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198-072
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~'~-' ©7'~,_ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other -Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned' by: Beverly Mildred Daretha Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is/ i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: D Oil DGas D Plugged a Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 a Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 9/23/2003 198-072 303-226 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/25/1998 50- 029-20339-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 07/22/1998 PBU 07-14A 511' SNL, 314' WEL, SEC. 33, T11N, R14E, UM 8. Elevation in feet (indicate KB, OF, etc.) 15. Field and Pool Top of Productive Horizon: 4235' NSL, 1020' EWL, SEC. 27, T11 N, R14E, UM KBE = 64' Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 4673' NSL, 58' EWL, SEC. 27, T11N, R14E, UM 11600' + 8930' Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Lease Designation and Serial No. Surface: x- 675869 y- 5950406 Zone- ASP4 11947' + 8920' Ft ADL 028309 TPI: x- 677083 y- 5955183 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 676110 y- 5955597 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes aNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD, LDL, GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE ... Top~ ,BOTTOM' ,.,SIZE" ,CEMENTINGRECORD.. . ' AMOUNT PULLED .. 20" 94# H-40 Surface 71' 30" 243 sx Arcticset 13-3/8" 72# L-80 Surface 2665' 17-1/2" 4200 sx AS II 9-518" 47# L-80 1 SOO-95 Surface 10524' 12-1/4" 1200 sx Class 'G' 2-718" 6.4# L-80 10546' 11879' 3-3/4" 70 sx LARC 23. Perforations open to Production (MD + TVD of Top and 24.. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2", 17#, L-80 9809' 9803' MD TVD MD TVD 4-1/2", 12.6#, N-80 9809' - 9913' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1 0650' Set CIBP ,.- 10362' P&A with 40 Bbls Class 'G' / 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED + OIL-BBL GAs-McF W A TER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attac~'CË1V~[)sary). Submit core chips; if none, state "none". , None :s)Cj~\I~~IN¡j~~Jr, DEI~ ~ @ 2003 DEC - 2 2003 BIIS Bf 1.. DEC ~ 14103 ORIGINAL Alaska Oil & Gas Cons. Commission A .1 I""""" --- ~úl \'1-\\( Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE l, t-- 2&. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sadlerochit 10189' 8451' None Zone 1 B 10804' 8889' RECEIVED DEC - 2 2003 A'aska Oi' & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date l~() PBU 07-14A Well Number 198-072 303-226 Permit No.1 A roval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". 0 ;~( \ G \ N A L ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Well: Field: API: Permit: Date 07-14B Prudhoe Bay Unit 50-029-20339-02 203-142 Accept: Spud: Release: Rig: 1 0102/03 1 0106/03 1 0/21 103 Nordic #1 "., "...".. "."."'",. ., ""."'."".""",..,,,... PRE-RIG WORK 09/10/03 ATTEMPT TO PULL RCP LINER TOP PACKER, FISH WIRE. 09/11/03 FISHED ALL OF WIRE AND TOOLSTRING. NOTE: UNABLE TO PULL RCP WI .125 WIRE. ANOTHER UNIT WILL COME BACK WI BRAIDED LINE. RIGGED UP BRAIDED LINE LRS PUMPED DOWN TBG TO KNOCK DOWN WELL HEAD PRESSURE. CURRENTLY RUNNING IN WI 4" GS TO PULL RCP. 09/12/03 ATTEMPTED TO PULL RCP WI BRAIDED LINE (NO SUCCESS). 09/14/03 RIH WITH RCP FISHING TOOL. LATCHED TO RCP. GAVE 50 JAR LICKS (15K OVER PULL) NO MOVEMENT. RELEASED FROM RCP AND POOH TO CUT PIPE AND REDRESS TOOLS. RE- DRESS TOOLS, RE-KILL WELL WITH COLD WATER, RBIH. 09/15/03 RBIH WITH BHA #1. PUMP 60 DEGREE 1 % KCL DOWN BACKSIDE TO COOL RCP. SET DOWN AND LATCH RCP AT 9826' CTMD. HIT 48 LICKS WIO PUMPING. 2 LICKS PUMPING. NO MOVEMENT. JAR DOWN TO RELEASE AND POOH. CUT PIPE AND REDRESS RCP PULLING TOOL AND RBIH WITH BHA #1. SET DOWN AND LATCH RCP AT 9826', HIT 10 LICKS. PUMP 7 BBLS HCL OVER RCP. WAIT 1HR. GIVE 10 JAR LICKS. NO MOVEMENT, PUMP ANOTHER 7BBLS HCL OVER RCP. BACKFLOW ACID ACROSS RCP & WAIT 45 MINS. GIVE 10 JAR LICKS. NO MOVEMENT. FLUSH AND PUMP FINAL 10 BBLS HCL OVER RCP. WAIT 20 MINS. GIVE 20 JAR LICKS. NO MOVEMENT. DOWN JAR TO RELEASE AND POOH. RDMO. RCP STILL IN PLACE I LEFT WELL SHUT IN. 09/17/03 ATTEMPTED TO CHEMICAL CUT RCP PACKER. WELLHEAD VALVES LEAKING AFTER GREASE CREW SERVICED, WILL ATTEMPT CUTTING RCP PACKER FOLLOWING DAY AFTER FLUIDS PUMPED AND VALVES SERVICED, 09/18/03 CORRELATED TO SWS PERF LOG RAN 317103, JEWELRY LOG PROVED RCP STILL IN PLACE AFTER ATTEMPTED RETRIEVAL. CHC DESCRIPTION: 2 1/8" CUTTING HEAD, NO ROLLERS, ONE 2.75" BOTTOM CENTRALIZER, GO/NO-GO ON CHEM TUBE, 2 1/8" & 1 11/16" WEIGHTS, NO STRINGSHOT. MAX DEVIATION & ANGLE AT CUT = 45 DEG. IA PRESSURE: 1800 PSI, TUBING PRESSURE: 100 PSI. FLUID AT CUT: SEAWATER. MIN ID: 2.35". USED ONE 2" X 48" CHEM TUBE. USED GO/NO-GO TO ALIGN CHC AND ANCHOR BODY. GO/NO-GO SET DOWN AT 9794'. CUT RCP AT 9797.4'. CHEMICAL CUT RCP @ 9797.41 MD (3.4' INTO RCP PACKER). CORRELATED TO SWS PERF LOG RAN 3/7/03. RAN JEWELRY LOG WI X-Y CALIPER TO PROVE RCP STILL IN PLACE AFTER ATTEMPTED RETRIEVAL. USED NO-GO TO ALIGN CHC AND ANCHOR BODY. GO/NO-GO SET DOWN AT 97941. CUT RCP AT 9797.4'. 07-14B, Coil Tubing Drilling, Pre-Rig Work Page 2 09/19/03 KILL WELL WITH SW, FREEZE PROTECT TO 2500' WITH CRUDE. PULL TOP 43" OF RCP. RUN LIB'S SET RELEASABLE SPEAR. 09/20/03 PLANT RELEASABLE SPEAR. FISH NECK ON SPEAR MANDREL TORE UP. RIG DOWN BRAIDED LINE SWITCH TO .125" WIRE. 09/21/03 PULLED SPEAR RAN LIB DFIFTED THROUGH MANDREL. RAN 4 112 WIRE GRAB ATTEMPT TO SET SPEAR. 09/22/03 SET RELEASABLE SPEAR @ 9781' SLM, PARTED WIRE, RECOVERED ALL WIRE & TOOLS RIGGED DOWN SIL, RIG UP BRAIDED LINE. JAR UP ON RCP. 09/23/03 / SET BAKER 028 N1 CIBP TOP @10650'. CORRELATE TO SWS RST BORAX 7-MAR-2000. WELL SHUT IN, READY FOR PRESSURE TEST. PULL LOWER HALF OF RCP. DRIFT WI 2" TO 10,7001 SLM, DRIFT WI 2.25" TO 10,582' SLM. ~ 09/24/03 CHEMICAL CUT 2 718" LINER. USED 2-1/8" E.R. CHC, TWO CENTRALIZERS, 2X48 CHEMICAL CYLINDER, 12" GRAIN CHARGE. TEMP AT CUT DEPTH - 142 DEG F, DEVIATION 51 DEG. SHOOT 1 STRAND OF 80 GR PRIMACORD PRIOR CUTTING. CUT LINER AT 105461. 09/25/03 RIH WI BHA #1 LATCH FISH AT 9831'. PUW 26 K. PUH WITH FISH TO 9800' (37') LINER IS CUT. RBIH SET DOWN AT 98181 (19' HIGHER THAN TAG) PUMP OFF DEPLOYMENT SLEEVE AND POH. FREEZE PROTECT WELL TO 25001. 09/28/03 RAN 4.465 GAUGE RING BRUSH TO SSSV NIPPLE @ 2256' (SLM). BRUSHED 20 MIN. BRUSHED BPV PROFILE FOR 20 MINUTES. SET 5 1/2 PRay PLUG IN SSSV @ 2258' (SLM). 09/29/03 SET PRONG FOR P-RQY PLUG @ 22361 (SLM). BLEED TUBING, CONTROL LINE AND BALANCE LINE TO 0 PSI. BPV CREW SET VALVE, REPLACED TREE, & PULLED BPV PULLED P-RQY PRONG @ 2236' (SLM). PULL P-RQY PULL @ 2248' (SLM). 09/30/03 TIIIO 240014010 WELL KILL. SPEAR IN WI 5 BBLS METH FOLLOWED BY 240 BBLS CRUDE. FREEZE PROTECT TBG WI 58 BBLS CRUDE. WELL ON VAC. FINAL WHplS VAC/150/300. BP EXPLORATION . Page 1 ~ Operations Summary Report , Legal Well Name: 07 -14 Common Well Name: 07 -14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 9/26/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 10/21/2003 Rig Name: NORDIC 1 Rig Number: N1 . Date From .. To Hours Task Code NPT Phase Description of Operations . ... . 9/30/2003 02:30 - 05:15 2.75 RIGD P PRE Rig released from G-12B @ 02:30Hrs on 9/30/2003. Cut CTC. Remove injector gooseneck & unstab coil. RID & store injector in stabbing box. 05:15 - 07:00 1.75 MOB P PRE Prep to move rig off well. 07:00 - 07:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for moving rig off well. 07:15 - 08:00 0.75 MOB P PRE Move off well. Set rig down on pad in front of well. 08:00 - 11 :15 3.25 MOB P PRE Lay down wind walls and derrick. 11: 15 - 11 :30 0.25 MOB P PRE PRE-RIG MOVE SAFETY MEETING. Review rig move plan and power line crossings. 11:30 - 20:00 8.50 MOB P PRE Move Nordic 1 rig to OS 7. Spot rig on mats in front of tree 20:00 - 22:00 2.00 MOB P PRE OS mech fin remove reel drive motor transmission on OS and replace. Rig electrician replace shunt in accumulator system 22:00 - 22:15 0.25 MOB P PRE Safety mtg re: replace derrick load guy line 22:15 - 00:00 1.75 MOB P PRE Replace derrick load guy line 10/1/2003 00:00 - 00:15 0.25 RIGU P PRE Safety mtg re: raise derrick 00:15 - 04:00 3.75 RIGU P PRE Raise derrick and scope out. Install guy wires. RD derrick stand, prep floor 04:00 - 10:00 6.00 RIGU N WAIT PRE WO wind to subside prior to raise windwalls (at 20 mph w/ gusts to 28 mph) 10:00 -12:00 2.00 RIGU N WAIT PRE W.O. wind to raise windwalls. Wind @ 15mph steady & 25mph gusts. Check WHP ... 800psi. Mobilize Litttle Red pumping unit' & 1 % KCL water to load well prior to moving in. 12:00 - 18:00 6.00 RIGU N WAIT PRE Wind picks up again @ 22mph steady & 35mph gusts. Suspend well killing ... will load well prior to moving in when wind subsides. Continue W.O. wind. 18:00 -18:20 0.33 RIGU P PRE Safety mtgITL 18:20 - 20:15 1.92 RIGU P PRE Move vac trucks and LRS. Prep to raise windwalls 20:15 - 20:25 0.17 RIGU P PRE Safety mtg re: raise windwalls 20:25-21:15 0.83 RIGU P PRE Raise windwalls and pin 21 :15 - 23:30 2.25 RIGU P PRE Fin RU guy wires. Find oil on absorb in bottom of BOP stack and determine a slow leak in annular preventer. Track down replacement annular (at Kuparuk). RU bails to blocks Safety mtg re: liquid pack wellbore. MIRU LRS to tree cap. Load wellbore with 542 bbls 1 % KCI at avg 4.7 bpm @ 1700 psi. Well on vac. RDMO LRS 23:30 - 00:00 0.50 RIGU N RREP PRE WO BOP stand and replacement bag 10/2/2003 00:00 - 06:00 6.00 RIGU N RREP PRE NO annular and replace w/ backup. Hook up hyd hoses 06:00 - 07:15 1.25 MOB P PRE Prep to move rig over well. Remove tree cap, remove mousehole & secure cellar. Jack up rig. 07:15 - 07:30 0.25 MOB P PRE PJSM for backing rig over well. Review rig back over well procedure, hazards & mitigation. 07:30 - 08:00 0.50 MOB P PRE Back rig over well & set down. 08:00 - 11 :00 3.00 BOPSUR P PRE N/U BOPE. Install lubricator. Meanwhile spot trailers & tanks. Accept rig at 10:00 Hrs on 10/2/2003. 11:00-13:30 2.50 RIGU P PRE Pick up injector head. M/U guide arch & stab CT into injector head. Changeout packoff. Meanwhile fill rig pits with KCUbio water. RlU hard line to tiger tank & PIT to 4000psi. " 13:30 - 14:00 0.50 BOPSUR P PRE RlU to PIT BOPE. Hook-up annular pressure transducers: lAP ... 