 11/12/98 08121/02 08124/02 09/29/02 03122/03 I MLLOUTWlNDOW / / 11555'-11562' I ~ I 11555' HMECHANIG'\ L FLOW-BY W~PsrOCK I IIh~ ~047' H2-7/W' LNR, 6.16#, L-80, .0058 bpf, ID = 2.440"1 " 1 12844' 1--12-7/8" PRE-DRLDLNR, 6.16#, I " I L-80,.0058bpf,ID=2.440" " ~ß~~ .-, I 11610' 1--1 BAKER rvoDEL "0" PKR ~I 14005' HPBTD I 14-1/2" LNR, 12.6#, L-80, ,0152 bpf, D = 3.958" H 14047 " " .- I , DATE REV BY COMrvENfS 05/17/04 JLJIKAK GLV C/O REV BY COMrvENiS ORIGINAL COMPLErION SIDETRACK (12-14A) JDNllKK CTD SIDErRACK(12-14AL 1) DTRlTP GLV 00 BM/1P WAIVER SA FETY NOTE JrvP/KK WAIVER SA FETY NOTE PRUDHOEBAY UNIT \NELL: 12-14AL 1 PERMIT No: 202122 API No: 50-029-20659-60 sæ 18, T10N, R15E BP Exploration (Alaska) AI»"~~ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021220 Well Name/No. PRUDHOE BAY UNIT 12-14AL 1 Operator BP EXPLORATION (ALASKA) INC A?~~.l;o-!2~-2~-6~ It MD 12884 /' TVD 9035 ,; Completion Date 8/21/2002 ,.- Completion Status 1-01L Current Status 1-01L UIC N --~-----~-- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ç:;:;Jç.---- ~--~~----- ---~----~---"'-'---- DATA INFORMATION Types Electric or Other Logs Run: MWD, DGR, SROP, EWR Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~ Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ Directional Survey ~t Directional Survey ,...ED---D 1~ lIS VorifiGatiClII- Rpt LIS Verification ß'D ~D ~ (.vJ ~"l {fo tt... Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ---~---- 1 11801 12884 Open 9/13/2002 1 11548 12136 Open 9/13/2002 PB1 11525 12091 ~/17/2003 PB1 11525 12091 C~3/17/2003 PB1 11525 12840 ~17/2003 11548 12136 ~3/2002 PB1 11525 12840 ~17/2003 116J2 Lib VgrifiGatien ~ '-C {~ý'L. Directional Survey LIS Verification ~ An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 6/11/2002. Directional Survey 11801 12884 Open 9/13/2002 A Directional Survey Log is required to be submitted, This record automatically created from Permit to Drill Module on: 6/11/2002. ---------------~-- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Permit to Drill 2021220 MD 12884 TVD 9035 ADDITIONAL INFORMATION ye Well Cored? Chips Received? - ¥ / ~~ - Y IN Analysis Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. PRUDHOE BAY UNIT 12-14AL 1 Operator BP EXPLORATION (ALASKA) INC Completion Date 8/21/2002 Completion Status 1.01L Current Status 1-01L Daily History Received? &/N ÐN Formation Tops ~ .¡ Date: API No. 50-029-20659-60-00 UIC N ---------~_._,'-~_._- ".......,.,. ----~--~---~----_._~-----_._- 1 C\~~'" '-4, ( ( ê¥oòJ-ldd / I i?\33 WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska March 11, 2003 RE: MWD FonnationEvaluationLogs 12-14ALl PB1, AK-MW-22138 1 LDWG formatted Disc with verification listing. API#: 50-029-20659-71 , . ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Date: ~~ ! " ì Si . : .:e (~ WPf?v-- RECEIVED MAR 1 7 2003 Alaska on & Gas Cons. Com~n Anchorage ( .~ Cd--Id;). / I (¿),3d WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 13, 2003 RE: MWDFonnationEvaluationLogs 12-14ALl, AK-MW-22138 1 LDWG fonnatted Disc with verification listing. API#: 50-029-20659-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ~,\ ".- ". U . ') S~: . £0.. ~ RECEIVED MAR 1 ~ 2003 Ala.a Oii & Gas f\A- Andl;; Co~n ( (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 10/16/02; Put on Production 1. Status of Well BOil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface i'''''''' \,.\-II<'''~ 527' NSL, 717' WEL, SEC. 18, T10N, R15E, UM ~ L<X:AÌ1ONIl At top of productive interval ; y~ .. 3107' SNL, 3805' EWL, SEC. 20, T10N, R15E, UM i Su~ .'"f i 4~~1~~~~~~~03' EWL, SEC. 20, T10N, R15E, UM l~:~~:J 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 69.68' ADL 028330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/13/2002 8/20/2002 8/21/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12884 9035 FT 12884 9035 FT 0 Yes 1m No 22. Type Electric or Other Logs Run MWD, DGR, SROP, EWR 2~. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" Conductor Weld Surface 80' 30" 300sx Permafrost II 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" 500sxClass'G' 7" 26# L-80/13Cr80 10614' 11493' 8-1/2" 270 sx Class 'G' 4-1/2" 12.6# L-80 11306' 11555' 6" 340 sx Class 'G' 2-7/8" 6.16# L-80 11320' 12884' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and 25. TUSING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) 2-7/8" Slotted Liner 4-1/2", 12.6#, 13CR-80 11309' Classification of Service Well 7. Permit Number 202-122 8. API Number 50- 029-20659-60 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-14AL 1 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2024' MD 1900' (Approx.) MD TVD TVD MD AMOUNT PULLED PACKER SET (MD) 11254' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 115551 Flow-By Whipstock 2000' Freeze Protected with MeOH 12072' - 12862' 9012' - 9035' 27. Date First Production September 24,2002 Date of Test Hours Tested 10/13/2002 6.2 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Injection, Shut-In PRODUCTION FOR OIL -BSL TEST PERIOD 827 WATER-BsL 3,181 W ATER-BsL GAs-McF 4,822 GAs-McF CALCULATED 24-HoUR RATE OIL-BsL GAS-OIL RATIO 5,828 CHOKE SIZE 83.18 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submil core c ~~s. ;~'. No core samples were taken. OCT 2 I E € E I V E D '~1 nMS BF L Form 10-407 Rev. 07-01-80 OCT 1 6 2002 _,œl~.!w,.GonS. Oalllmtsslcm øIUlJQI'IØ Submit In Duplicate " ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 11486' 8884' Shublik 11535' 8914' Sadlerochit 11719' 8983' Sadlerochit 11980' 9016' Sadlerochit 12835' 9035' 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin~ is true and correct to the best of my knowledge Signed TerrieHubble/(O~.~ Title Technical Assistant Date JV./0"o~ 12-14AL 1 202-122 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Alistair Sherwood, 564-4378 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well a¡a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 527' NSL, 717' WEL, SEC. 18, T10N, R15E, UM At top of productive interval 3107' SNL, 3805' EWL, SEC. 20, T10N, R15E, UM At total depth 4113' SNL, 3503' EWL, SEC. 20, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 69.68' ADL 028330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/13/2002 J 8/20/2002' 8/21/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12884 9035 FT 12884 9035 FT 0 Yes a¡a No 22. Type Electric or Other Logs Run MWD, DGR, SROP, EWR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" Conductor Weld Surface 80' 30" 300sx Permafrost II 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 sxClass 'G' 7" 26# L-80/13CrBO 10614' 11493' 8-1/2" 270 sx Class 'G' 4-1/2" 12.6# L-80 11306' 11555' 6" 340 sx Class 'G' 2-7/8" 6.16# L-80 11320' 12884' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and 25. TUSING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) 2-7/8" Slotted Liner 4-1/2", 12.6#, 13CR-80 11309' Classification of Service Well ï.>,..; :' , ~j-~,?~?,- ; 7. Permit Number 202-122 8. API Number 50- 029-20659-60 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-14AL 1 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2024' MD 1900' (Approx.) Vw~~ 115".s-:S-/.n?ß 8?ZI:/ 71/'1::> AMOUNT PULLED PACKER SET (MD) 11254' MD TVD MD TVD 12072' - 12862' 9012' - 9035' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11555' Flow-By Whipstock 2000' Freeze Protected with MeOH 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR OIL-BSL TEST PERIOD GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BsL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit Ue'E I'V E D No core samples were taken. 28. RBDMS 8Ft n 2n:r SEP 2 5' 2002 Alaska Oft & Gas Cons. CommisSion Anchorage ~p Form 10-407 Rev. 07-01-80 ORt INAL Submit In Duplicate ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 11486' 8884' Shublik 11535' 8914' Sadlerochit 11719' 8983' Sadlerochit 11980' 9016' Sadlerochit 12835' 9035' RI€IIVED SEP 2 5 2002 AI88kI OI,a GuOons. GomIDiSSIon AncI10mgÐ 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge r-l ~ Signed son~tewm~JJ.~ 12-14AL 1 202-122 Well Number Permit No. / Approval No. Title Technical Assistant Date OCt ~ z. r:;' '-0 Z- Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Alistair Sherwood, 564-4378 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 (OF, 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 OR'G\ f\\ L ( 12-14AL 1 Prudhoe Bay Unit 50-029-20659-60 202-122 Rig Accept: 08/12/02 Rig Spud: 08/13/02 Rig Release: 08/21/02 Nordic #1 PRE-RIG WORK 07/21/02 PPPOT-T PASSED TO 5000 PSI; MITOA PASSED TO 1000 PSI; WV & MV PT FAILED, CALLED VALVE SHOP TO SERVICE AND RE- TEST VALVES (PRE-CTD). 07/31/02 SET X-LOCK TOP LOADER PLUG IN TT. 08/01/02 SET X-LOCK TOPLOADER TTP IN X-NIPPLE AT 11287' MD. DUMMY OFF STATIONS 6,4,2 AND 1. MITIA.. TROUBLE SETTING PLUG DUE TO HEAVY PARRAFINS. 08/02/02 SET X-LOCK TOP LOADER (30" OAL) TT PLUG ( W 10 EQ PLUG), DUMMY OFF GLM'S , MITIA. 08/03/02 LOAD lA, SET DGLV IN STATION # 6.( DID NOT PASS TEST) SET PRONG IN TOP LOAD PLUG BODY. TAGGED WELL. INFORMED DSO OF WELL STATUS, TURN WELL OVER TO DSO. PRONG IS 72" LNG, PLUG BODY IS 28" LONG. SIP 1750 PSI. MIT IA. COMBO MIT IA X TUBING. GOOD MIT ON TBG AND lA, ATTEMPTING TO PULL PRONG FROM PLUG, 08/04/02 PULL BENT LATCH FROM STATION 6 AND SET NEW DGLV. ATTEMPT TO PULL TT PLUG. 08/05/02 PULL TT PLUG @ 11 ,277'SLM. UNABLE TO GET DOWN HOLE WITH PRE-PKR DRIFT. SET DOWN @ 11,310'SLM W/3.78 CENT. TURN WELL OVER TO DSO, WELL LEFT SHUT IN. WILL CO NT. LATER WITH BRUSH AND FLUSH. PUMP 40 BBLS DIESEL- XYLENE 190 BBLS 1950 CRUDE TO ASSIST HES WI BRUSH- N-FLUSH TO REMOVE ASPHAL TINES IN TBNG. BRUSH AND FLUSH TBG DOWN TO 11,706 WITH 4.5" BRUSH AND 2.9" GR, STOPPED DUE TO DEV. RIH WITH 3.75" CENT, 2' X 1 7/8" STEM, 3.80" CENT TO 11,622' SLM AND WORKED DOWN TO 11,656' SLM , DEVIATION AT THIS DEPTH 68 DEGREES.RIH WITH 21' X 3.65" DUMMY WHIPSTOCK TO 11,512 SLM. RDMO, NOTIFY DSO OF WELL STATUS. BAKER PACKER SETTING DEPTH = 11,560'. WHIPSTOCK SETTING DEPTH = 11,520'. 08/06/02 RAN A 3.625" X 21' DUMMY WHIPSTOCK AND E-LlNE JARS IN HOLE. MADE 3 ATTEMPTS TO REACH MAX DEPTH. DEPTH OF WHIPSTOCK BOTTOM FOR THE 3 ATTEMPTS: 11491 111492' 111490'. THE DEPTH WAS REFERENCED TO THE TUBING TALLY. 08/07/02 RIH WITH WFD 2 7/8" MHA & 3.65" DMY WHPSTCK, OAL=24.91'. DRIFT TBGILNR TO 11,680' CTMD, POOH. RIH WITH MEMORY GR/CCL. LOG FROM 11050' TO 12100'. FLAG PIPE. LOG SHOWS 2' PIP COLLAR AT 11,500' CORRECTED DEPTH. GR IS TOTALLY SATURATED AND NOT USABLE FOR TIE-IN PURPOSES. POOH. MU BAKER MOD. D PACKER WI CHECK VALVE. PACKER STROKED DURING PT OF LUBRICATOR, LOST SET OF SLIPS DOWNHOLE. STAND BACK UNIT, WIRELlNE RAN A WIRE BRUSH AND 2 1/4" GAUGE RING WORKING THROUGH THE GLM'S TO 11680' WLM. ( 12-14AL 1, Coil Tubing Drilling, Pre-Rig Work Page 2 08/08/02 STANDING BY WHILE WIRELlNE IS ATTEMPTING TO CHASE BROKEN SLIPS DOWN HOLE. GOT HUNG UP AT 10,482' WLM, JUST BELOW THE #6 GLM WITH WIRELlNE TOOLS. DROP CUTTER BAR AND RECOVERED ALL WIRE. RD CTU AND GO ON STAND-BY. 08/09/02 MU BAKER 2.25" FISHING TOOLS W/4" G-SPEAR. RIH AND LATCH FISH AT 10456' CTMD. BEAT 14 UP JAR LICKS TO FREE FISH. POOH. RECOVERED COMPLETE FISH. APPEARS TOOLS WERE HUNG AT THE 3.805" GAGE RING. RU SLlCKLlNE TO BRUSH HOLE. WIRELlNE RUNNING IN HOLE WITH 4.5" WIRE BRUSH & 2.25" GAGE RING WORKING THROUGH GLM'S WHILE PUMPING FILTERED SEAWATER WITH CTU PUMP. 08/10/02 WIRELlNE DRIFTED WELL WITH 4.5" WIRE BRUSH & 2.25" GAGE RING THEN 3.80" GAGE WITH A 4.5" WIRE BRUSH BELOW GAGE WHILE PUMPING FILTERED SEAWATER WITH COIL UNIT. WORKED THROUGH GLM'S TO 11680' MD ATTEMPTING TO CHASE SLIP SEGMENTS DOWN HOLE. TUBING CLEAR, RIG DOWN WIRELlNE. RIH WITH MEMORY GRlCCL. LOG FROM 11050' TO 11750' CTMD. FLAG PIPE. POOH. RIH WITH 4 1/2" BAKER MOD D PACKER W/ FLAPPER CHECK. SET PACKER (TOP) AT 11610' ELMD. POOH. FREEZE PROTECT TBG TO 2500' & FLOW LINE WITH 50/50 MEOH. PRESSURE TEST PKR FROM TOP 530 PSI. RIG DOWN. JOB COMPLETED. 