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178-091
. ~ ~ RECEI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COSIGN ~~~ ~ ~ 2007 WELL COMPLETION OR RECOMPLETION REPORT AN ~A~B~c~ Oil & Gas Conn COftlmis~ian Annknr~nra 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC zs.,os zoAAC zs_„o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 10/15/2007 12. Permit to Drill Number 178-091 307-268 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 06/09/1979 13. API Number 50-029-20347-00-00 - 4a. Location of Well (Governmental Section): Surface: 489' FSL 840' FWL SEC 01 N R 7. Date T.D. Reached 07/02/1979 14. Well Name and Number: PBU NGI-13 , , . , T11 , 14E, UM Top of Productive Horizon: 311' FSL, 2540' FWL, SEC. 01, T11 N, R14E, UM 8. KB (ft above MSL): 48' - Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 279' FSL, 2748' FWL, SEC. 01, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 8907 8581 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687016 y- 5972801 Zone- ASP4 10. Total Depth (MD+TVD) 8950 - 8620 16. Property Designation: ADL 028302 - TPI: x- 688719 y_ 5972665 Zone- ASP4 Total Depth: x- 688928 y- 5972639 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submi electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL / SP, BRCS /CAL / GR, FDC / CNL / GR /CAL, DLL, RFT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 74' Surface 74' 20" 277 Arcticset Cement 13-3/8" 72# N-80 Surface 2709' Surface 2709' 17-112" 4800 sx Arcticset II 9-5/8" 47# N-80 2440' 8015' 7741' 12-114" 700 sx Class 'G' 7" 29# N-80 7725' 8949' 7459' 8619' 8-1/2" 325 sx Cla s'G' 23. Open to production or inject ion? ^ Yes ®No 24. TuewG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 7", 29#, L-80 3508' - 7621' 7606' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SDUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Se KIND OF MATERIAL USED ``°~ ~:) ~~~ ~ ZO~7 7578' P&A w/ 59 Bbls Class'G' 2415' Set EZSV 2385' Set Whipstock on top of EZSV 26. PRODUCTION TEST Date First Production. ~ __ .. _ .... , .. ~ . _: , _ Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OlL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resul~AAC,250.071. None ~ ~)'~4` ~' ' '~) ~~~~ ~. Form 10-407 ReVISed 02/2007 CONTINUED ON REVERSE SIDE AX~'~I~ V' 1 _' ~ /- 28. ;,IC MARKERS (LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Sadlerochit 8405' 8118' None Base Sadlerochit 8864' 8542' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / / Signed Terrie Hubble ~ Title Drilling Technologist Date It ` 15` ~ 7 PBU NGI-13 178-091 307-268 Prepared By Name/Number.• Terrie Hubble, 564-4628 Drilling Engineer: Kris Honas, 564-4338 Well Number Permit No. / A royal No. INSTRUCTIONS GENeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. {TEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. treM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only Digi>~al Well File ~ ~ Page 1 of 2 . Well: NGI-13 Well History Well Date Summary NGI-13 8/27/2007 T/IA/OA= SSV/350/150 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (RWO prep) PPPOT-T RU HP bleed tool onto THA test void 200 psi bled to 0 psi. Cycled and re-torqued all LDS " Standard" all moved free with no broke or bent pins. Removed and replaced Alemite, check not holding. Pressure void to 5000 psi for 30 min test, 5000! 15 mins, 4950! 30 mins. Bleed THA void to 0 psi, RD test equipment re-installed Alemite cap. PPPOT-IC RU HP bleed tool onto IC test void 50 psi bleed to 0, flushed void until clean returns achieved. Cycled and re-torqued all LDS "Standard" afl moved free with no broke or bent pins. Removed and replaced Alemite, check not holding. Pressure void to 3500 psi for 30 min test, 3500/ 15 mins, 3500/ 30 mins. Bleed IC void to 0 psi. RD test equipment re-installed Alemite cap. NGI-13 8/31/2007 T/I/0 =SSV/360/160. Temp = SI. OA FL (pre MIT OA). Intergal installed on IA. OA FL @ surtace. NGI-13 9/2/2007 T/I/O=SSV/400/150. Temp=Sl. MITOA PASSED to 2500 psi w/Triplex (pre-RST). OA FL @ surface. Pressured u OA w/Diesel from 150 si to 2000 si. Start test, OA lost 0 psi in the first 15 min and 0 psi in the secon 1 min or a tota oss o psi in 30 min. Bled OAP from 2000 psi to 0 psi. SI, monitored for 30 min OAP increased to 150 psi. Final WHP's=SSV/350/150. NGI-13 9/3/2007 *** WELL S/1 ON ARRIVAL *** RAN 5.98" DRIFT- TAGGED TOP OF 7" INSERT @ 2182' SLM... DRIFT CLEAR. CURRENTLY IN THE PROCESS OF PULLING 7" INSERT FROM SVN. ***CONT. JOB ON 09/04/07 WSR*** NGI-13 9/4/2007 ***CONT. JOB FROM 09/03/07 WSR*** MADE 5 RUNS TO PULL 7" INSERT W/ GS FROM SVN @ 2199' MD... UNABLE TO MOVE INSERT. SET 4 1/2" XX PLUG [R keys] W/ NO-GO INTO INSERT @ 2199' MD AFTER FOUR ATTEMPTS. TRIED TO PERFORM EXTRACTION ON 7" INSERT... PLUG WILL NOT HOLD. PULLED 4 1/2" XX PLUG FROM 7" INSERT @ 2199' MD. CURRENTLY IN THE PROCESS OF R/D SLICKLINE & R/U BRAIDED LINE ***CONT. JOB ON 9/5/07 WSR*** NGI-13 9/5/2007 *"*CONT. J08 FROM 09104/07 WSR*** [pre p&a/sdtrk] RIG UP BRAIDED LINE. PULLED 7" INSERT FROM SVN Cad 2199' MD... LOCK INTACT, PACKING INTACT, NO-GO RING LOOKS INTACT, THREADS TIGHT. RIG UP SLICKLINE. RAN 4.5" DRIFT, TAG TOP_OF WRP ~ 7600' SLM FORA 5' CORRECTION TO 7595' ELMD. RAN WFD WRP PULL-TOOL W/O COLLET, TAGV1/RP FN- EQUALIZED PLUG. RAN WFD WRP PULL-TOOL W/ COLLET- PULLED WRP FROM 7600' SLM... MISSING ONE ELEMENT. RAN 4.56" CENT & 3 PRONG GRAB BAITED, DRIFT CLEAR TO TD @ 8855' SLM- 8850' ELMD... 12' COVERED PERFS. ELEMENT LEFT IN HOLE. CURRENTLY IN PROCESS OF RUN SBHP W/ PETRADAT GUAGES. ***CONT. JOB ON 9/06/07 WSR*** NGI-13 9/6/2007 ***CONT. JOB FROM 09/04/07 WSR*** [pre p&a/sdtrk] RAN SBHP SURVEY W/ PETRADAT GUAGES AS PER PROGRAM. ***WELL LEFT S/I, TURNED WELL OVER TO DSO*** NGI-13 9/18/2007 Heat Uprights (Rig ST prep) Heated two uprights of 1 % kcl to 125*f and 1 upright of fresh water to 110*f. NGI-13 9/19/2007 **** CTU 9 - P&A ****MIRU. Broadcasting. Begin weekly BOP test. Continued on 09/20/07 WSR. NGI-13A 9/19/2007 **** CTU 9 - P&A ****MIRU. Broadcasting. Begin weekly BOP test. Continued on 09/20/07 WSR. NGI-13A 9/19/2007 **** CTU 9 - P&A **** MIRU NGI-13A 9/19/2007 **** CTU 9 - P&A **`*MIRU NGI-13 9/20/2007 Continued from 09/19/07 WSR. Complete weekly BOP test. TesUgrease/test horse trailer isolation valves. Burp IA -fluid packed. -Kill well -Mix, um and lay in 59 bbls Class 'G' cement at 15.8 pg (45 bbls with 12 ppb aggregate) Bump WH to psi - can cemen ou o a ° **** Job in progress **** NGI-13 9/20/2007 Continued from 09/19/07 WSR. Complete weekly BOP test. TesUgrease/test horse trailer isolation valves. Burp IA -fluid packed. -Kill well -Mix, pump and fay in 59 bbls Class'G' cement at 15.8 ppg (45 bbls with 12 ppb aggregate) Bump WH to 800 psi -Clean cement out to 7602' - POH at 80%. Freeze protect from 2500' w/ water/meth. Trap 300 psi WHP. Wash BOP's, recover ball. Rig down in progress. Continued on 09/21/07 WSR. NGI-13 9/20/2007 Continued from 09!19107 WSR. Complete weekly BOP test. TesUgrease/test horse trailer isolation http://digitalwellfile.bpweb.bp.corn/WIInfo/Reports/ReportViewer.aspx 11 /8/2007 Digi>al Well File NGI-13 9/21/2007 valves. tsurp~nwo pacKeo. Continued from 09/20/07 WSR. Complete rig down. Move off. Job complete. Page 2 of 2 NGI-13 9/22/2007 **** WELL SHUT IN **** (post p8a /pre pre sdtrk) DRIFTED TBG W/5.50" CENT & S.BAILER SAT DOWN AT 7,568' SLM (NO SAMPLE). MIT-CEMENT TO 2500 si. NO PSI LOSS IN 30 MIN - , NO DEPTH CHANGE. D B 7578 , S.BAILER. (CEMENT SAMPLE). **** JOB STILL IN PROGRESS, WSR CONTINUED ON 9/23/2007**** NGI-13 9/23/2007 ARRIVE LOCATION, LRS FINISHING MIT ON WELL. PUNCH FROM 7572'-7577' 4 JSPF USING MEDIUM CHARGES. LRS START TO CIRCULATE 8.9 RIN HRU IA RETURNED THRU TUBING. COULD NOT PUMP IA TO TBG. SWITCHED DIRECTIONS AND STARTED CIRCULATING DOWN TUBING TAKING RETURNS THRU IA. PUMPING AT 4 BPM. ***JOB CONTINUED ON 9-24-07 AWGRS WSR*** NGI-13 9/23/2007 T/I/0=70/240/0 Temp=Sl MIT-T PASSED to 2500 psi (Rig ST Prep) - AOGCC Witnessed b Jeff Jones. Pressured up tbg (against cement plug) from 70 psi to 2500 psi w/1.9 s neat met ano . g os psi in 1st 15 min. Tbg lost 30 psi in 2nd 15 min. Watch for additional 15 min, tbg lost 10 psi. Passed, bleed TP all fluid -2 bbls. E-Line punched holes in tbg. Circ out well w/ 7 bbls meth spear, 475 bbls 9.8 Brine pumping down Tbg through tbg punched holes up IA to open top tanks. Continued on 09-24-07 NGI-13 9/23/2007 ***WSR CONTINUED FROM 9/22/2007**'' (Post P&A, pre sidetrack) TAGGED CEMENT AT 7578'SLM W/3.50" CENT (SAMPLE OF CEMENT). ****LEFT WELL SHUT-IN AND NOTIFIED DSO OF WELL STATUS**** NGI-13 9/23/2007 T!1/0= 100/250Nac. Temp= SI. Rig up 3 pen chart recorder (pre-MIT-IA). Rigged up 3 pen chart recorder. Pressure tested lines to 3500 psi. NGI-13 9/24/2007 ***CONTINUED FROM PREVIOUS DAY*** WELL CIRCULATED WITH APPROX. 700 BBLS OF 9.8# BRINE, FOLLOWED WITH 10 BBLS OF FREEZE PROTECT. GYRO DIRECTIONAL SURVEY PERFORMED FROM 3000' TO SURFACE. GYRO TOOL ZEROED AT WEATHER HOLD, WIND TO HIGH TO OPERATE CRANE. JET CUT TUBING AT 3508'. WIND READINGS AT 40 + MPH. WAITING FOR WIND TO DIE DOWN. ***CONTINUED ON 25 SEPT 07*** NGI-13 9!24!2007 Continued from 09-23-07 WSR. Circ Out w/ 9.8 brine. Pumped remaning 222 bbls (697 total) 9.8 brine, 5 bbls diesel down tbg through tbg punched holes up IA to opentop tanks. Casing valves open to gauges, tags hung. FWHP=O/0/0 Print Date: 11!8/2007 Page 1 of 1 http://digits.1we11file.bpweb.bp.comfWIInfo/Reports/ReportViewer.aspx 11/8/2007 • BP EXPLORATION Page 1 of 16 ' Operations Summary Report 'Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: I Date ~ From - To ~ Hours ~ Task ~ Code NPT ~ Phase 9124/2007 00:00 - 00:30 0.50 MOB P PRE 00:30 - 16:00 15.50 MOB P PRE 16:00 - 18:00 2.00 RIGU P PRE 18:00 - 19:00 1.00 RIGU P PRE 19:00 - 00:00 5.00 RIGU P PRE 19/25/2007 100:00 - 12:00 I 12.001 RIGU I N I WAIT I PRE 12:00 - 21:30 I 9.501 RIGU I N I WAIT I PRE 21:30 - 00:00 I 2.501 RIGU 1 N I WAIT I PRE 19/26/2007 100:00 - 12:00 I 12.001 RIGU I N I WAIT I PRE 12:00 - 00:00 I 12.001 RIGU I N I WAIT I PRE 19/27/2007 100:00 - 12:00 I 12.001 RIGU I N I WAIT I PRE 12:00 - 00:00 1 12.001 RIGU I N I WAIT I PRE Description of Operations R/D, prepare to move off location Move rig to NGI-13 Prepare to raise Derrick on the side of NGI Pad. -Remove front & rear booster tires. PJSM. Raise Derrick. PJSM. Rig up. -Clean and clear Rig floor -Hook up steam lines. -Prep all cables and hoses. Raise front wind wall and install braces -Skid rig floor into drilling position -Lower bridle lines, LD sheave and hang bridle lines in derrick -Lower C-section -Build BOP stack -Remove and break down block trolly -Install top drive goose neck and bale brace - PU top drive -Install upper top drive roller, remove bale brace and install lower top drive support brace Accept rig at 00:01 9-25-07 Cont. building BOP stack - RU top drive service loops - Mobilize rig tongs, IBOP and saver sub -Slide conveyor out into position -Move out block hanging roller asst'. -Install auger into rock washer -Install upper and lower IBOPs and saver sub. Commission top drive -Prepare rig floor for painting -Install PASON weight indicator Waiting on wind speed to slow down to pull off well house and prepare well site to spot rig. Wind speed still too high to safely remove well house Cont. commissioning top drive -Change out grabber /bell guide to 5" (top drive) -Work on camera mount -Split BOP stack and reorient annular -Hook up koomey lines and kill line to stack -Torque IBOP and saver sub -Install 3 lock rings, torque and wire tie -Lower stand pipe and install valves -Clean and paint drawworks Wind speed still too high to safely remove well house Cont. working on stand pipe and mud manifold -Remove bale stabilizer -Remove hanging shackle from blocks -Install bales and 5" elevators -Cont. painting drawworks and tugger -Wiring driller console, PASON and camera system -Attach secondary fall arrester -Install heaters in cellar -Finish commissioning top drive -Attach kelly hose -Install cement stand pipe -Hang tongs -Attach hole fill line -Cleaning pipe shed -Painting rig li floor '.Waiting on wind speed to slow down and remove well house Install derrick camera -Cont. preparing rig floor -Clean and paint rig floor and console guard - RU rig floor -Adjust kelly hose and stand pipe -Install glycol heaters in cellar Cont. adjusting kelly hose -Paint floor in pipe shed -Install camera mounts in pits and cellar -Cont. installing and calibrating PASON -Readjust elect. service loops (top drive) - Secure all guards for driller's console -Test run joystick for pipe skate -Clear rig floor of all unnecessary equipment - Secure alf guards for hydraulic fines -Run camera line down derrick side -Service air slips and dress w/ 5" dies -Attach snub lines and EZTOROUE lines to tongs -Attach landings to Printed: 10/25/2007 1:25:52 PM • ~ $P EXPLORATION Page 2 of 16 - Operations Siummary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT Phase Description of Operations 9/27/2007 112:00 - 00:00 1 12.001 RIGU { N 9/28/2007 00:00 - 03:00 3.00 RIGU N 03:00 - 03:30 0.50 MOB N 03:30 - 07:00 3.50 MOB P 07:00 - 09:00 I 2.00 f RIGU 1 P 09:00 - 10:00 1.00 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00 - 13:00 2.00 WHSUR P 13:00 - 14:00 1.00 WHSUR P 14:00 - 14:30 0.50 WHSUR P 14:30 - 16:00 1.50 WHSUR P 16:00 - 17:00 1.00 WHSUR P 17:00 - 18;30 1.50 WHSUR P 18:30 - 20:00 1.50 WHSUR P 20:00 - 20:30 0.50 WHSUR P 20:30 - 22:00 1.50 WHSUR P 22:00 - 00:00 2.00 BOPSU P 9!29/2007 00:00 - 02:30 2.50 BOPSU P 02:30 - 04:00 1.50 BOPSU P 04:00 - 11:30 7.50 BOPSU P 11:30 - 12:00 I 0.50 BOPSUF~P 12:00 - 13:00 1.00 FISH I P 13:00 - 14:00 ~ 1.OOI FISH I N 14:00 - 16:00 2.00 FISH P 16:00 - 19:00 3.00 FISH P WAIT PRE BOP -Attach service loop rings -Set CROWN-O-MATIC Note: Removed well house and flow line -Install BPV- Prepare site WAIT PRE Secure service loops -Finish painting in pipe shed Prepare well site -Lay down herculite and rig mats WAIT PRE Skid rig floor to moving position PRE Move rig down pad and spot on well -Spot and berm rock washer -Prepare rig pits -Hook up tiger tank -Skid rig floor to drilling position DECOMP RU line to OA - RU cellar dike -Fill pits w/ 9.8 ppg brine -Pull tree cap DECOMP RU DSM lubricator -Pull BPV - RD DSM lubricator DECOMP Pressure test OA to 2,000 psi x 30 min. Chart test DECOMP RU line from tubing to hard line and tiger tank. Test w/ air and then test w! brine to 1,000 psi. Blow down lines DECOMP Pump down the annulus 9.8 ppg brine @ 3 bpm-190 psi without returns. At 31 bbls pressure began to increase to 860 psi. Shut down pumps and pressure held. No returns. Bleed off pressure DECOMP Blow down lines - RU lines to pump down tubing and take returns to pits. DECOMP Pump 9.8 ppg brine down tubing, taking returns to pits @ 6 bpm-1,100 psi -Dump diesel returns (dump 74 bbls) -Let diesel migrate x 30 min -Pump 10 bbls until clean -Blow down lines DECOMP RU DSM lubricator -Install BPV - RD DSM lubricator -Install Cameron test dart DECOMP RU line to IA -Test BPV to 1,000 psi f/ below x 30 min. Chart test DECOMP RU on tree and test against test dart