155psi, OAP ... 115psi. Flowline is disconnected. , 14:00 - 19:30 5.50 BOPSUR P PRE PJSM. Perform initial BOPE pressure/function test. AOGCC test witness waived by John Crisp. Test rig alarms. 19:30 - 21 :00 1.50 KILL P DECOMP PJSM. RU and cut 130' CT. Install OS CTC. PT 38k. RU dart Printed: 10/27/2003 11 :37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . , Date From- To .. 1 0/2/2003 19:30 - 21:00 21 :00 - 22:00 22:00 - 00:00 1 0/3/2003 00:00 - 02:20 02:20 - 02:50 02:50 - 03:30 03:30 - 04:15 04:15 - 05:00 05:00 - 06:15 06:15 - 06:35 06:35 - 06:40 06:40 - 06:45 06:45 - 08:10 08:10 - 08:25 08:25 - 08:40 08:40 -11:30 11:30-12:15 12:15 -14:15 14:15 -19:20 19:20 - 20:55 20:55 - 21 :30 21:30 - 23:15 Page 2 .. BPEXPLORA TION Operations Summary Report ... ' 07 -14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Spud Date: 5/17/1979 End: . Hours Task Code NPTPhase . 1.50 KILL 1.00 KILL P P 2.00 PULL N 2.33 KILL P 0.50 PULL 0.67 PULL P P 0.75 KILL P 0.75 KILL P 1.25 KILL P 0.33 KILL P 0.08 PULL P 0.08 PULL 1.42 PULL P P 0.25 PULL 0.25 PULL P P 2.83 PULL P 0.75 EVAL P 2.00 EVAL P 5.08 EVAL P 1.58 EVAL P 0.58 EVAL P 1.75 ZONISO P Descri ption of Operations DECOMP catcher DECOMP Fill CT w/ KCI w/ bio water and pump dart. Check well for pressure and had 550 psi. Dart hit at 59.3 bbls. PT CTC and inner reel valve at 3500 psi. Bleed off pressures FLUD DECOMP WO vac trucks to rekill before MU BHA Service injector DECOMP Open up to well to pump thru kill line w/ both pumps. WHP initial 580, IA 150, OA 85 Begin liquid pack with 1 % KCI at est 5.0 bpm. Pump #1 rate and totalizer not working. Max WHP 1540 psi, ending WHP 1150, IA 125, OA 200. SO pumping after 580 bbls. ISIP 420, 5 min. 70. Bleed down and had gassy returns DECOMP SI @ master. MU shorty fishing BHA. Open master DECOMP RIH w/ BHA #1 (4" GS w/ jars) wI well SI pumping min rate , down CT 0.2/40 to let residual gas migrate PVT 266 DECOMP Open well to circ at 4000'. No returns initially except gas pockets. Pump 2.0 bpm at 950 psi while RIH. Got returns after 25 bbls. Continue RIH circ'ing 1.7/1.0 at 730 psi. Started getting gassy returns and incr'd out rate at 7000' DECOMP At 9000', SI at choke when returns got too gassy. Let WHP build to 500 psi then open choke to tiger tank and maintain 200 psi while circ out gas. Park at 9700' 38k Circ 2.3/1760 then 2.8/2230 holding 200-250 psi BP with no returns except gas DECOMP CTP stable 2.8/2810. Open choke and continue circ 2.8/2650 , holding 100 psi bp'(induced by friction in hardline to tiger tank). Check and have gassy KCI returns, but appear to be gaining ground DECOMP Continue circ KCL water taking returns to the pits @ 2.5/2.0bpm & 1480psi - no gas in returns. DECOMP RIH BHA#1 circ @ 1.6/630psi with clean returns. Tag TOF @. . 9823' & set down on fish. DECOMP P/U & confirm liner engagement with 41 k up wi. DECOMP POOH with liner fish, liquid packing wellbore down the kill line @ 1.25bpm/350psi. DECOMP OOH. SID pump & flowc;heck well - stable. DECOMP PJSM. Review procedure for UD liner, well control procedures & requirement for Norm testing. DECOMP SIB injector. RIU safety joint. Fill well across the WHD with C-pump. UD BHA #1 & recovered 100% of cut liner assembly... consisting of BKR deploy sub & 23.5 jts of 2-7/8" FL4S tbg. Test all retrieved pipe for Norm - normal @ 1-2uRem/hr. WEXIT M/U MWD tie-in BHA #2 with Sperry MWD, BHI straight motor & used 0331 mill. Stab injector on well. Loss rate - 8bbls/hr. WEXIT RIH with BHA #2. SHT - OK. Up wt check @ 10500' = 38klbs. Continue RIH BHA#2 to cut 2-7/8" 1m tagged @ 10569'. P/Ù clean & retag @ same depth. Correct -23' to the CCL cut depth of 10546'. WEXIT Log up GR from 10546' to 9700' (into tubing) @ 2.6/2.5bpm, 2550psi & +/-200fph. Swap to pump #1 at 9850' due to poor signal from pump #2-needs work Flag at 9600' EOP. POOH for cementing assy LD logging assy. MU cementing assy RIH wI BHA #3. MIRU OS cementers WEXIT WEXIT WEXIT Printed: 10/27/2003 11:37:45 AM BP EXPLORATION Page 3 ... Operations Summary Report , Legal Well Name: 07 -14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 9/26/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 10/21/2003 Rig Name: NORDIC 1 Rig Number: N1 .. Date From.-To . Hours Task Code NPT Phase Description of Operations 10/3/2003 21:30-23:15 1.75 ZONISO P WEXIT Safety mtg re: cement Batch up 40 bbls. Cmt to wt at 2300 hrs. TT 4:20 (too long by 2 hrs) Corr to flag -13'. RIH 23:15 - 23:50 0.58 ZONISO P WEXIT Stop at 10450'. PUH 39k and park at 10420'. PT OS at 3500 psi. OS load CT w/ 40 bbls 17.2# G cement 1.9/1.8/1680 23:50 - 00:00 0.17 ZONISO P WEXIT Displace with rig pump using bio water. RIH to 10440'. PUH 52k 10/4/2003 00:00 - 00:25 0.42 ZONISO P WEXIT Lay in cement from 10420' at 2.0/400 pulling 5'/min 53k. After ~ 15 bbls out nozzle started losing returns 2'.0/1.6/275 at 10'/min. After 30 bbls out nozzle @ 10320' 2.0/1.3/600 20'/min. PLF from 10200' 1.5/0.8/400 and last bbl out at 10100'. PUH to safety. Est lost 10 bbls to f9rmation (est TOC @ 9990') CIP 0015 hrs 00:25 - 01 :00 0.58 ZONISO P WEXIT Park at 9500', circ 0.5/0.35/490 and wait for cmt to settle. Returns steadily improved to 0.50/0.45/510 01:00 - 01:10 0.17 ZONISO P WEXIT SI at choke. Pressure up wellbore to 200 psi and lost 100 psi in 5 min. Bleed off press 01:10 - 01:30 0.33 ZONISO P WEXIT RIH jetting biozan 3.0/1600 to 10000' 01:30 - 03:10 1.67 ZONISO P WEXIT POOH jetting 3.5/1830 and displacing wellbore to bio water. Dumped cement contaminated fluid w/ max density of 12 ppg 03:10 - 03:30 0.33 ZONISO P WEXIT LD cement assy. MU swizzle stick. Jet stack on top of closed swab 03:30 - 12:00 8.50 ZONISO P WEXIT WOC Work on pump #2 and accumulator system 12:00 - 14:30 2.50 ZONISO P WEXIT Still W.O.C. Meanwhile crew watch BP Lifting Immersion General Training videos # 2 & 3. Lab reports 1 OOpsi compressive strength on UCA cement sample @14:30 - should be @ 2000psi in ca. 2hrs. 14:30 - 15:20 0.83 STWHIP P WEXIT PJSM. M/U cement milling BHA #4 with 3.80" HC 0331 mill, 2-7/8" motor with 1.25deg ABH. GR-DIR MWD, orienter & MHA (OAL = 64.87'). Scribe tools. M/U injector. 15:20 -17:35 2.25 STWHIP P WEXIT RIH cement milling BHA #4. SHT @ 1000' - OK. Lab reports 2000psi compressive strength on UCA cement sample @16:00. Close choke & allow WHP to increase to 1 OOOpsi. PIT cement plug to 1000psi for 1 Omins - held jug tight. Continue RIH & correct -15' @ flag. Wt check @ 9900', up - 40k & down - 20k. See cmt bubbles from 10117'. Ream in hole & found soft cement @ 10120'. 17:35 -18:10 0.58 STWHIP P WEXIT Log up GR from TOC to 10050' (in 9-5/8" csg). Subtract 6' from CTD. 18:10 -18:20 0.17 STWHIP P WEXIT Orient TF to 2R. 18:20 - 19:05 0.75 STWHIP P WEXIT RIH reaming w/ little resistance (100# diff) 2.7/2.7bpm. 2300/2350psi 120'/hr 5R 10120-200' 19:05 - 20:40 1.58 STWHIP P WEXIT 10200' PUH 44k Chk FS 2.7/2180/25R Drill cement from 10200-213' w/ 200# diff, 800# WOB 60'/hr. Stall at 10213'. Drill med firm cement 10213-258" 2.7/2170/21L 30-40'/hrw/ 150# diff 1500-2000# WOB 20:40 - 22:30 1.83 STWHIP P WEXIT 10258' PUH 44.4k Chk FS 2.7/2190/20R Drill hard cement from 10258-300' w/ 250# diff 1500-2500# WOB 21 L 20-30'/hr 22:30 - 23:30 1.00 STWHIP P WEXIT 10300' PUH 45.1k, get a click. Orientor got three instead. Orient around Chk FS 2.75/2390/13R Drill hard cement from 10300- w/ 250-300# diff 1500-2500# woe 23:30 - 00:00 0.50 STWHIP P WEXIT 10303' FS 2.75/2390/ Continue drill hard cement w/ 250-350# Printed: 10/2712003 11:37:45AM BP EXPLORATION Page 4 - OperationsSu m maryRe port Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17 J1979 Event Name: REENTER+COMPLETE Start: 9/26/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 10/21/2003 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/4/2003 23:30 - 00:00 0.50 SlWHIP P WEXIT diff 1500-2500# WOB 30'/hr to 10316' 10/5/2003 00:00 - 01 :25 1.42 SlWHIP P WEXIT Continue drilling hard cement high side 2.7/2400/15L-30R w/ 300-400# diff 1000-3000# WOB 25-35'/hr from 10316-350' 01 :25 - 01 :40 0.25 SlWHIP P WEXIT Orient to low side 01 :40 - 02:05 0.42 SlWHIP P WEXIT Drilliowside to casing contact 2.65/2340/178L from 10350-360' and saw CW movement in TF 02:05 - 03:50 1.75 SlWHIP P WEXIT POOH for one step mill 03:50 - 04:50 1.00 SlWHIP P WEXIT LD pilot mill assy. MU one step milling assy 04:50 - 06:50 2.00 SlWHIP P WEXIT RIH w/ BHA #5 (3 deg motor) & correct -24' @ flag. \I\It check @ 9800', up - 43k & down - 17k. Continue RIH to 10090' 06:50 - 07:15 0.42 SlWHIP P WEXIT Log up GR to 10070' (in 9-5/8" csg). Subtract 2.5' from CTD. 07:15-08:15 1.00 SlWHIP P WEXIT RIH without pump & stack out @ 10350' (TOCR). PUH & check TF - @ 140R. SID pumps & RBIH & tag @ 10357'. PUH 8' & check TF - @ 113L. PUH & orient TF to 112R. SID pumps & RBIH & tag @ 10359'. PUH 8' & check TF - @ 174R. RBIH & tag 10361.8'. See MW & flag pipe. P/U 1'. TF @ 157R - grab 1 click to 174R. 08:15 - 09:00 0.75 SlWHIP P WEXIT Begin extended time milling schedule. Mill from 10360.7' to 10360.8' with 179R-169L TF, 2.5/2.5bpm, 2400/2500psi. Swap the well to new bio-KCL water. 09:00 - 18:03 9.05 SlWHIP P WEXIT Mill from 10360.8' to 10363.9' with 169L TF, 2.6/2.6bpm, 2000/2200psi. Mill begining to take wt. 18:03 - 20:00 1.95 SlWHIP P WEXIT Mill from 10363.9' by schedule 2.6/2220/164L 20:00 - 22:20 2.33 SlWHIP P WEXIT Drill open hole from 10365.5' and slow going 22:20 - 00:00 1.67 SlWHIP P WEXIT 10368.2' Chk FS/wt 45k, 2.5/2150/164L Continue drilling open hole w/ 100-350# ditt/2-5k WOB 10/6/2003 00:00 - 01:15 1.25 SlWHIP P WEXIT Continue to drill open hole from 10369.7' w/ 2.5/2150/134R w/ 200-400# ditt, 1500-5000# WOB. Stall at 10370.2' Drill to 10371.0' 2.5/2150/170R 01:15 - 02:50 1.58 SlWHIP P WEXIT POOH for tapererd mill Window depths are TOW 10361.8', BOW 10365.5', TO 10371.0' 02:50 - 03:40 0.83 SlWHIP P WEXIT LD one step assy. Mill was 3.79" 00 and had center wear. MU tapered mill assy (2.25 deg motor and Wit 3.78 dia mill) 03:40 - 05:25 1.75 SlWHIP P WEXIT RIH w/ BHA #6 SHT. Corr -24' at 9600' flag 05:25 - 05:40 0.25 SlWHIP P WEXIT Begin tie-in up from 10090' 2.8/2530/58R 44k, no corr 05:40 - 05:50 0.17 SlWHIP P WEXIT RIH and tag w/o pump at 10362' 05:50 - 06:10 0.33 SlWHIP P WEXIT PUH to 10300' and orient to low side. RBIH & stack ouUstall @ 10360'. PUH 10' & RBIH to stack pt. 06:10 - 06:45 0.58 SlWHIP P WEXIT Ream window area to 10365.3' with 176L TF, 2.6/2.6bpm 2150/2200psi. Stall 5x while reaming window. TF flop to 135L. 06:45 - 07:00 0.25 SlWHIP P WEXIT PUH & orient TF to 126R. SID pumps & RBIH to 10364'. TF @ 172L. 07:00 - 08:15 1.25 SlWHIP P WEXIT Ease back & ream window area to 10366.3' with 178L TF, 2.6/2.6bpm 2150/2200psi. Stall2x @ 10366.3'. P/U & ease back into reaming from 10365'. 