08/11/02 PRESSURE TEST TREE AND FREEZE PROTECT FLOWLINE AS DIRECTED. ( ( Page .1.of9 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Task Code NPT Phase 8/11/2002 12:00 - 15:00 3.00 MOB P 15:00 - 19:45 4.75 MOB P 19:45 - 21 :45 2.00 MOB P 21 :45 - 23:30 1.75 MOB P 23:30 - 23:45 0.25 MOB P 23:45 - 00:00 0.25 MOB P 00:00 - 00:20 0.33 MOB P 00:20 - 00:50 0.50 MOB P 00:50 - 03:00 2.17 BOPSURP 03:00 - 04:00 1.00 RIGU P 04:00 - 06:00 2.00 RIGU P 06:00 - 07:00 1.00 RIGU P 07:00 - 12:30 5.50 BOPSUR P 12:30 - 13:15 0.75 STWHIP P 13:15 - 14:05 0,83 STWHIP P 14:05 - 14:35 0.50 STWHIP P 14:35 - 15:00 0.42 STWHIP P 15:00 - 15:45 0.75 BOPSURP 15:45 - 16:00 0.25 STWHIP P 16:00 -18:15 2.25 STWHIP P WEXIT WEXIT DECOMP WEXIT WEXIT PRE PRE PRE PRE 8/12/2002 PRE PRE PRE PRE DECOMP PRE PRE PRE DECOMP WEXIT WEXIT 18:15 -19:00 19:00 - 19:20 0.75 STWHIP P 0.33 STWHIP P WEXIT WEXIT 19:20 - 21 :00 1.67 STWHIP P WEXIT 21 :00 - 21 :20 0,33 STWHIP P WEXIT 21 :20 - 21 :50 0,50 STWHIP P WEXIT 21 :50 - 23:45 1.92 STWHIP P WEXIT 23:45 - 23:55 0.17 STWHIP P WEXIT 23:55 - 00:00 0.08 STWHIP P WEXIT 8/13/2002 00:00 - 02:30 2.50 STWHIP P WEXIT 02:30 - 04: 15 1.75 STWHIP P WEXIT 04:15 -10:00 5.75 STWHIP P WEXIT Start: Rig Release: Rig Number: N1 Spud Date: 7/5/1992 End: 8/21/2002 8/11/2002 Description of Operations Move rig from DS 18 to DS 1 Raise derrick and windwalls to allow access by East Security Checkpoint Move rig from DS 1 to DS 12. Set back derrick jacks. RD hardline to reel. Toolservice finish leveling pad Safety mtg re: move over well Move rig into position and back over tree ND tree cap. Fin move rig over tree and set down Spot rig equipment, RU crane Nordic NU BOPE while DS swap CT reels to used 361k RF reversed Accept rig for operation at 0300 hrs 8/12/2002. Pull injector out of pipe bay, Install gooseneck Pull CT off reel and stab into injector. DSM RU hardline to flowback tank, berm and set cuttings tank Crew change. Rig up for BOP test. Pressure test BOPE. Witness waived by AOGCC's Jeff Jones. Open well -- dead. lAP = 350 psi. Install CTC. Pull test. Load and circulate dart. Pump problems prevented getting good MM bbl count. Pressue test CTC. Safety meeting. Well hazards; whipstock MU. MU whipstock. PT inner reel valve. MU MHA. Stab inj. RIH. 11500' wt check 40k. RIH tag Baker packer 11626' CTM. PU to breakover 11622' CTM. Correct to 11610'. PUH to 11568' which puts top of whipstock at 11555' corrected. Est circ 1.6/600 psi. Drop 5/8" ball and circ to seat wI 2% KCI Ball hit 4 bbls early after rate was slowed. Press to 1200 psi and hold for 4 min while SS takes picture. Incr pressure to 5000 psi several times and sheared somewhere along the way (had incr in bypass rate and pressure falloff when pump SD). PUH 36k and verify free. RIH to 11571' stacking 4k to verify WS set. PUH 36k Set LSX WS with top at 11555', btm at 11568', RA at 11564' POOH filling from BS due to rate restriction thru CT LD WS setting assy, Orientation showed 17L at 55.67 deg MU milling BHA RIH wI BHA #2. Tag at 11556.6' CTD-did not correct. PUH 34k wI 7k overpull indicating pinch point Start motor 2.6/2150. RIH and first motor work at 11555.0' CTD! Flag it Begin milling window Mill window from 11555'. Lots of metal back 11557.6' 11558.5'. Very grabby here. Twelve sharp stalls. Continue trying to mill. Build pill. Pump 10 bbls of 3 ppb bio pill (equiv to about 150k LSRV). Unable to make progress. No longer grabby (sharp stalls), but no progress in last 4 hours. Thought we got past the grabby area, but still stalling (very gradual Printed: 8/26/2002 10:31 :12 AM ( Page2of9 BP Operations Sl.ImmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From-To Hours Task Co.de NPT Phase 8/13/2002 04:15 -10:00 5.75 STWHIP P WEXIT 10:00 - 12:00 2.00 STWHIP N DFAL WEXIT 12:00 - 13:00 1.00 STWHIP N DFAL WEXIT 13:00 - 15:00 2.00 STWHIP N DFAL WEXIT 15:00-15:15 0.25 STWHIP N WEXIT 15:15 -16:20 1,08 STWHIP P WEXIT 16:20 - 16:50 0.50 STWHIP P WEXIT 16:50 - 18:30 1.67 STWHIP P WEXIT 18:30 - 19:00 0.50 STWHIP P WEXIT 19:00 -19:10 0.17 STWHIP P WEXIT 19:10 - 21 :00 1.83 STWHIP N DFAL WEXIT 21 :00 - 21 :45 0.75 STWHIP N WEXIT 21 :45 - 23:50 2,08 STWHIP N WEXIT 23:50 - 00:00 0.17 STWHIP N WEXIT 8/14/2002 00:00 - 01 :30 1.50 STWHIP N WEXIT 01 :30 - 03:15 1.75 STWHIP P WEXIT 03:15 - 04:00 0.75 STWHIP P WEXIT 04:00 - 05:45 1.75 STWHIP P WEXIT 05:45 - 06:30 0.75 STWHIP P WEXIT 06:30 - 07:45 1.25 DRILL P PROD1 07:45 - 08:10 0.42 DRILL P PROD1 08:10-10:15 2.08 DRILL P PROD1 10:15 -10:25 0.17 DRILL P PROD1 10:25 - 10:40 10:40 - 12:30 PROD1 PROD1 0.25 DRILL P 1.83 DRILL P 12:30 - 13:00 0.50 DRILL N DFAL PROD1 13:00 - 13:20 0.33 DRILL P PROD1 13:20 - 13:45 0.42 DRILL P PROD1 13:45 - 14:45 1.00 DRILL P PROD1 14:45 - 14:05 23.33 DRILL P PROD1 Start: Rig Release: Rig Number: N1 Spud Date: 7/5/1992 End: 8/21/2002 8/11/2002 Description of Operations stalls), Free spin unchanged 2.8/2070. Motor chunked -- rubber over shaker. Swap well to Flo-Pro. POOH. C/O motor and MHA. Mills in gage. Very little wear. Will re-run, RIH with milling BHA #3 Stop at last flag at 11555'. Make -4' correction, Check free spin, got 2650 psi at 2.5 bpm. Resume milling window. Tag up at 11558.5', Getting good motor work and drilloffs. 11561.3', CTP=3250 psi at 2.5 bpm. Pit vol=296 bbls. Weight=14400 Ibs. 11562', appear to be stacking weight. PU and try again. RIH, free spin=2650 psi at 2.5 bpm, Tagged up/saw first motor work at 11559.4', not bottom, but easing back into it. 11562.7', Milling ahead. CTP=3370 psi, 2.5 bpm, pit vol=295 bbls, Weight=11165'. 11563.3' Stacked 8k. PU 38k 2.5/2750 RIH clean to 11559,6' and had slow 600# stall, 700# stall twice. Est 11562.5' is TD POOH for motor. Overpull/motor work at 11232' Change out motor. Mills in gauge w/ minimal wear RIH w/ BHA #4 Corr -8,0' to flag, Start pump 2.5/2530. RIH Ream to first motor work at 11560,0'. First formation at 11561,5' indicated by wt gain. Ease SR thru window 11562,5' Drill formation to 11570' Ream and backream thrice. Dry tag once, all clean, Official (for now) window 11555-562' POOH for drilling assy LD milling BHA MU drilling BHA. 30 minutes for Sperry to programlread resistivity tool. Pre spud hazard recognition meeting and safety discussion. RIH with BHA #5, first drilling BHA. DS49 bit, 1,04 deg BHI motor, resistivty/MWD. Check MWD at 800', ok. RIH and check orienter at 3500', passed ok, continue RIH. Tag TD at 11581', make -11' correction to last tag. PU H, log down over Gamma spike at 11530'. Unable to get meaningful tie in log due to high background radioactive signature from scale in well. Orient to high side. 11570', Begin drilling. Free spin 3100 psi, TF 14R, Pit Vol=296 bbls, 2.6/2.6/3650 psi. ROP=60 fph. 11622', Pulser quit in MWD tool. PU off bottom, cycle pumps, tag bottom, attempt to get it to work. Also, Gamma reading high. Most likely due to radioative scale in the near wellbore area. At this MD the BHA is only 5' from the old wellbore. Pulser apparently working again. Continue drilling. 2.6/2.6/3680 fph, Pit vol=293 bbls, ROP=35 fph. 11634', Orient to high side, Resume drilling, 11661', Wiper trip to window while calling town. Only getting 4 to 6 degree doglegs from current BHA. Needed 12's to land Printed: 8/26/2002 10:31 :12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/14/2002 8/15/2002 ( ( Page30f 9 BP Oip.erationsSummaryReport 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 14:45 - 14:05 Hours Task Code NPT Phase PROD1 14:05 - 15:45 15:45 - 16:05 16:05 - 17:40 17:40 - 18:05 18:05 - 20:05 20:05 - 22:10 22:10 - 22:40 22:40 - 00:00 00:00 - 01 :15 01:15 - 01:30 01:30 - 03:15 03:15 - 05:25 05:25 - 07:35 07:35 - 08:40 08:40 - 09:45 09:45 - 10:05 10:05 - 11 :05 11 :05 - 11 :25 11 :25 - 11 :45 11:45 - 12:30 12:30 - 12:45 12:45 - 14:10 14:10 -14:40 14:40 - 14:50 14:50 -15:10 15:10 -15:25 15:25 - 15:30 15:30 - 16:45 16:45 -17:10 17:10 -17:45 17:45 - 18:30 23.33 DRILL P 1,67 DRILL P 0.33 DRILL P 1,58 DRILL P 0.42 DRILL P 2.00 DRILL P 2.08 DRILL P 0.50 DRILL P 1.33 DRILL P 1.25 DRILL P 0.25 DRILL P 1.75 DRILL P 2.17 DRILL P 2.17 DRILL P 1.08 DRILL P 1.08 DRILL P 0.33 DRILL P 1.00 DRILL P 0.33 DRILL P 0.33 DRILL P 0.75 DRILL P 0.25 DRILL P 1.42 DRILL P 0.50 DRILL P 0.17 DRILL P 0,33 DRILL P 0.25 DRILL P 0.08 DRILL P 1.25 DRILL P 0.42 DRILL P 0.58 DRILL P 0.75 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: Rig Release: Rig Number: N 1 Spud Date: 7/5/1992 End: 8/21/2002 8/11/2002 well. Current motor bend will cause well to land at least 10' deep to plan. Confer with town engineer and geo. They can tolerate a maximum TVD of 8930'. We will drill ahead until we project our TVD max will exceed 8930'. Resume drilling, 2,6/2,6/3450 psi. Pit Vol=291 bbls, TF=42R, ROP=50 fph. Wiper trip to shoe to allow DD to examine latest numbers and formulate plan forward. POH, Can not land well within allowable tolerances. POOH to pick up bigger bend motor and layout resistivity tool. Tag up at surface. Standby for crew change. Changeout BHA #5, layout resistivity tool, change motor AKO. RIH w/ BHA #5. Slide thru window w/ no bobbles Tag TD at 11690' CTD. Carr to 11678'. Get survey 2.6/3280/119R. Orient around Drilling 2.6/3280/40R PVT 294. Drill to 11740' Drilling 2.6/3280/70R-90R Get a slug of crude back at 11750', Drill to 11832' and landed at 8928' TVD What happened to 'Wiper' in the picklist? Guess we'll 'REAMBK' to the window POOH for lateral assy Change motor AKO back to 1.0 deg,add resistivity and upload RIH w/ BHA #6, Made it slick thru window. RIH to TD, Set depth to last tag of 11832'. Make -1' correction. NO "LOG" IN THE DIMS ACTIVITY PICKLlST. THAT OPTION HAS BEEN REMOVED. I GUESS WE WILL CALL THIS BACKREAMING TO GET OUR MAD PASS COMPLETED. Log up at 400 fph to get missing resistivity data, make a -8' correciton. Orient to 30R, difficult getting clicks in high dogleg, Had to pull up into straight section of hole to orient, then run back to TD. Had to repeat 2 times to get TF where needed. 11832', begin drilling. Free spin=3350 psi. 2.6/2.6, Pit vol=283 bbls. Down weight=17200 Ibs. TF=52R, ROP=90fph. 11861', PU to orient. Resume drilling TF=57R, Inc=89 deg. 2.5/2.5/3420 psi, ROP=70 fph. 11870', Get 2 clicks Resume drilling. TF=75R. 11907', PU to orient. Resume drilling. TF=93R, Inc=92.5 deg. ROP=70 fph, 2.5/2.5/3650 psi. Pit vol=281 bbls 11980', Wiper trip to window. Resume drilling. Free spin 3250 psi, 2.5/2.5/3650, TF 122R, 11990', orient just off bottom. Drilling ahead. Resistivity tool down to 3 ohms. 2.6/2.6/3930 psi, 279 bbls pit vol. TF=69R, TVD=8920'. 12009', Geo has determined that the BHA has entered into the pyrite at the top of Z4. Orient to drop angle to get below pyrite. Resume drilling. 12090', Orient to 90R. Resume drilling. Drill to 12130' Wiper trip to shoe. Clean PU off bottom at 33 klbs. Printed: 8/26/2002 10:31 :12 AM ( ( BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 8/11/2002 Spud Date: 7/5/1992 End: 8/21/2002 Start: Rig Release: Rig Number: N1 8/15/2002 From- To Hours Task Code.NPT 18:30 - 19:00 0.50 DRILL N DFAL PROD1 19:00 - 20:50 1.83 DRILL N PROD1 20:50 - 23:00 2.17 DRILL N PROD1 23:00 - 00:00 1.00 DRILL N PROD1 00:00 - 01 :30 1.50 DRILL N PROD1 01 :30 - 01 :50 0.33 DRILL N PROD1 01 :50 - 02:05 0.25 DRILL N PROD1 02:05 - 02:20 0.25 DRILL N PROD1 02:20 - 02:35 0.25 DRILL N PROD1 02:35 - 04:00 1.42 DRILL N PROD1 8/16/2002 04:00 - 05:20 PROD1 1.33 DRILL N 05:20 - 07:15 1.92 DRILL N WAIT PROD1 07:15 -17:00 9.75 DRILL N WAIT PROD1 17:00 - 19:30 2.50 DRILL N PROD1 19:30 - 19:45 0.25 DRILL P PROD1 19:45 - 20:15 0.50 DRILL P PROD1 20:15 - 20:35 0.33 DRILL P PROD1 20:35 - 21 :40 1.08 DRILL P PROD1 21 :40 - 22:00 0.33 DRILL P PROD1 22:00 - 22:40 0.67 DRILL P PROD1 22:40 - 23: 1 0 0.50 DRILL P PROD1 23: 1 0 - 23:20 0.17 DRILL P PROD1 23:20 - 23:30 0.17 DRILL P PROD1 23:30 - 23:40 0.17 DRILL N STUC PROD1 23:40 - 00:00 0,33 DRILL P PROD1 8/17/2002 00:00 - 00:50 0.83 DRILL P PROD1 00:50 - 01 :40 0.83 DRILL P PROD1 Description of Operations Make MAD pass to check GR tool. Seems to be reading too high. POOH to change GR probes, Reading 50 api high Download data. Change GR probe RIH w/ BHA #8 Continue RIH Wt loss at btm of window at 11570' CTD. Carr -8'. RIH. Started losing 0.2 bpm at 11750' Set down at 12058', sticky-acts like packing off. Work to get thru at drilled TF and not Backream to window, Had 15k overpull at 11701' RIH to 11800', Major emergency on A-Pad Log MAD pass up from 11800' 2.5/3350 while curtailing all other work on rig. Got a ton of solids over shaker (2 bbls), Returns 1/1, Lost 17 bbls Gen 3 down due to power cord problem, Will have to operate on rig power til fixed Log up from window while WO A-Pad situation (knock some scale off looking for a tie-in point). Log to 11260' and GR counts too high in casing. GR counts in open hole are exactly double the drilled counts (using 0-300 scale) Park at 11260', circ min rate. All emergency resources on A-Pad. Rig on drywatch until situation on A pad is resolved. Contact A-pad incident commander to confirm situation. Continue to wait on resolution of A-pad incident. Rig continue on drywatch. Determine that the mud has absorbed NORM from the scaled up production tubing and has caused the high GR counts-see Remarks Check with NSPE's, wellsite activity is still SI pending resolution of A-pad well control situation. A-Pad incident concluding. Safety mtg re: refocus RIH from 11250', thru window, clean. Precautionary ream to TD 2.5/3550. Wt loss, motor work at 11710',11838'. Set down at 12050' at 177R Orient around to drilled TF RIH thru 12050' at 113R, clean. Set down at 12087', backream to 11950' several times. Work to 12109' and sticky/packing off Backream to window while wo new mud Start new/used 9.2 ppg mud. RIH from window. Slow ream 12030-124' and acts like TD, but stacking and motor work the whole way Wiper to 11800' while circ new mud up BS 2.5/2450. Slow ream from 12050' to tag at 12132' 2.6/3600, Slow drill at 128R while Sperry works a glitch on log screen. Drill to 12136' Log MAD pass up from 12132' Stuck BHA w/ bit at 12095'. Work free after two cycles at max pull. Wiper to 11900' Resume logging up from 12000' bit 2.4/3400, full returns Continue MAD pass up to 11770' RIH to 11970' to log section missed while logging up. Log down 2.4/3420/107R 240'/hr. Log down to 12090' and stacking Printed: 8/26/2002 10:31 :12 AM (' ( PageS of .9 BP Operations Summary . Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From-To 8/17/2002 00:50 - 01 :40 0.83 DRILL P PROD1 01 :40 - 01 :55 0.25 DRILL P PROD1 01 :55 - 04:00 2.08 DRILL P PROD1 04:00 - 06:00 2,00 DRILL P PROD1 06:00 - 06:30 0.50 STKOH X WAIT PROD1 06:30 - 09: 1 0 2.67 STKOH C PROD1 09:10 - 11 :10 2.00 STKOH X SFAL PROD1 11: 1 0 - 11 :20 0.17 STKOH C PROD1 11 :20 -12:30 1.17 STKOH C PROD1 12:30 - 14:30 2.00 STKOH C PROD1 14:30 - 14:45 0.25 STKOH C PROD1 14:45 - 15:05 0.33 STKOH C PROD1 15:05 -16:15 1.17 STKOH C PROD1 16:15 - 17:55 1.67 STKOH C PROD1 17:55 - 20:10 2,25 STKOH C PROD1 20:10 - 20:50 0.67 STKOH C PROD1 20:50 - 21 :25 0.58 STKOH C PROD1 21 :25 - 21 :50 0.42 STKOH C PROD1 21 :50 - 22:00 0.17 STKOH X DFAL PROD1 22:00 - 23:50 1.83 STKOH X PROD1 23:50 - 00:00 0.17 STKOH X PROD1 8/18/2002 00:00 - 00:15 0.25 STKOH X PROD1 00:15 - 02:50 2.58 STKOH X PROD1 02:50 - 03:05 0.25 STKOH X PROD1 03:05 - 03:35 0.50 STKOH X PROD1 03:35 - 03:50 0.25 STKOH X PROD1 03:50 - 04:20 0.50 STKOH X PROD1 04:20 - 04:30 0.17 STKOH X PROD1 04:30 - 06:15 1,75 STKOH X PROD1 06: 15 - 07:00 0.75 STKOH X PROD1 07:00 - 09:05 2.08 STKOH X PROD1 09:05 - 09:25 0.33 STKOH C PROD1 Start: Rig Release: Rig Number: N1 Spud Date: 7/5/1992 End: 8/21/2002 8/11/2002 pesçriptionof Operations and stalling. PUH w/ a good overpull. That's it. Will OH sidetrack to avoid this part of the hole Wiper to window POOH for sidetrack BHA LD drilling BHA. Download resistivity data WO DS to decide if to cut CT Cut pipe prior to remove damaged pipe at 1200'. MU SWC CTC. Coil egg shaped due to being reversed on reel. Took considerably longer than normal to get CTC installed. Pull test CTC to 30klbs. PT to 3500 psi. Make up sidetracking BHA #9. Smith Geodiamnd M26 bit, 1.75 deg motor, MWD, MHA. RIH with sidetracking BHA. Shallow hole test at 1500', ok. Tag up at 11485', Had to kick pumps on to work thru. RIH to 11765'. Kick on pumps. Log tie in up from 11765', Make a -15' correction. Orient to 150L toolface. Begin troughing down from 11795' to 11810', Free spin 3300 psi. Saw 300 psi motor work on first down trough. (Possibly sidetracked already!). Make 2nd trough down, and didn't see as much motor work. Make 3rd troughing pass and didn't see any motor work. Toolface 128L during troughing. Begin time drilling at 3'/hr. Seeing 50 psi motor work. 11816' 2.6/3440/131 L 11819.8' 2.5/3330/131 L Obviously sidetracked, but no survey confirmation yet. Sperry tool start working intermittently. Wiper to extend trough while work w/ SS tool Resume drilling at reduced rate 2.0/2600 where tool functions. Drill to 11822'. Can't drill ahead like this Wiper to window POOH for MWD Change MWD probe to different style Change MWD pulser and probe RIH wI BHA #10. SHT. Set down on GLM #6 at 10498' CTD. Orient to get by. RIH thru window, clean. RIH to 11773' Log tie-in up from 11765', corr -17' 2.6/3500/99R Orient to left Ream in hole and tag at 11822' Drilling 2.5/3500/132L slowly incr diff and attempt to drill. Drill to 11824.0'. MWD pulse flatlines when wtldiff applied (tagging btm). Assuming possible small washout above pulser Wiper to window POOH to check BHA PT CTC. Found leak in upper SWS NRJ. Probable cause of problems of last 2 runs. Change out NRJ. Change out motor as precaution. Rescribe motor. Visually check MWD and Orienter housings for leaks. No problems found. MU injector. RIH with BHA #11, Sidetrack BHA #3. 1.69 deg BHI motor, Smith Geodiamond M26 bit. shallow hole test of pulser and MWD at 500', passed ok. RIH, thru window and shublik slick. Orient to low side left tool face to get into sidetrack wellbore. Printed: 8/26/2002 10:31 :12 AM ( ( Page Bof9 BP Operations .SummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: N1 Spud Date: 7/5/1992 End: 8/21/2002 8/11/2002 From-.To HoUrs Task Description of Operations 8/18/2002 09:05 - 09:25 09:25 - 10:15 0.33 STKOH C 0.83 STKOH C PROD1 PROD1 10:15 -10:30 0.25 STKOH X DFAL PROD1 10:30 - 12:00 1.50 STKOH X DFAL PROD1 12:00 - 12:40 0.67 STKOH C PROD1 12:40 - 13:30 0.83 STKOH X DFAL PROD1 13:30 - 15:35 2.08 STKOH X DFAL PROD1 15:35 - 15:40 0.08 STKOH X DFAL PROD1 15:40 - 16:10 0,50 STKOH C PROD1 16:10 - 16:30 0.33 STKOH C PROD1 16:30 - 16:45 0.25 STKOH C PROD1 16:45 -17:10 0.42 STKOH C PROD1 17:10 -17:15 0.08 STKOH C PROD1 17:15 -17:25 0.17 STKOH C PROD1 17:25 - 19:30 2.08 STKOH C PROD1 19:30 - 21 :00 1.50 STKOH C PROD1 21 :00 - 00:00 3.00 STKOH C PROD1 8/19/2002 00:00 - 02:30 2.50 STKOH C PROD1 02:30 - 02:40 0.17 STKOH C PROD1 02:40 - 04:20 1.67 STKOH C PROD1 04:20 - 05:20 1.00 STKOH X HMAN PROD1 05:20 - 06: 10 0.83 STKOH X HMAN PROD1 06: 1 0 - 06:35 0.42 STKOH C PROD1 06:35 - 07:15 0.67 STKOH C PROD1 07:15 - 07:25 0.17 STKOH C PROD1 07:25 - 08:50 1.42 STKOH C PROD1 No problems at sidetrack, slid right in. TF=157L, RIH. Made it into sidetrack ok. Tag up at 11837', make -13' correction to get on depth to last tag of 11824'. Free spin=3000 psi @ 2.5 bpm, Pit volume=291 bbls, Returns 100%, ROP slow 20 fph. MWD not working, Pulser fine, Gamma Fine, Directional not updating. Sperry hand thinks it is a downhole proble failure, Cycle pumps and attempt to get it to work. No dice. Can't complete build/turn/sidetrack without toolface, 11829', Directional probe has failed. POOH to changeout MWD package. Stop at 500'. Hold Fire Drill. Simulated casing leak and fire in the cellar. Rig evacuation to primary muster area. Debrief and discussion of how events similar to the accident on A-22, could occur or impact our operation, Good participation and responce from all hands. Drill documented in ASA 2002-ASA-291229, Tag up at surface, troubleshoot BHA. Replace sperry probe with new probe. Change out bit for DS49, RIH with BHA #12 to finish sidetrack. Run thru window and shublick ok. In high dog leg build section pulser shut down, Didn't start again until we were on bottom, Orient around to 168L. Tag bottom, make -14' correction to get on depth. Made it thru sidetrack easily, with no problems or weight bobbles. Begin drilling. Free spn 3050 psi at 2.5 bpm. 2.5/2.5/3180, Pit vol=291 bbls, TF=170R, ROP=65 fph. 11845', Pick up to orient to 72R. Resume drilling. 11890', pick up orient 2 clicks. Resume drilling. Need 10' more to have well landed. 11900' MD, TVD=8934', INC=88 deg, Sidetrack completed and well landed. POOH to pick up lateral section BHA with resistivity tool. PT CTC. LD motor and bit. PT complete BHA-no leaks. LD BHA Weekly BOPE test. Witness waived by AOGCC TESTPRESSURE (Pressure test) has been removed from the Activity picklist Finish weekly BOPE test Note: Picklist does not have TESTPRESSURE Safety mtg re: BHA handling MU drilling BHA w/ resistivity RIH wI BHA #13 to 5400' POOH to torque up a connection in the middle of a new carrier for Sperry resistivity tool Tighten connections on ERW. Check scribe RIH with BHA #14 Shallow hole test of MWD and orienter at 3700', passed ok. Continue RIH. Made it thru window and shublick with no weight loss. 11664', pulser died. It has on every pass in the hole at this depth. High dogleg binding up pulser? Cycle pumps to kick it back on. Worked ok atter that. RIH thru OH sidetrack Printed: 8/26/2002 10:31 :12 AM ( Page 7 of9 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Frorn-To Hours Task Code NPT Phäse 8/19/2002 1.42 STKOH C PROD1 08:50 - 10:15 10:15 -10:20 0.08 STKOH C PROD1 10:20 - 10:30 0.17 STKOH C PROD1 10:30 -11:15 0.75 STKOH C PROD1 11: 15 - 11 :20 0.08 STKOH C PROD1 11 :20 - 12:00 0.67 STKOH C PROD1 12:00 - 12:15 0.25 STKOH C PROD1 12:15 -13:15 1.00 STKOH C PROD1 13:15 -13:50 0,58 STKOH C PROD1 13:50 - 13:55 0.08 STKOH C PROD1 13:55 -14:15 0.33 STKOH C PROD1 14:15 - 14:30 0.25 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 15:45 0.25 DRILL P PROD1 15:45 - 16:40 0.92 DRILL P PROD1 16:40 - 17:20 0.67 DRILL P PROD1 17:20 - 17:40 0.33 DRILL P PROD1 17:40 - 18:00 0.33 DRILL P PROD1 18:00 - 19:20 1.33 DRILL P PROD1 19:20 - 19:45 0.42 DRILL P PROD1 19:45 - 20:20 0,58 DRILL P PROD1 20:20 - 20:55 0.58 DRILL P PROD1 20:55 - 21 :25 0.50 DRILL N STUC PROD1 21 :25 - 21 :55 0.50 DRILL P PROD1 21 :55 - 23:00 1.08 DRILL P PROD1 23:00 - 23:30 0.50 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 8/20/2002 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 01 :30 0.50 DRILL P PROD1 01 :30 - 02:00 0,50 DRILL P PROD1 02:00 - 03:30 1.50 DRILL P PROD1 03:30 - 04:00 0.50 DRILL P PROD1 Start: Rig Release: Rig Number: N1 Spud Date: 7/5/1992 End: 8/21/2002 8/11/2002 Description of Operations Tag bottom, make -15' correction to get on depth. Catch survey on bottom, MAD pass up to get missing data, and tie into previous runs, Observed Gamma Ray data reading higher in sands than when we drilled. Mud probably contaminated with NORM again. Geo able to live with high GR for now. Will re-MAD pass to get good GR when we swap to next new mud system. Make +4' correction from MAD pass. Run back to bottom Orient 2 clicks to 10R. Begin drilling. Free spin=3300 psi. (Due to EWR tool) 2,5/2.5/3650 psi. TF=O deg. ROP=44 fph. 11966', Differentially stuck momentarily. Pulled 60klbs free, and got free, Resume drilling. 2.5/2.5/3900 psi. TF 0, ROP=107 fph, Pit vol=285 bls 12025'. PU to orient 2 clicks. Resume drilling. 2.4/2.4/3800 psi, TF 90R, ROP= 102 fph, Pit vol=285 bbls, 12100', Wiper trip to window. Clean PU off bottom. Clean up/down thru shublik, Get 2 clicks. Resume drilling. 2.6/2.6/3960, TF=180R, ROP=100 fph, Pit Vol=284 bbls. 12130', orient around to 90R. Back on targeted time with respect to SWS contract. Resume drilling. 12213', Pick up to orient to 90R. Resume drilling, 2,6/2.6/3900 psi. Pit vol=283 bbls. TF=90R. 12284', Wiper trip to shoe. Clean PU and clean up and down thru shublik. Orient to 80R. Return to drilling. 2.4/2.4/3800 psi. TF=90R, Inc=89 deg, ROP=70 fph, Pit vol=277 bbls. Drilled into the Shublik again at 12280'. Orient to straight down. Drill to 12356' and stacking A couple of 100' wipers before orient around Orient around to 90R Drill ahead while dropping out of Shublik and back into sand. Drill to 12389' and last 10' drilled like sand Diff stuck BHA while drilling at 12389' (8944' TVD). Give it a couple of trys, then SD pump and wait Pull free w/ 40K over. Wiper to window LOG is not in picklist-nothing else is suitable. Tie-in from 11830'-11720' bit, add 9.0'. GR is avg 50 api higher so hard to correlate w/ original GR Wiper 2.5/3350/144R back to TD. Tag at 12389' CTD Orient around. WO Sperry to fix surface depth problem Resume drilling from 12389' in a hard streak (pyrite) 2.6/3540/90R. Drill to 12412' Drill from 12412' 2.6/3600/140R to 12433' and got back in sand Orient around Drilling 2.6/2580/80R. Drill to 12564' and now in good sand Wiper to window, clean. RIH to 11800' Printed: 8/26/2002 10:31: 12 AM ( Page.8of.9 Operations. Summary Report Legal Well Name: 12-14 Common Well Name: 12-14 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 8/11/2002 End: 8/21/2002 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Hours Task Code NPT 8/20/2002 04:00 - 04:40 0.67 DRILL P PROD1 Orient around from 6R. Orientor only averaging 10 deg/click 04:40 - 05:05 0.42 DRILL P PROD1 RIH thru sidetrack at 149L. RIH to TD 05:05 - 05:25 0,33 DRILL P PROD1 Orient to right from 44L 05:25 - 06:30 1.08 DRILL P PROD1 Drilling from 12564' 2.5/3600/79R-110R holding 88 deg 06:30 - 06:40 0.17 DRILL P PROD1 Orient to 90L 06:40 - 08:00 1.33 DRILL P PROD1 12647', Resume drilling. Free spin 3500 psi. 2.4/2.4/4150 psi. Pit vol=253 bbls. 08:00 - 09:15 1.25 DRILL P PROD1 12750', Wiper trip to shoe. Weight bobbles thru 12400'-12280', but no motor work. Clean thru upper shublick. Clean back to bottom. 09: 15 - 09:30 0.25 DRILL P PROD1 Orient to 90L 09:30 - 11 :40 2.17 DRILL P PROD1 Resume drilling, begin mud swap. 2/4/2.3/3880 psi. TF=64L, INC=86 deg, ROP=115 fph. 11 :40 - 11 :50 0.17 DRILL P PROD1 Pickup to get 2 clicks. 11 :50 - 12:30 0.67 DRILL P PROD1 Resume drilling. 12:30 - 13:20 0.83 DRILL P PROD1 12881', Wiper trip. It appears that we have have drilling into the shublik again. Wiper trip to shoe allow town to make plan forward. No problems seen on trip up, 13:20 - 13:45 0.42 DRILL P PROD1 Log tie in pass, Make a +4' correction. 13:45 - 14:35 0,83 DRILL P PROD1 Finish wiper trip, RIH. 14:35 - 17:45 3.17 DRILL P PROD1 Tag bottom. Corrected depth of TD after tie in is 12884'. =- POOH. Flagged pipe at 9900' EOP, Continue POOH. 17:45 - 20:00 2.25 DRILL P PROD1 PJSM. Download memory resistivity data & UD drilling BHA. 20:00 - 20:15 0.25 CASE P COMP Fill hole with 3 bbls of mud & R/U to run liner. 20:15 - 20:30 0.25 CASE P COMP PJSM for running liner. 20:30 - 23:30 3.00 CASE P COMP M/U 2 pup jts, 25 jts of 2-7/8" 6.16# L-80 STL pre-drilled (3/8" each @ 4 holes/ft) & 22 jts of 2-7/8" 6.16# L-80 STL solid liners with shoe, O-ring sub, & cementralizers. M/U XN nipple, TIW Deploy sub, WF 4-1/2" G Spear LRT, MHA & CTC. Liner BHA total length = 1567.93'. 