to 4,000 psi x 5 min. Chart test - RD test equipment and drain tree DECOMP Terminate and blank off control lines on tree DECOMP ND tree and adapter flange -Actuate LDS to check they are. free -Confirm hanger thread with XO DECOMP NU spacer spool and BOP DECOMP NU 80P - CO upper rams to 4 112" X 7" -Install secondary valve on IA -Confirm 3 1 /2" x 6" variables in lower rams DECOMP RU to test BOP w/ 5" test'oint DECOMP Test BOP and related equipment as per BP / AOGCC regulations. est to 250 psi low - 4, 00 psi high (annular preventer to 250 psi low - 3,500 psi high). RD 5" test joint. f2U 7" test joint and test upper rams to 250 psi low - 4,000 psi high. Chart tests. Tests witnessed by WSL, Tourpusher and AOGCC Re .Chuck Scheve . ~ DECOMP RD testing equipment -Blow down lines -Vac out stack DECOMP Dry rod out Cameron test dart - RU to pull back pressure valve wl lubricator WAIT DECOMP Wait on DSM DECOMP RU DSM lubricator -Pull BPV - RD DSM lubricator DECOMP MU spear assy. -Engage tubing hanger and pull /work tubing progressively to 350k until tubing came loose. Conduct derrick inspection after tubing came loose. Printed: 10/25/2007 1:25:52 PM • - BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Event Name: REENTER+COMPLETE Start: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date ~ From - To ~ Hours I Task ~ Code ~ NPT (Phase I 9/29/2007 119:00 - 20:30 I 1.501 PULL I P 20:30 - 21:00 I 0.501 PULL ~ P 21:00 - 00:00 3.00` PULL P 19/30/2007 100:00 - 02:30 I 2.501 PULL I P 02:30 - 03:00 I 0.50 ~ PULL I P 03:00 - 05:30 2.50 PULL P 05:30 - 07:30 I 2.00 PULL I P 07:30 - 10:30 If 3.00 DHB P 10:30 - 12:30 12:30 - 17:00 17:00 - 19:30 19:30 - 20:00 20:00 - 21:00 21:00 - 00:00 110/1/2007 100:00 - 12:00 12:00 - 00:00 2.00 DHB 4.50 EVAL 2.50 DHB 0.50 DHB 1.00 DHB 3.00 PULL 12.001 PULL 12.001 PULL Spud Date: 6/9/1979 9/21/2007 End: Description of Operations DECOMP Pull tubing hanger to surface -Circulate soap sweep surface - surface @295 gpm - 320 psi DECOMP RU to POH 7" tubing and control lines DECOMP Break spear and LD tubing hanger - POH and LD 7" tubing (tight connections), recovering control lines. Both control lines broke off down hole @ +/- 950', and were recovered again @ +/- 1,200' DECOMP Cont. POH and LD 7" tubing (tight connections), recovering control lines to SSSV - LD SSSV Recovered 27 clamps Total jtts LD to this point: 53 jtts 7" tubing IJ4S DECOMP RD control line spool and hydraulic hoses DECOMP Cont. POH and LD 7" 8Rd tubing Total jtts LD overall: 99 jtts + 14.49' cut jt. DECOMP Clean and RD casing tools - PU spear, make service breaks and LD -Clear rig floor -Install wear bushing DECOMP RU E-line - MU tools -Run 8.3 gauge ring and junk basket to P DECOMP Make 2nd run w/ gauge ring and junk basket to 3,518' (WLM) P DECOMP Run USIT/GR/CCL log -Log from 3,480' to 200' -Take repeated section from 2,450' to 2,200' P DECOMP MU 9-5/8" EZSV plug and run on E-line -Set ESZV plug @ P P N N N 110/2/2007 100:00 - 12:00 I 12.00 I PULL I N 12:00 - 16:00 I 4.001 PULL I N 16:00 - 18:00 I 2.001 PULL 1 P 18:00 - 19:00 I 1.00 I PULL I P 19:00 - 22:00 3.00 CLEAN P DECOMP RD E-line DECOMP RU testing equipment and chart recorder -Test EZSV plug to 2,000 six 10 min. Chart test - RD testing equipment RREP DECOMP Rig service: clean wind walls -Paint dog house floor -Paint support brace for top drive rails Waiting for top drive PLC to replace damaged one RREP DECOMP Cont. servicing /painting on rig while waiting for top drive PLC to replace damaged one: paint centrifuge room, paint motor room walls RREP DECOMP Cont. servicing /painting on rig while waiting for top drive PLC to replace damaged one: painting in mud pits, rock washer, mud pumps and motor room walls. Paint ears on top drive. Adjust bridle line in derrick. Put new cable on stabbing board counterweight. Start to install heat exchanger on CAT #1. Glue rubber into gaps on ceiling in motor room. Clean up around parts bin. RREP DECOMP Cont. servicing /painting on rig while waiting for top drive PLC to replace damaged one: stuff rubber into cracks in wind wall and screen room. Paint stand pipe, cement line, back stair landings, driller's console, pipe shed floor and CATS #1 & #2. Remove and clean under rotary table. Repair (weld) table lock. RREP DECOMP Service / paint in rig while fixing top drive: clean wind walls. Paint lines in pump room and motor room. Fix glycol drip under drawworks. Glue rubber into cracks between walls in pit room -Finish repairing top drive DECOMP MU BHA w/ 9-5/8" casing cutter -RIH on 5" DP singles to 840'. BHA hang @ 650' and 840'. Decide to POH to run 9-5/8" scraper DECOMP POH and LD casing cutter DECOMP MU 8-1/2" bit and 9-5/8" scraper and RIH w/ 5" DP by stands, Printetl: 10/25/2007 1:25:52 PM • BP EXPLORATION Page 4 of 16 Operations Sumlmalry Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date I From - To I Hours I Task I Code I NPT I Phase Spud Date: 6/9/1979 Start: 9/21 /2007 End: Rig Release: Rig Number: Description of Operations 10/2/2007 19:00 - 22:00 3.00 CLEAN P DECOMP and then in singles from pipe shed, to 2,645' 22:00 - 22:30 0.50 CLEAN P DECOMP CBU @ 318 GPM - 240 psi 22:30 - 23:30 1.00 CLEAN P DECOMP POOH f/ 2,645' to BHA 23:30 - 00:00 0.50 PULL P DECOMP LD bit and scraper - MU BHA w/ 9-5/8" casing cutter 10/3!2007 00:00 - 00:30 0.50 PULL P DECOMP Finish MU BHA w/ 9-5/8" casing cutter 00:30 - 01:30 1.00 PULL P DECOMP RIH w/ casing cutter to 2,446' 01:30 - 04:00 2.50 PULL P DECOMP Locate collar @ 2,444'. PU and cut 9-5/8" casing @ 2,434'. POH and locate collar @ 2,326'. Run in and cut 9-5/8" casing @ 2,334' 04:00 - 05:00 1.00 PULL P DECOMP ose annular preventer. Line up OA to tiger tank. Attempt to circulate out OA to tiger tank w! none to very little returns. Pressure build up to 880 psi @ 3.5 bpm 05:00 - 06:30 1.50 PULL P DECOMP POH to 2,200'. Attempt cut 9-5/8" casing @ 2,200' w/ 5.8 bpm, 800 psi - 75 rpm, 3.5k tq - No progress 06:30 - 07:30 1.00 PULL P DECOMP Observe well - POH 07:30 - 09:30 2.00 PULL P DECOMP Inspect and change knives on cutter -RIH to 2,195' 09:30 - 10:00 0.50 PULL P DECOMP Pumping w/ 3.5 bpm 320 psi -Locate last cut attempt w/ knives at 2,200' -Begin rotating w/ 75 rpm, 3k tq -Begin pumping w/ 5.5 bpm 720 psi -Observe torque increase -Increase pump to 800 psi -Observe 500 psi pressure drop - "OA" pressure increase to 180 psi 10:00 - 11:00 1.00 PULL P DECOMP Stop pumps - PU to tool joint -Close annular -Pressure to 1500 psi w/ no returns -Bleed pressure -Pressure up to 1500 psi -Returns observed at slop tank -Establish circulation w/ 3.5 bpm, 1340 psi -Shut down 11:00 - 13:00 2.00 PULL P DECOMP PJSM - RU Hot Oil truck to pump down DP -Test lines to 2500 psi -Pump 125 bbls 100 deg diesel down DP w/ 2 bpm, 1250-450 psi taking returns out "OA" to slop tank -Displace diesel from DP w/ 40 bbls "Safe Surf O" and seawater pill at 140 deg. - 4 bpm, 720 psi 13:00 - 15:00 2.00 PULL P DECOMP Allow diesel to soak in "OA" 15:00 - 17:00 2.00 PULL P DECOMP Pump 40 bbls of soap pill @ 168 GPM - 690 psi, 61 bbls of diesel @ 84 GPM - 450 psi and 40 bbls high vis -Circulate w! 9.8 ppg brine until clean @ 223 GPM -1850 psi 17:00 - 18:30 1.50 PULL P DECOMP POH and LD casing cutter 18:30 - 19:30 1.00 BOPSU P DECOMP Pull wear ring -Install test plug 19:30 - 20:30 1.00 BOPSU P DECOMP C/O to rams to 9-5/8" 20:30 - 21:30 1.00 BOPSU P DECOMP RU to test top rams w/ 9-518" test joint -Test top rams to 250 si low - 4,000 si hi h. Chart tests - F'tD J-5/$" test joiTand testing equipment -Pull test plug 21:30 - 22:30 1.00 PULL P DECOMP MU 9-5/8" spear -Back out LDS -Engage mandrel hanger and pull casing to rotary table (250k to pull loose - 165k PUWT) 22:30 - 23:30 1.00 PULL P DECOMP CBU staging pumps f/ 150 - 318 GPM @ 60-300 psi. 23:30 - 00:00 0.50 PULL P DECOMP LD spear 10/4/2007 00:00 - 01:00 1.00 PULL P DECOMP Break out and LD mandrel hanger -Clear rig floor - RU elevators - MU head pin 01:00 - 02:00 1.00 PULL P DECOMP Circulate to balance columns 200 GPM @ 200 psi 02:00 - 09:30 7.50 PULL P DECOMP POH and LD 9-5/8" casino ffQlrLnit n ~ nn' Tight connections: breaking connections w/ rig tongs before applying casing tongs. Initial PUWT: 145k -Recovered 55 jts + cut joint (34.20') + 11 centralizers 09:30 - 11:00 1.50 PULL P DECOMP Clean Arctic pack from casing tools and rig floor -Glean and unplug drip pan under rig floor - LD casing equipment - Printetl: 10/25/2007 1:25:52 PM • - BP EXPLORATION Page 5 of 16 Operations Summary Report - Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date I From - To I Hours I Task I Code' NPT I Phase I Description of Operations 10/4/2007 Io2.30 - 14:00 ~ 1.501 BOPSU~P 14:00 - 15:30 1.50 PULL P 15:30 - 16:30 1.00 PULL P 16:30 - 17:30 1.00 PULL P 17:30 - 18:30 1.00 PULL P 18:30 - 22:30 4.00 PULL P 22:30 - 00:00 1.50 PULL P 10/5/2007 00:00 - 00:30 0.50 PULL P 00:30 - 02:00 1.50 PULL P 02:00 - 03:00 I 1.001 FISH I P 03:00 - 08:00 5.00 FISH P 08:00 - 09:30 1.50 FISH P 09:30 - 11:00 1.50 FISH P 11:00 - 13:00 2.00 FISH P 13:00 - 14:30 I 1.501 FISH I P 14:30 - 22:00 ~ 7.501 FISH I P (10/612007 100:00 - 04:30 I 4.501 FISH l P 04:30 - 08:00 I 3.501 FISH I P 08:00 - 10:00 I 2.001 FISH I P 10:00 - 13:00 3.00 FISH P 13:00 - 15:00 2.00 FISH P 15:00 - 16:00 1.00 FISH P 16:00 - 17:00 1.00 BOPSU P DECOMP Mobilize spear assembly to floor. DECOMP Install test plug -Change top rams to 4 112" X 7" variables DECOMP Test top rams w/ 5" test joint to 250 psi low - 4000 psi high. Chart test - RD test equipment -Pull test plug -lnstall wear ring OECOMP MU spear, BS, jars, 9- 6 1/4" DC's and acceleratorjar DECOMP RIH to 2,135' DECOMP Screw in T.D. -Obtain parameters -PUW 107k -SOW 110k - Break circ. w/ 2 bpm 60 psi -tag fill /arctic pack at 2,170' (30' above fish) -Increase pump to 9 bpm 350 psi -Attempt to wash down w/ no success -Rotate w/ 25 rpm and wash down to engage fish at 2200' -Rotate 2 turns left to set grapple - Jarring on fish w/ 140k over -Fish free -Pull up to 2,135' dragging 90k to 190k over DECOMP Circulate out arctic pack -Clean same from shakers and troughs DECOMP Pump out of hole w/ fish due to swabbing DECOMP Stand back HWs and DCs - LD jars DECOMP LD spear DECOMP LD fish: 8.85' 9-5/8" casing stump + 3 jtts 9-5/8" casing + 8.45' casing cutjt. Recovered also 2 centralizers (1 broken) DECOMP Clear /clean rig floor - RD casing false table - G/O elevators - Mob. BHA to rig floor - RU wash pipe false table and tools DECOMP PJSM - MU 11-15(16" washover shoe + 4 jtts 11-3/4" wash pipe. Cont MU rest of BHA (drive sub, jars, DCs, HWDP) DECOMP Cut excess driNing line -Slip line DECOMP Service top drive -Adjust brakes on drawworks DECOMP RIH f/ 510' to 2,090', screwing into top drive on every stand. Started taking weight @ 2,090' DECOMP Wash and ream down to top of fish @ 2,336' - 50 RPM @ 2-5k torque, 295 GPM@ 240-360 psi. PUWT: 110k, SOWT: 105k, ROTWT: 105k DECOMP Washover 9-5/8" casin fish f/ 2,336' to 2,348'. 50-100 RPM @ 10-15k torque, 84-340 GPM. Tag hard on last 2' and mill without pumps for 3 hrs. DECOMP POH to change washover shoe DECOMP Stand back BHA DECOMP LD bumper sub and oil jars -Stand back one stand of wash pipe -Attempt to break out washover shoe w/ no success - LD bottom joint of wash pipe w/ washover shoe DECOMP PU new joint of wash pipe - MU shoe -RIH w/ wash pipe and Dc's DECOMP RIH w/ DP screwing in to every joint w/ T.D. (Running over) to 2,295' OECOMP Screw in T.D. -Obtain parameters -PUW 115k -SOW 115k - ROT 115 w/ 3-5k tq -Break circulation w/ 3 bpm 60 psi -wash over top of fish at 2,336 w/ no issues -Tag at 2,343' -Milling / washing over f/ 2,343' to 2,345' w/ 70-100 rpm 7-13k tq - 5-15k weight on shoe - 2,345' all torque dropped off - No progress DECOMP Observe well - POH DECOMP Stand back DC's - LD jars -Stand back 1 stand wash pipe - Bottom 'oint of wash i e and shoe left in hole. DECOMP Clear /clean floor -Pull wear ring -lnstall test plug - RU to test BOP Printed: wrz5rzuo~ ~:zssz rnn • • BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: NGI-13 Common We11 Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase 10/6/2007 117:00 - 21:30 I 4.501 BOPSUF~ P 22:30 - 00: 0 I 1.501 BO H U~ P 1017/2007 1010:00 - 02:00 I 1.00 I FISH I P 02:00 - 03:30 + 1.501 FISH ~ P 03:30 - 04:30 I 1.00 FISH P 04:30 - 05:30 I 1.001 FISH I P 05:30 - 08:00 ~ 2.50 ~ FISH I P 08:00 - 09:00 1.00 FISH P Description of Operations DECOMP Test BOP and related equipment as per BP / AOGCC regulations. Test to 250 psi low - 4,000 psi high (annular preventer to 250 psi low - 3,500 psi high). Test w/ 5" test joint. Chart tests. Test witnessed by WSL and Tourpusher. Bob Noble, AOGCC Rep, waived witness of test DECOMP RD testing equipment -Pull Test plug -Install wear bushing DECOMP Mobilize tools to rig floor - MU spear assembly, bumber sub and jars DECOMP MU DCs and HWDP DECOMP RIH on 5" DP to 2,288' -Screw in TD and check parameters - RIH and tag fish @ 2,318' -Engage fish DECOMP POH w/ fish to HWDP DECOMP Stand back HWDP and DCs -Pull spear assembly with fish - Disengage and LD spear assembly - LD jars assembly - C/O elevators -Break washover shoe f/ fish - LD joint of wash pipe DECOMP C/O elevators - PU wash pipe stand f/ derrick and RIH -Break out 6-5/8 REG pin x 4-1/2 IF box XO f/ top of drive sub - MU 6-5/8 REG lifting sub and stand back wash pipe in derrick - Clear floor DECOMP MU Multi string cutter -RIH to 2,269' DECOMP Obtain parameters -PUW 107k -SOW 110k -Continue to RIH - Enter 9 5/8" stub at 2,336' w/ no issues -Continue RIH to 2,400' -Screw in TD -Pumping w/ 500 psi -Locate casing collar at 2,405' - PU to spot knives at 2,400' -Cut casing at 2 400' w/ 70 rpm, 900 psi -Observe total pressure loss of 650 psi -Set down on cut w/ no pump, no rotary -Pull up to 2,364' - Locate collar at 2,366' -Spot knives and cut casing at 2,361' as 09:00 - 10:00 I 1.001 FISH P 10:00 - 11:00 1 1.001 FISH P 11:00 - 11:30 ~ 0.501 FISH I P 11:30 - 13:30 2.00 FISH P 13:30 - 14:00 0.50 FISH P 14:00 - 16:00 2.00 FISH P 16:00 - 17:00 1.00 FISH P 17:00 - 19:30 2.50 FISH P 19:30 - 21:30 2.00 FISH P 21:30 - 22:00 0.50 FISH P 22:00 - 23:00 1.00 FISH P 23:00 - 00:00 1.00 FISH P 10/8/2007 00:00 - 01:00 1.00 FISH P 01:00 - 02:30 I 1.501 FISH I P 02:30 - 04:00 ! 