08:15-09:15 1.00 SlWHIP P WEXIT Ream to 10369' with 176R TF, 2.6/2.6bpm 2150/2200psi. See 600psi MW @ 1 0369'. 09:15 - 09:50 0.58 SlWHIP P WEXIT Backream up thru window to 10357' @ 179R TF, 2.6/2250psi. No MW observed - window looks clean. 09:50 - 09:55 0.08 SlWHIP P WEXIT RIH circ @ min rate & tag @ 10369'. Grab 3 clicks. 09:55 - 10:35 0.67 SlWHIP P WEXIT Backream up thru window to 10357' @ 130L TF, 2.6/2250psi. Getting metal shavings over the shakers. Printed: 10/27/2003 11:37:45AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION O.perations Summary Report Page 5'" 07-14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From -To Hours Task Code NPT Phase 10/6/2003 10:35 -10:40 10:40 -11:45 11:45 -12:05 12:05 - 12:40 12:40 - 12:45 12:45 - 12:50 12:50 -13:10 13:10 - 13:15 13:15 -14:50 14:50 - 16:10 16:10 -17:40 17:40 -18:15 20:00 - 21 :40 21:40 - 23:10 10/7/2003 23:10 - 00:00 00:00 - 01:55 01 :55 - 02:25 02:25 - 04:30 04:30 - 05:30 05:30 - 07:00 07:00 - 07:30 07:30 - 08:15 08:15 -10:00 10:00 - 10:20 0.08 S1WHIP P 1.08 S1WHIP P 0.33 S1WHIP P 0.58 S1WHIP P 0.08 S1WHIP P 0.08 S1WHIP P 0.33 S1WHIP P 0.08 S1WHIP P 1.58 S1WHIP P 1.33 DRILL P 1.50 DRILL P 0.58 DRILL P 1.75 DRILL P 1.67 DRILL P 1.50 DRILL P 0.83 DRILL 1.92 DRILL P P 0.50 DRILL 2.08 DRILL P P 1.00 DRILL P 1.50 DRILL 0.50 DRILL P P 0.75 DRILL P P 0.17 DRILL 0.50 DRILL P P 1.00 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N 1 Spud Date: 5/17/1979 End: Description of Operations RIH circ@ min rate & tag @ 10368.6'. Drill/extend rathole to 10373.5' with 150R TF, 2.6/2.6bpm 2200/2800psi. Sweep hole with 23bbls hi-vis pill. Orient TF to 11 OR. Backream clean up thru window to 10357' @ 110R TF, 2.6/2250psi. SID pumps & dry drift window - looks clean. POOH to 10090' for tie-in log. Log up GR to 10070' (in 9-5/8" csg). Add 1.5' to CTD. Paint EOP flag @ 10000' & POOH for drilling BHA. Pill @ shakers with metal shavings & formation sample. OOH. Changeout MWD probe. UD window dressing BHA. Diamond 'crayola' mill guage 3.78". PJSM. M/U drilling BHA #7 with used 3-3/4" x 4-1/8" Smith bicenter bit, 2-7/8" motor with 2.83deg bend, GR-DIR MWD, orienter & MHA. Scribe tools. M/U injector. RIH with drilling BHA #7 & correct -20' @ flag. Wt check @ 9800', up - 41k & down - 18k. Continue RIH to 10090'. Log up GR in 9-5/8" csg. 2.6/2540/4R Add 1.0'. RIH thru window w/o urn and ta at 10374'. PUH 44k Chk TF 160L. Start drilling 2.75/2620/170L and start fresh Flo Pro mud. Drill ahead while gradually working TF up the Ie side at 2.7/3000/100L to 10404' Ran into a brick wall at 10404' and tough to make progress-acts like Z3 a little early Drilled to 10417' and going nowhere fast. POOH for bit Change bit, orientor RIH w/ BHA #8 (tricone inse t w/ 2.83 deg motor). Corr 23.8' at flag. RIH thru wi ow clean and tag TO at 10417' Chk TF and orient a nd from 51 L Drill from 10417- 6' 2.5/2800/90-120L at 25-70'/hrw/ surveys to chk azm clicks as necessary. Probably out of the hard stuff, la ' was 70'/hr and base of Z3 at 10495' Su , then orient around-three times. Had to go to big hole, get clicks, then orientor flopped 180 deg on reaching TO POOH for bi bit and orientor OOH. Check MWD - OK. Changeout orienter. UD tricone bit - 3-5-1/16" undergauge. PJSM. M/U drilling BHA #9 with new 3-3/4" x 4-1/8" Smith bicenter bit, 2-7/8" motor with 2.83deg bend, GR-DIR MWD, new orienter & MHA. M/U injector. RIH with BHA #9. SHT MWD - OK. Continue RIH. Did not see flag. Correct -21' to CTD. Wt check @ 10090', up - 41 k & down - 20k. Log up GR in 9-5/8" csg. Subtract 13' from CTD. Orient TF to 20R. SID pump. RIH clean thru window & tight hole @ 10429'. Ream in hole with 2.5/2.5bpm, 2560/2600psi & 250fph. See 200psi MW @ 10474'. Backream & ream the 3-3/4" hole section until clean. Drill to 10500' with 95L TF, 2.7/2.7bpm, 2900/3200psi & 35fph ave ROP. Lost 2bbls @ 10475'. Printed: 1012712003 11:37:45AM WGA- ~ i -s 11.(}OI~ (' STATE OF ALASKA ( <;:~:':', ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAt1JlJ 20 AAC 25.280 r:,:,' , '~~::"\i: 1 . '~) ,') n f1 'J :'.'~I I., 'J - J '-' . , ,'" , ..., 1. Type of Request: ~ Abandon / 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Other 0 Alter Casing 0 Repair Well ~ Plug Perforations/ 0 Stimulate 0 Time Extension 0 Chanç¡e Approved Proqram 0 Pull Tubinç¡ 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. a Development D Exploratory 198-072 ./ 3. Address: D Stratigraphic D Service 6. API Number: .,.".- P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20339-01-00 7. KB Elevation (ft): KBE = 64' 9. Well Name and Number: PBU 07-14A /' 8. Property Designation: 10. Field 1 Pool(s): ADL 028309 Prudhoe Bay Field 1 Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11947' 8920' 11600' 8930' 11600' 11849' Casind .. ,,/ " ,Cendth.'.. .,.:..:",;,...:,,:',Size.' '.,,',',.:'.,..:'.."": I.,," '" ,. MD",~,:' ',,'1VD...'. "~~~ ,.' '.':..,:,:...,.., :....Bi.Jrst ,I.:.'.: ~ ;.. .:. '.....'.'.::'..:..' Collapse .. ',:" , ., .. ,,' ~trlJ('.tlJr::i1 r 71' 20" 71' 71' , 1530 520 Surface 2665' 13-3/8" 2665' 2665' 5380 2670 10524' 9-5/8" 10524' 8687' 6870 4750 P ..L..., I inAr 2074' 2-7/8" 9805' - 11879' 8180' - 8924' 10570 11170 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10676' - 11869' 8799' - 8924' 5-1/2" x 4-1/2" L-80 x N-80 9934' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer; Packers and SSSV MD (ft): 9803'; 5-1/2" Otis 'ROM' SSSV Nipple 2256' 12. Attachments: 13. Well Class after proposed work: a Description Summary of Proposal D BOP Sketch D Exploratory a Development D Service D Detailed Operations Program 14. Estimated Date for August 22, 2003 / 15. Well Status after proposed work: Commencing Operations: DOil 0 Gas D Plugged a Abandoned 16. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacotj, . Title CT Drilling Engineer Prepared By Name/Number: "11/) (],~ j lK'ŸAlJiI /1/' A I I ,-- g 11/03 Siç¡nature ',,' '1'J-).fJ Phone 564-4388 Date Terrie Hubble, 564-4628 I ..1'"' ., Commission Use Only " . . '-" I Sundry Number: '?O~. ~ / / Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity l21'BoP Test ~echanicallntegrity Test D Location Clearance fo ";5'"00 I Other: Test- Eo~E f1 ,. i . Subsequent form required 10- LiO"1 ¿ hd~ BY ORDER OF (3 JotJ,. °g Approved By: l~A i' COMMISSIONER THE COMMISSION Date Form 10-403 Revised 2/2003) OR!G!I~Æ~ Submit In Duplicate , ;-j 8 '\~I"l ED AUG 2 2003 _BFa. AUG 1 '. 2003 1 ( ( To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: M.S. Endacott CTD Engineer Date: August 11,2003 Re: CTD Sidetrack of well 7 -14A ./ 7-14A is scheduled for a through tubing sidetrack with the Nordic 1 coil drilling rig. The sidetrack, 7-14B, will kick off from an openhole whipstock set outside the existing window in Zone 2 and will target Zone 1./The perfs will be isolated by CIBP and the new sidetrack will be completed with a fully cemented liner. The well will be a producer. The following describes work planned to prep for sidetracking and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. 1. MITIAandOA / ~ing casings: 13-3/8" 72# L-80 9-5/8" 47# L-80 2-7/8" 6.5# FL4S L-80 Proposed casings: 3-3/16" 6.2# TC-II L-80 2-7/8" 6.5# ST-L L-80 ~ (psi) 5380 6870 10570 CoUapse(ps!} 2670 4750 11170 8520 10570 7660 11170 2. Set CIBP at 10,650' / 3. Cut and confirm free, existing 2 7/8" liner at top of cement, 10,500' ./ 4. Pull and recover liner / 5. Set openhole whipstock at 10,570' .,.-----¡ ".. / Steps 2 and 3 will be performed with service coil, scheduled for Au94S(22:/,-5teps 4 and 5 with the drilling coil, scheduled on October 1, 2003. ( .",,// .."<...,,.. ïn J. tßwi !111Ji(- M.S. Endacott CTD Drilling Engineer CC: Well File Terrie Hubble , ( TREE = GRA Y GEN 2 Wa.lHEAD = GRA Y ,..,."._""..",_,...'...'..".'.'.'" , ,. ".'..'.'" ""..... ACTUATOR = AXB..SON ."...-------"""."- ...".--..,.--..".... .'_.._"" KB. B..EV = 64' .....,.",......""",.....",......'.. "".... ,.. BF. B..EV = ~--_..__.._.._.._..__...._"..,'" KOP = 3000' -""---...""..-.-,....."....-------,, Max Angle = 98 @ 11637' ",.",.,..""..,.""".,.""...,., ,.. ,.,.,.. ...",........ ..."..... Datum MD = 10766' -.--..--"..-........,,-,...--..--,.-,...-.-,.-..- Datum1VD= 8800'SS 113-318" CSG, 72#, l80, 10 = 12.347" I TOPOF 2-7/8" LNR I 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" l-i I TOP OF 4-1/2" TBG l-i I TOP OF CEMENT I 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, 10 = 3.958" I ÆRFORA TION SUMMARY REF LOG: CNL MWD GR ON 11/10/98 ANGLEATTOPÆRF: 31 @ 10676' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10676 - 10690 isolated proposed 2" 4 10980 - 11130 isolated proposed 2" 4 11290 - 11445 isolated proposed 2" 4 11470 - 11530 isolated proposed 2" 4 11665 - 11869 isolated proposed I MLLOUT WINDOW 10524' 9-5I8" CSG, 47#, L-80, 10 = 8.681" I'" 10524' I 07 -148 Proposed CTD Sidetrack <8 2665' I I 9804' 9809' 9809' 9892' 9934' ( 2256' ST MD 1 2903 2 5186 3 7033 4 8174 58829 6 8902 7 9365 8 9443 9 9587 10 9658 9520' 9732' 9772' 9803' 9809' 98501 98501 9870' 9933' 9934' 9907' SAFETY NOTES: LDL INDICATES LNR LAP IS LEAKING. -15-1/2 OTIS ROM SSSV NIP, 10 = 4.562" I GAS LIFT MANDRELS lVD DEV lYPE VLV LATCH 2903 7 011S 1'2 4826 43 011S RA 6139 45 011S 1'2 6993 38 011S RA 7494 45 011S RA 7545 46 011S RA 7868 45 011S RA 7923 45 011S RA 8025 45 011S RA 8076 45 011S 1'2 PORT DA 1£ -i 5-1/2" OTIS SLIDING SL V I ""5-1/2" OTIS N NIP, 10 = 4.455" I -i5-1/2" BOT PBRASSY I -i 9-5/8" X 5-1/2" BKR SAB PKR I -i 6-5/8" X 4-1/2" XO I -i Top of 3-3/16" Liner -i Top of Cement -14-1/2" CAM DB-6 LAND NIP, ID = 3.813" I -14-1/2" BKR SHEAROUT SUB I -14-1/2" TUBING TAIL I l-i B..MD TT LOGGED 07/14/89 I / 10570' -1 Open Hole Whipstock I 3-3/16" X 2-7/8" Liner I 0 0 , " .' , '," , , ,'" 0 0 0 " ',,", " ,,' , , 12-7/8" LNR, 6.5#, Lo80, .00579 bpf, 10 = 2.441" l-i 11879' I 11849' -i FISH - 2-7/8" FASDRILL PLUG I DATE REV BY COMMENTS DA1£ REV BY COMMENTS 06/03179 ORIGINAL COMPLEll0N 06/22102 GRCltlh PERF CORRECll0NS 08/01/98 SIDETRACK 03107/03 RUTP ADD PERF 01/12101 SIS-SL T CONVERTED TO CANVAS 02/13/01 SIS-MD FINAL 09/23/01 RN/1P CORRECTIONS 03/07/02 PWEffiH SET CIBP PRUDHOE BAY UNIT WELL: 07-14A PERMIT No: 98-072 API No: 50-029-20339-01 Sec. 33, T11N, R14E, 5220.78 FEL 606.71 FNL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2725 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Milne Pt. 04/02/03 Color Well Job # Log Description Date Blueline Prints CD ~.