23:30 - 00:00 0.50 CASE P COMP RIH with 2-7/8" Pre-Drilled/Solid liner completion to 3200'. 8/21/2002 00:00 - 01 :30 1.50 CASE P COMP Continue RIH with 2-7/8" Pre-Drilled/Solid liner completion to EOP flag seen @ 11484.7' (should be @ 11467.9' i.e. -16.8' corr). Did not correct CTD. Wt check: Up wt = 44k, Dwn Wt = 22k. 01 :30 - 02:00 0.50 CASE P COMP RIH 2-7/8" liner thru window @ 11555' & sidetrack pt @ 11810' without bobbles. Continue RIH smoothly @ 50 fpm in open hole. Set down @ 12790', P/U & work thru. Continue RIH & tag TD @ 12900' (same -16' corr). P/U twice & retag @ same TD. 02:00 - 02:10 0.17 CASE P COMP Circ @ 1.5/1.5bpm, 2135psi & release from G-spear LRT. P/U @ 31 k & confirm liner release. Top of liner deployment sleeve is @ 11320' with btm of liner @ TD of 12884'. 02:10 - 02:30 0.33 CASE P COMP Swap wellbore to 2% KCL water @ 2.5/2.5bpm, 3125psi. 02:30 - 04:30 2,00 CASE P COMP POOH chasing flo-pro mud OOH, Continue POOH to 2000'. 04:30 - 04:50 0.33 CASE P COMP Freeze protect wellbore from 2000' with MeOH while POOH. 04:50 - 05:00 0.17 CASE P COMP OOH. SI swab (23 turns). UD WF G-spear LRT. 05:00 - 05:05 0.08 RIGD P COMP M/U nozzle & stab onto well. 05:05 - 05:15 0.17 RIGD P COMP Safety meeting for B/D CT with nitrogen. 05: 15 - 06:45 1.50 RIGD P COMP PlTest N2 unit - OK. Blow down CT with N2 & bleed off. Meanwhile clean out pits & tanks. 06:45 - 07: 15 0,50 RIGD P COMP SAFETY MEETING. Review procedure, hazards and mitigation for setting injecter head in pipe bay for rig move, 07:15 - 09:30 2.25 RIGD P COMP Cut coil, set CT to side, remove guide arch, set injecter head in Printed: 8/26/2002 10:31:12AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: (' Page90f 9 BP 0 J)erations . Summary ReJ)ort 12-14 12-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: N1 Spud Date: 7/5/1992 End: 8/21/2002 8/11/2002 8/21/2002 From-To Hours Task Code NPT Phase Dêsçriptipn of Op~rations 07:15 - 09:30 09:30 - 11 :00 2,25 RIGD P 1.50 RIGD P COMP COMP pipe bay. Clean cuttings tank, RID hardline, move tank. PJSM. NID BOPE. N/U tree cap and pressure test. RIG RELEASE AT 11 :00 HRS 8-21-2002. Total of 9.33days on well. Printed: 8/26/2002 10:31 :12 AM AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 12-14AL 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,801.61' MD Window / Kickoff Survey 11,810.00' MD (if applicable) Projected Survey: 12,884.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP1 3 2002 Alaska Oit & Gas C AnCb:S;: CommiSSion 13-Sep-02 ao;;;, /d~ JEFN-Y: North Slope Alaska BPXA PBU_EOA DS 12, Slot 12-14 12-14AL 1 Job No. AKMW22138 Surveyed: 20 August, 2002 ,- SURVEY REPORT 11 September, 2002 Your Ref: API 500292065960 Surface Coordinates: 5930839.99 N 696891.17 E (70012' 54.9333" H, 1480 24' 42.4863" W) Kelly Bushing: 69.68ft above Mean Sea Level /~~~ SP@!"""Y-5UIl DRIL.LII\@G .~"A\llCE5 A Halliburton Company Survey Ref: svy11315 Sperry-Sun Drilling, Services .' Survey Report for 12-14AL1, Your Ref: API 500292065960 Job No. AKMW22138, Surveyed: 20 August, 2002 BPXA North Slope Alaska PBU_EOA DS 12 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11801,61 84.760 161.570 8923.29 8992.97 3707.81 S 4577.68 E 5927252.83 N 701564.00 E 4642.54 Tie On Point ~c. 11810.00 83,960 160.770 8924.12 8993.80 3715.72 S 4580.38 E 5927245.00 N 701566.90 E 13.452 4650.84 Window Point 11851.21 80,270 162.930 8929.77 8999.45 3754.50 S 4593.09 E 5927206.56 N 701580.62 E 10.350 4691.49 11883.68 81.430 165.940 8934.93 9004.61 3785.37 S 4601.69 E 5927175.92 N 701590.02 E 9.825 4723.51 11925.48 82.910 168.800 8940.63 9010.31 3825.78 S 4610.74 E 5927135.77 N 701600.12 E 7.647 4764.91 11958.04 86.340 169.850 8943.68 9013.36 3857.63 S 4616.75 E 5927104.08 N 701606.96 E 11.013 4797,30 11994.96 90.660 171.440 8944.64 9014.32 3894.03 S 4622.74 E 5927067.85 N 701613.90 E 12.467 4834.12 12027.33 94.1 00 171.970 8943.30 9012.98 3926.03 S 4627.41 E 5927035.98 N 701619.40 E 10.752 4866.35 12068.73 94.450 176.370 8940.21 9009.89 3967.09 S 4631.60 E 5926995.04 N 701624.66 E 10.632 4907.30 12102.48 92.160 179.370 8938.27 9007.95 4000.76 S 4632.85 E 5926961.42 N 701626.79 E 11.170 4940.38 12132.18 89.690 178.490 8937.79 9007.47 4030.45 S 4633.41 E 5926931.76 N 701628.12 E 8.828 4969.44 12162,88 88,900 183.600 8938.17 9007.85 4061.13 S 4632.85 E 5926901.07 N 701628.36 E 16.841 4999.21 12191.54 87.840 185.890 8938.98 9008.66 4089.68 S 4630.48 E 5926872.4 7 N 701626.74 E 8.802 5026.49 12236.88 89.690 194.170 8939.96 9009.64 4134.27 S 4622.59 E 5926827.69 N 701620.01 E 18.707 5068.17 12272.76 88.810 198.570 8940.43 9010.11 4168.69 S 4612.48 E 5926793.02 N 701610.80 E 12.505 5099.42 12306.36 90.130 201.390 8940.74 9010.42 4200.26 S 4601.00 E 5926761.16 N 701600.15 E 9.266 5127.61 12338,96 88.020 204.920 8941.27 9010.95 4230.22 S 4588.19 E 5926730.87 N 701588.12 E 12.613 5153.92 12369.91 86.870 208.270 8942.65 9012.33 4257.87 S 4574.35 E 5926702.88 N 701575.01 E 11 .434 5177.74 ,...-., 12410.04 86.870 211.090 8944.84 9014.52 4292.67 S 4554.51 E 5926667.56 N 701556.09 E 7.017 5207.20 12444.29 85.550 213.910 8947.10 9016.78 4321.49 S 4536.15 E 5926638.27 N 701538.49 E 9.074 5231.15 12481.96 86.610 217.780 8949.68 9019.36 4351.95 S 4514.15 E 5926607.25 N 701517.28 E 10.628 5255.87 12523.08 88.550 221.480 8951.42 9021.10 4383.59 S 4487.95 E 5926574.94 N 701491.92 E 10.152 5280.80 12562.41 88.460 224.650 8952.44 9022.12 4412.31 S 4461.10 E 5926545.53 N 701465.83 E 8,061 5302.75 12599.58 89.250 230.4 70 8953.19 9022.87 4437.37 S 4433.69 E 5926519.76 N 701439.08 E 15,798 5321.01 12635.11 88.190 231.530 8953.98 9023.66 4459.73 S 4406.09 E 5926496.70 N 701412.07 E 4.219 5336.58 12662.88 86,060 232.340 8955.37 9025.05 4476.83 S 4384.25 E 5926479.03 N 701390.69 E 8,205 5348.33 12704.98 85.110 225.890 8958.62 9028.30 4504.28 S 4352.53 E 5926450.76 N 701359.70 E 15.441 5367.95 12739.98 87.670 225.540 8960.82 9030.50 4528.67 S 4327.53 E 5926425.72 N 701335.34 E 7.382 5386.08 12779.83 87.750 220.430 8962.41 9032.09 4557.79 S 4300.39 E 5926395.91 N 701308.97 E 12.814 5408.35 12816.26 90.400 215.310 8963.00 9032.68 4586.53 S 4278.04 E 5926366.59 N 701287.38 E 15,823 5431.33 ~---~------~-.- ~-~._---- - 11 September, 2002 - 13:59 Page 20f4 DrillQuest 2.00.08.005 Sperry-Sun Drilling, Services Survey Report for 12.14AL1 Your Ref: API 500292065960 Job No. AKMW22138, Surveyed: 20 August, 2002 . BPXA North Slope Alaska PBU_EOA DS 12 Measured Sub-Sea Vertical Local Coordinates G~obal Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (Q/100ft) 12847.33 90.040 212.850 8962.88 9032.56 4612.26 S 4260.63 E 5926340.42 N 701270.64 E 8.002 5452.49 ~ 12884.00 90.040 212.850 8962.86 9032.54 4643.07 S 4240.74 E 5926309.10 N 701251.56 E 0.000 5478.03 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 167.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12884.00ft., The Bottom Hole Displacement is 6288.24ft., in the Direction of 137.593° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~h 11801.61 1181 0,00 12884.00 8992.97 8993.80 9032.54 3707.81 S 3715.72 S 4643.07 S 4577.68 E 4580.38 E 4240.74 E Tie On Point Window Point Projected Survey . -_._-_.._._------------_...__..~ --------.-- - 11 September, 2002 - 13:59 Page 3 of4 DrillQuest 2.00.08.005 North Slope Alaska Survey tool program for 12-14AL 1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0,00 11300,00 0.00 11300.00 8768.55 12884.00 8768.55 AK-4 BP _CM (12.14PB1) 9032.54 MWD Magnetic (12-14) 11 September, 2002 - 13:59 Sperry-Sun Drilling. Services Survey Report for 12..14AL1 Your Ref: API 500292065960 Job No. AKMW22138, Surveyed: 20 August, 2002 . BPXA PBU_EOA DS 12 - Survey Tool Description ->. ---_._-- --------,------- ----~--~-_.._- - - Page 4 of4 DrillQuest 2.00.08.005 aœ~/cJ;;< 13-Sep-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 12-14AL 1 PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,548.90' MD Window / Kickoff Survey 11,550.00' MD (if applicable) Projected Survey: 12,136.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED SEP 1 3 2002 Attachment(s) Alaska O,} & Gas Cons. Commission Anchorage :JEF N '-'YE North Slope Alaska BPXA PBU_EOA DS 12, Slot 12-14 12..14AL1 PB1 Job No. AKMW22138, Surveyed: 15 August, 2002 SURVEY REPORT 11. September, 2002 Your Ref: API 500292065971 Surface Coordinates: 5930839.99 N, 696891.17 E (70012' 54.9333" N, 148024' 42.4863" W) Kelly Bushing: 69.68ft above Mean Sea Level S5¡ :,~I'I'Y-5U'" DRILI,;:.nING... 'SEAVIç:es A Halliburton Company Survey Ref: svy11314 Sperry-Sun Drilling, Services . Survey Report for 12-14AL 1 PB1 Your Ref: API 50029206597'1 Job No. AKMW22138 Surveyed: 15 August 2002 BPXA North Slope Alaska PBU_EOA DS 12 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11548,90 59.090 121.980 8847.51 8917.19 3537.29 S 4417.16 E 5927419.10 N 701399.09 E 4440.28 Tie On Point 11550.00 59,190 121.950 8848.07 8917.75 3537.79 S 4417.96 E 5927418.62 N 701399.90 E 9.388 4440.95 11555.00 ... 59.670 122.460 8850.62 8920.30 - 3540.09 S 4421.61 E 5927416.43 N 701403.60 E 13.011 4444.00 Window Point 11570.91 62.470 124.050 8858.31 8927.99 3547.72 S 4433.25 E 5927409.10 N 701415.44 E 19.652 4454.06 11598.18 65,100 126.670 8870.36 8940.04 3561.88 S 4453.19 E 5927395.46 N 701435.74 E 12.934 4472.34 11630,98 66,960 129.690 8883.69 8953.37 3580.41 S 4476.74 E 5927377.55 N 701459.77 E 10.145 4495.69 11654.28 68.760 131.740 8892.47 8962.15 3594.49 S 4493.10 E 5927363.91 N 701476.49 E 11.229 4513.09 11685.26 72.330 130.730 8902.79 8972.4 7 3613.74 S 4515.06 E 5927345.24 N 701498.95 E 11.926 4536.79 11710.16 76.300 137.610 8909.52 8979.20 3630.44 S 4532.23 E 5927328.99 N 701516.55 E 31.007 4556.92 11742,06 80.700 146.770 8915.89 8985.57 3655.11 S 4551.35 E 5927304.82 N 701536.30 E 31 .329 4585.26 11772,76 83.080 152.940 8920.23 8989.91 3681.38 S 4566.60 E 5927278.96 N 701552.23 E 21.352 4614.29 11801.61 84.760 161.570 8923.29 8992.97 3707.81 S 4577.68 E 5927252.83 N 701564.00 E 30.308 4642.54 11830.31 87.670 168.620 8925.19 8994.87 3735.47 S 4585.04 E 5927225.37 N 701572.07 E 26.523 4671.14 11876,58 92.070 174.960 8925.29 8994.97 3781.23 S 4591.64 E 5927179.80 N 701579.87 E 16.676 4717.21 11906.61 93.130 177.430 8923.93 8993.61 3811.16 S 4593.63 E 5927149.93 N 701582.64 E 8.943 4746.82 11941.25 92,690 182.010 8922.17 8991.85 3845.74 S 4593.80 E 5927115.36 N 701583.71 E 13.266 4780.56 11969,66 91.280 183.770 8921.19 8990.87 3874.10 S 4592.37 E 5927086.98 N 701583.02 E 7.935 4807.87 12000,00 90.660 189.060 8920.67 8990.35 3904.23 S 4588.98 E 5927056.77 N 701580.42 E 17.553 4836.4 7 ~, 12045.06 89.780 192.940 8920.50 8990.18 3948.46 S 4580.38 E 5927012.34 N 701572.98 E 8.829 4877.62 12071,28 87.210 193.930 8921.19 8990.87 3973.95 S 4574.30 E 5926986.69 N 701567.55 E 10.503 4901.09 12104.33 87.750 198.570 8922.64 8992.32 4005.64 S 4565.06 E 5926954.77 N 701559.15E 14.121 4929.89 12136.00 87.750 198.570 8923.89 8993.57 4035.64 S 4554.98 E 5926924.52 N 701549.85 E 0.000 4956.85 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 167.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12136.00ft., The Bottom Hole Displacement is 6085. 57ft. , in the Direction of 131.540° (True). --~~----~--- ~------~- 11 September, 2002 - 13:56 Page 2 of3 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 12-14AL1 PB1 Your Ref: API 500292065971 Job No. AKMW22138, Surveyed: 15 August, 2002 . North Slope Alaska BPXA PBU_EOA DS 12 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11548.90 11555,00 12136.00 8917.19 8920,30 8993.57 3537.29 S 3540.09 S 4035.64 S 4417.16 E 4421.61 E 4554.98 E Tie On Point Window Point Projected Survey Survey tool program for 12-14AL1 PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description .,....... ," 0.00 11300.00 0.00 11300.00 8768.55 12136.00 8768.55 AK-4 BP _CM (12-14PB1) 8993.57 MWD Magnetic (12-14) ~'" -------------- ~_._._--~----~ - 11 September, 2002 - 13:56 Page30f3 DrillQuest 2.00.08.005 ~L~7E 1 0\~ ~,JJ U:,-í \:::!,) iÆ~iÆ~[[~ / / I / ¡ I TONY KNOWLES, GOVERNOR A'(1A~1iA OILAlQ) GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 AnchorageAK 99519 Re: Prudhoe Bay Unit 12-14ALl BP Exploration (Alaska), Inc. Permit No: 202-122 Surface Location: 527' NSL, 717, WEL, Sec. 18, TI0N, RI5E, UM Bottomhole Location: 4393' SNL, 3979' EWL, Sec. 20, TI0N, RI5E,UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from. other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. The permit is for a new wellbore segment of existing well PBU 12-14A, Permit No 198-146, API 50-029- 20659-01. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a repr~sentative of the Commission to witness a test. of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (fl,*,"dA/ ~. ~-/ ~~~;&chsli Taylor' Chair BY ORDER OF THE COMMISSION DATED this i9( day of June, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA, ALASKA ~IL AND GAS CONSERVATION COMM( -,ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 69.68' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028330 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 12-14AL 1 9. Approximate spud date 07/03/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13100' MD / 8957' TVDss 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 97 Maximum surface 2295 psig, At total depth (TVD) 8800' / 3350 psig Setting Depth T oj) Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) 1650' 11450' 87931 13100' 8957' Uncemented Slotted Liner ./ 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 527' NSL, 717' WEL, SEC. 18, T10N, R15E, UM At top of productive interval 3082' SNL, 3810' EWL, SEC. 20, T10N, R15E, UM At total depth 4393' SNL, 3979' EWL, SEC. 20, T10N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028335, 887' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11520' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couplina 3-3/4" 3-3116" X 2-7/8" 8.81#/6.16# L-80 ST-L 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 14047 feet 8997 feet 14004 feet 9006 feet Length Size 80' 20" 2644' 13-3/8" 11471' 9-5/8" 879' 7" 2741' 4-1/2" \t-iGA- {P/12-/0 L :IF 'f{~ 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Plugs (measured) RECEIVED JUN 11 2002 Junk (measured) CemeAte4ka Oil & Gas Cons. COJMIJission Anchorage 300 sx Permafrost 80' 3250 sx Fondu, 400 sx Arcticset III 2644' 500sxClass'G' 11471' TVD 80' 2644' 8875' 270 sx Class 'G' 340 sx Class 'G' 10614' - 11493' 8348' - 8889' 11306' - 14047' 8775' - 8997' 11710' - 11790', 11810' - 12030', 12190' - 12265', 12335' - 12355', 12435' - 12455', 12855'- 12915', 12965' - 13015', 13250' - 13320', 13440' - 13500', 13725' - 13750', 13895' - 13995' true vertical 8983' - 8995', 8996' - 8994', 8991' - 8991', 8991' - 8991', 8993' - 8994', 9026' - 9028', 9029' - 9029', 9037' - 9040', 9040' - 9038', 9031' - 9030', 9023' - 9008' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Alistair Sherwood, 564-4378 Prepared By Name/Number: Terrie Hubble, 564-4628 Perforation depth: measured 20. Attachments 21. I hereby certify that the Signed Alistair Sherwood Permit Number ":>02.- / Z 2- Conditions of Approval: the best of my knowledge Title CT Drilling Engineer Date API Number 50- 029-20659-60 Samples Required 0 Yes ..ŒI No Hydrogen Sulfide Measures 't8f Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: ',est BapE fo 'SSoo t9~/ . A¡J~1i ~I Plte See cover letter (I IVlI (J ~ for other reauirements Mud Log equired 0 Yes L!I No Directional Survey Required S Yes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU Approved By ,.jHglnal Signed By Form 10-401 Rev. 12-01-8503mmy Oechsli Taylor 0 RCfGTf\TÄ L by order of the commission Date ~l!~t~cate TREE = WELLHEAD = ÄCtûÂTÖR'; . KB. ÈLÈV = SF. ÊlEVu;;; '..n.. .m'"'''''''' ................ KOP= ... ... .~."."...........~....'''''' Max Angle = . . ............... ..n.... Datum MD = oatu¡'¡"Ì'ÝD = (" 12-14A FMC GEN 2 MCEVOY , ",,,... ".. ..... OTIS " 76' 3700' ..~ ." .. , ,. ..... 102 @ 13892' 11461' . . '" . . 8800' SS I I 113-3/8" CSG. 72#. L-80. ID = 12.347" H ~ ' ¡-..41 L Minimum ID = 3.813" @ 2024' 4-1/2" HES X NIPPLE I TOP OF 7" LNR l-i 10614" 1 .. I 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" l-i 11258" 1 I TOP OF 7" LNR l-i 11258" 1 8 , & , I I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" l-i 11309" ~ I TOP OF 4-1/2" LNR l-i 11309" 1 ~ i 19-5/8" CSG, 47#, L-80, 10 = 8.681" l-i I TOP OF WHIPSTOCK l-i I 7" LNR, 26#, 13-CR-80, .0383 bpf, 10 = 6.276" 1--1 ~ n 11471" 11492" 11493" PERFORA TION SUMMARY REF LOG: GRlCCL ANGLEATTOPPERF: 75 @ 11710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 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 3 3/8" 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 3 3/8" 4 13250-13320 0 11/10/98 3 3/8" 4 13440-13500 0 11/10/98 3 3/8" 4 13725-13750 0 11/10/98 3-3/8" 4 13895-13995 0 11/10/98 1 PBTD l-i 14005" ...AFETY NOTES: WAIVERED WELL - T x IA COM M UNICATION, PRODUCING ON NO-FLOW WAIVER. IA x OA COMMUNICATION ON AIL. 70° @ 11678' AND 90° @ 11837' 2024" 1-i4-1/2" HES X NIP, 10 = 3.813" I ~ GAS LIFT MANDRELS DEV TYÆ VLV LATCH 2 MMG RK 48 MMG RK 53 MMG RK 53 MMG RK 49 MMG RK 54 MMG RK 52 KBG2LS INT PORT DA TE ST MD 1VD 1 3349 3349 2 5455 5192 3 7471 6402 4 8515 7013 5 9392 7586 6 10486 8272 7 11099 8647 I 11254" l-i 9-5/8" BAKER S-3 PKR 1 I 11287" 1-i4-1/2"HESXNIP,ID=3.813" 1 r 11309' 1-i4-1/2" WLEG 1 1 l-i ELMO TT NOT LOGGED 1 ~ 7" MILLOUT WINDOW 11493' - 11505' 14-1/2" LNR, 12.6#, L-80,.0152 bpf, 10 = 3.958" l-i 14047' 1 DATE 1981 11/12/98 12/14/00 02/23/01 02/27/02 REV BY DA TE REV BY COMMENTS COMMENTS ORIGINAL COMPLETION SIDETRACKED SIS-SL T CONVERTED TO CANVAS SIS-LG REVISION RNlTP CORRECTIONS PRUDHOE BAY UNIT WELL: 12-14A PERMIT No: 198-1460 API No: 50-029-20659-01 SEe 18, TION, R15E 4474.83 FEL 3499.14 FNL BP Exploration (Alaska) TREE = WELLHEAD = 'AciüÄìbR';; , KB:'"B..EV = ï3F.ELEV ~' " ......om............'" .....h... KOP= ,~'-~~~I.~~; ,," Datum MD = Datum ¡YD = FMC GEN 2 MCEVOY OTIS 76' 12-14A L 1 1 Proposed CTD Sidetrack AFETY NOTES: WAIVERED WELL - T x IA COM M UNICA TION, PRODUCING ON NO-FLOW WAIVER. IA x OA COMMUNICATION ON AlL. 70° @ 11678' AND 90° @ 11837' 3700' '1'" Ö2'@"1'3a92Î 11461' 8800'SS I I 2024' 1'14-1/2" HES X NIP, ID = 3.813" I '" GAS LIFT MANDRELS 113-3/8" CSG, 72#, L-80, ID = 12.347" 1'1 ~4~ ~ ST MD ¡YD DEV TYPE VLV LATCH PORT DATE 1 3349 3349 2 MMG RK L 2 5455 5192 48 MMG RK 3 7471 6402 53 MMG RK Minimum ID = 3.813" @ 2024' 4 8515 7013 53 MMG RK 4-1/2" HES X NIPPLE 5 9392 7586 49 MMG RK 6 10486 8272 54 MMG RK 7 11099 8647 52 KBG2LS INT 1 TOP OF 7" LNR 1'1 10614' I ,. I 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1'1 11258' 1 8 & I 11254' 1'19-5/8" BAKER S-3 PKR 1 '-I I I TOP OF 7" LNR 1'1 11258' 1 I . I 11287' 1'14-1/2" HES X NIP, ID = 3.813" 1 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 1'1 11309' J I 1'14-1/2" WLEG 1 ~ i 11309' I TOP OF 4-1/2" LNR l-i 11309' 1 B 1 1'1 8..MD TT NOT LOGGED 1 PERFORA TION SUMMARY REF LOG: GRlCCL ANGLEATTOPPERF: 75 @ 11710' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 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 3 3/8" 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 33/8" 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 11471' r--.4 11492' ~ 11493' ~ / 8 I 11450' l-i Top of Proposed 3-' Liner 1 I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1'1 I TOP OF WHIPSTOCK 1'1 1 7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" 1'1 .. .L.- 7" MILLOUT WINDOW 11493' - 11505' --- ~II \ \. l' 11520' l-i Mechanical Flow -by Whipstock ./ ~~ \~111620'I'1 3-3/16"X2-7/8"XOI 13-3/4" Open Hole 1 E I&!\ 0 0 0 0 0 0 0 0 0 0 0 o~ 12-7/8" L-80 Pre-drilled Liner 1'1 13100'1 '" 11675'1-i Standing Valve 1 .-" I PBTD 1'1 14005' 1 114047' 1'14-1/2" LNR, 12.6#, L-80, .0152 BPF, 10=3.958"1 DATE 1981 11/12/98 12/14/00 02/23/01 02/27/02 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACKED SIS-SL T CONVERTED TO CANVAS SIS-LG REVISION RNlTP CORRECTIONS DA TE REV BY COMMENTS PRUDHOE BAY UNrr W8..L: 12-14A PERMIT No: 198-1460 API No: 50-029-20659-01 SEC 18, TION, R15E 4474.83 FEL 3499.14 FNL BP Exploration (Alaska) BPX 12-14A L 1 Sidetrack ( Summary of Operations: /' A sidetrack lateral from production well 12-14A will be drilled by Nordic 1 CTO rig. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Screen & Prep Well: Screen - Install dummy GlV's, fluid pack IA & MIT. Fluid pack OA & MIT./ Pressure test wellhead seals & tree valves. Prep - as detailed below is planned to start June 18th, 02 . Set permanent isolation packer with modified check v/v at 11 ,675'md, (-8903'tvd ss) ./' Set a mechanical thru-tbg, flo-by whipstock at 11,520' md, (-8,834' tvdss). . Note: a 10-403 Sundry Permit has not been subitted as the current production intervals are being retained /" Phase 2: Drill and Complete CTD sidetrack: Planned for July 3rd, 02. 2%" coil will be used to drill -1580ft of 3%" OH sidetrack from a window cut in the 4%", l-80 liner at 11,520' - as per the attached plan. The lateral will be completed with an uncemented 33/16" solid & 2* solid./ & slotted liner which is designed to preserve production from the existing perfs, via the PIP with modified check vIvo Mud Program: . Phase 1: Seawater , . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) /' Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 33/16" l-80 solid liner from 11 ,450'md (TOl, -8,793' tvd ss) to 100' outside the window at 11,620' md . 2*" l -80 solid & slotted liner from 11,620' to TO at approx. 13,100' md - solid joints will be run over high Sw intervals. Well Control: . BOP diagram for Nordic 1, coil tubing drilling rig is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. I'" . The annular preventer will be tested to 400 psi and 2,200 psi../ Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . Real time MWO, Gamma Ray & Resistivity logs will be run in the open hole section. Hazards . 12-14A was last tested for H2S on the 3/25/02, and recorded a 30ppm sample concentration. . No faults or natural fracture systems are prognosed along the planned wellbore. If fluid losses were to be experienced thy would be dealt with appropriately, from doing nothing to treating with lCM. Reservoir Pressure Reservoir pressure is estimated to be 3,350 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,295 psi. J - -------~----------~- - BP Amoco Contact Information: Plan: Plan #3 (12-14/Plan#312-14AL 1) Created By: BMj Potnis Date: 4/24/2002 Direct: (907) 267-6613 E-mail: brij,potnis@inteqcom Baker Hughes INTEQ: (907) 267-6600 T ^M ¿ LEGEND - g:1:¡g:m.) - 12-14 (12-14PB1) - Plan#3 12-14AL1 - Plan #3 P.....t w.n~th: Tie on MD: RIø' Ref. o.tum: WELLPATH DETAILS Plan#3 12-14AL 1 500282085880 12.14A 11517.18 INTßQ Azimuths to True North Magnetic North: 26.47. Magnetic Field Strength: 57515nT Dip Angle: 80.79. Date: 4/24/2002 Model: BGGM2001 - -- -~-.-_.--~-~.__. --- bþ Nordic 1 24: 147/111".11:38 58.7Oft V.s~tIo. Ansle 187.00' ~1J~ ~~-= 0.00 ::::'~ 0.00 REFERENCE INFORMATION .: :- '. ]"",", ,r,;: '~''';' ,r,', Well Centre: 12-14, True North ", ,.i,:::'::;~:~:X: ~ :::: E:: ~Ft~T~~~g§~~~~el 69,70 Calculation Method: Minimum Curvature AzI 1 11517.18 as.33 122.88 2 11520.00 85.87 122.80 3 11S40.oo 87.38 123.53 : U~t:::: ~:gg t:~:~: ð 12388.54 87.48 187.88 ., 12818.84 90.78 187.88 : t~'::= ~:= t~:= SECTION DETAILS 1VD +NJ..s +~ DLeg TFace vSec Target ..3522.98 4384.63 0.00 0.00 4421.28 -3524.28 43M.80 12.18 349.00 4422.84 -3533.38 4410.88 8.00 20.00 4434.88 -38efMS 4818.93 12.00 18.00 4840.45 -3950.81 478'7.80 12.00 e5.oo 4922.07 '4 -4187.39 4718.31 12.00 80.00 5159.75 :=::: ==j~ :~~=~ ~I:= ~;:: =~::: 8958.88 -4918.17 4714.28 12.00 -80.00 5852.80 ANNOTATIONS TVÞ MD Annotation +E/-W Shape g~ ~~g~ jg~t~~ ~~ $92g:~ ~~:~g ~&U~ ~ 8930.00 -3991.01 4711.63 Point 8945.00 -4390.90 4761.20 Point ~I íH 11i¡1 ~¡ 8830.31 11817.18 TIP 8831..2 11820.00 KOP '842... 11540.00 1 8.20.88 11818.84 2 8828.81 12118.84 3 8840.74 12388.84 4 81144A. 12818.84 5 8857..1 12888.84 8 8858.88 13100.00 TO 111m . -[1,2.;EO£-..!1L% ~> 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 West(-)/East(+) [100ft/in] E' . pfã¡iÎÍ:r1ž:14AL11 TO I ;'i ~ -r- ,.,m'~'j ~. / L.. .. D:B.m.2-14~L!ThIJ /¡"112:;¡ThL 1 T3,61 / UtJ4AL 1 HÆ - l.:!B:4AL 1 T3,4] ,~ 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 5950 6000 6050 6100 Vertical Section at 167.000 [50ft/in] ----------~--~. - -_u4/24/2002 uu10:49 AM - Obp BP Baker Hughes INTEQ Planning Report ( ... .... INTEQ ¡Company: BPAmOco ¡Field: Prudhoe Bay ¡ Site: PB.DS12 ì Well: 12-14 ¡ WeDpath: Plan#312-14AL 1 ])ate: .. .4/24/2002 Time: ...10:49:51 Co-Ordmate(NE) Referençe: Wen:12.:.14,TrueNorth Vertical (fvn) Referenee: Sys!ef11: Mean~eaLevel Seetion(VS)Refe¡oenee: Well (0.OON.0.00E.161.00Azj) SorveyÇalculation Method: MinirnumCurvature Db: Oracle Page: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 Site: PB DS 12 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5932650.90 ft 697966.79 ft Latitude: Longitude: North Reference: Grid Convergence: 70 13 12.462 N 148 24 9.888 W True 1.50 deg Well: 12-14 12-14 Well Position: Slot Name: 14 70 12 54.933 N 148 24 42.486 W +N/-S -1782.17 ft +E/-W -1122.81 ft I Position Uncertainty: 0.00 ft I Wellpath: Northing: 5930839.99 ft Easting: 696891.17 ft Latitude: Longitude: Plan#3 12-14AL 1 500292065960 Current Datum: 24: 147/1/199811:36 Magnetic Data: 4/24/2002 Field Strength: 57515 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 12-14A 11517.16 ft Mean Sea Level 26.47 deg 80.79 deg Direction deg 167.00 Height 69.70 ft Targets J,\1ap Map .<::~.. Latitude....