1.501 FISH I P DECOMP POH to BHA DECOMP Stand back DC's -Service break cutter - LD cutter bullnose and stab. DECOMP Clear /Clean floor -Mob spear assembly to rig floor DECOMP PU spear BHA -RIH to 2,300' DECOMP Obtain parameters -PUW 110k -SOW 115k -Break circulation w/ 3.5 bpm, 60 psi - Engage fish at 2,336' -Pull up and hit jars 1 time w/ 180k -Pulled free -Set back down, tum 2 LH turns to ensure grapple set. PU w/ no overpull. DECOMP POH -Stand back BHA DECOMP LD fish recovered 9.38' piece) -Pin pulled out of "FO" collar DECOMP Inspect grapple (OK) - MU BHA -RIH to 2,300' DECOMP Screw in TD and check parameters -RIH and tag fish @ 2,345' - Engage fish -Jar on fish pulling to 250k, let jar hit, pull to 350k and then slack off to set jars back and repeat jarring -Jar 153 times with no progress -Disengage spear DECOMP Conduct derrick inspection after jarring DECOMP POH to BHA DECOMP Stand back HWDP and DCs - LD spear assembly DECOMP Clear /clean rig floor -Mob. washover tools to rig floor - RU false table and wash pipe handling tools DECOMP MU washover shoe, 1 jt wash pipe, drive sub and jars -RIH w( DCs and HWDP DECOMP RIH on 5" DP to 2,300'. Screw in TD on every stand (running over) Printed: 10/25/2007 1:25:52 PM • BP EXPLORATION Page 7 of 16 Operations Summary Report° ` Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21 /2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date 1 From - To 4 Hours ~ Task I Code ~ NPT ~ Phase Description of Operations 10/8!2007 104:00 - 12:00 1 8.001 FISH ~ P 12:00 - 14:00 2.00 FISH P 14:00 - 15:30 1.50 FISH P 15:30 - 16:30 1.00 FISH P 16:30 - 00:00 7.50 FISH N 10/9/2007 00:00 - 04:00 4.00 FISH N 04:00 - 05:00 1.00 FISH P 05:00 - 07:30 2.50 FISH P 07:30 - 08:30 1.00 FISH P 08:30 - 10:00 1.50 FISH P 10:00 - 10:30 0.50 FISH P 10:30 - 11:30 1.00 FISH P 11:30 - 14:30 3.00 FISH P 14:30 - 16:30 2.00 FISH P 16:30 - 18:30 2.00 FISH P 18:30 - 00:00 5.50 FISH P 10/10/2007 00:00 - 11:30 11.50 FISH P 11:30 - 12:30 1.00 FISH P 12:30 - 15:30 3.00 FISH P 15:30 - 17:00 1.50 FISH P 17:00 - 17:30 0.50 FISH P 17:30 -18:00 0.50 FISH P DECOMP Check parameters PUW 110k, SOW 115k, ROTW: 115k -Tag fish @ 2,344' - Washover /mill fish f/ 2,344' - 2,346'. 50-120 RPM @ 5-7k torque; 173 GPM @ 70 psi - "Dry Drill" f/ 30 min in attempt to make drill wi no success DECOMP POH -Stand back BHA -PJSM -Break shoe -Inspect same - Shoe shows very little wear - LD wash pipe and drive sub. DECOMP MU 11-1/4" Pilot mill w/ 8-9/16" pilot - MU jars -RIH w/ DCs and HWDP DECOMP R1H on 5" DP (7 stands) to +/- 1,000'. Stab safety valve - Electric brake locked out RREP DECOMP Rig repair: changing out electric brake on drawworks RREP DECOMP Continue Rig repair: -C/O "Dretech" electric brake on drawworks. DECOMP Continue to RIH to 2,278' md. DECOMP Screw in TD -Obtain parameters: -P/U= 110K, SOW= 114K, ROT= 114K. -Milling on "FO" collar/ casing f/ 2,345'-2351' md. -RPM= 110, Tq= 3-5K @ 770 psi w/ 700 gpm. -Pump H.V. !fiber sweeps while milling. -Last 1ft milled in 5 minutes, indicating milling on casing below collar. DECOMP Pump HV /fiber sweep around w/ 700 gpm, 770 psi. -Rotate and reciprocate w/ 150 rpm. DECOMP POH -Stand back DC's - LD pilot mill assembly. -Mill showed good wear pattern. DECOMP Clean /Clear Rig floor. -P/U "Wash Over assembly" to rig floor. DECOMP R/U and attempt to test casing w/ no success. -Seawater um in awa 1.5 b DECOMP PJSM. -R/U Wachs cutter on rig floor. -P/U 1 stand of Washpipe f/derrick. -Cut Washpipe w/ Wachs cutter (3 cuts). -Washpipe jts had fused together. -UD Wachs cutter. -Clean /Clear Rig floor. DECOMP M/U BHA. DECOMP RIH to 2,270' md. -Screw into each stand of DP to prevent overflow f/ Washpipe. DECOMP Wash over 9 5/8" casing f/ 2,351' and to 2,381' md. -GPM= 212 @ 90 psi. RPM= 80, Tq= 3K-5K, P/U= 115K. DECOMP Continue to Wash over 9 5/8" casing to 2,406' md. -No progress at casing collar. -W06= 5-20K, RPM= 80, Tq= 18K. -P/U= 115K, SOW= 111 K, ROT wt= 114. -200 gpm @ 120 psi. DECOMP POH to BHA. DECOMP Stand back BHA. -L/D Wash pipe. -Noted trouble breaking Wash pipe connections. DECOMP M!U 9 5/8" casing Spear assembly. DECOMP RIH w/ Spear assembly to 2,300' md. DECOMP Tag Fish @ 2,351' md. -Engage Fish., Printetl: 70/25/2007 1:25:52 PM BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date ~ From - To I Hours ~ Task I Code I NPT' Phase I Description of Operations 10/10/2007 17:30 - 18:00 0.50 FISH P 18:00 - 19:00 1.00 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 20:30 0.50 FISH P 20:30 - 21:00 0.50 FISH P 21:00 - 22:00 I 1.001 FISH ~ P 22:00 - 23:30 1.50 FISH P 23:30 - 00:00 0.50 FISH P 10/11/2007 00:00 - 00:30 0.50 FISH P 00:30 - 01:00 0.50 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 02:00 0.50 FISH P 02:00 - 04:00 I 2.001 FISH I P 04:00 - 12:00 f 8.001 FISH 1 P 12:00 - 19:00 I 7.001 FISH { P 19:00 - 20:30 I 1.501 FISH I P 20:30 - 22:00 1.50 FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 00:00 1.50 FISH P 10/12/2007 00:00 - 03:00 3.00 CLEAN P 03:00 - 05:00 { 2.00- CLEAN { P 05:00 - 06:30 { 1.501 CLEAN I P DECOMP -P/U= 115K, SOW= 111K, -212 gpm @ 80 psi. DECOMP POH w/ Fish. DECOMP Stand back BHA. -- L/D Fish {9.7 ft). -M/U BHA for 2nd Spear run. DECOMP RIH w/ Spear to 2,300' md. DECOMP Tag Fish @ 2,360' md. -Engage Fish. -P/U= 115K, SOW= 111 K. -212 gpm @ 80 psi. DECOMP POH to BHA. DECOMP Stand back BHA. UD Fish (37.27 ft). -L/D BHA. DECOMP Clear Rig Floor. OECOMP Continue to clear Rig floor of Wash over tools. DECOMP Service Rig. DECOMP P/U & M/U Pilot Mill BHA. DECOMP RIH w/ 5" DP & Pilot Mill assembly. -Ta Fish 2,397' md. DECOMP Suck out Pits # 1 & 2. -Displace Seawater to 9.1 ppg LSND milling fluid. -Pumped 30 bbl Nigh viscosity spacer. -Pumped 350 bbls of 9.1 ppg LSND milling fluid. -330 psi / 550 gpm. DECOMP Ease into 9 5/8" stump. -Attempt to mill, Mud running over shakers. -C/O shaker screens. -Mill f/ 2,404' to 2,416' md. -P/U= 111 K, S/0= 115K, ROT= 115K. -W06= 5-7K, Tq= 3k, RPM= 110. -450 psi / 650 gpm DECOMP Continue to mill 9 5/8" casing f/ 2,416' to 2,440' md. -Pump Hi vis sweeps every 6' milled. -420 psi / 650 gpm. -WOB= 6-9K, Tq= 1-8K. DECOMP Pump 30 bbl Hi vis sweep. -Pump 20 bbls water. -Circulate, Reciprocate & Rotate until hole clean. -2K Tq @ 150 RPM. 420 psi @ 650 gpm. Total Mud contaminated metal recovered= 2,100 lbs. DECOMP POH DECOMP Stand back, L/D BHA. DECOMP Pull Wear ring. Flush Stack and Flow line. --I,~stall Test o1uq. DECOMP O en all Ram doors. - Clean metal shavings from cavity and rams. DECOMP R/U for BOP body test @ 250 psi low & 4000 psi high for 5 minutes. -Test 4 1/2" x 7" Variables -Pass. -3 1/2" x 6" Variables -Pass. -Blind rams -Pass. DECOMP M/U 12 1/4" bit, 13 3/8" scraper, 12 1l4" string mill and jars. YOfI(2Q: lU2blZW / 1:"Lb:DZ YM • • BP'EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date 'From - To I Hours' Task I Code ~ NPT, Phase ~ Description of Operations 10!1212007 107:30 - 09.00 I 1.501 CLEAN ~ P 09:00 - 11:00 I 2.001 CLEAN I P 11:00 - 12:00 I 1.00 (CLEAN I P 12:00 - 13:30 1.50 CLEAN P 13:30 - 14:30 1.00 CLEAN P 14:30 - 15:30 I 1.00 CLEAN I P 15:30 - 17:30 2.00 CLEAN I{ P 17:30 - 18:30 I 1.001 CLEAN I P 18:30 - 19:00 { 0.501 CLEAN I P 19:00 - 19:30 I 0.501 CLEAN I P 19:30 - 20:30 1 1.00 CLEAN P 20:30 - 22:00 I 1.501 CLEAN I P 22:00 - 22:30 0.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 10/13/2007 00:00 - 01:30 1.50 CLEAN P 01:30 - 02:30 1.00 CLEAN P 02:30 - 04:30 2.00 CLEAN P 04:30 - 05:00 0.50 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 06:30 1.00 CLEAN P DECOMP -RIH w/ DC's. DECOMP RIH w! DP to 2,300' md. DECOMP Screw in Top Drive. -Ream to bottom. -P/U= 111K, SOW= 115K, ROT wt= 115K. -GPM= 290 @ 1200 psi. -Taking weight at 2,302' md. -C1ean out f! 2,302' to 2,404' md, RPM= 100, W06= 0. -Clean out f/ 2,404' to 2,436' md, RPM= 100, W06= 2-4K. DECOMP Pump Hi Vis sweep: -Reciprocate & rotate @ 100 rpm. -GPM= 200 @ 1240 psi. DECOMP Observe well - POH to BHA. DECOMP Stand back DC's - LD BHA. DECOMP Clean & Clear Rig floor of tools. -P/U RTTS. DECOMP M/U 13 3/8" RTTS. -RIH w/ DC's. DECOMP RIH wi DP t/ 2,430' md. -Drilling fluid running over tool joints. -Screw into each joint. DECOMP Set RTTS 2 430' md. -Test casing -Failed. -Injecting @ 600 psi / 1.5 bpm. DECOMP Set RTTS 2,360' md. -Test casing -Failed. -Injecting @ 730 psi ! 1.9 bpm. -Perform FIT @ 2,360' and to 10.6 ppg EMW. -Applied 185 psi -Pass. DECOMP Set RTTS 2 330' md. -Test casin -Failed. DECOMP Set RTTS 2 200' md. -Test casin for 20 minutes 2000 si -Pass. -R/D test equipment. DECOMP Observe well - no flow. -Pump dry job. -POH f/ 2,200' to 366' md. DECOMP Stand back HWDP and DCs. -L/D RTTS. DECOMP P/U casing cutter & DP to 930' md. DECOMP RIH w/ Casing cutter f/ 903' to 2,366' md. DECOMP Attempt to break circulation. -Casing cutter nozzle plugged. -Attempt to reverse circulate to clear nozzle. -Work drill string in an attempt to clear nozzle. -Pressure up drill string to engage knives. -Work drill string. -Locate 13 318" Casing collars @ 2,419' and & 2,378' md. DECOMP Observe well - No flow. -POH wet (plugged nozzle). DECOMP Stand back DC's -Service break and LD cutter. DECOMP Clean & Clear rig floor. DECOMP M/U 13 3i8" EZSV running tool on DC's. Printed: 10/25/2007 1:25:52 PM .L- • BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/13/2007 05:30 - 06:30 1.00 CLEAN P DECOMP -Dummy run through wear ring. -M/U EZSV. -RIH w/ DC's. 06:30 - 08:00 1.50 CLEAN P DEGOMP RIH w/ DP at controlled rate to 2,400' md. 08:00 - 08:30 0.50 CLEAN P DECOMP Screw in Top Drive -Obtain parameters: P/U= 105K, SOW= 105K. -Spot EZSV top at 2,415' md. 8:30 - 10:00 .50 LEAN P ECOMP -Rotate 40 Right Hand turns. -P/U in 10K over pull increments to 40K over. -Pull to 65K over and shear off of EZSV. -P/U 3 ft, Rotate 25 Right Hand turns. -Set down w/ 45K weight on EZSV to ensure no movement. R/U testing equipment. -Isolate all surface equipment. -Test EZSV to 2000 psi f! 15 min. -Record on chart -Pass. -RD test equipment -Blow down lines and Top Drive. 10:00 - 11:00 1.00 CLEAN P DECOMP Observe well -Static - POH to BHA. 11:00 - 12:00 1.00 CLEAN P DECOMP Stand back DC's &HWDP - L/D EZSV running tool. 12:00 - 12:30 0.50 CLEAN P DECOMP Clean & Clear Rig floor. 12:30 - 13:00 0.50 CLEAN P DECOMP Pull wear ring, Drain stack. 13:00 - 14:00 1.00 CLEAN P DECOMP Set test plug. R/U BOP test equipment. 14:00 - 17:30 3.50 CLEAN P DECOMP PJSM -Test BOPS per BP / AOGCC regulations: -Test to 250 psi low - 4,000 psi high. -Annular preventer to 250 psi low - 3500 psi high. -Test wt 5" test joint -Chart tests -Pass. -Test witnessed by WSL and Toolpusher. -Jeff Jones, AOGCC Rep, waived witness of test. 17:30 - 18:00 0.50 CLEAN P DECOMP Pull test plug. Install Wear ring. 18:00 - 18:30 0.50 CLEAN P DECOMP Slow down Kill & Choke lines. -Break down Floor valves. 18:30 - 19:30 1.00 CLEAN P DECOMP P!U Mills, XO's, Flex jt, Float, UBHO & Bumper subs. 19:30 - 21:30 2.00 CLEAN P DECOMP PJSM. M!U Window milt & tower mill. -M/U Flex jt, Upper mill, XO, Float sub & UBHO sub. 21:30 - 23:30 2.00 STWHIP P WEXIT P/U Whipstock. Attach Mills. -Orient UBHO sub. -P/U XO, Flex collar, XO, Bumper sub & six 8" DCs. 23:30 - 00:00 0.50 STWHIP P WEXIT P!U XO & DC. -At 309' md, stacked 30-35K while RIH. -Work pipe per Baker rep. -Decision to POH. Pulled 40K over to free. -POH. 110/1412007 100:00 - 01:30 i 1.501 STWHIPI N I DFAL ~ WEXIT 02:30 - 03:30 ~ 1.001 STWHIPI N 'DFAL WEXIT 03:30-04:001 0.501STWHIPIN (DFAL (WEXIT 04:00 - 05:00 I 1.001 STWHIPI N I DFAL I WEXIT -Top of slide @ 279' md, Retrievable slot @ 287' md. -Continue to POH: Stand back DCs, Break off starter Mill. -L/D Bumper sub, Flex collar & Mills. R/D SLB tools & sheave. P/U & M/U Retrieval hook, Jars, Bumper sub. -M/U DCs &HWDP. Hook into Fish, open Jars w/ 25K over. -Pulled 62K over & sheared anchor. POH -L/D Bumper sub, Jars and Retrieval hook. Pnntetl: 10/25/2007 1:25:52 PM Iv~ • • BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/21/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2007 05:00 - 05:30 0.50 STWHIP N DFAL WEXIT PJSM. L/D Whipstock. -Inspect anchor: No apparent damage. 05:30 - 07:00 1.50 STWHIP N DFAL WEXIT Clear & clean Rig floor. -Cut drilling line. -Service T.D. 07:00 - 08:00 1.00 STWHIP N DFAL WEXIT Adjust brakes. 08:00.09:30 1.50 STWHIP N DFAL WEXIT M/U 12 1/4" bit, string mills, Bumper Sub & Jars. -RIH wl DC's. 09:30 - 11:00 1.50 STWHIP N DFAL WEXIT RIH w/ 5" DP -Tag EZSV at 2,415' md. 11:00 - 13:00 2.00 STWHIP N DFA!_ WEXIT Circulate @ 6 bpm / 470 psi. -Condition mud w! 0.5% lubricant [Lo-Torq] -P/U= 132K -SOW= 135K -Rot wt= 135K -Rotate & Reciprocate DP @ 20 rpm. 13:00 - 15:00 2.00 STWHIP N DFAL WEXIT Flow Check well -Static. -POH f/ 2,400' to 600' md. -POH slowly due to high winds. -Service loop blowing outside wind walls. 15:00 - 16:30 1.50 STWHIP N DFAL WEXIT Rack back BHA, L/D string mills. 16:30 - 18:00 1.50 STWHIP N DFAL WEXIT P/U & M/U Flex DC and window mill. -LID same in pipe shed. 18:00 - 20:00 2.00 STWHIP N DFAL WEXIT PIU Whipstock, Window mill, Flex collar. -P/U & Orient UBHO sub. -P/U DCs and HWDP. 20:00 - 20:30 0.50 STWHIP N DFAL WEXIT PJSM. Hang E-line sheave in derrick. 20:30 - 21:30 1.00 STWHIP P WEXIT RIH f/ 635' to 2,397' md. -Run speed 90-120 seconds per stand. 21:30 - 22:00 0.50 STWHIP P WEXIT Fill pipe, drill string pressured up to 1800 psi. -Bleed off. -Re-pressure up to 1700 psi. -No Returns, bleed off pressure. -Assembly plugged. 22:00 - 23:00 1.00 STWHIP P WEXIT RU Gyro tools and E-line bottom sheave. -RIH wi Gyro to 2,397' md. -E-line failure. 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT POH & troubleshoot E-line failure. 10/15/2007 00:00 - 01:30 1.50 STWHIP N DFAL WEXIT C(O Gyro tool head. -Wireline cable short [midcable]. -Switch to large cable spool. 01:30 - 02:30 1.00 STWHIP P WEXIT RIH w/ Gyro tool. -Orient Whi stock er G ro surve to azimuth 99. -POH w/ Gyro tool. 02:30 - 03:00 0.50 STWHIP P WEXIT Single into anchor setting depth at 2,415' md. -Set whipstock anchor w/ 25K down. -Confirm anchor set with 45K down. 03:00 - 03:30 0.50 STWHIP P WEXIT RiD & UD Schlumberger E-line. 03:30 - 04:30 1.00 STWHIP P WEXIT Pump dry job. -POH t! 6 1/4" DCs @ 635' md. 04:30 - 06:30 2.00 STWHIP P WEXIT Stand back DCs & HWDP. -L/D Mill, UBHO, Flex collar, XOs & Jars. 06:30 - 07:00 0.50 STWHIP P WEXIT Clear & clean rig floor. 07:00 - 09:00 2.00 STWHIP P WEXIT PJSM - M/U Milling BHA. 09:00 - 10:00 1.00 STWHIP P WEXIT RIH w/ DP. Tag Whipstock @ 2,385' md. - u wm ow - m . Printed: 10/2572007 1:25:52 PM TREE= McEvov WELLF~AD= McEvoylGray ~ ACTUATOR= ~AXELSON KB: ELEV = 29.65 BF. fl.EV = KOP = 2x08' Max Angk = 33 ~ 4453' Deturn MD = 901)6 DawmTVD= 8515' SS DRLG DRAFT ~ ~ ~'~ ~~ 7-5/8" TBG, 29:7#, L-80, fPC VAM TOP, .0459 bpf, ~ = 6.875 7" TBG, 26#, L-80, TC-9, .0383 bpf, ~ = 6.276 Minimum ~D = 5J7Q" d(,,) 83Q9' 7" HES RN NIPPLE 13-3/8" 1AM~STOCK t3-318" EZSVB (1oJ2sto6) 2415 13-3/8" CSG, 72#, 2709' N-80, 10 = 12.347" 21179' 21or 7-5/8" X 7" XO, D = 6.276" ~7" HES R N~', ID = 5.963" 9-5/8"X7" BKR S-3 PKR, ID = 6.00„ ~~ 7-518" TBG, 29.7#, L-80, ~'C VAM TOP, _0459 bpf, ID = 6.875 7" TBG, 26#, L-80 TCII, .0383 bpf, ID = 6.276" 8331' 9-5/&" a~#. ~-80, Hydrd 563 Caskg -- PERFORATi~I SL~UIUARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical pert data S2E SPF W7ERVAL Opn/Sclz DATE SLOTTED 8597'/9006' ~7" HES RN Nom, D = 5.770" ~ 8324" 9-518" X T' BKR ZXP PKR w / HMC HGR , ~ = 6.37" $331' ~7" MULE SHOT; ID = s.27s° 7" SOLD LNR, 26#, L-80, 8r39T ~~ BTGM, .0383 bpf, ~ = 6.276" ~ \ 7" PERFORATED LNR, 26#, 1-80, BTGM, .0383 bpf, ~ = 6.276" 9006' DAlE REV BY COMIAEN7S DATE REV BY COMMENTS 07J88lI9 ORIGINAL COMPLETION 1111 SlOfi RRDlfLH IBP PULLED/WRP SET (10!2006) 09Ji8/0fi TEL/TLH IBP SET 10129!07 014 Nq-13ASIDETRACK 09/29106 RRDJPJC PULL 8 RESET IBP 11 /07!07 ROW/TL CORRECTIONS (7" TBG MIFO) 09!30/06 JCMJPA PULL~PBIBPFISH 10101 JO6 RRD/PA RESET BKR lQP 10/10/06 CJNJTLH IBP FISH PRUDHOE BAY UNff WELL NGE13A PERMff No: M API No: 5(}`029-20347-01 Sec. f , T11 N, R14E, 2531.95 FEL 4999.09 FNL BP Ezplotatioh (Alaska) 1 SAFETY NOTES: i ~7" X 7-S/8" XO, ~ = 6.276" ~ 2079' H 7-5/8" x 7" xo, ~ = s.27s" ~ 2090' 7" CAMCO DB LANDNVG NIP, ~ = 6.00" 2103' 7" x 7-5/s" xo, ID = s.278" 13-318" MLLOUT VN~fDOW 2385" - 2408' Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wel F-48 G-19A NGI-13 MPE-30A F-11 B W-12A 11-27 02-22A 01-16 01-14 L5-05 D-21 14-15 D-18A 14-0SA 1-23/0-15 S-03 1-09A1L-21 P2-19A OWDW-NW K-01 11-32 3-25B/L-27 Job# 11846815 11890315 11.890313 11855817 11649954 11418301 11637127 11216214 11630486 11801086 11767129 11626119 11221550 11695074 11813055 11846802 11223120 11849930 11649963 11211370 11695073 11630498 11630490 5tANNED OCT 3 1 2007 . L .." ~.. ....