~20,.B ~-~-c:~ q 23081 CH EDIT MGR 12/08102 1 · 9-35A/C~ .~ ~ ~ I 23050 RST 01/08103 I t o.s. ~-~SA ~q,~ -~ ~ 2~s~ ,ST ~/~0/0~ ~.18-05~'%~'~~ 22411 MCNL 08149102 ~.S~-44A '~ % '~ 23100 SCMT 03/05/03 2 ~S-30,~-~,~ 23078 :SCMT 0~3/03 2 ~IA~ 23087 OH EDIT ARC & IMPULSE (PDC) 14/03102 1 j ~'~ ~31A ~ ,~ ~ 23087 MD VISION RESISTIVIW 11103/02 ~ -- ~-31A / ~ ' 23087 ~D VISION RESISTIVI~ ~1103102 ~-31A/ 23087 MD VISION RESlSTIVI~ (BHP) 11103102 ,,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receive '"'--" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERES Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development._.X RKB 64 feet 3. Address Explorato~._ 7. Unit or Property name P. O. Box 196612 Stratigraphic._. Anchora~le, AK 99519-6612 Service._ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 508' FNL, 315' EEL, Sec. 33, T11N, R14E, UM (asp's 675868, 5950406) 07-14A At top of productive interval ~ 9. Permit number / approval number 1044' FNL, 4260' EEL, Sec. 27, T11 N, R14E, UM (asp's 677081, 5955182) ~ 198-072 At effective depth 10. APl number 836' FNL, 4975' FEL, Sec. 27, T11 N, R14E, UM (asp's 676361, 5955373) 50-029-20339-01 At total depth 11. Field / Pool 607' FNL, 5221' FEL, Sec. 27, T11 N, R14E, UM (asp's 6760108, 5955597) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11947 feet Plugs (measured) ClBP set @ 11600' (03/07/2002) true vertical 8920 feet Effective depth: measured 11600 feet Junk (measured) Pushed Fastdrill Plug to 11849' (05/24/2000) " true vertical 8930 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 71' 20" 243 sx AS 101' 101' Surface 2635' 13-3/8" 4200 sx AS II 2665' · 2665' Intermediate 10494' 9-5/8" 1200 sx Class 'G' 10524' 8687' Liner 2075' 2-7/8" 15 bbls LARC 9804' - 11879' 8179' - 8924' Perforation depth: measured Open Perfs 10676' - 10690', 11145' - 11290', 11470' - 11530'. Sqzd Perfs 10980' - 11130'. Open Perfs Below CIBP 11665' - 11869'. true vertical Open Perfs 8799'- 8810', 8953'- 8949', 8940'- 8937'. Sqzd Perfs.8940'- 8953'. Open Perfs Below ClBP 8922' - 8924'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC TBG @ 9809'. 4-1/2" 12.6# NPCT TB~i~_~~'r-~' Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SAB Packer @ 9803'. 5-1/2" Otis RQM SSSV Nipple @ 2256'. MAR 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) /~[~(~ & C~J Co~. C~iOFi Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 03/05/2003 Shut-In ' Subsequent to operation 03/08/2002 658 15021 0 942 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is~ true and correct to the best of my knowledge. .~~'~.~j~'3~*'J~ Title: Techical Assistant .._ Date March 11, 2003 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 07-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02~20/2003 PERFORATING: DRIFT/TAG 03/05/2003 PERFORAT];NG: CEMENT BOND LOG--SCMT/US;[T; PERFORATTNG 03/05/2003 SECURE WELL: LEAK DETECT[ON LOG; LOAD WELL TO SECURE 03/06/2003 PERFORAT];NG: PERFORATZNG 03/07/2003 PERFORAT];NG: PERFORATING 03/08/2003 TESTEVENT --- BOPD: 959, BWPD: 12, MCFPD: 16,880, AL Rate: 0 EVENT SUMMARY 02/20/03 DRIFT 2" D-GUN TO TARGET DEPTH OF 10700' SLM. <<< WELL LEFT SI >>> 03~05/03 SCMT LOGGED FROM 10710' 9960' TOP OF EXCELLENT CEMENT 10650', STRING CEMENT TO FREE PIPE @ 10550'. GASEOUS WELLBORE LIMITED FURTHER LOGGING. FREEZE PROTECTED WITH CRUDE/MECH. <<< NOTIFY DSO WELL LEFT SHUT FOR ADD PERF >>> 03~05/03 E-LINE ASSIST, PUMP MEOH SPEAR, PUMP 360 BBLS SEAWATER DWN TBG, PUMP AS DIRECTED BY E-LINE. O3/06/03 PERFORATE 10681'-10690', WITH 2" 2006 POWERJET, 6SPF, PENE 18.6", EH 0.20", 6.5 GMS. CORRELATED TO SWS RST LOG DATED MAR-7-2000. (WILL BE BACK IN AM TO COMPLETE PERFORATING) <<< NOTIFY DSO OF WELL STATUS >>> O3/O7/O3 PERFORATE WITH 5' HSD GUN (2" POWERJET 6 SPF 60 DEGREE PHASING) WAS SHOT AT A DEPTH OF 10676'. THE TOTAL PERF INTERVAL WAS 10676'- 10681'. THIS JOB WAS A CONTINUATION FROM THE PREVIOUS DAY. THE PREVIOUS DAY ONE, 9' GUN OF THE SAME DIAMETER AND SHOT DENSITY WAS PERFORATED AT AN INTERVAL OF 10681'-10690'. <<< NOTIFY DSO OF WELL STATUS >>> 03/08/03 TESTEVENT --- BOPD: 959, BWPD: 12, MCFPD: 16,880, AL Rate: 0 FLUIDS PUMPED BBLS 2 DIESEL FOR PRESSURE TESTING SURFACE PRESSURE EQUIPMENT 22 60/40 METHANOL WATER 55 CRUDE 525 SEAWATER 604 TOTAL ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" HSD POWER JET, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 03/07/2003 10676'-10690' Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ ClaP Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 64 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 508' FNL, 315' FEL, Sec. 33, T11N, R14E, UM (asp's 675868, 5950406) 07-14A At top of productive interval 9. Permit number / approval number 1044' FNL, 4260' FEL, Sec. 27, T11 N, R14E, UM (asp's 677081, 5955182) 198-072 At effective depth 10. APl number 836' FNL, 4975' FEL, Sec. 27, T11N, R14E, UM (asp's 676361, 5955373) 50-029-20339-01 At total depth 11. Field / Pool 607' FNL, 5221' FEL, Sec. 27, T11 N, R14E, UM (asp's 6760108, 5955597) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11947 feet Plugs (measured) CIBP set @ 11600' (03/07/2002) true vertical 8920 feet Pushed Fastdrill Plug to 11849' (05/24/2000) Effective depth: measured 11600 feet Junk (measured) true vertical 8930 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 71' 20" 243 sx AS 101' 101' Surface 2635' 13-3/8" 4200 sx AS II 2665' 2665' Intermediate 10494' 9-5/8" 1200 sx Class 'G' 10524' 8687' Liner 2075' 2-7/8" 15 bbls LARC 9804' - 11879' 8179' - 8924' RECEIVED Perforation depth: measured Sqzd Perfs 10980' - 11130', Open Perfs 11145' - 11290', 11470' - 11530'. Open Perfs BelowCIBP 11665'-11869'. ~J~R ~' -~ ~00~. true vertical Sqzd Perfs 8940'- 8953', Open Perfs 8953'- 8949', 8940'- 8937'. Open Perfs Below CIBP 8922'- 8924'. ~l~01~&~l~lt~~w iTubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC TBG @ 9809'. 4-1/2" 12.6# NPCT TBG @ 9934'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SAB Packer @ 9803'. 5-1/2" Otis RQM SSSV Nipple @ 2256'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/08/2002 522 20340 0 846 Subsequent to operation 03/08/2002 533 22280 0 798 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~/-~~)'u~ ~J~''''' Title: Techical Assistant Date March 11,2002 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · OD ®IiIAL SUBMIT IN DUPLICATE 07-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/06/2002 PACKERS/BRIDGE PLUGS' CAST IRON BRIDGE PLUG 03/07/2002 PACKERS / BRIDGE PLUGS' CAST IRON BRIDGE PLUG EVENT SUMMARY 03/06/02 MIRU. DRIFT COIL W/1.25" BALL. TEST BOPs. LINE UP AND START WELL KILL. O3/O7/02 KILL WELL WITH 2% KCL. MAKE GAGE RUN TO 11600 WITH 2.25" JS NOZZLE. SET HES 2.875" CIBP @ 11600' CTM. DSO TO POP WELL. FLUIDS PUMPED BBLS 80 METHANOL WATER 16 KCL WATER 298 2% KCL WATER 394 TOTAL Page I Well Compliance Report File on Left side of folder 198-072-0 MD 11947 -' TVD 08920 Microfilm Roll / - PRUDHOE BAY UNIT 07-14A 50- 029-20339-01 BP EXPLORATION (ALASK ff/31/9 A '~ rl~.Tt'~ fCompletion Date: 8 Completed Status: 1-OIL Current: Roll 2 / Name D 8742 D GR/CCL L NGP-MD L NGP-TVD L RST/B 1947 R SRVY RPT ~ER~Y 10500-11947 Daily Well OpsS~_/~3~ -- Was the well cored? yes ~ Interval Sent Received T/C/D SPERRY GR OH 11/18/98 11/18/98 CH 5/12/00 5/12/00 OH 11/18/98 11/18/98 OH 11/18/98 11/18/98 CH 5 5/18/00 5/19/00 C OH 8/11/98 8/12/98 Dry Ditch Samples Required? yes ~.~And Received? Are Analysis Description Rece' 9 'ample Set# 0?3 Comments: Tuesday, August 01, 2000 Page 1 of 1 5/~ 8/00 Schlumberger NO. 162 Schlumberger Technology Corporation, by anti through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Color Well Job # Log Description Date BL Sepia Print CD D.S. 3-33A i~t c._ LEAK DETECTION 000508 I I . 'D.S. 4-18 COLLAR LOG/DDL 000509 I 1 D.S. 9-16 c~, (._.. JEWELRY & TUBING LOG 000508 I 1 D.S. 4-49 20063 MCNL ~ ~ Lo (~ c~ 000126 I I 1 D.S. 6-07 20072 'CNTG Jc~ ~O 000131 I I 1 D.S. 7-06A 20064 MCNL--;tr.- ~L~ L~ ~ 000124 I I 1 D.S. 7-14A 20106 RST '[~-~L(,c~ 000307 I I 1 D.S. 15-05A 20178 USIT 000412 I SIGNED~//~~'' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address Or fax to (907) 561-8317. Tha~fl[q~i~l.age RECEIVED MAY 1, 9 2000 Alaska 0ii & Gas Cons. u0mmissl.0.1! TAANStVilFrA£ Diagnostic Services, Inc. To: ARCO Alaska, Inc. AOGCC Lori Taylor RE · Distribution - Final Print[s) The technical data listed below is being submitted herewith, Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey POS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 JJ LOG CD-ROM MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S] OR FLOPPY FILM BLUELINE Open Hole 1 1 1 · . Res. Eval. CH I I 1 07-14A 5-7~10 Mech. CH I I Rpt or CalliPer Survey ~ECE J V ED I BL/1F Signed · Print Name: 12 200O Date ' Alaska Oil & Gas Cons. commmsion A~chOm~e ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdspmdhoe~NAS00.net Website: CSMy Documents'~istribution_FormsLArco_pb_form.doc MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 1998 Blair Wondzeil, P. I. Supervisor FROM: Larry Wade,"~~¢f~ SUBJECT: Petroleum Inspector FILE NO: .DOC BOP Test CDR 1 PBU DS 7-14A PTD 98-072 June 14~1998: I traveled to PBU DS-7 to witness the initial BOP test on CDR 1 which is a coil tubing drilling unit. it is of unique design because of the coil being installed above the rig floor. The driller and directional hand have a doghouse office on the rig floor where the driller can run the coil or the rig blocks from a Star Trek looking chair with three joysticks and 2 keypads and a coffee cup holder. The most unique feature about the rig is the coil which goes into the injector head directly off the coil. Sensors on the injector head keep the coil directly over the injector thus reducing pipe fatigue by reducing bends in the pipe. The rest of the rig is compromised of modules scattered about. ARCO intends to install the modules on a couple of floats with external catwalks. The rig also has a lot of work to do to ready it for cold weather operation. Again ARCO expects to have it done by fall. The coil is 2 5/8" and looks to have a lot of potential but needs much modification by Winter. The ARCO company man had already pressure tested everything so when I arrived on location, we went thru an official BOP test where everything tested and the most time consuming problem was ineffective portable radio's. SUMMARY: I Witnessed the initial BOP test on CDR 1, 0 failures, 5 ¼ hours. Attachments: ag9gfofe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OPERATION: Drlg: X Thru tubing: Drlg Contractor: Trans Ocean/Nabors Operator: ARCO Well Name: DS 7-14A Casing Size: 5 1/'2" tb~ Set @ Test: Initial X Weekly OIL AND GAS CONSERVATION COMMISSION BOPE Test Report (For Coil Tubing Units) Rig No. CDR 1 PTD # g8-072 Rep.: Rig Rep.: 9,934 Location: Sec. Other DATE: June 14, lg98 Rig Ph.