~"> 57-. Longitude ,~> Name Description. TVD +NÞ.S +E/-W Northing E~ting Deg Min;Sec DegMin See Dip. . Dir. ft ft ft ft ft 12-14AL1 Polygon2.1 0.00 -3861.52 4574.37 5927099.30 701564.44 70 12 16.942 N 148 22 29.746 W -Polygon 1 0.00 -3861.52 4574.37 5927099.30 701564.44 70 12 16.942 N 148 22 29.746 W -Polygon 2 0.00 -3956.73 4962.03 5927014.24 701954.43 70 12 16.003 N 148 22 18.498 W -Polygon 3 0.00 -5011.42 4934.35 5925959.25 701954.27 70 12 5.630 N 148 22 19.321 W -Polygon 4 0.00 -4961.20 4545.51 5925999.31 701564.27 70 12 6.126 N 148 22 30.602 W 12-14AL 1 Fault 1 0.00 -5122.24 4011.08 5925824.38 701034.25 70 12 4.545 N 148 22 46.111 W -Polygon 1 0.00 -5122.24 4011.08 5925824.38 701034.25 70 12 4.545 N 148 2246.111 W -Polygon 2 0.00 -5658.17 5372.57 5925324.17 702409.18 70 11 59.266 N 148 22 6.620 W 12-14AL 1 Fault 2 0.00 -3409.95 4331.12 5927544.34 701309.51 70 12 21.384 N 148 22 36.791 W -Polygon 1 0.00 -3409.95 4331.12 5927544.34 701309.51 70 12 21.384 N 148 22 36.797 W -Polygon 2 0.00 -3766.85 4970.01 5927204.24 701957.45 70 12 17.870 N 148 22 18.263 W 12-14AL1 T2.1 8920.00 -3642.98 4660.67 5927320.00 701645.00 70 12 19.090 N 148 22 27.238 W 12-14AL1 T2.2 8930.00 -3991.01 4771.63 5926975.00 701765.00 70 12 15.667 N 148 22 24.024 W 12-14AL 1 T2.3 8945.00 -4390.90 4761.20 5926575.00 701765.00 701211.734N 148 22 24.334 W 12-14AL 1 T3.8 8957.00 -4913.00 4719.59 5926052.02 701737.02 70 12 6.599 N 148 22 25.551 W 12-14AL 1 T3.7 8960.00 -4888.43 4724.13 5926076.70 701740.92 70 12 6.841 N 148 22 25.418 W 12-14AL 1 T3.6 8961.50 -4863.68 4727.46 5926101.53 701743.60 70 12 7.084 N 148 22 25.321 W 12-14AL 1 T3.4 8963.00 -4813.93 4730.46 5926151.34 701745.30 70 12 7.574 N 148 22 25.234 W 12-14AL 1 T3.5 8963.00 -4838.82 4729.57 5926126.43 701745.06 70 12 7.329 N 148 22 25.260 W Obp BP Baker Hughes INTEQ Planning Report (' ... HA"" ..... LN'TEQ ¡ Company: BPAmoco Date:....,., 4/24/2002 Time: . . .10:49:57 Page: 2 i.. Field: prud~Bay Co--orciinate(NE)..Reference: Well:12-14,T"\JeNorth ¡ Site: PB 0812 'Vertical (TVI»Jleferellce:. System:.MeanSea'.Level ! WeD: 12-14 SeetiOD (VS)Refere~: Weli (Q.OON,O.OOE, 167.00Azi) i WeUpatb: PIan#3 12-14AL1 ~urveyÇalculatiollM:etbod: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 11517.16 8830.31 TIP 11520.00 8831.92 KOP 11540.00 8842.95 1 11819.54 8920.56 2 12119.54 8928.51 3 12369.54 8940.74 4 12619.54 8944.65 5 12869.54 8957.91 6 13100.00 8956.86 TO Plan: Plan #3 Date Composed: 4/24/2002 200' short of Lamar's Plan #1 w/new targets Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Iud Azim TVD +N/..S +E/-W DLS Build Turri TFO Target ft deg deg ft ft ft deg/1 OOftdeg/1 OOft. deg/100ft deg 11517.16 55.33 122.88 8830.31 -3522.98 4394.63 0.00 0.00 0.00 0.00 11520.00 55.67 122.80 8831.92 -3524.25 4396.60 12.19 11.97 -2.82 349.00 11540.00 57.36 123.53 8842.95 -3533.38 4410.56 9.00 8.47 3.65 20.00 11819.54 90.00 131.75 8920.56 -3696.15 4618.93 12.00 11.67 2.94 15.00 12119.54 87.06 167.65 8928.51 -3950.81 4767.80 12.00 -0.98 11.97 95.00 12369.54 87.46 197.68 8940.74 -4197.39 4756.31 12.00 0.16 12.01 90.00 12619.54 90.79 167.86 8944.65 -4444.23 4744.39 12.00 1.33 -11.93 276.00 12869.54 83.25 196.96 8957.91 -4690.81 4734.23 12.00 -3.01 11.64 105.00 13100.00 97.26 173.06 8956.86 -4918.17 4714.28 12.00 6.08 -10.37 -60.00 Survey MD Incl Azim SST\1> N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft. ft deg/100ft deg - -------'-- 11517.16 55.33 122.88 8830.31 -3522.98 4394.63 5927433.01 701375.94 4421.26 0.00 0.00 TIP 11520.00 55.67 122.80 8831.92 -3524.25 4396.60 5927431.80 701377.94 4422.94 12.19 349.00 KOP 11525.00 56.09 122.99 8834.73 -3526.50 4400.07 5927429.64 701381.47 4425.92 9.00 20.00 MWD 11540.00 57.36 123.53 8842.95 -3533.38 4410.56 5927423.04 701392.13 4434.98 9.00 19.90 1 11550.00 58.52 123.90 8848.26 -3538.08 4417.61 5927418.52 701399.30 4441.15 12.00 15.00 MWD 11575.00 61.43 124.77 8860.77 -3550.29 4435.48 5927406.78 701417.48 4457.06 ~.oo 14.81 MWD 11600.00 64.34 125.59 8872.17 -3563.11 4453.66 5927394.44 701435.99 4473.64 12.00 14.37 MWD 11625.00 67.25 126.38 8882.42 -3576.51 4472.11 5927381.53 701454.78 4490.85 12.00 13.99 MWD 11650.00 70.17 127.13 8891.49 -3590.45 4490.77 5927368.08 701473.80 4508.63 12.00 13.67 MWD 11675.00 73.08 127.86 8899.37 -3604.89 4509.59 5927354.14 701492.99 4526.93 12.00 13.40 MWD 11700.00 76.01 128.56 8906.03 -3619.79 4528.52 5927339.74 701512.30 4545.71 12.00 13.17 MWD 11725.00 78.93 129.25 8911.46 -3635.12 4547.51 5927324.91 701531.68 4564.92 12.00 12.98 MWD 11750.00 81.86 129.92 8915.63 -3650.82 4566.50 5927309.71 701551.08 4584.49 12.00 12.83 MWD 11775.00 84.78 130.59 8918.54 -3666.87 4585.45 5927294.16 701570.43 4604.39 12.00 12.72 MWD 11800.00 87.71 131.24 8920.17 -3683.20 4604.30 5927278.32 701589.70 4624.54 12.00 12.64 MWD 11819.54 90.00 131.75 8920.56 -3696.15 4618.93 5927265.77 701604.67 4640.45 12.00 12.60 2 11825.00 89.94 132.41 8920.57 -3699.81 4622.98 5927262.22 701608.81 4644.92 12.00 95.00 MWD 11850.00 89.68 135.39 8920.65 -3717.14 4640.99 5927245.36 701627.27 4665.87 12.00 95.00 MWD 11875.00 89.42 138.38 8920.84 -3735.39 4658.08 5927227.56 701644.82 4687.49 12.00 94.99 MWD 11900.00 89.16 141.37 8921.15 -3754.50 4674.18 5927208.88 701661.42 4709.74 12.00 94.97 MWD 11925.00 88.91 144.36 8921.57 -3774.43 4689.27 5927189.35 701677.02 4732.54 12.00 94.93 MWD 11950.00 88.65 147.35 8922.11 -3795.11 4703.30 5927169.04 701691.58 4755.85 12.00 94.88 MWD 11975.00 88.40 150.34 8922.75 -3816.50 4716.22 5927148.00 701705.06 4779.60 12.00 94.82 MWD 12000.00 88.16 153.33 8923.50 -3838.52 4728.02 5927126.29 701717.42 4803.72 12.00 94.74 MWD 12025.00 87.92 156.33 8924.36 -3861.13 4738.64 5927103.97 701728.63 4828.14 12.00 94.65 MWD 12050.00 87.68 159.32 8925.32 -3884.26 4748.07 5927081.09 701738.66 4852.79 12.00 94.55 MWD 12075.00 87.45 162.31 8926.38 -3907.85 4756.28 5927057.73 701747.48 4877.62 12.00 94.43 MWD ObP BP ( ... SA"" Baker Hughes INTEQ Planning Report IN'TEQ ! . Company: . BPArnoco Date: ... ....4124/2002 TÎlne: .... 10:49:57 Page: 3 ¡Field: . . Prudhoe Bay co-ortiiltate(NJS) .Jleference: W~U:12-14, Tru~Nprth ¡ Site: PB 0512 YertkaJ.(1'~) ~efer~nce: Sy~~m:MeanS~L~vel ; wen: 12-14 Section (VS)~fere~: W~U (O.OON,O.OOE, 167.00Azi) ! Wenpatb: PIan#312-14AL1 SurveyCalculatìonMetbod: Minimum Curvature Db: Oracle Survey MD Inti AziJn SSTVD NIS EJW MapN MapE VS DLS TFO Tool ft d~ deg ft ft ft ft ft. deg/100ft d~ 12100.00 87.23 165.31 8927.54 -3931.83 4763.24 5927033.94 701755.07 4902.56 12.00 94.30 MWD 12119.54 87.06 167.65 8928.51 -3950.81 4767.80 5927015.09 701760.12 4922.07 12.00 94.17 3 12125.00 87.06 168.31 8928.79 -3956.14 4768.94 5927009.79 701761.40 4927.52 12.00 90.00 MWD 12150.00 87.07 171.31 8930.07 -3980.71 4773.36 5926985.35 701766.45 4952.46 12.00 89.97 MWD 12175.00 87.08 174.31 8931.35 -4005.48 4776.48 5926960.67 701770.22 4977.29 12.00 89.81 MWD 12200.00 87.11 177.32 8932.61 -4030.38 4778.30 5926935.83 701772.69 5001.96 12.00 89.66 MWD 12225.00 87.13 180.32 8933.87 -4055.34 4778.82 5926910.89 701773.86 5026.40 12.00 89.51 MWD 12250.00 87.17 183.32 8935.11 -4080.29 4778.02 5926885.93 701773.71 5050.53 12.00 89.36 MWD 12275.00 87.22 186.33 8936.33 -4105.17 4775.92 5926861.00 701772.26 5074.30 12.00 89.21 MWD 12300.00 87.27 189.33 8937.54 -4129.90 4772.52 5926836.19 701769.51 5097.64 12.00 89.06 MWD 12325.00 87.33 192.33 8938.71 -4154.43 4767.83 5926811.55 701765.46 5120.48 12.00 88.92 MWD 12350.00 87.40 195.34 8939.86 -4178.68 4761.86 5926787.16 701760.12 5142.76 12.00 88.77 MWD 12369.54 87.46 197.68 8940.74 -4197.39 4756.31 5926768.31 701755.06 5159.75 12.00 88.64 4 12375.00 87.53 197.03 8940.98 -4202.60 4754.68 5926763.06 701753.57 5164.45 12.00 276.00 MWD 12400.00 87.84 194.04 8941.99 -4226.66 4747.99 5926738.83 701747.51 5186.40 12.00 276.03 MWD 12425.00 88.17 191.06 8942.86 -4251.04 4742.56 5926714.31 701742.72 5208.94 12.00 276.15 MWD 12450.00 88.50 188.08 8943.59 -4275.68 4738.41 5926689.58 701739.21 5232.01 12.00 276.25 MWD 12475.00 88.83 185.10 8944.17 -4300.51 4735.54 5926664.69 701736.99 5255.55 12.00 276.34 MWD 12500.00 89.17 182.11 8944.61 -4325.45 4733.97 5926639.71 701736.07 5279.50 12.00 276.41 MWD 12525.00 89.51 179.13 8944.90 -4350.45 4733.70 5926614.72 701736.45 5303.80 12.00 276.46 MWD 12550.00 89.85 176.15 8945.04 -4375.42 4734.73 5926589.78 701738.13 5328.36 12.00 276.50 MWD 12575.00 90.19 173.17 8945.03 -4400.31 4737.05 5926564.96 701741.11 5353.14 12.00 276.51 MWD 12600.00 90.53 170.19 8944.88 -4425.04 4740.67 5926540.33 701745.37 5378.05 12.00 276.51 MWD 12619.54 90.79 167.86 8944.65 -4444.23 4744.39 5926521.26 701749.59 5397.58 12.00 276.49 5 12625.00 90.62 168.49 8944.58 -4449.57 4745.51 5926515.95 701750.84 5403.03 12.00 105.00 MWD 12650.00 89.84 171.39 8944.48 -4474.18 4749.87 5926491.46 701755.85 5428.00 12.00 105.01 MWD 12675.00 89.07 174.29 8944.72 -4498.98 4752.99 5926466.75 701759.61 5452.86 12.00 105.02 MWD 12700.00 88.29 177.19 8945.30 -4523.90 4754.85 5926441.88 701762.12 5477.56 12.00 104.99 MWD 12725.00 87.52 180.09 8946.21 -4548.88 4755.44 5926416.94 701763.36 5502.03 12.00 104.93 MWD 12750.00 86.76 182.99 8947.46 -4573.83 4754.77 5926391.97 701763.34 5526.20 12.00 104.82 MWD 12775.00 86.00 185.90 8949.04 -4598.71 4752.83 5926367.06 701762.06 5550.00 12.00 104.67 MWD 12800.00 85.26 188.82 8950.94 -4623.43 4749.64 5926342.27 701759.51 5573.36 12.00 104.49 MWD 12825.00 84.52 191.74 8953.17 -4647.92 4745.20 5926317.66 701755.71 5596.24 12.00 104.27 MWD 12850.00 83.81 194.67 8955.71 -4672.13 4739.52 5926293.31 701750.66 5618.55 12.00 104.01 MWD 12869.54 83.25 196.96 8957.91 -4690.81 4734.23 5926274.50 701745.86 5635.56 12.00 103.71 6 12875.00 83.58 196.39 8958.54 -4696.01 4732.67 5926269.27 701744.44 5640.27 12.00 300.00 MWD 12900.00 85.09 193.78 8961.01 -4720.03 4726.20 5926245.09 701738.60 5662.22 12.00 300.07 MWD 12925.00 86.61 191.19 8962.82 -4744.37 4720.81 5926220.62 701733.84 5684.72 12.00 300.32 MWD 12950.00 88.14 188.60 8963.96 -4768.97 4716.52 5926195.92 701730.20 5707.73 12.00 300.51 MWD 12975.00 89.67 186.02 8964.44 -4793.76 4713.34 5926171.05 701727.66 5731.16 12.00 300.63 MWD 13000.00 91.20 183.44 8964.25 -4818.67 4711.28 5926146.10 701726.25 5754.97 12.00 300.68 MWD 13025.00 92.73 180.86 8963.40 -4843.63 4710.34 5926121.12 701725.96 5779.09 12.00 300.66 MWD 13050.00 94.25 178.27 8961.88 -4868.58 4710.53 5926096.18 701726.80 5803.44 12.00 300.57 MWD 13075.00 95.76 175.67 8959.70 -4893.45 4711.84 5926071.36 701728.77 5827.97 12.00 300.41 MWD 13100.00 97.26 173.06 8956.86 -4918.17 4714.28 5926046.72 701731.85 5852.60 12.00 300.19 TD All Measurements are from top of Riser 6/6/2002 '- Q) en -- a: top of bag Schlumber. er BAG . I I I " bttm of bag middle of flow cross Blind/Shears .................., I TOTs /' 2 3/811 Pipe/Slips _...-,/"""'" -- r-- Mud Cross Mud Cross -- '-- middle of blind/sherars middle of pipe I slips middle of variable bore 2 3/811 - 3 1/211 VBR I .................- // TOTs middle of pipe/slips I 2 3/811 Pipe/Slips _.../........-- , Flow Tee áJI;~~~w"i.'.\..- ""~"">'''Ø!.....¿''-l-''<\.'''~''~'''\'-';,,(~'--' c::.~><-,..<,,~-,.,. ~ H 206920 DATE INVOICE I CREDIT MEMO OS/23/02 CK052302C THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BPiEXRLORATIPN,(ALASKA) '.INC. , P.O. BeX19661;2 , . ANCHORAGE,ÄLASRA995f9..6612 PAY TO.THE ORDER OF .Äl.ãska.. .QitrcSii{Gas CÖnservå.tion.Coxnmission '3:.l~ . W7th Ave, ste 100 .l¥i:icho~àgei'AK 99501 DESCRIPTION GROSS Permit To Drill Fee PIs call Terrie Hubble X4628 \?-- \y~~\ TOTAL ~ DATE OS/28/02 CHECK NO. H206920 VENDOR DISCOUNT NET $100.00 RECE\VED JU~~ 1 '\ 20Q2 " ,,- "H~imi~§ii.~b~ 0$1 & ~s t,{)H~" ',OJ' ~ è.oclïor~Qf' $100.00 No. H 206920 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY <BANK CLEVELAND, OHtÐ 56-389 412 /fJ. r:.~"'...... ........."..'.l'" ,11"". ¡dl~..1 ,{".,¡' ". ''''I 1'1.\: - . - . J t. . ",t. 1.,.lf. .11..1. 11111'/ 1\tI,I ,m", .,,,,.., ..,,, CONSOLIDATED COMMERCIAL ACCOUNT DATE AMOUNT *****$100.00******* ***May 28,2002** III 20 b ti 20". 1:0.... 20 :is I:i 51: 008....... tilll NOTVALlD AFTER 120 DAYS \2-~Jß~LL- H "~" .. ~, CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORA TION INJECTION WELL INJECTION WELL RED RILL Rev: 5/6/02 C\jody\templates ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /'ðu 12--/~/JL / CHECK WHAT APPLIES ADD-ONS (OPTIONS) "CLUE" MUL TI LATERAL The permit is for a new wellbore segment of existing well ¡t!Jdq J2. -1!iß., Permit No/ff-/'" API No. 56'" ot.9 - :<'0 '$.,.." I (If API number last two (2) Production should continue to be reported as a function of digits are between 60-69) the original API number stated above. v PILOT HOLE (PH) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SP ACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. " 'WELL PERMIT CHECKLIST COMPANY f/J)t WELL NAME /'Bt' J /Z.-.j9A¿J PROGRAM: Exp - Dev.,X Redrll- SeM, - Wellbore segX- Ann. disposal para req- FIELD & POOL CSlo)..S"'"~ INITCLASS ~ /-e:>;/ GEOLAREA r90 UNIT# //ó/~ ON/OFFSHORE OoN ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ry) N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~j~ .91Tbz.