- Lo!! Description US IT 1<1/- Oí [" USIT 1'-1'1- to' ~ USIT I )"í..t'. . ':J-" ~ -rf=t I USIT ~Ó I - 0 tI MCNL ;)~ - ¡C>¡£.( -# /~5 ~5 MCNL }'ì1r-/~d .. ¡~ç-:Jq RST ¡F¡(lo - /4'lf tt I "'"~--:}~ MCNL .oN'I - (...~D, 1t J ç~ J.--:¡'" RST J"+'7r-(JO'1r ""1-:çS-~<g RST¡ /J.. ':I- _ "'-:¡.? · I ~-~ -+'-1 MCNL /1f '":) _t")(~c... f :- . ~<:-S. 0 RST ,'7f;:) - c.,~.;::) ... ,~x ¡ RST 111' I - ó"ðL( ." 1":>~"Xl RST 0f1/- In''A ¢. 1~:'I ?5 RST I Do¡ ~ - (10 I .. 1 ~ l5 (.., RST d""'.t'. IC\'-I'-I:J-x 1t 1')5155 RST J 11- I - I c., I') 11:, 'f) :"\"6<-( RST I C\ ~ - (\,Q q 11: I ss- ? 6' MCNL ~'){)+-()jd .... 1~5~d RST UTI' ,....... -V/~ a:l t5S~1 RST I '7f3 - If) 1 ... 107)1-0 RST D.,L./- I~I #-1~"')l...'9 RST .Q(~~ - ()~ I ..... .c:-<:7_ <;(' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Date 10/12/07 09/30/07 09/30107 10/01/07 03/22/07 09/10/06 06/05/07 10/02/06 06/28/07 07/07/07 06/17/07 09/12/07 03/07/06 08/28/07 06/11/07 08/11/07 06/13/06 08/04/07 04/22/07 02/28/06 08/27/07 09/03/07 07/26/07 NO. 4459 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt.,LisburnE BL Color 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 =-::' ""'£L Received by: Cd 10/23/07 . . • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, October 03, 2007 6:10 PM To: Regg, James B (DOA) 1 `'~~ (L~'~~~0 ~ Cc: NSU, ADW Well Integrity Engineer C Subject: RE: PBU NGI-13 MIT Attachments: NGI-13.pdf ~ ~" ~~ `~ Jim - .~ ". My schematic shows the MD of the packer in NGI-13 to be 7606' and the TVD to be 7344'. I'm including a schematic. Sorry for being so late getting back on this. Thank you - jack L. Winslow (for Anna Dube) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, September 28, 2007 11:37 AM To: NSU, ADW Well Integrity Engineer Cc: Fleckenstein, Robert J (DOA) Subject: PBU NGI-13 MIT Please check the reported packer TVD for MIT witnessed by AOGCC on 9/23/2007. The inspector normally obtains this info from your field personnel when he arrives at the well; inspector's report indicated the packer TVD was 7602 ft -that. is actually the MD. I calculate the TVD for the packer to be 7337 ft<ure is ok (the difference actually reduces the minimum required test pressure to 1834 psi). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~~~ ~vav ~ ~ ~~aa 10/4/2007 State of Alaska • Alaska Oil and Gas Conservation Comm' TO: '-"~ DATE: Thursday, September 27, 20(~ Jim Re ` ~ P.I. Sup~r~visor ~ \"~~f`r r ZJ'~~~ ~ SUBJECT: Mechanical Integrity Tests t BP EXPLORATION (ALASKA) INC NGI-13 FROM: Jeff JOrieS PRUDHOE BAY UNIT NGI-13 Petroleum Inspector Src: Inspector Reviewed Bv: P.I. Suprv~~ NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI-13 API Well Number: So-029-20347-00-0o Inspector Name: Jeff Jones Insp Num• mitJJ070924062359 Permit Number: 178-091-0 -~ Inspection Date: 9123%2007 Rel Insp Num: Packer Depth ?~3"7 ~ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well f NGIa3 !Type Inj. ' N I TVD I ?~ ~ IA j zao ~ sno i sao sao ~ sao P.T. i 18o9IO TypeTest SPT j Test psi ~ I9oos 1 OA i o ~ o ! o ~ o I o OTHER ~ P ~~ TUbin ~ 70 ~ 2500 ~ 2480 2450 ~ 2440 Interval P/F g' NOteS' MIT tubing to demonstrate integrity of a P&A cement plug prior to a re-drill operation. Estimated top of cement at 7602' MD. 1.9 BBLS /- methanol pumped. t~` ~ n~cc tee;- ~~~~;% ~ ~ 3 3 ? ~ ! /~/ 5~~ on i c?y lei ~'e?5~-1-- ~.?'+`SjLt.'~ ~ 5 1 `c 3~ :~;~ 3 b Thursday, September 27, 2007 Page 1 of 1 TREE _ ? VVEILHEAD= GRAY ACTUATOR ~ AXELSON~ KB. ELEV = d8' BF. ELEV K_OP = ~. 3 3G'G' Phax Angle -- _ 27 ~ 410G' Qatufn~~,1C7=~~M ,_~~~~„ 9188;. Dattu~ TV D =8800' SS 7" TBG-NPC, 26#, L-80, .0383 bpf, iD = 6.276" ~--~ 2220' 13-318" CSG, 72#, N-8G, ID = 12.347° ~ 2709' 7Miimyu~A 1®= 4.843'" c 72Q° € 49 K~E ® Ii~ 'r~~ V :roc!G9f23/07j J---{ 7578' 7" TBG-NPC; 29#, L-80:.0371 bpf, lD = 6,18d'° '-~ 7611' TOP CAF 7" LNR 9-5r'8" CSG, d7#, N-8G, ID = 8.681" ~--{ 8015° PERFtJRATION SUhPNtARY REF LOG: BRCS ON 06,•`3Gr79 ~ ANGLE AT TOP PERF: 18 cT; 8d10' Note: Refer to PrasJuctior; BB for historical perf data SIZE SPF INTERVAL Op~ifSgz DATE 3-3,"8" 4 8410 -8532 S 09f2Gf07 3-3i8° 4 8536 - 8663 S 09/20107 3-3; 8" 4 8665 - 8750 S 09)2G/07 3-38" 4 8760 - 8780 S 09120/07 3-318" d 8785 - 8821 S 0912G107 3-3i8" 4 8852 - 8862 S OJ!2Gl07 PBTD 89fl7' 7" LNR: 29#, N-80, .0371 bpf, ID = 6,18d" 8949' TD - 8950° SAFETY NfJTES: 3 2'199' 7" C?TlS RPB SSSV NIP. !D = 5.963" 3508" ~-~ JET CUT {09i24i07) 7572' - 7577' ~ TUBING PIiNCH {fl9'23iG7} 7596" -BKR "K"ANCHOR j 7603' 7°' SEAL BORE EXT 7606' 9-5J8°` X 7" BAKER SAB-2 PKR 7620` 1d' BKR MILLOUT EXTENSIQR~ 7621" --~ BKR SHE7lROl,T SUB 7611' ELI~•1D rr LoGGEO 05/24/87 r,~~ _ 8830" LN[ FISH: IBP Bt~LLNOSE ~ ~~~w 8855' SLM FISH - ttJRP ELEMF_P~1T {09,0'07) r.~ 89fl7' FISH- 28' flF 4" PERF GUN ~; DATE REV BY C0~11~1EN-TS {37108179 C3ittGiAL C43PL~flf3h G9118./06 7'ELiTLH IBP SET G9'29106 RRDIPJC PULL 2~ RESET IBP G9f30.-06 JCMIPAG I~JLL IBP&IBP FISH 10r011G6 RRL7iPAG f2ESC:T BKR IBP 1Gi1fl106 CJNrTLH IBP FISH DATE REV BY CC71~1MENTS 11;15106 RRD%TLH IBP PULLEDrU~IRP SEI~ (10,'2G06; {l9l18iG7 MSlP,1%, PULL '7+JRP 1 FISH {09107>%Q7 09122rG7 JGM'SV P&A {09;2Gi07j G9,'24;07 RRDiP iC 1-BG PUNCH & JET CUT {r~ 3508' ~ iil,'UHC3E BAY UN! F w^~I-~I.L: ~1GI-13 PERfti•1tT No; 178-{lJ1G API No: 5{3-G29-20347-OG SEC 1. T11N, R1dE 253'.95 FEL 4999.09 FNL BP Explaratlon {Alaska} • gyrodata Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713!461-0920 October 2, 2007 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 1'.00 Anchorage, Alaska 99501 ~ ~~ !!AA 1~ Re: NGI Pad #NGI-13 Prudhoe Bay, Alaska Enclosed, please find two (2} copies, and one (1}disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Rob Sh uo p North American Regional Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation • gyr data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP NGI Pad #NGI-13 Prudhoe Bay, AK AK0907G_545 25 Sep 2007 Serving the Worldwide Energy Industry with Precision Survey Instrumentation l~g-oa~ A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) INC. Lease: NGI Pad Well: NGI-13, 7" Tubing • Location: Mast Truck, Prudhoe Bay, Alaska Job Number: AK0907G 545 Run Date: 25 Sep 2007 Surveyor: Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.330528 deg. N Longitude: 148.482639 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North • Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location BP Exploration (Alaska) Inc. Lease: NGI Pad Well: NGI-13, 7" Tubing Location: Mast Truck, Prudhoe Bay, Alaska Job Number: AK0907G 545 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 100 ft. VERTICAL DEPTH feet CLOSURE HORIZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0.00 N 0.00 E -- ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 0 - 3000 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 7" TUBING ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO THE BASE FLANGE AT 17.62 FT. AMSL 50.00 0.11 27.20 N 27 12 E 0.23 50.00 0.0 27.2 0.04 N 0.02 E 100.00 0.04 311.92 N 48 5 W 0.22 100.00 0.1 17.6 0.10 N 0.03 E 150.00 0.17 266.30 S 86 1$ W 0.29 150.00 0.1 332.3 0.11 N 0.06W 200.00 0.17 266.26 S 86 15 W 0.00 200.00 0.2 295.5 0.10 N 0.21 W 250.00 0.14 242.73 S 62 44 W 0.14 250.00 0.3 281.1 0.07 N 0.34 W 300.00 0.33 239.32 S 59 19 W 0.39 300.00 0.5 266.0 0.04 S 0.51 W 350.00 0.37 241.97 S 61 58 W 0.07 350.00 0.8 256.7 0.19 S 0.78 W 400.00 0.39 228.18 S 48 11 W 0.19 400.00 1.1 250.4 0.37 S 1.05 W 450.00 0.73 232.60 S 52 36 W 0.68 449.99 1.6 244.5 0.68 S 1.43 W 500.00 0.87 229.96 S 49 57 W 0.29 499.99 2.3 240.4 1.12 S 1.97 W 550.00 1.03 218.97 S 38 58 W 0.49 549.98 3.1 236.1 1.71 S 2.55 W 600.00 1.05 217.70 S 37 42 W 0.05 599.97 3.9 232.1 2.43 S 3.11 W 650.00 0.78 215.91 S 35 55 W 0.53 649.97 4.7 229.5 3.06 S 3.59 W 700.00 0.79 216.24 S 36 i4 W 0.02 699.96 5.4 227.8 3.62 S 3.99W 750.00 0.85 228.09 S 48 6 W 0.35 749.96 6.1 227.2 4.15 S 4.47 W 800.00 0.69 212.26 S 32 16 W 0.53 799.95 6.8 226.6 4.64 S 4.91 W 850.00 0.62 221.02 S 41 1 W 0.24 849.95 7.3 225.8 5.10 S 5.25 W 900.00 0.53 212.49 S 32 29 W 0.25 899.95 7.8 225.2 5.50 S 5.55 W 950.00 0.39 226.97 S 46 58 W 0.36 949.95 8.2 224.9 5.81 S 5.79 W 1000.00 0.23 194.88 S 14 53 W 0.46 999.95 8.5 224.6 6.02 S 5.94 W ~J • 2 A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: NGI Pad Well: NGI-13, 7" Tubing Location: Mast Truck, Prudhoe Bay, Alaska Job Number: AK0907G 545 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. 1050.00 0.16 201.14 S 21 9 W 0.14 1049.95 8.6 224.1 6.19 S 6.00 W 1100.00 0.17 167.46 S 12 33 E 0.19 1099.95 8.7 223.5 6.33 S 6.01 W 1150.00 0.27 159.19 S 20 49 E 0.22 1149.94 8.8 222.4 6.51 S 5.95 W 1200.00 0.35 160.58 S 19 25 E 0.14 1199.94 8.9 220.9 6.77 S 5.85 W 1250.00 0.17 146.11 S 33 54 E 0.37 1249.94 9.0 219.6 6.97 S 5.76 W 1300.00 0.40 154.95 S 25 3 E 0.47 1299.94 9.1 218.1 7.19 S 5.65 W 1350.00 0.40 153.80 S 26 12 E 0.02 1349.94 9.3 216.2 7.50 S 5.50 W 1400.00 0.46 162.10 S 17 54 E 0.17 1399.94 9.5 214.3 7.85 S 5.36 W 1450.00 0.31 95.05 S 84 57 E 0.89 1449.94 9.6 212.7 8.05 S 5.16 W 1500.00 0,34 98.75 S 81 15 E 0.07 1499.94 9.4 211.1 8.09 S 4.88 W 1550.00 0.43 68.80 N 68 48 E 0.43 1549.94 9.2 209.5 8.04 S 4.56 W 1600.00 0.47 91.57 S 88 26 E 0.36 1599.94 9.0 207.6 7.98 S 4.18 W 1650.00 0.55 99.82 S 80 11 E 0.22 1649.93 8.9 205.0 8.03 S 3.74 W 1700.00 0.68 111.42 S 68 35 E 0.35 1699.93 8.8 201.5 8.18 S 3.23 W 1750.00 0.62 111.01 S 68 59 E 0.12 1749.93 8.8 197.9 8.38 S 2.70 W 1800.00 0.62 106.34 S 73 39 E 0.10 1799.93 8.8 194.4 8.55 S 2.19 W 1850.00 0.54 92.75 S 87 15 E 0.31 1849.92 8.8 191.1 8.64 S 1.70 W 1900.00 0.59 98.79 S 81 13 E 0.16 1899.92 8.8 187.9 8.69 S 1.21 W 1950.00 0.61 97.15 S 82 51 E 0.06 1949.92 8.8 184.5 8.76 S 0.69 W 2000.00 0.64 95.76 S 84 15 E 0.06 1999.91 8.8 180.9 8.82 S 0.15 W 2050.00 0.62 100.11 S 79 53 E 0.10 2049.91 8.9 177.4 8.90 S 0.40 E 2100.00 0.61 95.63 S 84 22 E 0.10 2099.91 9.0 174.1 8.97 S 0.93 E 2150.00 0.55 102.64 S 77 22 E 0.18 2149.91 9.2 171.0 9.05 S 1.43 E 2200.00 0.55 87.85 N 87 51 E 0.28 2199.90 9.3 168.2 9.09 S 1.90 E • • 3 BP Exploration (Alaska) Inc. Lease: NGI Pad Well: NGI-13, 7" Tubing Location: Mast Truck, Prudhoe Bay, Alaska Job Number: AK0907G 545 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. 2250.00 0.53 75.83 N 75 50 E 2300.00 0.62 88.23 N 88 14 E 2350.00 0.64 82.56 N 82 33 E 2400.00 0.59 89.08 N 89 5 E 2450.00 0.35 105.21 S 74 48 E 2500.00 0.36 144.86 S 35 8 E 2550.00 0.39 119.41 S 60 36 E 2600.00 0.35 128.34 S 51 39 E 2650.00 0.29 146.82 S 33 11 E 2700.00 0.35 130.29 S 49 43 E 2750.00 0.56 136.69 S 43 19 E 2800.00 1.44 119.78 S 60 13 E 2850.00 2.56 111.03 S 68 58 E 2900.00 3.32 99.94 S 80 3 E 2950.00 4.64 100.36 S 79 38 E 3000.00 5.95 102.09 S 77 55 E Final Station Closure: Distance: 22.88 ft Az: 126.23 deg. DOGLEG VERTICAL CLOSURE HORIZONTAL SEVERITY DEPTH DIST. AZIMUTH COORDINATES deg./ feet feet deg. feet 100 ft. 0.23 2249.90 9.3 165.3 9.03 S 2.37 E 0.31 2299.90 9.4 162.3 8.96 S 2.87 E 0.13 2349.90 9.6 159.0 8.92 S 3.42 E 0.18 2399.89 9.7 156.0 8.88 S 3.95 E 0.53 2449.89 9.9 154.0 8.91 S 4.35 E 0.48 2499.89 10.2 153.2 9.08 S 4.59 E 0.33 2549.89 10.5 152.5 9.29 S 4.83 E 0.13 2599.89 10.8 151.7 9.47 S 5.10 E 0.24 2649.89 11.0 151.3 9.67 S 5.29 E 0.21 2699.89 11.3 151.0 9.88 S 5.47 E 0.43 2749.89 11.7 150.5 10.15 S 5.75 E 1.85 2799.88 12.5 148.7 10.64 S 6.47 E 2.30 2849.85 13.9 144.7 11.35 S 8.05 E 1.89 2899.78 16.0 138.8 12.00 S 10.52 E 2.65 2949.66 18.8 132.2 12.62 S 13.93 E 2.65 2999.44 22.9 126.2 13.52 S 18.46 E • • 4 BP Exploration (Alaska) Inc. Well: NGI Pad NGI-13 7" Tubing Location: Mast Truck, Prudhoe Bay, Alaska Outrun Gyrodata AK0907G,~545 DEFINITIVE 0 -2 •4 •6 ~8 0 ~~ 2 60TTOM HOLE 4 MD: 3000.00 -5 0 5 t 0 1S ,-. w ... z 0 z -1 -1 -1 FASTING (ft) • • BP Exploration (Alaska) Inc. Well: NGI Pad NGI-13 7" Tubing Location: Mast Truck, Prudhoe Bay, Alaska 5.0 4.'~ 4.0 3.5 Q O 3.0 m -~ ... ~ 2.5 w w J 2.0 C9 O 1.5 1.0 0.5 0.0 Outrun Gyrodata AK0907G_545 DEFINITIVE i OTTOM HOLE L A D MD: 3000.00 0 50 0 10 00 15 00 20 00 25 00 30 00 C] • MEASURED DEPTH (ft) BP Exploration (Alaska) Inc. Well: NGI Pad NGI-13 7" Tubing Location: Mast Truck, Prudhoe Bay, Alaska °1 E a~ .. w ~~ u~ a ~5 Outrun Gyrodata AK0907G_545 DEFINITIVE i8 i6 OTTOM HOLE OCATED i4 i2 D: 3000.00 i0 8 ~ 6 4 2 0 8 ~ ~ ~ i 0 50 0 10 00 15 00 20 00 25 00 30 00 • • MEASURED DEPTH (ft) l3P Exploration (Alaska) Inc. Well: NGI Pad NGI-13 7" Tubing ~ Location: Mast Truck, Prudhoe Bav. Alaska ~ 3.5 Q z ~ 3.0 U Z 2.5 0.0 Outrun Gyrodata AK0907G_545 DEFINITIVE 6.D 5.5 5.0 4.5 4.0 2.0 1.5 1.0 0.5 BOTTOM HOLE LOCATED nnn. ~nnn nn .7 0 500 1000 1500 2000 2500 3000 MEASURED DEPTH (ft} . @1f@1f~ rm~@[¡ IE (~[.Yí @ W 11 LW J IJ'D.=> ~ (1)) J~ . I / I / / i f I SARAH PAUN, GOVERNOR AI4ASIi& OIL AND GAS COlVSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc PO Box 196612 Anchorage, AK 99519-6612 \Î'l:( Dq \ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-13 Sundry Number: 307-268 SCANNED AU G 1 'Ì 2007 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this -If day of August, 2007 Encl. . I 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension q o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program ~PUII Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. D Development o Exploratory 178-091 / 3. Address: ~ Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20347-00-00 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU NGI-13 ' Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): - ADL 028302 ( 48' / Prudhoe Bay Field / Prudhoe Bay Pool 1~'>i .... vvt:.LL > ..... . i .....,.............. ... . ... ... '. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8950 ./ 8620 . 8907 8581 7595 8830 Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 74' 20" 74' 74' 1530 520 Surface 2709' 13-3/8" 2709' 2709' 4930 2670 Intermediate 8015' 9-5/8" 8015' 7741' 6870 4760 Production Liner 1224' 7" 7725' - 8949' 7459' - 8619' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8410' - 8862' 8123' - 8540' 7",29# L-80 7621' Packers and SSSV Type: 9-5/8" x 7" Baker 'SAB-2' packer I Packers and SSSV MD (ft): 7606' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch o Exploratory o Development ~ Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: August23,2007 DOil o Gas D Plugged ~ Abandoned 17. Verbal Approval: Date: o WAG DGINJ DWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kris Honas, 564-4338 Printed Name Greg HßÞb¥ Title Senior Drilling Engineer /7 L// H Date e/;]M Prepared By Name/Number: Signature ¿r. Phone 564-4191 Terrie Hubble, 564-4628 ·v/ ' Commission Use On Iv I Sundry Number: S07, d.fo 1'1 Conditions of approval: Notify Commission so that a representative may witness ~IUg Integrity '¢.êOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: Subsequent Form Required: ~G~ --r:;¡ C MISSIONER APPROVED BY Date f5,¡i ,'f Approved Bv: THE COMMISSION Form 10-403 Revised 06/2006 '-"""'" J \ Submit In Duplicate '"I Ø7S ~//b/? . STATE OF ALASKA Cf)- fSe1 ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 ~7 RECEIVED ~fs-" ç AUG 1 4 2007 Alaska Oil & Gas Cons. Commiss . ' ORIGINAL RBDMS BFl t\UG 1 ' 2007 . ' . . Obp G~~..". To: AOGCC Date: August 13, 2007 From: Kristopher E. Honas - BPXA GPB Rotary Drilling Subject: NGI-13 Application for Sundry Approval- P&A for Sidetrack Operations Approval is requested for the P&A of PBU well NGI-13. Well NGI-13 is an Ivishak gas cap injector currently shut-in due to a failed MIT -IA. A production casing leak was found at -5101' MD. The well has been shut in and secured with a wire line retrievable plug set at 7,595' MD (10/12/06). NG 1-13 was drilled and completed in July 1979. The completion is 7" tubing and the 7" liner has 400' of perforations. Well integrity issues began with T x IA communication. The source appeared to be the SSSV control line. In February 2002 the SSSV was changed and a mechanical integrity test on the inner annulus passed. By 2005 the IA pressure began to increase again and the SSSV was replaced with an injection valve. The well received an AA from the state in June 2006 to continue operations. When another MIT-IA failed in September a production casing leak was discovered at 5101' MD. The liquid leak rate was 1.2 gpm. The AA was canceled and a plug was set at 7595' MD. The plan to repair NGI-13 includes the following: The existing 7" tubing string will be cut and pulled below 3000' MD. The 9-5/8" casing will be pulled from 40' below the EOCU formation. It is possible that some cement and 9-5/8" casing will need to be milled. A whipstock exit from the 13-3/8" casing below the EOCU formation is estimated at -2410' MD. A 12-1/4" bit will be used to drill from the window to -8473' MD (below the bottom of the HRZ formation). 9-5/8" production casing will be run with cement to -4100' MD. An 8-1/2" bit will be used to drill from the 9-5/8" shoe to TO at -9002' MD. The production hole will utilize 7" slotted liner. The well will be completed with 7-5/8" plastic coated tubing with premium threads from the 7" liner top to surface. The barriers below will be used to plug and abandon the existing perforations in NGI-13 prior to sidetracking the well: 1. 53 bbls of cement in the existing 7" liner from plug back TO to the 9-5/8" x 7" packer at -7602' MD. .037149 bbls/ft = 43.9 bbls .073206 bbls/ft = 8.3 bbls .025606 bbls/ft = 0.23 bbls .037149 bbls/ft = 0.33 bbls -....., ~ C{~~ ~ \ <'-....J\~ \-\0" ~''O\J~ ~~~~ ~1)v\ C6((<Ç" The NGI-13A sidetrack is currently scheduled for Nabors 2ES beginning August 30,2007. The pre-rig work for this sidetrack will be a top priority once Sundry approval has been obtained. a. CEMENT CALCULATIONS i. 1182' of 7", 29# liner: ii. 114' of 9-5/8", 47# casing: iii. 9' of 9-5/8", 47# x 7", 29#: iv. 9' of 7", 29" tubing: v. TOTAL: 53 bbls '/ 2. 13-3/8" EZSV plug set at -2443' MD. Estimated Pre-Rig Start: Estimated Spud Date: 08/23/07 08/30/07 Kristopher E. Honas GPB Rotary Drilling Engineer Office: 564-4338 Cell: 440-2389 NGI-13 Application for Sundry . . NGI-13A Drill and Complete Summary Pre-RiQ Operations: 1. Pull the WRP set at 7595' MD. 2. Run a static bottom hole pressure survey to determine proper mud weights during drilling operations. 3. Plug and abandon the existing perforations with 53 bbls of 15.8 ppg class G cement. Lay cement in with coil from PBTD to the 9-5/8" x 7" tubing packer. Cement volume based on the following calculations: a. 1182' of 7", 29# liner: .037149 bbls/ft = 43.9 bbls b. 114' of 9-5/8",47# casing: .073206 bbls/ft = 8.3 bbls c. 9' of 9-5/8", 47# x 7",29#: .025606 bbls/ft = 0.23 bbls d. 9' of 7",29" tubing: .037149 bbls/ft = 0.33 bbls e. TOTAL: 53 bbls 4. RU slick line and drift the tubing to TOC to verify depth.. ~"- 1:: c.~~ \~~'{'(..-c;.,,> 5. Pressure test the cement plug to 2500 psi. ~ t'«:S (~~ 1.0 6. Perforate the tubing above the production packer for circulation holes. ~ ?rY\.<6I[Ç 7. Circulate the well to 9.8 ppg brine. 8. Jet cut the 7", 26# tubing in the middle of a full joint at -3000' MD. 9. Bleed all casing and tubing pressures to zero. Freeze protect the tubing and IA with diesel to 2200' MD. 10. Function all lock down screws and repair/replace as necessary. 11. PPPOT - T to 5000 psi, PPPOT - IC to 3500 psi. 12. Set a BPV. Remove the well house and flow lines. Level the pad as necessary. RiQ Operations: 1. MIRU Nabors rig 2ES. 2. MIT-OA to 2000 psi for 30 minutes. 3. Pull BPV. 4. Run and test a TWC from below to 1000 psi for 30 minutes. 5. Nipple down the tree. Nipple up and test the BOPE to 4,000 psi high, 250 psi low. Pull the TWC. a. Ensure one set of rams are equipped to close around 7" tubulars. 6. Circulate out freeze protect by circulating 9.8 ppg brine around tubing cut. 7. Unseat the hanger. Pull and lay down 7" tubing from the pre-rig casing cut at -3000'MD. 8. Rig up E-line. Make up a gauge ring / junk basket to drift 9-5/8" casing. RIH and tag tubing stump. POOH. 9. Make up USIT\GR\CCL. RIH, log from tubing stump to surface. Rig down E-line. 1 O. Change out one set of rams to 9-5/8". Test to 4000 psi high and 250 psi low. 11. Make up 9-5/8" casing cutter for 47# casing. RIH, picking up singles. Cut casing as deep as possible above the top of cement depending on USIT results, DO NOT a collar. NOTE: KOP must be at least 10' below EOCU formation. If cement is above the bottom of the EOCU, cut the casing deep enough to put the top of the window 10' below EOCU. Make additional cuts every 90' until the TOC is reached. Washover and pull the -90' sections one at a time until the deepest cut is reached. 12. Establish circulation through 13-3/8" x 9-5/8" annulus to verify cut above TOC. POOH. 13. Spear 9-5/8" 47# casing from the mandrel hanger. Circulate as required to clear annulus. Pull and lay down. 14. Change rams back to variables. Test to 4000 psi high, 250 psi low. 15. PU 13-3/8" casing scraper and 12-1/4" mill assembly. Cleanout to the EZSV set depth. POOH. LD assembly. NGI-13 Application for Sundry . . 16. Make up an EZSV for 13-3/8" 72# casing. RIH and set as deep as 9-5/8" casing cut allows. POOH. 17. Test the EZSV and 133/8" casing to 4000 psi for 30 minutes. Chart test. . \ 18. Pick up and RIH with 13-3/8" Baker bottom trip anchor whipstock assembly. Th\C7 a..~~«:NG.- 1 a. Verify orientation with Gyro. t 19. Shear off. Displace well to 9.1 ppg milling fluid. 20. Mill window, plus 20' beyond the window. Circulate well clean. 21. Conduct FIT. If FIT does not reach a minimum of 10.6 ppg, contact engineer immediately. .~" 22. Drill the 12-1/4" intermediate hole increasing MW as necessary until 200 ft above the HRZ. At 200 ft " above the HRZ, the MW must be adjusted to a minimum weight of 9.6 ppg. ~ð 23. Drill ahead to TO in the base HRZ / top Put River at -8467' MD with 9.6 ppg drilling fluid; monitor for '\ ~ losses. Circulate the wellbore clean. POOH and lay down 12-1/4" drilling assembly. 24. Change out one set of rams to 9-5/8". Test to 4000 psi high, 250 psi low. 25. Run 9-5/8", 47#, TCII casing to TO. 26. Cement 9-5/8" production casing to 4100' MD. Pump freeze protection to ensure the annulus is protected below 2100' TVD. 27. Change rams back to variables. Test to 4000 psi high, 250 psi low. 28. Make up and RIH to the landing collar with the 8-1/2" drilling assembly. 29. Test the 9-5/8" casing to 4000 psi for 30 minutes and chart. 30. Drill out the 9-5/8" float equipment to the shoe. 31. Displace the well with 8.4 ppg FloPro SF drilling fluid. 32. Drill out the shoe, plus 20' of new formation. 33. Conduct an FIT to 10.0 ppg EMW. 34. Drill the 8-1/2" hole to TO at -9,002' MD. 35. Circulate the well bore clean, short tip to the shoe; circulate. POOH. 36. Run USIT/GR/CCL log on 95/8" casing to find TOC. 37. Pickup and RIH with 7" slotted production liner. 38. At TO, release from liner. Set liner top hanger/packer. POOH. 39. Change out rams to 7-5/8" for running tubulars. Test to 4000 psi high, 250 psi low. 40. Make up and run 7-5/8", 29.7#, L-80, VAM TOP internally plastic coated (IPC) completion string. Torque turn each connection. 41. Reverse circulate corrosion inhibitor and diesel freeze protection sufficient for annular freeze protection to 2200' MD. 42. Drop the ball and rod. Set the packer and immediately bring pressure up to tubing test pressure of 4000 psi. Chart this test for 30 minutes. Bleed the tubing pressure to 2000 psi. Increase the annular pressure to 4000 psi. Chart this test for 30 minutes. Notify the AOGCC to witness tubing and annular pressure test. 43. Bleed the annulus pressure to zero. Bleed the tubing pressure to zero. 44. Set and test a TWC to 1000 psi. 45. Change rams back to variables. Nipple down the BOPE. 46. Nipple up and test the tree to 5000 psi. Lubricate out the TWC. 47. Rig up slickline. Pull the ball and rod. Rig down slickline. 48. Bullhead diesel freeze protection fluid down the tubing, sufficient to freeze protect 2200' of 7-5/8" tubing. 49. Secure the well with a BPV. RDMO. Post-Ria Operations: 1 . Set SSSV injectiòn valve. 2. Install well house and instrumentation NGI-13 Application for Sundry T,REE;; __7 \fIÆLLHEAD = GRAY ........................... ACTUA TOR = AXELSON .................................. KB. ELEV = 48' .................................................................... BF. ELEV = u. ....................... KOP = 3300' NGI-13 I SAFETY NOTES: Max Angle = Datum MD = ............................. Datum T VD = 27 @ 4100' 9188' 8800' SS 2199' H7" OTIS RPB SSSV NIP, ID = 5.963" I ................................................. 17" TBG-NPC, 26#, L-80, .0383 bpf, ID = 6.276" H 2220' 113-3.18" CSG, 72#, N-80, ID = 12.347" H 2109' ITOP OF 7" LNR I -14-1 !2" V\ofD V\JRP (10112106) I -17" SEl!\L BORE EXT 1 1602' -19-518";{ 7" BAKER SAB-2 PI{R Minimum ID = 4.843" 01620' 1" BAKER SHEAROUT SUB I7"TBG-NPC,29#,L-80, .0371 bpf,ID=6.184" H 1611' 1620' H7" BAKER SHEAROUT SUB I 1611' H ELMD TT LOGGED 05124187 19-518" CSG. 47#, N-80, ID = 8.681" PERFOR.",TION SUMMARY REF LOG: SHCS ON 06130f79 ANGLE AT TOP PERF: 18 @ 8410' Nate: Re fer to P roduc1 ion DB for historical perf data SIZE SPF NTERVl',L Opntsqz DATE 3- 3.18" 4 841 0 -8532 1 98011 987 3- 318" 4 8536 - 8663 198011 987 3-318" 4 8665 - 8750 198011 987 3- 318" 4 8760 - 8780 198011 987 3- 318" 4 8785 - 8821 C 1 98011 987 3- 31'8" 4 8852 - 8862 198011 987 I PBTD H 8901' 18830' 5LM HFISH: IBP BULLNOSE -128' OF 4" PERF GUN I 7" LNR, 29#, N-80, .0371 bpf,ID = 6.184" ITD DATE OJIOI"9 0911 8106 0912 9106 0913 0106 10101106 1011 0106 REV BY COMMENTS ORIGINAL COMPLETION TELlTLH IBP SET RRDiPJC PULL & RESET IBP JCMfP l',G PULL IBP & IBP FISH RRDfP AG RESE T BKR IBP CJNITLH IBP FISH DATE REV BY COMMENTS 11115106 RRDfT LH IB P PU LLED NllRP SET (1 012006) PRUDHOE BAY UNIT \fIÆ LL: NGI-1 3 PERMIT No: 178-091 0 API No: 50-029-20347-00 SEC 1, T11 N, R14E 2531.95 FEL 4999.09 FNL liP Explonrtjon (Alllllkll) TÆE= ? VlJ8..l.J·EA.D = ORA. Y ..................................................................... AGTUATOR= AXa.sON ..................................................................... K8. ELB/ = 48' ..................................................................... 8F. ELB/ = .................................................................... KOP= .................................................................... .~.~..I!::.n.g.I.~..:::.........?!...@..~~.ºº: Datum MD= 9188' DatumlVD= 8800' SS N G 1-13 PRE-RIG SAFETY NOTES: . 2199' 1-17" OTIS RPB SSSV NIP, ID = 5.963" 1 17" TBG-NPC, 26#, L-80, .0383 bpf, ID = 6.276" H 2220' 113-318" CSG, 72#, N-80, ID = 12.347" I 2109' -3000' Tubing Punch for Circullll.ion Jet Cut '" 2&tI tu bing I PBTD H 8901' -1514' Minimum ID = 4.843" 07620' 7" BAKER SHEAROUT SUB 1596' 1602' H 7" SEAL BORE EXT 1 -19-518" X 7" BAKER SAB-2 PKR 7"TBG-NPC,29#,L-80, .0371 bpf,ID=6.184" I TOP OF 7" LNR H 1125' 1620' 1611' H7" BAKER SHEAROUT SUB I H ELMD IT LOGGED 05124187 19-518" CSG, 47#, N-80, ID = 8.681" H 8015' Plug and abandonorigìnal perforatìons with 53 bbls of 15.8 ppg cement from PBTD to 9-5/8" x 7" Baker SAß..2 PKR PERFORA TION SUMMARY REF LOG: BHCS ON 06ß0f79 ANGLE AT TOP PERF: 18 @ 8410' N ole: Refer to Prod uction DB for historic al perf data SIZE SPF INTERVAL OpnlSqz DATE 3-318" 4 8410 -8532 C 198011987 3-318" 4 8536 - 8663 C 198011987 3-318" 4 8665-8750 C 198011987 3-318" 4 8760.. 8780 C 198011987 3-318" 4 8785.. 8821 C 198011987 3-318" 4 8852 - 8862 C 198011987 -128' OF 4" PERF GUN 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" I I TD H DATE REV BY COMMENTS O'lOlm. ORIGINAL COMPLETION 09118106 TELrrLH IBP SET 09129106 RRDJPJC PULL & RESET IBP 09ßOlO6 JCMJPAG PULL IBP & IBP FISH 10101106 RRDJPAG RESET BKR IBP 1 011 010 6 CJ NrrLH IBP FISH DATE REV BY COMMENTS 11115106 RRDrrLH IBP PULLEDfoI\.IRP SET (1 012006) PRUDHOE BAY UNIT VVELL: NGI-13 PE RMIT No: 1 78-0910 API No: 50-029-20347-00 SEC 1, T11N, R14E 2531.95 FEL 4999.09 FNL liP Ellplorlll.ion (A1..k.) Prop edN G!I-13A =6. 7rn~·.9344· NIPPLE \ \ \ \ \ \ \ \ \ \ \ \ \. pRll)HQf I!>A Y It\ !T \f'ÆLL: N¡:¡;I·13A pERMIT No: APUIQ So..W9-2iJ347-m See, fNl BP bplorJIlUon CAt_lot) • ~~aa~y xT ~~v II® ~+ AT s~e3,aea ~,aLe~, cov~Re~oe~ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907j 279-1433 FAX {907) 276-7542 CANCELLATI®N ADMINISTRATIVE APPROVAL NO. AIO 4E.007 ~~ ~ ~~ I Mr. Steve Rossberg, Well Program Manager BP Exploration (Alaska) Inc. P.O. Box 196612 ~,~~~~~ j ~A~1 2~~~ Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 04E.007 (Well PBU NGI-13) Dear Mr. Rossberg: Pursuant to BPXA's request dated December 7, 2006 AOGCC hereby- cancels Administrative Approval AIO 04E.007, which allows gas injection in well PBU NGI-13. This well exhibited T x OA pressure communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that gas injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has determined that PBU NGI-13's condition has deteriorated to the point that safe operation is no longer supported. The well is shut in awaiting a rig work over. Consequently, Administrative Approval AIO 04EA07 no longer applies to operation of this well. Instead, injection in well PBU NGI-13 will be governed by provisions of the underlying Area Injection Order No. 4E. DONE at Anchorage, Alaska and dated December 15, 2006. _air ~- The Alaska Oil and Gas Conservation Commission ~n ~~;_ Daniel T. Seamount, Jr. Cathy . Foerster Commissioner Commissioner • _- =- ~v ~~77~~++~~tt ~-~at7~~ ®a.is .