# 659-5545 Arvetl Bass Terry Wasyluk 33 T. 11N R. 14E Meridian Urniat Test Pressures MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location X Standing Order Posted Well Sign X Unit Condition ok Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly /IBOP Ball Type Inside BOP Quan. Pressure P/F 0 BOP STACK: Stdpper/Packoff Blind/Shear Rams Blind/Shear Rams Pipe Rams Pipe Slip Rams HCR Valves Kill Line Valves Check Valve Quan. Test Press. PtF I 0 P 1 0 P 0 I 0 P 0 I 0 P 3 0 P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X Test CHOKE MANIFOLD: Pressure P/F No. Valves 10 0 I P No. Flanges 21 0 ! P Manual Chokes 2 Functioned P Hydraulic Chokes Funcb'oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2050-2000 2,9O0 2,25O minutes 15 sec. minutes 45 sec. X Remote: X Psig. Number of Failures: ,Test Time: Hours. Number of valves tested '/3 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687' If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c -Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade Fl-021L (Rev. 12/94) agggfnfe.xls STATE OF ALASKA ALASI~A OIL AND GAS CONSERVATION COMMISS"~N REPOFIT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X (Cmt Sqz f/GSO) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 64 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 508' FNL, 315' FEL, Sec. 33, T11 N, R14E, UM (asp'$ 675868, 5950406) 07-14A At top of productive interval 9. Permit number / approval number 1044' FNL, 4260' FEL, Sec.27, T11 N, R14E, UM (asp's 677081, 5955182) 198-072 At effective depth 10. APl number 50-029-20339-01 At total depth 11. Field / Pool 607' FNL, 5221' FEL, Sec. 27, T11 N, R14E, UM (asp'$ 676108, 5955597) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11947 feet Plugs (measured) Pushed Fastdrill plug on (5/24/2000) to 11849' OTM. true vertical 8920 feet Effective depth: measured 11849 feet Junk (measured) ,~_¢~~i-\ ~ [ !~,.~¢ ~ii'~U L true vertical 8924 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 71' 20" 243 Sx AS 71' 71' Surface 2601' 13-3/8" 4200 Sx AS I~ 2665' 2665' Production 10460' 9-5/8" 12oo Sx Class G 10524' 8687' Liner 2075' 2-7/8" 15 bbls 15.8 ppg LARC 11 879' 8924' Perforation depth: measured 11290'- 11445'; 11470'- 11530'; 11665'- 11869'. ';"'~.i ?~.i~ true vertical 8949' - 8940'; 8940' - 8937'; 8922' - 8924'. ~ !!,.i;'~ Tubing (size, grade, and measured depth) 5-1/2", 17¢, L-80 PCT @ 9809' MD; 4-1/2", 12.6#, N-80 NPCT Tbg @ 9934' MD. :;;~,::~;:3!;'~'~ ~i,;i <:;. Packers & SSSV (type & measured depth) 9-5/8 X 5-1/2 BAKER SAB PACKER @ 9803' MD. 5-1/2 OTIS RQM SSSV NIPPLE ID--4.562 @ 2256' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 719 21512 0 - 1099 Subsequent to operation 569 13857 15 - 297 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil ~X Gas ~ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed y~ ,~, ~ Title PAI WellworkDesign&OptimizationSupervisor Date Erin Oba Prepared by Paul Rauf 263-4990 · Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE .... 07-14A ...... DESCRIPTION OF WORK COMPLETED ACID WASH / CEMENT SQUEEZE FOR GSO Date Event Summary 3/07/2000: 5/07/2000: 5/08/2000: 5/09/2000: 5/13/2000: 5/24/2000: Borax PNL' RST Borax log run. Results indicate RCP Packer is holding & channel exists f/ 10980' to 10850' MD. MIRU CTU. PT'd equip to 3000 psi - ok. Killed well. RIH w/Mem GR/CCL logging tools & logged well. Tagged PBTD @ 11877' MD. POOH. Stand down for night. An Acid Wash & Cement Squeeze for Gas Shutoff were performed as follows: PT'd BOPE to 2500 psi. RIH & set Fastdrill Bridge Plug @ 11145' to isolate the following perforated intervals: 11290'- 11445' MD (Zone 1 B) 11470'- 11530' MD (Zone lB) 11665'- 11869' MD (Zone 1 B) POOH. RIH w/CT nozzle. Reciprocated an acid wash across the open perforations @: 10980'- 11130' MD (Zone 1 B) Pumped the following fluid schedule: (A) 250 bbls of 160© F 1% Slick Water down backside, followed by (B) 50 bbls of 160© F 1% Slick Water down CT @ 1.3 bpm, followed by (C) (PUH f/Fastdrill BP) 50bbls of 160© F 1% Slick Water @ 1.5 bpm, followed by (D) 20 bbls of 70© Diesel - 20% Xylene - 10% Musol @ 1.5 bpm, followed by (E) 40 bbls of 70© of 12% HCL - 10% Xylene - 3% Acetic Acid @ 1.5 bpm, followed by (F) 1% Slick Water down CT @ 1.8 bpm, followed by Saw small break in WHP. Injection test w/CT @ 10950': 0.5 bpm @ 1750 psi, 1.0 bpm @ 2000 psi, 1.5 bpm @ 2350 psi, & 1.8 bpm @ 2600 psi. Pumped 30 bbls of Latex Acid Resistive Cement to squeeze off all the open perforations listed above. Squeezed 1.5 bbls of Cement behind pipe @ a max squeeze press of 2200 psi. PUH to safety. Contaminated Cement w/Biozan & cleaned out to Fastdrill BP. FP'd well. POOH w/CT. Left 500 psi on wellhead. RD CTU. WOC. RIH & drifted to 10810' SLM. MIT to 1000 psi - held. RIH & milled Cement / Fastdrill BP. Pushed it downhole to 11849' CTM Placed well BOL & obtained a valid well test. Well has since gassed out - options are being evaluated. Page 1 0 Fi I I--I--I I~ G SE I::!~/I C G S WELL LOG TRANSMITr~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 i-..~ ~ ~r RE: MWD Formation Evaluation Logs D.S. 7-14A, AK-MW-80262 November 18, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention or2 Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 7-14A: 2"x 5"MD Gamma Ray Logs: 50-029-20339-01 2" x 5" TVD Cramma Ray Logs: 50-029-20339-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia NOV i0 ~cm · I~ 0ii & Ga~ Cons. Gom~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 , Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ~,SKA OIL AND GAS CONSERVATION COMMI$~..?4 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_Z 64' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic _ Anchorage, AK 99510-0360 ~ Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1410' FNL, 996' FWL, Sec 27, T11N, R14E, UM 07-14A At top of productive interval: 9. Permit number/approval number: 1044' FNL, 4260' FEL, Sec 27, T11N, R14E, UM. 98-72 At effective depth: 10. APl number: 50-029-20339-01 At total depth: 11. Field/Pool: 607' FNL, 5221' FEL, Sec 27, T11N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11947 feet Plugs (measured) PBTD Tagged at 8924' MD (7/29/98). true vedical 8920 feet Effective Depth: measured 11879 feet Junk (measured) true vertical 8924 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 71' 20" 243 Sx ArcticSet 71' 71' Surface 2601' 13-3/8" 4200 Sx AS II 2665' 2665' Production 10460' 9-5/8" 1200 Sx Class G 10524' 8687' Liner 2074' 2-7/8" 15 bbls 15.8 ppg LARC 11879' 8924' Perforation Depth measured 10980'- 11130'; 11290'- 11445'; 11470'- 11530'; 11665'- 11869'. true vertical 8940' - 8953'; 8949' - 8940'; 8940' - 8937'; 8922' - 8924'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PO Tbg @ 9809' MD; 4-1/2", 12.6#, N-80, NPO Tbg @ 9913' MD. Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" Baker SAD Packer @ 9803' MD; 5-1/2" Otis RQM SSSV @ 2256' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached summary) ;? ~-!~* 2. Intervals treated (measured) ~(?~ rjii & Gas Cons. 14. Reeresentitive Daily Average Production or Injection Data ¢8¢10l'10~'a-~ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1860 54451 0 976 Subsequent to operation 1902 4943 0 - 733 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Repeal of Well Operations _ .Z Oil _.X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ 0~' '~'~!~ _E"{¥~0~¢~. Title: Engineering Supervisor Date Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 07-14A ~' DESCRIPTION OF WORK COMPLETED SET RCP PACKER FOR GAS SHUTOFF 8/14/9 8: MIRU SLU & PT'd BOPE/Riser to 3500' psi. RIH & set 2-1/8" Baker IBP @ 9950' - 9943' SLM. POOH & RD 8/16/98: MIRU SLU & PT'd equip to 2500 psi. RIH & extracted IBP f/wellbore @ 9944' SLM. RIH w/4-1/2" x 3" RCP Packer & set @ 9808' SLM for GSO in liner lap. Returned the well to production & obtained valid well test. Page I .... . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION VVrL.'- ~,UIWr,-r I IUr~ uri rir~.,U~Wr~_r ~ IU~ rirruri I ~mL~ LU~L. ~,. E I t/'/.; 1 Status of Well Classification of Service Well Oil_X Gas__ Suspended__ Abandoned__ Service__ ~ ,, A ,.,, 2 Name of Operator 7 Permit Number ~U~' ARCO Alaska, Inc. 98-72 A,~ ~ ..... 3 Address 8 APl Number m.~Cl,31~ UII & GaS Corlg. Corl'l~j~ P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20339-01 4 Location of well at surface ~' ..................... 9 Unit or Lease Name 511'FNL, 314'FEL, Sec33, T11N, R14E, UM ; ' ........ ~ ; ~1~~ PRUDHOE BAY UNIT 10 Well Number At Top Producing in,erval 7- 14A 607' FNL, 5221' FEL, Sec 27, T11N, R14E, UM~.