- 12. Permit can be issued without administrative approval.. . . . . Y N ff~ Fý~ 13. Can permit b~ approv~d before 15-day wait.. . . . . . . . . . ~Y..N "" ENGINEERING 14. Conductor stnng provided. . . . . . . . . . . . . . . . . . . - N 15. Surface casing protects all known USDWs. . . . . . . . . . . ,. N I 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N tJ k' 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -¥-N- ' 18. CMT will cover all known productive horizons. . . . . . . . . . '~ N- s(ol(ed 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 'ðY N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . éf) N C. T J) fA... 21. If a re-drill, has a 10-403 for abandonment been approved. . . -¥-N-N/}t F-iovV - b'1 whÅps þJC(t.. 22. Adequate wellbore~separation proposed~. . . . . . . . . .-. . éP N 23. If diverter required, does it meet regulations. . . . . . . . . . ~ NIA 24. Drilling fluid progra. m sChe. matic & equip list adequate. . . . . ICy¿ N. N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . . N A~PR DATE 26. BOPE press rating appropriate; test to 3500 psig. N jlte;. P 2- z.qS fSt'. 1\ W6Á-' (plrL/O~L 27. Choke manifotdcomplies w/API RP-53 (May 84). . . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . , N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N "3 0 pp~ . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y CbD 31. Data presented on potential overpressure zones. . . . . .. ~N ¿ Ll 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y /( '/ r' APPR ~AJE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N .. ~ b/ýt?þZ-' 34. Contact name/phone for weekly progress reports [exploratory onlY.. N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y. N (D) will not damage producing formation or impair recovery from a N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPc#'-, JDH '-.J H- COT WGA W6V DTS 06!"/0¿ ) GEOLOGY APPR DATE P4~~ Commentsllnstructions: G:\geology\permits\checklist. doc Well H ¡story 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 infonnation. information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically , . organize this category of information. ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 12 15:20:50 2003 Reel Header Service name.............LISTPE Date.....................03/03/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/03/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. ( Scientific Technical Services Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW2213800000 B. JAHN G. SARBER / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MiiV2213800000 B. JAHN G. SARBER / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MW2213800000 B. JAHN SARBER I SEV # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 12-14ALl 500292065960 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 12-MAR-03 MWD RUN 2 MW2213800000 B . JAHN C. SEVCIK / MViJD RUN 6 MW2213800000 B. JAHN G. SARBER I MWD RUN 9 MW2213800000 B. JAHN SARBER / SEV 18 ION 15E 527 717 69.68 40.88 MWD RUN 3 MW2213800000 B. JAHN C. SEVICK / HWD RUN 7 MW2213800000 B. JAHN SARBER I SEV OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ::¿x L~};)- / d;) / I &:J3 d (, ( 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 3.750 4.500 11555.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A CEMENT PLUG IN THE 12-14A Ll PBl. THE TOP OF THE PLUG WAS AT ABOUT 11810' MD. 4. DURING THE COURSE OF A MAD PASS PRIOR TO RUN 3 (TO ACQUIRE RESISTIVITY DATA OVER THE RUN 2 INTERVAL)IN THE 12-14A L1 PBl WELLBORE, IT WAS OBSERVED THAT THE DGR VALUES DID NOT CORRELATE WITH THOSE OF RUN 2. POST RUN 3 MAD PASS DGR DATA ALSO DID NOT CORRELATE. AFTER POOH TO CHANGE THE GAMMA PROBE, IT WAS DISCOVERED THAT THE MUD SYSTEM WAS RADIOACTIVE (PROBABLY DUE TO SCALE FROM THE PRODUCTION TUBING). THE MUD SYSTEM WAS SUBSEQUENTLY CHANGED OUT. A MAD PASS WAS PERFORMED WHILE RIH FOR RUN 4; 6 FEET OF NEW HOLE WERE DRILLED; AND THE DECISION'V\JAS MADE TO DO AN OPEN-HOLE SIDETRACK. MAD PASS DATA WERE ACQUIRED WHILE POOH. THESE POST RUN 4 DGR DATA ARE SUBSTITUTED FOR THE INVALID RUN 3 DATA. THE LAST RESISTIVITY DATA ACQUIRED (I.E., THOSE OF THE VARIOUS MAD PASSES) OVER THE RUN 2 AND RUN 3 INTERVALS WERE MERGED/SPLICED AS APPROPRIATE. FOR THE 12-14A Ll WELLBORE, EWR DATA FOR THE INTERVAL OF RUNS 5 - 8 WERE ACQUIRED AFTER RIH FOR RUN 9, BUT PRIOR TO COMMENCEMENT OF DRILLING ON RUN 9. NO SEPARATE MAD PASSES ARE PRESENTED. 5. tvIWD RUNS 1, 3, AND 9 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 2, 5, & 8 COMPRISED DIRECTIONAL AND DGR ONLY. MWD RUNS 6 & 7 COMPRISED DIRECTIONAL AND NATURAL GAMMA TOOL (PCG) UTILIZING SCINTILLATION DETECTORS. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. ..., I. MWD RUNS 1, 2, 3, 5 - 9 REPRESENT WELL 12-14A Ll WITH API#: 50-029- 20659-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12884'MD/8963'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) . ( SEME' = SMOOTHED SPACING) . SEDP = SMOOTHED SPACING) . SFXE = SMOOTHED $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPM RPS RPX RPD ROP $ 1 ( PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM PHASE SHIFT-DERIVED RESISTIVITY (DEEP FORMATION EXPOSURE TIME. clipped curves; all bit runs merged. .5000 START DEPTH 11525.0 11539.0 11539.0 11539.0 11539.0 11563.0 11571. 5 STOP DE PTH 12840.0 12853.0 12853.0 12853.0 12853.0 12853.0 12884.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 5 6 7 8 9 # REMARKS: MERGED MAIN PASS. $ MERGE TOP 11525.0 11678.5 11647.5 11810.0 11822.0 11824.0 11829.0 11900.0 MERGE BASE 11678.5 11810.0 11693.0 11822.0 11824.0 11829.0 11900.0 12884.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units...... . . ., . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR W;';¡D API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 ( (' FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11525 12884 12204.5 2719 11525 12884 ROP MWD FT/H 0.13 2017.74 86.5939 2626 11571.5 12884 GR MWD API 17.62 536.54 95.2962 2631 11525 12840 RPX MWD OHMM 0.14 2000 35.0025 2629 11539 12853 RPS MWD OHMM 0.13 2000 40.4492 2629 11539 12853 RPM MWD OHMM 0.1 2000 37.3922 2629 11539 12853 RPD MWD OHMM 0.6 2000 33.6828 2581 11563 12853 FET MWD HOUR 0.2508 107.31 12.3756 2629 11539 12853 First Reading For Entire File..........11525 Last Reading For Entire File...........12884 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPH FET RPD ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 11525.0 11539.0 11539.0 11539.0 11539.0 11563.0 11571. 5 STOP DEPTH 11634.0 11647.0 11647.0 11647.0 11647.0 11647.0 11678.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEHORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUH ANGLE: MAXIMUM ANGLE: 14-AUG-02 Insite 4.3 Memory 11678 . 0 11570.0 11678.0 59.1 68.8 # ( TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OH~1) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: 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..................O Data Specifica'tion Block Type..... 0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value....................... -999 Depth Units. . . . . . . . . . . .. . . . . . . . . . . Datum Specification Block sub-type...O ( TOOL NUMBEE 72829 126583 3.750 11555.0 Flo Pro 8.60 7.0 9.0 23000 9.2 .175 .100 .242 .300 92.0 166.1 92.0 92.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWDOI0 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MV'ifD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET \1WD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11525 11678.5 11601. 8 308 11525 11678.5 ROP MWDOI0 FT/H 0.13 319..23 36.1706 215 11571.5 11678.5 GR MWDOI0 API 86.73 536.54 387.064 219 11525 11634 RPX MWD010 OHMM 0.14 1970.36 137.681 217 11539 11647 RPS MWD010 OHMM 0.13 2000 275.49 217 11539 11647 RPM MWD010 OH1'1M: 0.1 1946.42 246.698 217 11539 11647 RPD MWD010 OH1'1M: 13.53 216.64 68.5671 169 11563 11647 FET MWD010 HOUR 0.5454 2.0007 1.45493 217 11539 11647 First Reading For Entire File..........11525 Last Reading For Entire File...........11678.5 File Trailer (' Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 F i 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER~ DEPTH INCREMENT~ # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 (' header data for each bit run in separate files. 2 .5000 START DEPTH 11634.5 11679.0 STOP DEPTH 11782.0 11810.0 # LOG HE.ADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION~ DOWNHOLE SOFTWARE VERSION~ DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT) ~ TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) ~ HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 (OH~~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 15-AUG-02 Insite 4.3 Memory 11810.0 11678.0 11810.0 59.1 68.8 TOOL NUMBER 69706 3.750 11555.0 Flo Pro 8.60 7.0 9.2 23000 12.6 .175 .090 .242 .300 72.0 169.0 72.0 72.0 ( ( # TOOL ST_~DOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units............... ........ Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11634.5 11810 11722.3 352 11634.5 11810 ROP MWD020 FT/H 1. 39 273.65 77.6548 263 11679 11810 GR MWD020 API 19.91 416.93 78.8378 296 11634.5 11 782 First Reading For Entire File..........11634.5 Last Reading For Entire Fi1e...........11810 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 FE e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name...... ...... .STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUlI'lBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPM RPS $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 11647.5 11647.5 11647.5 11647.5 11647.5 STOP DEPTH 11693.0 11693.0 11693.0 11693.0 11693.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction.. .... .. . .. . . . . . . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( 15-l\UG-02 Insite 4.3 Memory 11693.0 11647.5 11693.0 87.2 93.1 TOOL NUMBER 126583 3.750 11555.0 Fio Pro 8.60 7.0 9.2 23000 13.0 .175 .090 .242 .300 72.0 155.0 72.0 72.0 Name Service Order Units Size Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MWD030 OHMM 4 1 68 4 2 RPS MWD030 OHMM 4 1 68 8 3 RPM MWD030 OHMM 4 1 68 12 4 RPD MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11647.5 11693 11670.3 92 11647.5 11693 RPX HWD030 OHMM 14.09 124.88 68.4904 92 11647.5 11693 RPS MWD030 OHMM 13.4 351.08 79.0107 92 11647.5 11693 ( ,( RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR 11. 7 3 13.55 9.0964 2000 793.65 17.8717 111.136 85.9045 14.8661 92 92 92 11647.5 11647.5 11647.5 11693 11693 11693 First Reading For Entire File..........11647.5 Last Reading For Entire File...........11693 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ La Previous File Name.......STSLIB.OO4 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 5 .5000 START DEPTH 11782.5 11810.5 STOP DEPTH 11793.5 11822.0 # 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: 17-AUG-02 Insite 4.3 Memory 11822.0 11810.0 11822.0 85.6 85.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 72829 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11555.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Flo Pro 9.20 7.0 9.0 90000 6.4 ( ( RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .062 .020 .080 .080 65.0 160.0 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ... . . . . . . . . . . . . . . . . . . . -999 Depth Units........ . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11782.5 11822 11802.3 80 11782.5 11822 ROP MWD050 FT/H 3.04 6.95 5.03083 24 11810.5 11822 GR MWD050 API 30.63 48.63 37.7765 23 11782.5 11 793.5 First Reading For Entire File..........11782.5 Last Reading For Entire File...........11822 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name............... .STSLIB.006 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 6 header data for each bit run in separate files. 6 ( DEPTH INCREMENT: .5000 .II 11" FILE SUJI1MARY VENDOR TOOL CODE GR ROP $ START DEPTH 11794.0 11822.5 STOP DEPTH 11795.5 11824.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units..... . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( l8-AUG-02 Insite 7.75 Memory 11824.0 11822.0 11824.0 85.6 85.6 TOOL NUMBER TLG033 3.750 11555.0 Flo Pro 9.20 7.0 9.2 90000 6.8 .062 .020 .080 .080 65.0 175.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 First Last Name Service Unit DEPT FT ROP ~~D060 FT/H GR MWD060 };.,.PI Min 11 794 11. 55 55.89 Max 11824 97.47 65.43 First Reading For Entire File..........11794 Last Reading For Entire File...........11824 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO7 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 File Type... .............LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 Mean Nsam 11809 61 71. 02 4 61. 305 4 ( Reading 11 794 11822.5 11 794 Reading 11824 11824 11795.5 header data for each bit run in separate files. 7 .5000 START DEPTH 11796.0 11824.5 STOP DEPTH 11800.5 11829.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (l'-1EMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 18-AUG-02 Insite 7.75 Memory 11829.0 11824.0 11829.0 85.6 85.6 TOOL NUMBER TLG033 3.750 11555.0 Flo Pro 9.10 7.0 9.0 90000 ( 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: 6.8 .062 .020 .080 .080 65.0 175.4 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spa'cing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11796 11829 11812.5 67 11 796 11829 ROP MWD070 FT/H 1. 