~.as~~r~+~7~Y f~J FRArVX ii, hYUR6tOW1SiC1, GOp1ErRMOR AIDMgNIST1~TIVE APPR®~'AL ~E.007 Mr. Steve Rossberg We11s Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 333 W. 7"° AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE {907 279-1433 FAX (907J 276-7542 RE: PBU NGI-13 (PTD 178-091) Request for Administrative Approval Dear tilr. Rossberg: Pursuant to Rule 9 of Area Injection Order (`=AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue gas injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU NGI-13. The Commission further finds that the well exhibits IA repressurization of about 150 psi per day, that can be safely managed with periodic pressure bleeds. How- ever, the Commission acknowledges that events such as SSSV control line failures may allow the well's tubing pressure to communicate with the IA. Accordingly, the Commis- sion believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the con- straints enumerated below. AOGCC's administrative approval to continue gas injection in PBU NGI-13 is condi- tioned upon the following: 1. BPXA shall record weiihead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT - IA every four years to the maximum anticipated injection pressure, the anniversary date of which shall be this approval's effective date; • a~ tilr.Steve Rossberg stay 31, 2006 Page 2 of 2 4. BPXA~shall limit the well's IA operating pressure to 2000 psi; ~. SPXA shall install and operate remote pressure monitoring equipment on the well's IA; b. BPXa shall immediately shut in the well and notify the AOGCC if there is any change in the weii"s mechanicai condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day foilow•ing the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Done~-Ane~lie, Alaska and dated May 31, 2006. Chairman -~~_: -_ '...y.:S Dan T. Seamount Commissioner i Cath P. Foerster Commissioner . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) 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 : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 í' I; -Li (',' 1) 2) 3) 4) 5) 6) 7) EDE Disk NGI - 13 Leak Detect 16-Nov-06 / , /J (~.!t- é h r'¡ 6 fi i/I P /J1 /1 t M t:. ¡¿IA t''\ F""·/-~":, -1 .""'.,;"'-;"". ;,,\ U;CLj ':....' {dtJ:;~1 Signed: Date : Print Name: U I-G r=t-?r - OC1/ lÌ I ~I d -::;-6 PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE. AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: 'pD.s)\¡'jCHC;~:t.A<;:::@!.'J1E~flCRYL;~G.COfu] WEBSITE : :1\J1I'd\}f.ivì¡:rvl0¡~~/LC;G.';:;(1i\il D:\OO _ PDSANC-2006\Z _ W ord\Distribution\Transrrutta1_ Sheets\Transmit_ Original.doc Re: WGI-06 (PTD # 1900300) Slow IA Repressurization e BP notified the Commission about varying degrees of pressure communication affecting 6 PBU gas injectors. Wells are: AGI-06; TxIA NGI-01; TxIA NGI-06¡ IAxOA NGI-10¡ IAxOA NGI-13¡ TxIA WGI-06¡ TxIA BP intends no repairs to correct the pressure communication, instead relying on human intervention to manage the pressures. The correct mechanism for reviewing continued operation of these wells is the administrative approval process under AIO 4D Rule 9. Please submit admin approval requests to the Commissioner's attention. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim and Winton. Well WGI-06 (PTD # 1900300) is exhibiting indications of pressure communication between the tubing and lA, as noted on the attached TIO plot. An MITIA on 6/15/03 passed to 2500 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 30 days. This pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time. Attached is a TIO plot and wellbore schematic. Please call with any questions. «WGI-06.pdf» «WGI-06 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWelllntegrityEngineer@bp.com <11.l~J:l!:.<2-=-~_~U~!JWe ~_1_~!::1:t::.~_9.E~!:.Y~E!:9.~!1ee r@bp_.:_':..<2ffi> 1 of 1 3/24/2006 10:03 AM NGI-13 (PTD #1780910) Slow IA Repressurization e e Hello Jim and Winton. Well NGI-13 (PTD #1780910) is exhibiting indications of pressure communication between the tubing and lA, as noted on the attached TIO plot. An MITIA on 6/1/02 passed to 2500 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 8 days. This pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time. An IA pressure monitoring system and automatic shut-in equipment will be installed. Attached is a TIO plot and well bore schematic. Please call with any questions. «NGI-13.pdf» «NGI-13 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllnteç¡rityEnç¡ineer@bp.com Content-Description: NGI-13.pdf Content- Type: application/octet-stream Content-Encoding: base64 Content-Description: NGI-13 no Plot.jpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 3/20/2006 10:51 AM IA .... TREE = WB.lHEAD = ACTUATOR = KB. ElEV = BF ElEV = KOP- Max Angle = Datum MD = DatumlVD = ? GRAY AXELSON 48' 3300' 27 @ 4100' 9188' 8800' SS IT' TBG-NPC, 26#, l-80, 0.0383 bpf, ID= 6.276" I 2220' 13-318" CSG, 72#, N-80, ID = 12.347" 2709' Minimum 10 = 4.843" @ 7620' 7" BAKER SHEAROUT SUB 7"TBG-NR::, 29#, l-80, 0.0371 bpf, ID= 6.184" lDPOF7" lNR I NGI-13 . 2199' -':> I SAFETY NOTES: 7" OTIS RPB SSSV NIP, ID = 5.963" ~::r<-( P -=. 53&JF" éó~(q¡se -=- 2b 70re:.: 9-5/8" CSG, 47#, N-80, ID= 8.681" PERFORATION SUMMARY REF lOG: BHCS ON 06/30/79 ANGLE AT lDPPERF: 18 @8410' IIbte: Refer to Production DB for historical perf data SIZ E SPF INTER\! Al OpnlSqz DtI TE 3-3/8" 4 8410-8532 0 1980/1987 3-3/8" 4 8536-8663 0 1980/1987 3-3/8" 4 8665-8750 0 1980/1987 3-3/8" 4 8760-8780 0 1980/1987 3-3/8" 4 8785-8821 0 1980/1987 3-3/8" 4 8852-8862 0 1980/1987 8907' 8949' 8950' 7620' 7" SEA l BORE EXT -J 9-518" X 7" BAKER SAB-2 PKR 7611' H ElMD TT lOGGED OS/24/87 7" SA KER SHEA ROUT SUB -;> ~ p':: b'D 70fs' (øll~ ~ 47~; 8907 28' OF 4" PERF GUN DtlTE REV BY COMMENTS DATE REV BY COMMENTS 07/08179 ORlGINð.l COMA...EllON 01/12/01 SlS-CS CONVERTED TO CANV AS 03112/01 SIS-MD FINð.l 01/10102 RN/TP CORRECilONS PRUDHOE BAY UNIT WEll: Nm13 PERMT lib: 178-0910 API lib: 50-029-20347-00 SEC1. T11N, R14E 2531.95 Æl4999.09 FNl BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector TO: Camille O. Taylor (.,O~ DATE: June 1, 2002 Chair SUBJECT: Mechanical Integrity Tests ''1~,-~O~-~ 07,09,13 & 14 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. 'we,,I NG,-07 I mype,nj.I G ]T.V.D.I 7398 I Tubingl 3360 I 3360 1'3360 I 3366 I,nterva,I 4 P.T.D.I 1760380 ITypetestl P' I'TestpsiI 1850 I Casingl 280 I 2040 I 2030 I 2030 I P/F J P Notes: WellI NGI-09 I Typelnj. I G I T.v.D. I 7510 I'l:ubing I 3550 I 3550 J 3550 I 3550 I lntervall" ,~'" P.-r.D'.I 1760680 ITypetestl P ITestpsil 1878 I Casingl 300 I 2450 I 24501 2,45°1 P/F I -P" Notes: WellI NGI-13 P.T.D.I 1780910 Notes: WellI NGI-14 P.T.D.I 1780920 Notes: WellI P.T.D.I Notes: Type Inj.I G I T.V.D. 17344 I Tubi,g I~0 I~0 I~0 I~0 I Inte~vall 4' Type testI P I TeStpsil 1836 I CasingI' 80 I 25001 24901 25001 P/F I -P'i I Typelnj. I G I T.V.D. i~,~, I Tubi.g 13550 13550 I~.0 I~0 I lntervall 4' Type testI P I Test psiI 1793 I Casing'l ' 50 I 2560 I 2330 I 2300 ] PIE I P JType Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test' M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I'- Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field NGI Pad to Witness 4 year MIT's. Good tests, no failures or problems witnessed. M.I.T.'s performed: 4 Attachments: Number of Failures: 0 -- Total Time during tests: 3 hrs. CC: MIT report form 5/12/00 L.G. MIT PBU NGI 06-01-02jc.xls 6/4/02 P. I"1.. R{]× i O0~AO DATE' ,.. ,._ ~...- R 7 ~ 4- { ,.'2 -~4-t 2 6-20-R7 ""- ..~-i ~ R-i S-R7 ~ 7-t { R-t 4-R7 ~- i 4-~0 R-24-R7 ~"N .F, T- ~ .5-4-R7 '",, N.F, T -2 5-Z-87 ~NG '11-6 5-- 2- R 7 ~ Ng t -R S-P-FI'7 . .. ,:.. ,;. COI..I. cnl_l Cfil I. AR/F'ER~flRTT~N ROI..I.. AR/F'ERFORAT ~ ON Cll!... I. AR'/F'FR'FF1RAT 1' ~N Cfil...I .AR/PFR'FflRAT C~l. I. AR'/F'ERFn~'~TTON CO/..I.. C~I..1.. A R'./F'F R FRR A T 'r COI.I AR/PERF~RAT COL I.. AR/PFRF'fll7 AT 'r ON Rill .. I... A R/E'ER FOR A T I, lg T,4 ..5-25-87 /I C 0~.. A r.~'./F' g R' F'I-tR A T 1' 0 N I.F..A,.~E .~.T.f;N S' RI:".[.'.ETF'T OF I)AT~,. A V E AN .T. C PEF. GY BENNETT 'ATO-t .. ¢' ,~:.. · Tg:A N.g "'°R~7'z "Il' L.~ ~...,.I AF'F'R.r_IVE D D],~TRT~I.ITTON -.-" CENTRAl_ FII..E~7 ~ CHEVRON ~: EXT.F: N,? TON F'XP[..RR'AT T .ON · "- EY, Y. FIN ,-ii- NAR'ATHON .,.-"- MI]RTl_._ PM I 1...I... T. P.? F'T4 LdFI...I. FTI...FY ..~AF'C .~TATE JiF AI..A,S'KA TFYAf:R DRF~FR D~FX~FR DRF~XFF~ DRE~FR DRF~!CR T)RF~FR I)RFS~FR DRE~IrR DRF~FR ARCO Alaska, In Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 25, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-9, 13 & 14 Approval Nos. 7-477, 7-476 & 7-478 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations performed on the above-referenced wells. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company P 1 (NGI-9) W1-3 P1 (NGI-13)W1-3 Pi (NGI-14)W1-3 detailing work RECEIVED Gas Cons, Commission Anchora§e WELL S / 117 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ' ALAb,,A OIL AND GAS CONSERVATION COlt ,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Ala_~ka.. Tnt. 3. Address Post 4. Location Office Box 100360, Anchoraqe, AK 99510 of well at surface 489' FSL & 840' FWL, Sec. At top of productive interval 314' FSL & 2541' FWL, Sec. At effective depth 285' FSL & 2567' FEL, Sec. At total depth 282' FSL & 2533' FEL~ Sec. 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 5. Datum elevation (DF or KB) 48 ' RI(R Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-13 (24-1-11-14) 8. Approval number 9. APl number 50-- ~l?q-?n347 10. Pool Sadlerochit 11. Present well condition summary Total depth: measured true vertical 8950 feet 8619 feet Effective depth: measured feet true vertical feet Plugs (measured) Junk (measured) None 8847' - Fill 8847 8526 Casing Length Size Cemented Measured depth ~ue Vertical depth Conductor 43½' 20" 277 sx Arcticset 74' 74' Surface 2678½' 13-3/8" 4800 sx Arcticset II 2709' 2709' Production 7984½' 9-5/8" 700 sx Class G Cmt 8015' 7740' Liner 1224' 7" 325 sx 7725'-8949' 7828'-8618 Perforation depth: measured 8410-8488', 8496-8663', 8665-8750', 8760-8780', 8785-8821', 8852-8862' true vertical 8122-8196', 8204-8359', 8361-8439', 8448-8466', 8471-8503', 8531-8540 ' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM 8rd to 7594 'MD Packers and SSSV (type and measured depth) R E £ E IV E D 9-5/8" x 7" Baker SB-2 Packer @ 7606'MD/Otis 12. Stimulation or cement squeeze summary Si"ii;) 2 3 1987 Intervals treated (measured) Alaska 0il & Gas Cons. C0mmiss[01 Treatment description including volumes used and final pressure Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -- 172 .... 216 Tubing Pressure 3900 3900 14. Attachments Daily Report of Well Operations I~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Operations Engineerin9 Manager Date '/'~/~/" Submit in Duplicate(/~ Lantero (263-4312~ NGT-13/STAT16 P.V. DRILL SITE NGI-13 SELECTIVE STIMULATION On August 26, 1987, the following treatment was performed on NGI-13: · · MI and RUN2 truck, pump truck and transports. Rolled all acid compartments. 3. Pumped the following fluids: 4~ At B. C. D. Ee F. G. H. Ie J. K. L. Me 5000 gals of PAD dispersed acid w/additives 5000 gals of 12% HCl-3% HF w/additives 5000 gals of 2% NH.Cl water w/additives 35 bbls of 2% N~zCl gelled with 40 lbs/1000 gals CMHEC w/2450 SCF/BBL of N~ 2500 gals of ZPAD dispersed acid w/additives 5000 gals of 12% HC1-3% HF w/additives 5000 gals of 2% NH.C1 water w/additives 35 bbls of 2% NH%.C1 gelled with 40 lbs/1000 gals CMHEC w/2450 SCF/BBL of N? 4000 gals of-PAD dispersed acid w/additives 8000 gals of 12% HC1-3% HF w/additives 8000 gals of 2% NH.C1 water w/additives 35 bbls of 2% N~.C1 gelled with 40 lbs/1000 gals CMHEC w/2450 SCF/BBL of N? 1500 gals of-PAD dispersed acid w/additives 3500 gals of 2% NH.CI^ water w/additives 3500 gals of 2% NHTC1 water w/additives RD and released equipment and returned well to injection immediately. 5. Tested well for new injection capacity. RECEIVED Oil & ~as Cons, Anchor~fle WELLS/il73 -- STATE OF ALASKA AL/- ,A Oil AND GAS CONSERVATION CO.~,~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska. Inc. 3. Address Post 4. Location 489' At top of 314' FSL & 2541' At effective depth 285' FSL & 2567' At total depth 282' FSL & 2533' 11. Present well condition summary Total depth: measured Office Box 100360~ Anchoraqe, AK 99510 of well at surface FSL & 840' FWL, Sec. 1, T11N, R14E, UN productive interval FWL, Sec. 1, T11N, R14E, UM FEL, Sec. 1, T11N, R14E, UM FEL, Sec. 1~ T11N~ R14E~ UM 8950 feet Plugs (measured) 5. Datum elevation (DF or KB) &R ' RKR Feet 6. Unit or Property name Prudh0e Bay Unit, 7. Well number NGI-13 (24-1-11-14) 8. Approval number 7-_e_~7 9. APl number 50-- (l?q-2f)347 10. Pool Sadlerochit None true vertical 8619 feet Effective depth: measured 8847 feet true vertical 8526 feet Casing Length Size Conductor 43½' 20" Surface 2678½' 13-3/8" Production 7984~' 9-5/8" Junk (measured) 8847' - Fill Cemented Measured depth 277 sx Arcticset 4800 sx Arcticset II 700 sx Class G Cmt True Vertical'depth 74' 74' 2709' 2709' 8015' 7740' Liner 1224' 7" 325 sx 7725'-8949' 7828'-8618 Perforation depth: measured 8410-8488', 8496-8663', 8665-8750', 8760-8780', 8785-8821', 8852-8862' true vertical 8122-8196', 8204-8359', 8361-8439', 8448-8466', 8471-8503', 8531-8540' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM 8rd to 7594 'MD Packers and SSSV (type and measured depth) 9-5/8" X 7" Baker SB-2 Packer @ 7606'MD/Otis SSSV ~ 2203'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 5/21/87 -- 166750 .... Subsequent to operation 5/29/87 -- 143160 .... Tubing Pressure 3745 3696 14. Attachments Daily Report of Well Operations j~ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my kno~, ~ge ~_~L. Signed Form 10-404 Rev. 12-1-85 Title Operations El MI~CI (?F;i:;_RRll3 ~ neering Mana~ler Date ~/~"~ Submit in Duplicate NGI-13 ADD PERFS Daily Report of Well Operations 5/24/87 PT lub/rams to 4000 PSI. OK. Pull SSSV. RIH w/Bailer, TTL, & Dummy Gun. Tag bottom @ 8864'. POH - asphaltenes on tool string. PT hardline to 4000 PSI. OK. Pump in diesel/cylene wash - spot across perfs. PT lub/rams to 4000 PSI. OK. RIH w/ 4' & 16' select fire gun, 3-3/8", 4 SPF, 120° phasing. Shoot 8594-8610' (16'). Shoot 8532-8536' (4'). POH - all shots fired. PT lub/rams to 4000 PSI. OK. RIH w/8' & 16' select fire gun, 3-3/8", 4 SPF, 120° phasing. Shoot 8805-8821' (16'). Shoot 8556-8564' (8'). POH - all shots fired. PT lub/rams to 4000 PSI. OK. RIH w/25' gun, 3-3/8", 4 SPF, 120° phasing. Shoot 8705-8730' (25'). POH - all shots fired. PT lub/rams to 4000 PSI. OK. RIH w/ 8' & 13' select fire gun, 3-3/8", 4 SPF, 120° phasing. Shoot 8650-8663' (13'). Shoot 8488-8496' (8'). POH - all shots fi red. PT lub/rams to 4000 PSI. OK. RIH w/26' gun, 3-3/8", 4 SPF, 120° phasing. Shoot 8506-8532' (26'). POH - all shots fired. PT lub/rams to 4000 PSI. OK. RIH w/18' gun, 3-3/8", 4 SPF, 120° phasing. Shoot 8430-8448' (18'). POH - all shots fi red. PT lub/rams to 4000 PSI. OK. RIH w/SSSV and sit @ 2171' SLM. PT lines to 4500 PSI. OK. Flow test'w/500 psi differential pressure. OK. ~ARCO Alaska, In( Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 27, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS NGI-13 Permit No. 78-91 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp At tachment cc: Standard Alaska Production Company Pi(NGI-13)W1-3 to be WELL S / 118 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALA,_.,A OIL AND GAS CONSERVATION COl, ,tSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown [] Re-enter suspended well Lq Alter casing ii Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order E3 Perforate ['] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 48' RKB feet 3. Address 6. Unit or Property name Post Office Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 489' FSL & 840' FNL, Sec. At top of Productive interval 314' FSL & 2541' FWL, Sec. At effective de_pth 286' FSL & 2583' FEL, Sec. At total depth 282' FSL & 2533' FEL, Sec. 