~ ~ PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Seri~ 64' RKB ADL 28309 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 6/25/98 7/22/98 7/31/98 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 11947' MD / 8920' TVD 11879' MD / 8924' TVD YES_X NO__ 2256' MD 1900' (approx) 22 Type Electric or Other Logs Run MWD, LDL, & GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP DOT[OM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 94# H~40 Surface 71' 30" 243 Sx Arcticset 13-3/8" 72# L-80 Surface 2665' 17-1/2" 4200 Sx AS II 9-5/8" 47# L-80/S00-95 Surface 10524' 12-1/4" 1200 Sx Class G 2-7/8" 6.4# L-80 9805' 11879' 3-3/4" 15 bbls 15.8 ppg LARC 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 5-1/2" Tbg 9809' 9803' 10980' - 11130' MD; 8940' - 8953' TVD; @ 4 spf. 4-1/2" Tbg 9913' 11290' - 11445' MD; 8949' - 8940' TVD; @ 4 spf. 11470' - 11530' MD; 8940' - 8937' TVD; @ 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11665'- 11869' MD; 8922'- 8924' TVD; @ 4spf. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 8/1/98 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 8/4/98 3.0 TEST PERIOD --I 16052 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 1478 24 HOUR RATE _X 2258 36245 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved 4/20/98 (Permit # 98-72). )11 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Top Sadlerochit (other pics) GEOLOGIC MARKERS MEAS DEPTH 10189' TRUE VERT DEPTH 8451' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. 31 LIST OF ATTACHMENTS Summary of 7-14A CT Sidetrack Drilling Operations + Survey. 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Erin Oba INSTRUCTIONS Prepared by Paul Raut 263-4990 General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases. 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. 7-1-80 __, 7-14A ~' DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 5/13/98: MIRU CTU. PT'd equip to 4000 psi. RIH & milled pilot hole f/9892' to 10470' MD. POOH. RD. 6/14198 - 6/17/98: MIRU new Nabors CDR CTU. Tested BOPE. CTU maintenance. RIH w/BHA & tagged TOC @ 10485' MD. Milled pilot hole to 10520' MD. 6/18198: Milled pilot hole f/10520' to 10565' MD. POOH w/BHA. 6/19/98 - 6121198: RIH to 8500' MD. Performed rig maintenance on injector traction cylinders. Circulated hole w/clean SW. Tagged BTM @ 10562'. POOH. RIH & milled pilot hole to 10628'. 6/22/98 - 6/24/98: POOH. Purged CT on reel w/N2, installed new reel of pipe, & performed misc rig modifications. 6/25/98 - 6/27/98: PT'd BOPE. RIH & tagged BTM @ 10628'. Commenced window milling operation. Orienter failed. POOH & encountered problems spooling pipe. 6/28198: RIH w/BHA & tagged BTM. Began time drilling. 6/29/98 - 6/30/98: POOH w/BHA. Repaired gripper blocks on CTU. Rig maintenance. 7/01/98: RIH w/BHA to 9854' (DB nipple restricted further penetration). POOH w/BHA. 7/02/98: RIH and tagged 10640'. Drilled forward to 10648'. Reamed window & attempted to do LOT but formation would not take fluids. POOH. BHA did not penetrate casing. 7/03~98: RIH w/BHA & tagged BTM @ 10649'. Pumped 8 bbls of 17 ppg Class G Cement to plug back pilot hole. Dressed off cement top to 10500'. POOH while circulating out excess cement. PT'd BOPE. Performed Rig maintenance while WOC. 7/04/98: RIH to 5061'. Made field repair to reel chain sprocket. RIH to TOC.@ 10501' & milled a new pilot hole to 10585'. POOH. 7/05/98: RIH &tagged BTM. Milled ramp f/10585' to 10597'. POOH. RIH w/milling BHA but shallow test indicated the motor was locked up. POOH to c/o motor. 7/06/98: RIH w/BHA & tagged BTM. Milled window f/10597' to 10600' MD. POOH w/BHA. Page 1 ,~- ~. 7-14A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 7/07/98: RIH & milled window f/10599' to 10604, MD. Drilled to 10614' w/lost returns. POOH. 7/08/98: Cont to POOH. RIH & dressed window interval. Tagged BTM @ 10611' MD. POOH. 7/09/98: RIH w/BHA & tagged BTM. Displaced well to FIo Pro. Drilled to 10611' & performed FIT. Drilled to 10654' & encountered pure cmt in returns. Indication is the BHA is not out of window & tracking the old wellbore. PUH to 9500' & performed injectivity test (no injection @ 1500 psi). POOH. 7/10/98: Interrupted POOH @ 2100' MD to c/o reel motor. POOH. RIH w/nozzle & tagged BTM @ 10654'. Circulated well to fresh water. Laid in 10 bbls of Class G Cement & squeezed to 800 psi. Contaminated cement w/Biozan & cleaned contaminated cement to 10425'. POOH w/nozzle. PT'd BOPE. WOC. 7/11/98: RIH w/pilot mill & tagged PBTD @ 10431'. Milled a new pilot hole to 10524' & POOH. 7/12/98: RIH & milled a window through the 9-5/8" casing f/10524' to 10529'. Drilled fm to 10536'. Backreamed window. 7/13/98: POOH. RIH & attempted to dress window area. POOH. RIH w/BHA & dressed 1.5' of the window. 7/14/98: POOH w/BHA. RIH & tagged TOW. POOH due to GR tool failure. RIH w/jet nozzle. 7/15/98: Tagged BTM @ 10536'. Pumped FIo Pro sweep. Dressed & backreamed window area. POOH. 7/16/98: RIH & drilled to 10603'. Displaced well to new FIo Pro. Drilled to 10630'. Performed LOT to EMW of 9.6 ppg. Backreamed hole f/10546' to 10540'. Drilled ahead to 10775'. 7/17/98: Drilled build section to 10910' MD. POOH. BOPE tested. RIH w/BHA & drilled to 10918'. 7/18/98: Drilled to 11120' & lost MWD pulser signal. POOH. RIH & drilled ahead to 11230'. 7/19/98: Drilled to 11241' & POOH. RIH & drilled to 11399' (through 170' shale interval) & c/o mud. 7/20/98: Drilled to 11915' MD w/periodic shorf trips to window. 7/21/98: Had problems w/shaley intervals. Worked/reamed f/11600' to 11915'. Drilled to 11923'. Pumped 2 Crude pills. PUH to tbg for misc CT rig repairs & to cleanup mud spill. RBIH & swapped mud. Page 2 _. 7-14A .~_. DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 7/22/98: Reamed shaley intervals f/11850' to 11922'. Drilled to TD @ 11947' MD. Pumped 2 Lubtex pills. POOH. 7/23/98: RIH & reamed multiple tight spots f/10950' to 11615'. 7/24/98: Reaming tight spots f/11615' to 11875' w/frequent motor stalls. 7/25/98: Ream to 11881'. Displaced open hole w/clean FIo Pro. POOH. Performed CT rig maintenance. 7/26/98: Cont CT maintenance. RIH w/2-7/8" FL4S liner. Worked liner through tight spots located @ 10684', f/11584' - 11634', & 11764' - 11872'. Landed liner @ 11872'. 7/27/98: Attempted to cement liner in place w/15 bbls of 15.8 ppg LARC Cement but aborted job & reverse circulated all cement f/CT. POOH. RIH & cemented liner w/15 bbls of LARC Cement. Cleaned out liner & POOH. 7/28/98: RIH & milled cement f/11600' to 11740'. POOH. 7/29/98: RIH w/BHA & tagged TOC @ 11740'. Drilled to 11820' & tagged landing collar. Drilled through LC to float collar located @ 11851' Milled cement to 11879' (float shoe). Displaced liner to clean FIo Pro. POOH. 7/30/98: RIH w/perforating guns. Shot 569' of initial perforations located @: 10980'-11130' MD 11290'-11445' MD 11470'-11530' MD 11665'-11869' MD (Z1B) (Z1B) (Z1B) (Z1B) Used 2" carriers & shot all perfs @ 4 SPF, overbalanced pressure, & random orientation. POOH w/guns. Noted all guns fired. RIH w/nozzle. 7/31/98: Tagged TOL @ 9805' MD & POOH while displacing well to Crude. RDMOL. Placed well on initial production & obtained a valid well test. Page 3 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 07 07-14A S UR VEY REPORT '10 August, '1998 Your Reft API-500292033901 Last Survey Date 22-July-98 Job# AKMW80262 KBE- 64.00' sp~,~r,~j-SLJn DRILLING SERVICE=; RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Survey Ref: svy3655 Prudhoe Bay Unit Measured Depth Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10500.00 45.000 21.000 8606.89 8670.89 10527.00 49.320 21.200 8625,24 8689.24 10539.80 50.890 16.000 8633.45 8697.45 10567.50 47.280 8.000 8651.61 8715.61 10592.40 44.740 359.000 8668.92 8732.92 10608.51 43.170 353.580 8680.52 8744.52 10644.05 34.100 338.460 8708.32 8772.32 10674.18 32.700 327.560 8733.49 8797.49 10710.00 41.660 316.840 8762.03 8826.03 10737.13 47.720 307.170 8781.33 8845.33 10771.69 50.270 295.040 8804.06 8868.06 10798.17 50.890 286.080 8820.89 8884.89 10844.66 64.420 281.150 8845.72 8909.72 10878.13 74.090 277.460 8857.56 8921.56 10905.22 79.980 274.480 8863.64 8927.64 10933.77 79.720 269.730 8868.67 8932.67 10973.97 81.210 268.320 8875.33 8939.33 11001.81 82.440 269.550 8879.29 8943.29 11031.26 84.110 269.550 8882.74 8946.74 11067.10 85.520 270.610 8885.98 8949.98 11113.47 87.630 271.310 8888.75 8952.75 11142.13 90.090 272.72-0-- 8889.32 8953.32 11172.40 92.280 273.950 8888.69 8952.69 11205.35 89.820 274.300 8888.09 8952.09 11234.35 89.470 273.420 8888.27 8952.27 11268.36 94.040 277.290 8887.23 8951.23 11292.67 96.330 283.090 8885.03 8949.03 11322.17 97.210 289.240 8881.55 8945.55 11368.82 92.200 295.040 8877.72 8941.72 11397.61 90.700 299.080 8876.99 8940.99 Sperry-Sun Drilling Services Survey Report for 07-14A Your Ref: API.500292033901 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings R~te Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 4581.63 N 1395.17 E 5955019.16 N 677157.19 E 416.32 4600.10 N 1402.30 E 5955037.79 N 677163.89 E 16.009 416.60 4609.40 N 1405,42 E 5955047.16 N 677166.79 E 33.488 417.18 4629.84N 1409.81 E 5955067.69 N 677170.70 E 25.403 420.74 4647.68 N 1410,93 E 5955085.56 N 677171.40 E 27.914 426.36 4658.83 N 1410.21 E 5955096.69 N 677170.43 E 25.297 431.19 4680.27 N 1405.17 E 5955118.00 N 677164.89 E 36.687 443.86 4695.01 N 1397.70 E 5955132.56 N 677157.07 E 20.425 456.30 4711.91 N 1384.33 E 5955149.15 N 677143.31 E 30.790 475.02 4724.58 N 1370.13 E 5955161.48 N 677128.82 E 33.528 492.92 4737.96 N 1347.85 E 5955174.34 N 677106.23 E 27.468 518.58 4745.12 N 1328.73 E 5955181.05 N 677086.95 E 26.233 538.99 4754.22 N 1290.64 E 5955189.26 N 677048.65 E 30.437 577.73 4759.24 N 1259.79 E 5955193.56 N 677017.69 E 30.670 608.22 4761.98 N 1233.54 E 5955195.68 N 676991.39 E 24.239 633.59 4763.01 N 1205.47 E 5955196.05 N 676963.30 E 16.402 660.02 4762.33 N 1165.83 E 5955194.45 N 676923.69 E 5.070 696.54 4761.82 N 1138.28 E 5955193.30 N 676896.16 E 6.216 721.91 4761.59 N 1109.03 E 5955192.38 N 676866.93 E 5.671 748.95 4761.64 N 1073.34 E 5955191.60 N 676831.25 E 4.915 782.08 4762.42 N 1027.06 E 5955191.29 N 676784.96 E 4.793 825.30 4763.42 N 998.43 E 5955191.63 N 676756.31 E 9.893 852.24 4765.18 N 968.22 E 5955192.69 N 676726.07 E 8.297 880.92 4767.55 N 935.36 E 5955194.29 N 676693.17 E 7.541 912.29 4769.51 N 906.43 E 5955195.56 N 676664.20 E 3.266 939.86 4772.68 N 872.60 E 5955197.94 N 676630.30 E 17.603 972.43 4776.95 N 848.78 E 5955201.66 N 676606.39 E 25.558 996.12 4785.11N 820.66 E 5955209.15 N 676578.08 E 20.916 1025.25 4802.62 N 777.63 E 5955225.66 N 676534.66 E 16.394 1071.71 4815.71 N 752.01 E 5955238.15 N 676508.74 E 14.964 1100.37 Comment Tie-on Survey Window Point Alaska State Plane Zone 4 PBU EOA DS 07 Continued... 