79 105.76 39.367 10 11824.5 11829 GR MWD070 API 67.76 81.18 74.947 10 11796 11800.5 First Reading For Entire File..........11 796 Last Reading For Entire File...........11829 File Trailer Service name.............STSLIB.007 Service Sub Level Name.... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.008 Physical EOF File Header Service name............... STSLIB. 008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OO7 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and 8 log header data for each bit run in separate files. ( BIT RUN NUMBER: DEPTH INCREMENT: # FILE Sill1MARY VENDOR TOOL CODE GR ROP $ 8 .5000 START DEPTH 11801.0 11829.5 STOP DEPTH 11872.5 11900.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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: M.ìl..TRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sUb-type...O ( 18-AUG-02 Insite 4.3 Memory 11900.0 11829.0 11900.0 85.6 85.6 TOOL NUMBER 72829 3.750 11555.0 Flo Pro 9.10 7.0 9.0 90000 6.5 .062 .020 .080 .080 65.0 170.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1. 68 0 1. ROP MWD080 FT/H 4 1. 68 4 2 GR MWD080 API 4 1 68 8 3 ( ( First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11801 11900 11850.5 199 11801 11900 ROP MWD080 FT/H 2.06 188.27 84.6509 142 11829.5 11900 GR MWD080 API 17.62 75.03 40.4933 144 11801 11872.5 First Reading For Entire File..........11801 Last Reading For Entire File...........11900 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/03/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.009 Physical EOF File Header Service name.............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physi.cal Record.. 65535 File Type................ LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 9 header data for each bit run in separate files. 9 .5000 START DEPTH 11693.5 11693.5 11693.5 11693.5 11693.5 11873.0 11900.5 STOP DEPTH 12853.0 12853.0 12853.0 12853.0 12853.0 12840.0 12884.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 20-AUG-02 Insite 4.3 Memory 12844.0 11900.0 12844.0 82.9 94.5 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 69706 126588 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH (FT): 3.750 11555.0 ( # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 9.20 7.0 8.8 90000 5.8 .062 .020 .080 .080 65.0 17 9.0 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units........ . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RH1 MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11693.5 12884.5 12289 2383 11693.5 12884.5 ROP MWD090 FT/H 0.39 2017.74 94.6822 1969 11900.5 12884.5 GR MWD090 API 28.12 412.42 69.7295 1935 11873 12840 RPX JvlWD090 0 HJvW 0.24 2000 24.0705 2320 11693.5 12853 RPS JvlWD090 OHMM 0.39 2000 16.9357 2320 11693.5 12853 RPM MWD090 OHMM 0.45 2000 14.8905 2320 11693.5 12853 RPD MWD090 OHMM 0.6 2000 29.0708 2320 11693..5 12853 FET MWD090 HOUR 0.2508 107.31 13.2983 2320 11693.5 12853 First Reading For Entire File..........11693.5 Last Reading For Entire File...........12884.5 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/12 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.010 (, Physical EOF Tape Trailer Service name.... .........LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. ...............UNKNOv~ Continuation Number......Ol Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Reel Trailer Service name.............LISTPE Date.....................03/03/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. ( Scientific Technical Services Scientific Technical Services ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 11 08:40:55 2003 Reel Header Service name.............LISTPE Date.....................03/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Oi Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date.....................03/03/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW2213800000 B. JAHN G. SARBER / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW2213800000 B. JAHN C. SEVCIK / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 12-14AL1 PB1 500292065971 BP Exploration (Alaska) Sperry-Sun Drilling Services ll-MAR-03 MWD RUN 2 MW2213800000 B. JAHN C. SEVCIK / MWD RUN 3 MW2213800000 B. JAHN C. SEVICK / 18 iON 15E 527 717 69.68 40.88 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 11555.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: fJ' :9œ~'/¿}d / I f£,33 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT ABOUT 11555' MD. 4. DURING THE COURSE OF A MAD PASS PRIOR TO RUN 3 (TO ACQUIRE RESISTIVITY DATA OVER THE RUN 2 INTERVAL) IT WAS OBSERVED THAT THE DGR VALUES DID NOT CORRELATE WITH THOSE OF RUN 2. POST RUN 3 MAD PASS DGR DATA ALSO DID NOT CORRELATE. AFTER POOH TO CHANGE THE GAMMA PROBE, IT WAS DISCOVERED THAT THE MUD SYSTEM WAS RADIOACTIVE (PROBABLY DUE TO SCALE FROM THE PRODUCTION TUBING). THE MUD SYSTEM WAS SUBSEQUENTLY CHANGED OUT. A MAD PASS WAS PERFORMED WHILE RIH FOR RUN 4; 6 FEET OF NEW HOLE WERE DRILLED; AND THE DECISION WAS MADE TO DO AN OPEN-HOLE SIDETRACK. MAD PASS DATA WERE ACQUIRED WHILE POOH. THESE POST RUN 4 DGR DATA ARE SUBSTITUTED FOR THE INVALID RUN 3 DATA. THE LAST RESISTIVITY DATA ACQUIRED (I.E., THOSE OF THE VARIOUS MAD PASSES) OVER THE RUN 2 AND RUN 3 INTERVALS WERE MERGED/SPLICED AS APPROPRIATE. NO SEPARATE MAD PASSES ARE PRESENTED. 5. MWD RUNS 1, 3, AND 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 COMPRISED DIRECTIONAL AND DGR ONLY. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 4 REPRESENT WELL 12-14A L1 PBl WITH API#: 50-029-20659-71. THIS WELL REACHED A TOTAL DEPTH (TO) OF 12136'MD/8924'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. $ File Header Service name.............STSLIB.OO1 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generatìon.......03/03/11 Maximum Physical Record..65535 ( File Type.............. ..LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUJv!MARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 11525.0 11539.0 11539.0 11539.0 11539.0 11539.0 11571.5 STOP DEPTH 12091.0 12104.0 12104.0 12104.0 12104.0 12104.0 12135.5 ( # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 11525.0 11678.5 11832.5 12129.0 MERGE BASE 11678.5 11832.5 12129.0 12135.5 # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log dept,h units........... Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS Míl'JD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR Min 11525 0.13 12.75 0.14 0.13 0.1 0.08 0.3092 Max 12135.5 2453.46 536.54 1970.36 2000 2000 2000 29.9111 Mean 11830.3 79.6637 129.403 50.012 83.1966 82.5948 102.97 6.03765 Nsam 1222 1129 1133 1131 1131 1131 1131 1131 First Reading For EntLr::e File..........11525 First Reading 11525 11571.5 11525 11539 11539 11539 11539 11539 Last Reading 12135.5 12135.5 12091 12104 12104 12104 12104 12104 ( Last Reading For Entire File...........12135.5 File Trailer service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/03/11 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/11 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.001 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 11525.0 11539.0 11539.0 11539.0 11539.0 11539.0 11571. 5 # LOG HEADER D.A.TA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ STOP DEPTH 11634.0 11647.0 11647.0 11647.0 11647.0 11647.0 11678.5 14-AUG-02 Insite 4.3 Memory 11678.0 11570.0 11678.0 59.1 68.8 BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 72829 126583 # 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): 3.750 11555.0 FIo Pro 8.60 .0 9.0 23000 9.2 ( ( RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .175 .100 .242 .300 92.0 166.1 92.0 92.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset, Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT!H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11525 11678.5 11601. 8 308 11525 11678.5 ROP MWD010 FT/H 0.13 319.23 36.1706 215 11571.5 11678.5 GR MWD010 API 86.73 536.54 387.064 219 11525 11634 RPX MWD010 OHMM 0..14 1970.36 137.681 217 11539 11647 RPS MWDOI0 OHMM 0.13 2000 275.49 217 11539 11647 RPM MWDOI0 OHMM 0.1 1946.42 246.698 217 11539 11647 RPD MWDOI0 OHMM 0.08 2000 260.63 217 11539 11647 FET MWD010 HOUR 0.5454 2.0007 1.45493 217 11539 11647 First Reading For Entire File..........11525 Last Reading For Entire File...........11678.5 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/11 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOr File Header Service name............ .STSLIB. 003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/11 ( Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Corn,¡nent Record FILE HEADER FILE NUMBER: R.A.W MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE Sill1MARY VENDOR TOOL CODE GR ROP $ 3 ( header data for each bit run in separate files. 2 .5000 START DEPTH 11634.5 11679.0 STOP DEPTH 11805.0 11832.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: Mfu'UMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... 15-AUG-02 Insite 4.3 Memory 11832.0 11678.0 11832.0 59.1 68.8 TOOL NUMBER 69706 3.750 11555.0 FIo Pro 8.60 .0 9.2 23000 12.6 .000 .000 .000 .000 .0 169.0 .0 .0 ( ( Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11634.5 11832.5 11733.5 397 11634.5 11832.5 ROP MWD020 FT/H 1.39 273.65 82.6721 308 11679 11832.5 GR MWD020 API 19.91 416.93 72.8943 342 11634.5 11805 First Reading For Entire File..........11634.5 Last Reading For Entire File...........11832.5 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/l1 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO4 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/11 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 11647.5 11647.5 11647.5 11647.5 11647.5 11805.5 11833.0 STOP DEPTH 12098.5 12098.5 12098.5 12098.5 12098.5 12085.5 12129.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 15-AUG-02 Insite 4.3 Memory 12130.0 11832.0 12130.0 87.2 93.1 # ( TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTRO}1AG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S C~SING 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 TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MA.TRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O ( TOOL NUMBER 72829 126583 3.750 11555.0 FloP ro 8.60 .0 9.2 23000 13.0 .175 .090 .242 .300 72.0 155.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHHM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11647.5 12129 11888.3 964 11647.5 12129 ROP MWD030 FT/H 0.22 2453.46 93.5848 593 11833 12129 GR MWD030 API 12.75 243.29 64.2786 561 11805.5 12085.5 RPX MWD030 OHJI1tv! 0.38 145.39 29.0408 903 11647.5 12098.5 RPS MWD030 OHMM 0.33 351. 08 34.0826 903 11647.5 12098.5 RPM MWD030 OHMM 0.43 2000 40.7831 903 11647.5 12098.5 RPD MWD030 OHMM 0.3 2000 54.4209 903 11647.5 12098.5 FET MWD030 HOUR 0.3092 18.9656 6.84854 903 11647.5 12098.5 First Reading For Entire File..........11647.5 Last Reading For Entire File...........12129 File Trailer (' Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/11 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/11 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 ( header data for each bit run in separate files. 4 .5000 START DEPTH 12086.0 12099.0 12099.0 12099.0 12099.0 12099.0 12129.5 STOP DEPTH 12091. 0 12104.0 12104.0 12104.0 12104.0 12104.0 12135.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOF'rWARE 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: MA...ì(IMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 17-AUG-02 Insite 4.3 Memory 12136.0 12130.0 12136.0 87.8 87.8 TOOL NUMBER 69706 126583 3.750 11555.0 Flo Pro 8.60 .0 8.9 22000 8.4 .000 .090 .000 .0 173.0 .0 ( MUD è.í\¡{E; At 1'1'1': .000 . c NEUTRON TOOL P.ATRIX: HATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): E\~R FREQUE~¡CY (HZ) : # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Clìanne 1 DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4. 1 68 12 4 RPS MWD040 OHMM 4. 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12086 12135.5 12110.8 100 12086 12135.5 ROP MWD040 FT/H 27.28 236.88 92.6869 13 12129.5 12135.5 GR MWD040 API 72.5 84.14 77.8727 11 12086 12091 RPX J.VWiJD040 OHMM 29.72 78.42 42.0755 11 12099 12104 RPS MWDO 40 OHMM 94.34 1079.46 321. 59 11 12099 12104 RPH MWDO 40 OHMM 92.26 961. 27 277 . 639 11 12099 12104 RPD MWD040 OHMM 366.39 2000 978.248 11 12099 12104 FET MWD040 HOUR 29.8479 29.9111 29.8756 11 12099 12104 First Reading For Entire File..........12086 Last Reading For Entire File...........12135.5 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/11 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Physical Eor Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 03/ 11 0 rig in. . . . . . . . . . . . . . . . . . . ST S Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services (" R.eel 'l'raller Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 03/ 11 Origin. '...'..'.' ....... .STS .....,.... ._., ~"t.-., ~ ""'''''''''.'''''..r---.:"-"'':''.'r r\t::'t:'..L l'id.E~~............................... Ul\!r\.l'l,-IV'¥l"l Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. E'hysìcal t:;OE Pl"<isical EOF End Of LIS File (, Scientific Technical Services