10 August, 1998 - 16:50 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 07-14A Your Ref: AP1-500292033901 Prudhoe Bay Unit Measured --; Sub-Sea Vertical Local Coordinates Global Coordinates Do__~qleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 11442.08 91.670 305.060 8876.07 8940.07 4839.31 N 714.35 E 5955260.86 N 676470.54 E 13.620 1144.11 11472.87 90.620 309.280 8875.45 8939.45 4857.90 N 689.83 E 5955278.87 N 676445.58 E 14.121 1173.81 11496.65 92.460 312.800 8874.82 8938.82 4873.51 N 671.90 E 5955294.06 N 676427.30 E 16.697 1196.26 11533.52 94.390 318.070 8872.61 8936.61 4899.72 N 646.08 E 5955319.65 N 676400.88 E 15.197 1230.00 11558.63 95.360 322.990 8870.48 8934.48 4919.02 N 630.18 E 5955338.58 N 676384.53 E 19.901 1251.96 11599.34 96.420 330.550 8866.29 8930.29 4952.87 N 608.01 E 5955371.90 N 676361.57 E 18.655 1285.17 11636.66 97.820 331.250 8861.67 8925.67 4985.23 N 590.00 E 5955403.83 N 676342.81 E 4.188 1313.95 11660.92 96.240 328.970 8858.70 8922.70 5006.10 N 578.00 E 5955424.42 N 676330.32 E 11.376 1332.88 11695.40 90.890 324.380 8856.55 8920.55 5034.83 N 559.10 E 5955452.70 N 676310.76 E 20.424 1361.14 11723.91 90.260 321.580 8856.27 8920.27 5057.59 N 541.94 E 5955475.05 N 676293.07 E 10.066 1385.56 11752.23 89.740 317.010 8856.27 8920.27 5079.05 N 523.47 E 5955496.08 N 676274.11 E 16.241 1410.70 11778.89 88.500 314.200 8856.68 8920.68 5098.10 N 504.83 E 5955514.68 N 676255.02 E 11.519 1435.11 11813.18 87.100 306.990 8857.99 8921.99 5120.38 N 478.83 E 5955536.35 N 676228.51 E 21.404 1467.55 11843.44 87.890 302.600 8859.32 8923.32 5137.63 N 454.01 E 5955553.01 N 676203.29 E 14.727 1497.01 11881.00 91.250 298.970 8859.60 8923.60 5156.85 N 421.75 E 5955571.47 N 676170.60 E 13.168 1534.11 11882.77 91.410 298.380 8859.56 8923.56 5157.69 N 420.20 E 5955572.28 N 676169.02 E 34.529 1535.87 11908.73 93.600 294.690 8858.42 8922.42 5169.28 N 397.00 E 5955583.32 N 676145.56 E 16.517 1561.71 11924.51 93.690 292.580 8857.42 8921.42 5175.59 N 382.57 E 5955589.30 N 676130.99 E 13.356 1577.45 11947.00 93.810 289.740 8855.95 8919.95 5183.69 N 361.65 E 5955596.91 N 676109.88 E 12.612 1599.89 ~AII data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 291.923° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11947.00ft., The Bottom Hole Displacement is 5196.29ft., in the Direction of 3.991° (True). Comment Projected Survey Alaska State Plane Zone 4 PBU EOA DS 07 Continued... 10 August, 1998 - 16:50 - 3 - DrillQuest Prudhoe Bay Unit Comments Measured Depth (ft) 10500.00 10527.00 11947.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8670.89 4581.63 N 1395.17 E 8689.24 4600.10 N 1402.30 E 8919.95 5183.69 N 361.65 E Sperry-Sun Drilling Services Survey Report for 07-14A Your Ref: API-500292033901 Comment Tie-on Survey Window Point Projected Survey Alaska State Plane Zone 4 PBU EOA DS 07 10 August, 1998 - 16:50 - 4 - DrillQuest 0 I::! I I--L_I ~ G S E I~.~1 r' E~ S 11-Aug-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 07-14A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,500.00' MD 10,527.00' MD 11,947.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) AUG 12 1998 Alaska Oil & Gas 0OHS. 6ommission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 20. 1998 Erin Oba Engincering Supetw'isor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Rc~ Prudhoc Bay Unit 7-14A ARCO Alaska, Inc. Permit No. 98-72 Sur. Loc. 511'FNL, 314'FEL, Sec. 33. T11N. R14E. UM Btmnholc Loc. 512'FNL. 25 I'FEL. Sec. 28, T11N. R14E, UM Dcar Ms. Oba: Enclosed is the approved application for pcrmit to rcdrill thc above rcfcrcnccd wcll. Thc permit to rcdrill docs not excmpt you from obtaining additional pcrmits rcquircd by law from other govcrnmcntal agencies, and does not authorize conducting drilling operations until all other requircd pcrmitting dctcrminations are made. Blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25 035. Sufficicnt noticc (approximatcly 24 hours) must bc given to allow a rcprcscntativc of thc Commission to xx'itncss a test of BOPE installcd prior to drilling ncw hole. Notice may be givcn by contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. ~$inc t'- David W. J~l~ston ' Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosurcs CC2 Dcpartmcnt of Fish &Gamc, Habitat Scction xv/o cncl. Departmcnt of Environmental Conservation v,'/o cncl. STATE OF ALASKA ~¢-- ALA~7~A OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Ddll_ Redrill X lb. Type of Well Exploratory_ Stratigraphic Test_ Development Oil Re-Entry__ Deepen _ Service_ Development Gas_ Single Zone X Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28309 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 511' FNL, 314' FEL, Sec 33, T11N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1410' FNL, 996' FWL, Sec 27, T11N, R14E, UM 7-14A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 512' FNL, 251' FEL, Sec 28, T11N, R14E, UM. April, 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 12340' MD / 8903' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10610' MD Maximum hole an~lle 94° Maximum sudace 3310 psig At total depth ('FVD) 8800' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling ILength I MD I TVD I MD I TVD I (include stage data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 2490' 9850' 8201' 12340' 8903' 15 bbls I I I I I I 19. To be completed for Reddll, Re-entry, and Deepen Operations. L Present well condition summary Total depth: measured 1 1075 feet Plugs(measured) true vertical 9078 feet Effective depth: measured 10998 feet Junk (measured) /~aSk~, 0il & t2as 00ns. O0mmissi0r:, true vertical 9023 feet -- Anchorage casing Length Size Cemented Measured depth True Vertical depth Conductor 71' 20" 243 Sx Arcticset 71' 71' Surface 2601' 13-3/8" 4300 Sx AS II 3665' 2665' Production 10979' 9-5/8" 1200 Sx Class G 11043' 9055' Perforation depth: measured 10604- 10606'; 10690 - 10704'; 10833- 10843'; 10857- 10891'; 10898 - 10906'; 10912 - 10934' true vertical 8744 - 8746'; 8805 - 8815'; 8906 - 8912'; 8923 - 8947'; 8952 - 8958'; 8962 - 8977'0 R [ G [ NA 20. Attachments Filing fee ~x Property plat _ BOP Sketch __x Diverter Sketch _ Drilling program Drilling fluid program Time vs depth pict _ Refraction analysis Seabed report 20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,~ ~.S~'~ o;'~ %; f,_, ¢'~,i ~ 5 ~'~',~' Signed '~ ,,,~ '"~. ~ Titlle Engineering Supervisor Date ~- Commission Use Only Permit N~.r ,~ APl number Appr°val date '~'~¢;~ ~'8 See cover letter for ~ 50- ~'3.2 <~ - .~.. (~I ~,.~,¢~. <:2! ~)"' other requirements Conditions of approval Samples required Yes .~_ No Mud log required Yes _~'~o Hydrogen sulfide measures J~"CCes _ No Directional survey required _,~Yes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 1OM; _ 15M X 3500 psi for CTU Other: 0r~glr~al Signed :.dy Uo, vid W. Johnston byorderof Approved by Commissionerthecommission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 7-14A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Perforate and produce. Intended Procedure: · Cement squeeze and plugback the existing completion to - 9900' md. Mill window in 9-5/8" casing at -10610' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. Directionally drill 3.75" x 1700' horizontal well to access Lower Romeo reserves. Build angle to -90° at TD. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Place well on production. April 1,1998 DS 7-14A Proposed CT Sidetrack Horizontal 5-1/2" Tubing 5-1/2" E 5-1/2" XN Nipple 9732' Packer 4-1/2" TT I 21256' 9520' 5-1/2" RQM SSSV Nipple ID ='4.562" 5-1/2" XA Sliding Sleeve ID = 4.562" Top of 2-7/8" Liner in 4-1/2" Tbg. tail. Initial Perfs- 1200' 9-5/8" Casing shoe @ 11 Window cut in 9-5/8" at ,--10610- 10615' 2-7/8" liner 3.75" Open hole Current perforations I o 6cZ~- I O'~ ~ cement squeezed TD @ ~ 12340' /True 28.3~ Declination . . ARCO ALASKA INC. 7-14A COILED TUBING SIDETRACK Prudhoe Bay, Alaska 8100 --. __. 8350 -- .-~ 8600--~.' ..... .... 8850 .............. _.. SCALE I i r~ch · 500 feet ......... 6000 .-- _ __ -' 5500 ___~. __ o .... II _1 . .. iii I I I i ii I . i_ . '7 6 _ SCALE 1 inch ' 250 feet 9100" · -4 23 1 . . 9 TD 8839,0 TVD MD 12339 93.9- 7-14AT 7-14ORTR oo 0 0 o o {,~ o {~ 0 Compan}~ Cn]cuta~lon Melhod: Vertical SeCtr Rant: Surv Men.red From; [i 7 [1~11_]._ ! [ I [11[ [ [ ] ] iff ...... SURVEY CALCULATIONS Coordiuates provided in: TRUE and GRID relalive to Wellhead and ALASKA STATE PLANE ARCO ;~ta~k~ ]mx Rig:. 7-14A FSrld: Minimtmi Curvature Mag. Dedknmtian: 291.913 TRUE 290.6 GRID Grkl Corre~flam Mi) from RKqL Total Correction: 'r¥1l fi'om .%a tevd Caort~. - TRUE N(+}~S(-) tat 0') ~. fxl 4653.98 1423.73 469~.M 14~2.54 471L3l 1415.59 47~.49 13~.67 47~.76 1272.~ 4729_~ 1029.~ 52~Z67 57.18 ~7.9g Nabon 3~. I)!8 ('1' uni; g4 AYE No: 28,~0 Job Start Dntr: L339 Jab ~ ~: 2~.~ ~ D~ ~r ( f~ f m ): C:~rd~. - GRID Coordt - ASP I~t. (g) Dip. tX) lat. (~ ~ ~ 46[2.~) 12~7.73 3955019.20 6~915720 ~79,3'7 1312. t0 5955085.5 g 677181.57 1314.59 5955~2.20 6771 ~.06 4722.75 1322.55 5955 t28.~ 6771~2.02 ~74~. [ I 1 ~4.9g 59551 S5.32 6~7174.45 4774.63 1233 .~ 595518D.M 677102.91 4773.21 ] t6 [ .17 ~955 t79A2 6~7030.M 475~ 918.~ ~a 5955l. 57.98 676797.69 5269.5g:: ~65.9g 6~58~3.49 -71.33 59556~.97 ~ 675798.14 0.05 mtn Toting tl~an-~! IO0.O COMMEN~ KOP. 1730 ft. KOPto TD. C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection )tis 7" WLA Quick onneot ' ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure '~ I -- 7" Riser I I I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual J Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manu.a,! over .,Hydraulic 7-1/16 ID wi~n Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus I I13-3/8" Annulus Fuel Shop oilers Mu~ Tanks Water Pump Fire Ext. Ext. 6O14O1 I TrplxI /~\Pipe rac,,~ I I I Ext. EDOWell Drilling quipment Traillr Preferred Major Equipment Layout for CT Drilling · ADMINISTRATION WELL PERMIT CHECKLIST COMPANY ~ __ WELl_ NAME ~',,~,/_.~ ~ °/"~ PROG, RAM: exp [] dev~redrll~serv [] wellbore segl ann disposal para C~E-OL ,~REA C~'d UNrT#/ '~/~__ ~"/'~ ON/OFFSHORE ..... <~__~,,) I'~'[[~il le~' attached ?. I ease llunl[:~er appropriate 3 Unique well name and numbe~ 4 Well located in a defined pool ....... 5 Well located ploper distance flora d~illing unil boundary. 6 Well located proper distance from other wells . . 7 Sufficient acreage available in drilling unit 8 If devialed, is wellbore plat included ()peralor o~fly affected pady. 1(} (.)peralor t~as appropriate bond in force 11 r-'em,it can be issued without conservation order I'eru~it.can be iSsLJed wilhoul administralive approval (.;iii ll[!~rllll [)¢) apl)roved before 15-day wail Conductor sh~ng provided . . Suriace casing prolects all know~ LJSDWs. . . CM 1' vol adequale Io circulate on conductor & surf csg. CMl vol adequate to tie-in long string Io surf csg .... _.~R D~IE' 17. ENGINEERING 14 15 16 17 19 2O 21 GEOLOGY AD_PR CM'I will cover' all known productive horizons... Casing designs adequate for C, -I'. B &permatrost Adequate lankage or reserve pit .......... I1 a re-drill, has a 10-403 for abandomnenl been approved. 22 23 24 25 27 28 N REMARKS Y N Y N ~N Adequate wellbore separation proposed . . I1 diverler required, does il rneel regulations [)filhn[t fh~id program scheft]alit & eqlJip list adequate t3¢)['F p,ess rating appr;priate: lest to._ '~2.__~.? .... ps,(.] N Choke rnanilold complies w/APl RP-53 (May 84) Work will occur wilhout operalion shuldown t~; l~fesefl(:e of tI:.S gas probable. . 30 Pernut can be issued w/o hydrogen sulfide measures 31 Data presenled on polenlial overpressure zones 32 Sem~nic analysis of shallow gas zones. 33 Seabed condition survey (if off-sho~e) .... 3,1 (';t~r]lz](:t ~]al~le/phorm for we~klyprogress ~eports lexplor~lo~y only] G [-- _(:_)~' ENGINEERING COMMISSION DW: ,I Pt' t.._.-'~-~- RNC~ co Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumUlated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drillin~ Services LIS Scan Ut2_ ~cY _ Tue Nov 10 18:48:08 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/11/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 16 AK-MW-80262 D. LABRECQUE M. JOHNSON 7-14A 500292033901 ARCO ALASKA INC. SPERRY-SUN DRILLING SERVICES 10-NOV-98 MWD RUN 17 AK-MW-80262 D. LABRECQUE M. JOHNSON MWD RUN 23 AK-MW-80262 W. JACKSON M. JOHNSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 24 AK-MW-80262 W. JACKSON M. JOHNSON MWD RUN 25 AK-MW-80262 W. JACKSON M. JOHNSON 33 lin 14E 511 314 64.00 .00 MWD RUN 26 AK-MW-80262 W. JACKSON M. JOHNSON GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 5.500 27.0 4.500 9501.0 5.500 9625.0 3.750 11881.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-15 ARE ATTEMPTS TO MILL THE WINDOW AND ARE NOT PRESENTED. 3. MWD RUNS 16, 17, AND 23-26 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION TYPE DETECTORS. MWD RUNS 18-22 DID NOT DRILL ANY FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUN 27 DID NOT REACH BOTTOM DUE TO HOLE CONDITIONS. AS A RESULT, MWD DATA IS PRESENTED TO 11947'MD AND FINAL TD OF THE WELL IS l1881'MD. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1881'MD, 8860'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10399.0 11940.5 ROP 10399.0 11917.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 10399 0 10417 0 10421 5 10560 5 10579 5 10599 0 11940.5 GR 10400.0 10418.0 10422.0 10563.5 10584.5 10602.5 11944.0 EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO 16 17 23 24 25 26 MERGED MAIN PASS. $ MERGE TOP 10432 0 10524 0 10536 0 10910 1 11120 0 11241 5 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10524.0 10536.0 10910.1 11120.0 11241.5 11947.8 -Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10399 11940.5 11169.8 3084 10399 GR 11.146 217.288 70.0928 3037 10399 ROP 0.874 1796.83 68.406 3084 10399 Last Reading 11940.5 11917 11940.5 First Reading For Entire File .......... 10399 Last Reading For Entire File ........... 11940.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 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 ....... 98/]~ /t0 Maximum Physical Record..655. File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10400.0 10495.5 ROP 10400.0 10523.5 $ LOG HEADER DATA DATE LOGGED: 10-JUL-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 10524.0 10432.0 10524.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 280 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 3.800 3.8 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: SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 84.4 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 API 4 1 68 4 2 ROP MWD 16 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10400 10523.5 10461.8 248 10400 GR 13.62 40.76 18.8544 192 10400 ROP 13.32 1139.71 136.387 248 10400 Last Reading 10523.5 10495.5 10523.5 First Reading For Entire File .......... 10400 Last Reading For Entire File ........... 10523.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 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 ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 17 DEPTH INCREMENT: .5 0 0 0 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10496.0 ROP 10524.0 $ 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: STOP DEPTH 10513.0 10535.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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): MLTD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 12 -JUL- 98 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 10536.0 10524.0 10536.0 .0 .0 TOOL NUMBER NGP SPC 280 3.800 3.8 SEk-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 89.1 .3 .Max frames per record ........... Undefined Absent value .................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 17 API 4 1 68 4 2 ROP MWD 17 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10496 10535.5 10515.8 80 10496 GR 15.266 36.398 21.1475 35 10496 ROP 0.874 1046.68 76.409 24 10524 Last Reading 10535.5 10513 10535.5 First Reading For Entire File .......... 10496 Last Reading For Entire File ........... 10535.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NIIMBER: 4 P_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 23 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 10513.5 10882.5 10536.0 10909.5 16-JUL-98 SURFACE SOFTWARE VERSION: DOWN-HOLE 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 NGP NATURAL GAMMA PROBE $ 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 PCG 7.53 PCD 3~._~e MEMORY 10910.1 10536.0 10910.1 32.7 74.1 TOOL NUMBER NGP SPC 289 3.750 3.8 FLO-PRO 8.80 .0 8.3 6.0 .000 .000 .000 .000 86.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 23 API 4 1 68 4 2 ROP MWD 23 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 10513.5 10909.5 10711.5 793 GR 11.15 148.9 45.433 739 ROP 21.2 1796.83 65.5408 748 First Reading 10513.5 10513.5 10536 Reading 10909.5 10882.5 10909.5 First Reading For Entire File .......... 10513.5 Last Reading For Entire File ........... 10909.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 24 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10883.0 11092.5 ROP 10910.0 11119.5 $ LOG HEADER DATA DATE LOGGED: 17-gilL-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: PCG 7.53 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11120.0 TOP LOG INTERVAL (FT) : 10910.1 BOTTOM LOG INTERV~_L (FT) : 11120.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 79.7 FLAXI~ ANGLE: 85.5 PCD 3.01e · TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYi NGP NATURAL GAMMA PROBE $ BOREHOLE ARID 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 318 3.750 3.8 FLO-PRO 8.8O .0 8.3 6.0 .000 .000 .000 .000 70.3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 24 API 4 1 68 4 2 ROP MWD 24 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10883 11119.5 11001.2 474 10883 GR 29.071 162.992 62.9801 420 10883 ROP 13.707 124.724 60.1744 420 10910 Last Reading 11119.5 11092.5 11119.5 First Reading For Entire File .......... 10883 Last Reading For Entire File ........... 11119.5 File Trailer Service name ............. sTsLiB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 25 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11093.0 11214.0 ROP 11120.0 11241.0 $ LOG HEADER DATA DATE LOGGED: 18-JUL-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.6 MAXIMLR~ ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 11241.5 11120.0 11241.5 TOOL NUMBER NGP SPC 252 3.750 3.8 FLO-PRO MI/D DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.80 .0 8.1 6.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 25 API 4 1 68 4 2 ROP MWD 25 FT/H 4 1 68 8 3 72.6 First Name Min Max Mean Nsam Reading DEPT 11093 11241 11167 297 11093 GR 54.063 143.497 90.5358 243 11093 ROP 18.469 160.46 53.0876 243 11120 Last Reading 11241 11214 11241 First Reading For Entire File .......... 11093 Last Reading For Entire File ........... 11241 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF r~j~ File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NLIMBER: 7 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 26 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11214.5 11920.5 ROP 11241.5 11944.0 $ LOG HEADER DATA DATE LOGGED: 22-JUL-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.1 MAXIMUM ANGLE: 97.8 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 11947.8 11241.5 11947.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NLTMBER NGP SPC 252 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 3.750 3.8 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 8.80 .0 8.6 6.2 .000 .000 .000 .000 72.6 · NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 26 API 4 1 68 4 2 ROP MWD 26 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11214.5 11944 11579.2 1460 11214.5 GR 26.608 217.288 89.5558 1413 11214.5 ROP 4.221 232.622 62.8606 1406 11241.5 Last Reading 11944 11920.5 11944 First Reading For Entire File .......... 11214.5 Last Reading For Entire File ........... 11944 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNE/qOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/11/10 Origin ................... STS Reel Name ................ UNK/~OWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