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 7. Well ~r~_b~ ( 2 4-1 - 11 - 14 ) 8. Permit number 78-91 9. APl number 50-- 029-20347 10. Pool Sadlerochit 11. Present well Condition summary Total depth: measured true vertical 8950 feet 8619 feet Effective depth: measured 8831 feet true vertical 8512 feet Casing Length Size Conductor 43½' 20" Surface 2678½' 13-3/8" ProduCtion 7984½' 9-5/8" 8907' - Cement Plugs (measured) Fish @ 8831' Junk(measured) (28' of 4" Perf Gun & CCL) Cemented Measured depth Rue Vertical depth 277 sx Arcticset 74' 74' 4800 sx Arcticset II 2709' 2709' 700 sx Class G Cmt 8015' 7740' Liner 1224' 7" 325 sx 7725'-8949' 7828'-8618 8410-8430' 8448-8488' 8496-8506' 8536-8556' 8564-8594' ~r{%r_a~(¢ ,P ~ b~e-a~6e5d ' , , , , ¢ t 6 ' 8730-8750' 8760-8780' 8785-8805' 8852-8862' true vertical 8122-8141' 8158-8196' 8204-8213' 8241-8260' 8267-8295' 8310-8347' 8361-8398' 8420-8439' 8448-8466' 8471-8489' 8531-8540' Tubing (size, grade and measured depth) 7" 29# L-80 ABM 8rd to 7594'MD Packers and SSSV t e and measured depth) 9-5/8" x ~¥PBaker SB-2 Packer 12.Attachments Description summary of proposal 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~, ~-~/~ ~AT. ,S'~.Z¢ ~c Title Operations Engineering Manager Commission Use Only Conditions of approval Approved by Date Notify commission so representative may witness I Approval No. [] Plug integrity L~ BOP Test [] Location clearanceI ?- 77,~ ~ ;~)~:~t:' Commissioner the commission Date Form 10-403 Rev 12-1-85 MRO (265-6810) ,/~ Submit in triplicate DRILL SITE NGI-13 SELECTIVE STIMULATION PROCEDURE AFE #699055 PROPERTY CODE #2130629 . Be e MI and RUN2 truck, pump truck and transports. Stimulate the well as follows: A, B. C. D. go F. G. H. Ie J. K. L. Me 5000 gals of dispersed acid w/additives 5000 gals of 12% HCl-3% HF w/additives 5000 gals of 2% NHoC1 water w/additives 5000 gals of 2% NH~Cl gelled w/40 lbs/1000 gals CMHEC w/2450 SCF/BBL of NA 2500Zgals of dispersed acid w/additives 5000 gals of 12% HC1-3% HF w/additives 5000 gals of 2% NHoC1 water w/additives 35 bbls of 2% NH4~i gelled w/40 lbs/1000 gals CMHEC w/2450 SCF/BBL of NA 4000Zgals of dispersed acid w/additives 8000 gals of 12% HC1-3% HF w/additives 8000 gals of=2% NHAC1 water w/additives 35 bbls of 2% NH4C~ gelled w/40 lbs/1000 gals CMHEC w/2450 SCF/BBL of N_ 15002gals of dispersed acid w/additives 3500 gals of 12% HC1-3% HF w/additives 3500 gals of 2% NH4C1 water w/additives RD and release equipment and return well to injection immediately. Test well for new injection capacity. WELLS/il82 .... STATE OF ALASKA --' ALASK . OIL AND GAS CONSERVATION COMN....,$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well L~ Alter casing ~ Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska: Tnt. 3, Address Post Office Box 100360~ Anchora§e~ AK 99510 4. Location of well at surface 489' FSL & 840' FWL, Sec. At top of productive interval 314' FSL & 2541' FWL, Sec. At effective depth 286' FSL & 2583' FEL, Sec. At total depth 282' FSL & 2533' FEL, Sec. 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 5. Datum elevation (DF or KB) 48' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-13 (24-1-11-14) 8. Permit number 78-91 9. APl number 50-- 029-20347 10. Pool Sadlerochit 11. Present well condition summary 8907' - Cement Total depth: measured 8950 feet Plugs (measured) true vertical 8619 feet Effective depth: measured 8831 feet Junk (measured) Fish @ 8831' true vertical 8512 feet (28' of 4" Perf Gun & Casing Length Size Cemented Measured depth True Vertical Conductor 43½' 20" 277 sx Arcticset 74' 74 Surface 2678½' 13-3/8" 4800 sx Arcticset II 2709' 2709 Production 7984½' 9-5/8" 700 sx Cla¢~ G Cmt 8015' 7740 Liner 1224' 7" 325 sx 7725'-8949' 7828 CCL) depth I I I Perforation depth: measured 8410-8430', 8448-8488', 8496-8506', 8536-8556', 8564-8594', 8610-8650', 8665-8705', 8730-8750', 8760-8780', 8785-8805', 8852-8862' true vertical 8122-8141', 8158-8196', 8204-8213', 8241-8260', 8267-8295' 8310-8347', 8361-8398', 8420-8439', 8448-8466', 8471-8489', 8531-8540' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM 8rd to 7594' MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SD-2 Packer @ 7606'MD/0tis SSSV @ 2203'MD 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch ~ 13. Estimated date for commencing operation May, 1987 14. tf proposal was verbally approved Name of approver Date app,,roved 15. I hereby/c~rtify that the~ore.gcing i.~ true and correct to the best of my knowledge ~1-1~~~/~'!/1t I/~.~ Title Operations Engineering Manager Date Signed Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. r-i Plug integrity ~ BOP Test [] Locationclearancel...' '~" by order of P7 Approved by ~ [¢t{~!~ §, ~;~ Commissioner the commission Date feet [ '-861~ ' Form 10-403 Rev 12-1-85 MR0 (265-6810) Submit in triplicate NGI-13 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-13. The proposed perforation intervals are as follows: Existing Perforations Proposed Perforations Reference 8410-8430 (20') 8430-8448 (18') BHCS of 6/30/79 8448-8488 (40') 8496-8506 (10) 8536-8556 (20) 8564-8594 (30) 8610-8650 (40) 8665-8705 (40) 8730-8750 (20) 8760-8780 (20') 8785-8805 (20') 8852-8862 (10') 8528-8536 (8') 8556-8564 (8') 8594-8610 (16') 8650-8663 (13') 8705-8730 (25') 8805-8821 (16') TOTAL = 270' TOTAL = 104' A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. WELL: SURFACE LOCATION: BOTTOM HOLE LOCATION: ORIGINAL RKB': TOP OF SADLEROCHIT: NGI #13 ~-- SPUD DATE: 6/9/79 48g'N ~840'E of SW ct. ~ec. 1, TllN, R14E, UN 282'N & 253'3'~ of SE cr. sec. 1, ~lN, R14E, UM 48' RKB TO Gray HANGER 30.5' 8405' , MD ALL DEPTHS ARE RKB MD Depths are to TOP of equipment ] -1 AVERAGE HOLE ANGLE: HAXIMUM ANGLE: ,ANGLE AT TD: ANNULUS FLUID: 74' 20", 94#, H-40 Vetco (19.124" ID) w/ 277 sx 2180' 7", 26#, L-80 ABIJ4S (6.276" ID) 2203' Otis RPB Landing Nipple (5.963" ID) 2320' Bottom of 9-!/8", 47#, S00-95 BTC (8.681"ID) ._..2341' 9-5/8" FO 2463' 9-5/8" FO ~ 2709' 13-3/8", 72#, N-80 BTC (12.347" ID) w/ 4800 sx 7594' Bottom of 7", 29#, L-80 ABM 8rd (6.184" ID) 7602' Baker Seal Bore Extension 7606' 9-5/8" x 7" Baker SB-2 Packer 7620' Baker Mill Out Extension 7621' Baker Shear Out Sub (4.843" ID) NO TUBING TAIL 7725' Top of Liner, BOT MC Hanger 8015' 9-5/8", 47#, N-80 BTC (8.681" ID) w/ 700 sx - 8430' - 8488' - 8506 - 8556 - 8594 - 8650 - 8705' - 8750' - 8780' 8785' - 8805' 8852' - 8862' *FISH in hole,28' of 4" Perf Gun & CCL 8907' PBTD 8949' 7", 29#, N-80 BTC (6.184" ID) w/ 325'sx 8950' TD 8410 8448 8496 8536 8564 8610 8665' 8730' 8760' 19.9o '26.5o @ 4126" 14o 10.8 CaC12 & Diesel NOTE: Well was under cut and sidetracked @ 7155-8040' to avoid 1/84 I4 ! ! ! ! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) .3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EQU I PMENT April ~17~ 1980 P. O. Box 360 Anchorage, A~_aaka 99510 testing in PrudhOe Bay gas inje~.on wells. Our understanding is that NGI ~ 2, 12, 13, and 14 are equipped. with Otis flapper type valves. We have been Witnessing initial '~tests of these valves prior to the w~lls being used for /njection. i' i ~Al,th0uFh ~these tests are impartant, we are anxious to see how these ,va%. ~ve,s . ,perf. ~c~m,. under operating ccn~~. Due to the prob~ involved wi~ .b~ off the gas during the testg~., we agree that opera~~ testing,of.~se~ .valves should be ~lay~ until ARCO Oil and Gas~ompany P(;s! C_.';l~ice :.:.,x S5S Ancho~ag::. Alaska 9:,'5!0 i ,.~, en. hon,.;., '.)07 277 :.~'-~'~o ~, ~ March 13, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99510 Subject: DS 3-11, Permit No. 79-47 DS 3-12, Permit No. 79-58 DS 3-13, Permit No. 79-71 DS 3-14, Permit No. 79-82 NGI #13, Permit No. 78-91 NGI #14, Permit No. 78-92 Dear Sir' Enclosed please find Completion Reports and Perforating Histories for the above-mentioned wells. Production information for these wells will be sent as soon as it is available. Very truly yours, P. A. VanDusen District Drilling Engineer Enclosures ARCO Oil and Gas Company is ~ Division of ,~l[anhc!~,tchfieldCon:pany Form P--7 SUBMIT IN Db, ~...,FE* STATE OF ALASKA (see other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: ,,~,- ,---~ ,O,,1~ LF1 GAS WELLI I DRYEr] Other Gas Injection b. TYPE OF COMPLETION: NEW ~ WORKIII DEEP-III PLUG ~ DIFF. I~1 WELLI "1 OVER I I EN I I BACKI I RESER.I I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 630 Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 489'N & 840'E of SW cr Sec 1, T11N, R14E, UM At top prod. interval reported below 314'N & 2539'W of SW cr Sec 1, TllN, R14E, UM At total depth 282'N & 2533'W of SE cr 13. DATE SPUDDED 114. DATE T.D. REACHED 6/9/79 I 7/2/79 18. TOTAL DEPTH, MD&TVD 119. PLUG BACK I DEPTH 8950'MD 8620' TVD I 8907'MD 22, PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* Top Sadlerochit 8405'MD 8118'TVD Base Sadlerochit 8864'MD 8542'TVD 5. APl NUMERICAL CODE 50-029-20347 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #13 (24-1-11-14) IO~FIEL[~ AND P~OL, O[~ ~/II.~DqAT Frudnoe Hay field Prudhoe Oil Pool 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 1, TllN, R14E, UM Sec 1, T11N, R14E, UM 12. PERMITNO. 78-91 7/8/79(2/11/80 perf'd 48' RKB MD&TVD 20. IF MULTIPLECOMPL., I CABLE TOOLS HOW MANY* 21. ROTARY TOOLS INTERVALS DHILLbL) BY 8581 'TVD Sin§leI All 23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/CAL/GR, 25. CASING SIZE 20" 13-3/8" 9-5/8" FDC/CNL/GR/CAL, DLL, RFT IWEIGHT, LB/FT. I GRADE / DEPTH SET (MD) 94# Welded H-40 [74' below GL 72# Butt N-80 / 2709' 47# Butt I N-Rnl I LINER RECORD AMOUNT PULLED CASING RECORD (Report all strings set in well) HOLE SIZE I CEMENTING RECORD 20" I 277 sx Arcticset cmt 17-1/2" 14800 sx Arctic_set II cmt 17-1/4" 17nn~y Clag¢ G nmt -' I 27. TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) 7" 7621' 26. SIZE TOP (MD) PACKER SET (MD) 7" 7725' BOTTOM (MD) SACKS CEMENT* 8949' 325 sx 28. PERFORATIONS OPEN TO PROD!JCTION (Interval, size and number) :8852'-8862' ~8665'-8705' =-8448'-8488 .8805'-8815' 8650'-8610" , 8410~-8430 8784'-8804' ;8594'-8564' :8759'-87791 ~,!8536'-85561 ~ _~.~ / :8730'-8750' F 8496'-8506' 7606' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) ]AMOUNTAND KIND OF MATERIAL USED N/A I i,~,., ' ' "" 30. PRODUCTION /i'- DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping~ize and type of pumP) . I WELL STATUS (Producing or I , [ shut-in) N/A /,. , . PR ESS. 24-HOUR RATE 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ITEST WITNESSED BY 32. LIST OF ATTACHMENTS Perforating History 33. I hereby certify that the foregoing.~nd attached information is coCplete and correct as determined from all available records, SIGNED, . _ - TITLE District Drilling Engineer *(See instructions and Spaces for Additional Data on Reverse Side) DATE 3/14/80 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: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME MEAS. DEPTH TRUE vERT. DEPTI None Top Sadlerochit 8405' 8118' Base Sadlerochit 8864' 8542' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LI'THOLOGY,'POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. _ , , Sent under separate cover letter by Geological Department dated 8/2/79. , Perforating Hi story NGI #13 (24-1-11-14) API 50-029-20347, ADL 28302, Permit No. 78-91 Began perf operations @ 0600 hrs 1/26/80. Installed & tstd BOP's. Perf'd intervals from 8852'-8862', 8805'-8815', 8784'-8804', 8759'-8779'., 8730'-8750', 8685'T8705', 8665'-8685', 8640'-~_~Q'~, 8620'-8640.', ~.~61~0'-8620', 8584'-~8~9~='., ]t5~'-8584 , 8.536'- 8556' 8496'-8506' 8468'-8488' ..844.~8'-8468' and 8410'-8430' Ran HP press bomb Installed & tstd tree cap to 5000 psi. Released well @ 2400 hrs 2/11/80. ARCO Oil and Gas Company ,,?.~lchr.',~;~51:. Al~',5;k,q 99510 '-i'cl(i)l~'.:)n~: !)07 277 February 11, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 3-15, Permit No. 79-92 DS 12-7, Permit No. 79-86 · - , Permit No. 78-67 lPermit No 78-91 A, Permit No. 79-81 I COMM I-i~s INa .... I 4 ~N~ I 3 O~OL ~1 STAT 7} cO~FER: FILF: ,, Dear Sir' Enclosed please find Monthly Reports outlining work done on the above-mentioned wells. .~/~. ~Very trul~ P. A. VanDusen District Drilling Engineer PAY'cs Enclosures ARCO Oil and Gms Company is a Division of AllnnticP, ichfi~ IdCn;~;p,'~ny Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20347 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME O,L [] GAS [] Gas Injection WELL WELL OTttER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360 Anchorage, Alaska 99510 NGI #13 4. LOCATION OF WELL 489'N & 840'E of SW cc Sec 1, TllN, RI4E, UM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 78-91 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for January, 1980 Began perf operations @ 0600 hrs 1/26/80. Pulled SSSV. Perf'd intervals 8852'-8862' & 8805'-8815' w/4 shots per ft. Made up gun #2. Suspended operations due to bad weather. As of 1/31/80, operations suspended, waiting on weather. 14. , hereby ~..~ th.e_f~or~ing isM and correct SIGNED ~ ./~/.. l~q~rt~~.~l.~}_ ~ TITLE District Drlg. Engineer DATE 2/7/80 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ARCO Oil and Gas '~'"~pany North Alaska ,strict Post Office Bo× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 19, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservati on Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 Subject:~Permit No. -'1~4, Permit No 78-91 78-92 Dear Mr. Hamilton' Enclosed please find a Sundry Notice outlining our plans for each of the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'jh Enclosures ARCO Oil ~nd Gas Comp-~ny is a Division of AllanticRichlieldCompany ,~,~- o rm~ 10-403 ~REV. 1-]~ 0-73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) " °w~LLLF-IWELLGAS r-~ OTHER Gas Injection 2. NAME OF OPERATOR ARCO Oil and Gas Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL At surface 489'N & 840'E of SW cr Sec l, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 51' RKB, 18' Pad Elevation (Gravel) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20347 6. LEASE DESIGNATION AND SERIAL NO, ADL 283O2 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #1 3 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi eld-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 1, TllN, R14E, UM 12. PERMIT NO. 78-91 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT .SHOOT REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE., Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent al®tails, and give pertinent dates, Including estimated date of starting any proposed work. ARCO 0il and Gas Company proposes to perforate selected intervals in the Sadlerochit between 8410' and 8862'MD. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The well will be flowed to the flare pit for clean up and liquids will be burned in accordance with the Department of Environmental Conservation Burn Permit. The downhole safety valve will be installed and tested upon conclusion of the job. Estimated start is December 15, 1979. 16. I hereby certify that the foregoing is true and correct TITLE District Drillinq En_qineerDATE_ 1]./19/7Q (T his space for State..~.. ~e).. A~y,,~ See Instructions On Reverse Side COMMISSIONER DATE F~etur.cd 1'4~rth Ala:.;k:~ Dislric! Post O!''''~, ~.,x 330 Tclephon:~ 2,)7 277 5637 August 30, 1979 Reference' " Enclosed are Cased H°le Logs for ARCO wells' D.S. 1-6 D.S. 2-7 D.S. 1-9 D,S. 9-20 D.S. 13-1 D.S. ]_3-2 D.S. ·14-4 D.S. 5-16 7-9-79 Spinner 5-20-79 Spinner 6- 3- 79 Spinner 6-17 -79 Spinner 8- 5- 79 Spinner 8-2-79 Spinner 8-1-79 Spinner 6-16-79 Spinner Flo~neter 6-28-79 Spi~mer Flo~neter .7- 7- 79 Compensated Neutron GR - o · Please sign and return the attached cop>' as receipt of data. Very t~uly yours, K. J. Sahlstrom North Engineering TP~NSMIT17U, it, 302 DISTRIBlfI'ION North Geology lixxon Dri 11 ing Mol) i 1 Eng. b!anager Cetty R & D SohJo Ceo] ogy Ma-rat]~c)~ State of Alaska l~hillips D & M Chevro:t Anchorag~.,Ala~ka g9'5i0 Tclep;;,~e 907 277 503'? August 28, 1979 Reference: F~closed are Magnetic Directional Su'~A~eys o~[ the following ARCO wells' ~','G;~I 7/31/79 Multi-Shot D.S. 3-10 8/19/79 Multi-Sl~ot '~LT~ 6/7/79 Single-Shot WQ.I--1 · 7/9/79 Single-Shot ~lease sign and return the attached copy as rcceSpt of data. Ve~T t~!y yours, R. A. Bellinger -North Engineering TPekNS31ITI'AL ~ 29.~ gJ. 5'l'l( ]h'J llJ. ng blob5 ]. Geology ~.!:~ ~'~ t}~o~ North AlaskaD,~,rl~.t' ;-" '" Post Ofiice.~ox 350 Anchoras~ taska 99510 Telephone 997 277 5635 August 9, 1979 Reference: Enclosed are Cased Hole Logs of the following J~(CO wells' p.S..5:14 6/9/79 Spinner Survey Run 1 S" ~~' 7/31/79 t-~/dro Log ~tn 1 5" q~:S. 9-20 6/24/79 Continuous Flo~ Su~wey 5" Run 1 ~~.6 6/23/79 Continuous Flow Su~ey 5'.' ~n 1 6/ 0/7 cm z"6 Please sign~r8 return the attached copy as receipt of data. ~ Very truly )'ours, R. A. Bellinger North Engineering TRANS~II%fAL # 259 DISTRIBt~ION North Geology Drilling Ih~g. Manager Geology State of Alaska Mobil Getty Sohio Marathon Phillips Chevron North Alaska District Post Offic, ,.x 3G0 Anchora§e, Ataska 99510 Telephone 907 277 5637 August 9, 1979 Reference: Enclosed are Open-Hole Logs for the following ARCO ~ 6/5o/79 ~ 7/1/79 NC~-ZS, 6/5o/79 · Na~-ZS 6/5o/79 NGI-I3 6/30/79 NG~-13 .6/50/79 NG~-15 6/30/79 ~.s. 12-1 6/17/79 D.S. 12-1 6/27/79 D.S. 12-1 6/27/79 D.S. ~2-1 6/27/79 p.s. 12-1 6/27/79 NGI-14 5/31/79 NGZ-14 5/51/79 D.S. 14-3 11/21/78 BHCS 2" & 5" Run 1 CPL 5" " FDC 5" " DL 2"& 5" " DIL 2" & 5" " CNL/FDC 5" " CNL/FDC 5" " CPL 5" " BHCS 2" & 5" " DIL 2" ~ ~ ~1 ,, FDC 5" " DIL 2'~ " BHCS 2" " BHCS 2" " ; Please,~d/gn and return the attached copy as receipt of data.. ~/ Very truly yours, ~ R, A. Bellinger North Engineering TRANSMITTAL # 257 DISTRIBb]'ION North Geology Drilling Eng. Manager R & D Geology State of Alaska F~xon Mobil Getty Sohio Marathon ~zillips Chevron North Am~~''' ~n Produciag Divis$on r.lorth Alask.. District Post Office Box 360 Anchorage, Alaska ¢J9510 Telephone 907 277..o3t August 3, 1979 Reference' COMM . [ COMM COMM . RES ENG 1 ENG 2 ENG 3 ENG 4 ENG I 3 GEOL I S'FAT TE(E-'- _ I STAT ,- -- T,_C CONFER: FI[.F: Enclosed are Magnetic Tapes for the following ARCO wells' l7/21/79 CNL/CCL/GR 7/21/79 CNL/CCL/GR Please sign~return the attached copy as receipt of data. Very truly yours, R, A. Bellinger North Engineering TRANSMITTAL # 251 DISTRIBUI'ION North Geolog~ Drilling Eng. Manager R & D Geology State of Alaska 1] ~ M Mobil Getty Sohio Marathon t 11111 zps ARCO Oil and Gar .... 3mpany North Alask,.. ~Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 2, 1979 Mr. Hoyl e Hamilton State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Core Summary, NGI #13 Dear Mr. Hamilton: Enclosed please find the Core Summary for NGI #13, submitted as Item No. 36 on Form P-7 for the above well. Very truly yours, Sr. Geological Associate RWC:kdm Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany NORTH GAS INJECTION #13 ARCo Sec. l, TllN, R14E, UM Core No. . Depths Recovered Lithol ogy 1 8255' - 8276' 4', 19% Shale 2 8276' - 8284' 2.2', 28% Conglomerate 3 8284' - 8311' 0', 0% -- 4 8311' - 8318' 3', 43% Conglomerate Anchor~:.qa., Alaskn ~JO3'lO August 1, 1979 Re£erence: i~cIosed are Magnetic Tapes for the following MICO wells' 5.:;450 554 Sa #.5.,63~ Run 1 Please sign and return the attac}~ed copy as 'r'ece:i.l'.rc o,r' data. Very truly yours, :? . ,n . 9 ' R. A. Bellin~cz North En~inee-rinq T}L&NS~IITTAL # 245 I)1 S'I I.,.] I,LFi ] ON North Ccoloo) I)ri 1 ].inp, ]2~g. ,X!anagcr Goo] o2Y State o£ Alasta ]!xxorl Cett'y So]~io Chevron ARCO Oil and Gas Company Alaska Dislrict Post Of~'''', Box 360 Telephone 907 277 5637 SAMPLE TRANSMITTAL SHIPPED TO' State of Alaska Division Of Oil &.Gas conservation 3001Porbupine Dr. Anchorage, Ak. 99501 Attn: Wm. VanAl~en DATE' July 18 1979 OPERATOR- ARCo SAbIPLE TYPE: core chips · S/k~[P LES SENT: 8255 8256 8257 8258 8276 8277 8311 8312 8313 NAME: North Ga.s Inj. #13 NUMBER OF BOXES' one UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND MAlL A SIGNED COPY OF THIS FORbI TO' ARCO OIL & GAS CO. P. O. BOX 360 ANCHORAGE, ALASKA 99510 ATTN' DICK BROOKS' / DATE ARCO Oil and Gas Company Is a Division of AtlanticRichlieldCompany ARCO Oil and ~.s Company Post C, ff~cc- ~ox 360 Anchora~3e, Alaska 99510 'Teleuhone 90'7 277 5637 July. 27, 1979 Mr. Hoyle H. Hamilton State of Alaska · Alaska Oil & Gas Conservation Commission 3001 pOrcupine Drive Anchorage, AK 99501 I cot~ ~ ~N~ ~lq"OEO~ STAT ~STAT I '~FER: FILF: Subj-ect :~ermit 'No. 79-23 ~_!.~3~_.~ermit No 78-91 Dear Sir' Enclosed is a Completion Report along with the Drilling History and Gyroscopic Survey for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilli. ng Engineer PAY'cs Attachments AF~CO Oil and Gas Company is a Division of AllanticRichfieldCompany Form SUBMIT IN DUi-L ,TE* STATE OF ALASKA (see other in- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OIL GAS I--1 _ WELLr--] WELLI I DRYE~ Other Gas In.iection b. TYPE OF COMPLETION: NEW WORK r-~ DEEP- PLUG r--1 DIFF. WELL [l~q OVER I I EN E~ BACKI I RESER. r~ Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 489'N & 840'E of SW cr Sec l, TllN, R14E, UM At top prod. interval reported below 314'N & 2539'W of SW cr Sec l, TllN, R14E, UM . At total depth 282'N & 2533'W of SE cr Sec l, TllN, R14E, UM 5. APl NUMERICAL CODE 50-029-20347 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WE.LLaNO,-_, ~.._.~NG I #13 :(24-1-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi eld Dy,, ,~-I k~,-, fl41 · ~.4 ~! E OBJECTIVE) Sec 1, TllN, R14E, UM 2. PERMIT NO. 78-91 13. DATE SPUDDED /14. DATE T.D. REACHED [15. DATE COMP, SUSP, OR ABAND. 7/8/79 Ir6' ELEVATIONS (DF' RKB' RT' GR' ETC)* ]17' ELEv' CASINGHEAD ii-, 6/9/79 ] 7/2/79 [ 48;' RKg :~ I~'i TOTAL DEPTH MD&TVD ]19. PLUGBACK MD&TVDI20 IF MULTIPLE COMPL | INTERVALS DHILLED BY ' | DEPTH ! ' HOW MANY* " 121. ROTARY TOOLS CABLE TOOLS 8950'MD 8620'TVD B907'MD 8581'TVD | Sinole I All 22. PRODUCING INTERVAL(S}, OF THIS COMPLETION --TOP, BOTTOM, NAME (M~D & TVD}* 23. WAS DIRECTIONAL Top Sadlerochit 8405'MD 8118'TVD SURVEYMADE Base Sadlerochit 8864 'MD 8542'TVD Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/CAL/GR, FDC/CNL/GR/CAL, DLL, RFT 25, CASING SIZE 20" 13-3/8" 9-5/8" AMOUNT PULLED IWEIGHT, LB/FT. ] GRADE ] DEPTH SET(MD) ] 94# Welded IH-40 174' below Gq 72# Butt IN-80 ] 2709' / LINER RECORD TOP (MD) BOTTOM (MD) ISACKS CEMENT* 7725' I SIZE PACKER SET (MD) 11 CASING RECORD (Report all strings set in well) HOLE SIZE I CEMENTING RECORD 20" 1277 sx Arcticset cmt 17-1/2" [4800 sx Arcticset II cmt 12-1/4" 1700 sx Class G cmt I 27. TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) 7" 7671' 28. PERFORATIONS OPEN TO PRODUCTION N/A · 8949' 325 sx I (Interval, size and number) 76D6' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 30. PRODUCTION DATE FIRST PRODUCTION DATE OF TEST. HOURS TESTED CHOKE SIZE FLOW TUBING CASING PRESSURE CALCULATED PRESS. 24-HOUR RATE PRODUCTION METHOD (Flowing, gas lift, pumping-size and type of pump) IWELL STATUS (Producing or I shut-In) OIL-BBL. GAS--MCF. WATER-BBL. IOIL GI~'AVITY-API (CORR.) I 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ITEST WITNESSED BY 32. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey 33. I hereby certify that.~'~ foregoir)~ and attached information is co~nplete and correct as determined from all available records: ~.-Z~-7/~"~J',~"~ '~ T,TLE District Drilling Enoineer SIGNED *(See instructions and Spaces for Additional Data on Reverse Side) DATE 7/30/79 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: 16' 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD ,,, NAME None iV1EAS. DEPTH TRUE VERT. Di~PTt Top Sadlerochil 8405' 8118' Base Sadl erochi 8864' 8542' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. t4ill be sent under separate cover letter by Geological Department. ! NGI #13 Drilling History API 50-029-20347, ADL 28302, Permit No. 78-91 Spudded well @ 0400 hrs 6/9/79. D_~]c_ld 17½" hole to_2Y_33.'. Ran 13-3/8" csg to 2709'. Cmtd w/4800 sx Arcticset II cmt. Did 60 sx top job. Installed & tstd pkoff Drld shoe & 10' new hole. Tstd formation to 12.5 ppg equiv MW. Dr___l.~ 12-1/4" hole to~_.~' Ran multishot. Undercut & sidetracked @ 4155' to avoid NGI #5. D~r!d t~._~t040'. Ran 9-5/8" csg w/shoe @ 8015'. Cmtd w/700 sx Class G cmt. Dwnsqz thru lower FO w/300 sx Arcticset I cmt. Did Arctic Pack job thru upper FO. Drld shoe & 10' new hole. Tstd formation to 12.5 ppg equiv MW. ~r_!d 8½" hole to $.2._55~'. Ran GR log. Drld to _8276~. PU core bbl. Core #1, 8255-8277', rec 4'; core #2, 8276-8284', rec 2.2'; core #3, 8284-8311', rec O; core #4, 8311'8318', rec 3'. LD core bbl. D~l~c[~" hole to 8950'. Ran DIL/SP, BHCS/CAL/GR, FDC/CNL/GR/CAL & DLL logs. Ran'RFT. RU & ran~7'' lnr w/btm @ 8949' & top @ 7725' Cmtd w/325 sx Class G cmt. CO cmt to top of lnr. Tstd lnr lap. Displ mud w/~tr & wtr w/CaC12. Ran gauge ring & junk bskt. RU & ran 7" tub compl assy w/shear sub @ 7621', pkr @ 7606'. NU & tstd tree. Pulled dummy valve. Displ CaC12 w/diesel. Set pkr. Ran CNL/GR/CCL. Ran & tstd SSSV. RU for long term tbg tst. Released riq @ 0600 hrs 7/8/79. Eastman ~ ~ipstock A FETROLANE COMPANY REPORT of SUB-SURFaCE D IREC TI ON.4 L SURVEY ARCO OIL AND GAS COMPANY WELL NAME PRUDHOE BAY, ALASKA LOCATION JOB NUMBER A679 D0328 TYPE OF SURVEY MAGNETIC SINGLE SHOT DATE 6-7-79 SURVEY BY Steve Ratc!iff OFFICE · MAGNETIC SINGLE-SHOT SURVEY RADIUS OF' CURVATURE NETHOD OF COMPUTATION COMPUTED FOR EASTMAN BY F tvl LINDSEY & A, K B ELEV 48 FT DECLiNATiON 3]. DEG EAST ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER iTAL.'COORDtNA 0 $...U R DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE D M DEG, D M $ SEVERITY 5~C~T._I ON': DEG/].OOFT DISTANCE ~;"o0 ::N' 0'oo o,'00" : 0 ,o 0;" 879 0 45 878,99 830,99 520.00W 0,15 N 0,87 W 0,89 N 79 59 59 W 0.389 1235 0 15 1234,97 1186,97 N46.00E 1,07 5 1,01 E 1.47 5 43 20 20 E 0.140 1509 0 15 1508,97 1460,97 530,00E 1,2L 5 2,03 E 2,37 5 59 l~. 9 E 0.144 i:1206i 0 45 Z060.95 ~2012,95 .$75,00E 7'08 5 75 E 0.076 ; 2337 0 30 '2336,93 2288,93' 579,00E 2,49 ].0,09 5 75 40 43 E 0,091 2646 0 30 2645,92 2597.92 573.00E 2900 3 0 2899,78 2851.78 574,00E 3081 7 45 3079.93 3031,93 586.00E 3,14 5 12,39 E 12.78 S 75 44 46 E 0,017 5,35 S 19.83 E 20,54 S 74 53 54 E 0.984 __8.28 S 36.49 E 37.42 5 77 1~ 8 E 2.6.~7 3189 8 0 3186,91 3138,91 N86,00E 3342 11 15 3337,74 3289,74 N88,00E 3500 15 45 3491,34 3443~34 588,00E 3784 21 0 3760,76 3712,76 584.00E 4126 26 30 4073.68 4025,68 S83.00E 8,28 5 51,27 E 51,94 5 80 49 1 E 6,95 5 76,82 E 77,13 5 84 ½9 4.7 E 6,99 $ !13,68 ~ 113,90 _5 86 30 4 E 13,19 5 202.94 E 203,37 5 86 16 50 E 28.?7 S 339.74 E 340.96 $ 85 9 29 E 0.272 2,125 _2.._.8_~ .,, 1,857 1.609 -0,89 1,14 2,1d ].0~02 12.69 20,36 51,92 77,07 202,93 3~0,60 37,40 5 409.96 E, 4434 17 30 4358.87 4310,87 583.00E ~576 17 0 4494.48 4446,48 583,00E 4888 18 0 4792,04 4744,04 584,00E 42,85 5 454,35 E 47,98 5 496,15 E 58,60 5 589,36 E 456.37 S 84 36 44 E 498,46 $ 84 28 33 E 592.27 S 84 19 !7.~ .. 5258 19 30 5142,39 5094,39 582.00E 73.09 S 707,40 E 86.49 S 824,99 E 99,94 S '952,95 E 711.17 S 84 6 1 E 829,51 5 84 0 53 E 2,985 456.06 0,352 498,17 0,3~2__ ~91,97 0,410 710.89 0,453 829,23 0,1~0 957,84 6244 20 30 6063,91 6015,91 582,00E 113,46 S 1055,63 E 1061.71 5 83 51 55 E 0,349 1061,41 AR¢O:o/G NG!-13 ".' MAGNETIC SINGLE,-sHoT SUR~EY -:'- ......................................... :'"'i,',5 AUG 79 =---"~: ~' 'i' ' ' , .. · ,.. ,,... · v:. .' .' .... · ,: ,... . r , ,.. r '~ RECORD OF SURVEY ~ / ALL CALCULATIONS PERFORMED BY I B M ELECTRONI'C COMPUTER TRUE MEAS. DRIFT VERTICAL ,SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC _ D _M , D £G_~.. TOTAL COORDINATES C L O 5 U R E 5 SECTION DISTANCE ANGLE. DISTANCE D M__~ SEVERITY DEG/IOOFT 67!~ !9.' 30 6505,56 6457,§6 ~83,00E 3 k222,41 5 83 41... 8 E 0,214 1222,16 71S9 17 0 $928.14 6880'!4. 58.~00E 15 E 136~'73 5 83_ ~3'~".~ _~ 7407 16 0 7165.93 7117.93 $79.00E 164,25 5 1422.61E 1432,06 5 83 24 49 E 0.414 1431,88 7695 15 0 7443.45 7395.45 576,00E 180.91 S 1497,74 E 1508,63 S 83 6 45 E 0.354 1508,54 7~65 1~ 0 7705.42 7657.42 ~7~..OOE 197,26 5 1..5b0,~8 E ..157~__5__~Z.~7 5! E 8200-.14 0 7933,92 7885.9~ $7~.00E. 21!,92. ~ !6!3~84 E 1627.69 5 82 3~ 8 E 0.426 1627.69 BOTTOM HOLE CLOSURE ,].627,69 FEET.AT 5 82 31 8.E ~RCO DIG NGI-13 MAGNETIC $!NGLE~SHOT 'SURVEY AUG 79 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH.__ MEASURED DEPTH T R.U_E . VERTICAL SUB -MD'~TVD -~ DEPTH SEA:;.'DIFF£RENCE ': CORRECT!O~ TOTAL COORDINATE~ 148 2~, 8 448 648 748 848 948 1248 1348 148, 4~ 648. 748. 848. 948. 100 0 600 0 700 0 800 o 0 0 0 0.00 S 0.00 0 0 .0,005 0,00 O;oo s O,O.O...w 0,005 O,QOW 0.00 5 0,00 0.11 N 0.05 0,67 $ .0 1248, 1200 0 0 1,03 5 1348. 1300 0 0 0.88 5 1448 1448. 1400 0 0 .......... ~_0! S 15~S i :. .... ':' ': 60.. :1.. '. 36., ~, ].748 1.05 E 1.45 E ..... L~6 .E 1848 1848, 1800 0 0 1948 1948, 1900 0 0 2048 2048. 2000 0 0 2148 2248 2348 2448 2548 2748 2848 2948 3049 3150 3251 3352 3455 3559 2148, 2100 0 0 2248, 2200 0 0 2348, g300 ___~ 0 2448, 2400 0 0 2548. 2500 0 0 2748, 2700 0 0 28~8, 2800 0 0 2948, 2900 0 0 3048, 3000 0 0 3148, 3100 1 1 3248, 3200 2 1 3345, 3300 4 2 3448, 3400 7 3 3548. 3500 11 4 1,60 5 4.38 E 1.61 5 5.47 E LL78 $ ~60.E_ 2,08 S 7,89 E 2'33 $ 8'95 E 2~15 9.,87 g 2,69 5 10.72 E 2.91 5 11,57 E 3,66 5 1~,10 E 4,65 5 17.4~ E 6,10 5 22~77 E 7,81 $ 32.42 E 8.52 5 45,84 E 6.88 5 78,79 E 6,70 S 101,97 E 7.65 S 1~0.23 . ARCO O/G NGI-13 · MAGNETIC SINGLE-,SHOT SURVEY ';!5 AUG '79 MEASURED D.E_P_~H_~AND OTHER:DATA FOR EVERY EVEN iOQiFEET OF SUB :SEA TRUE MEASURED VERT MD~TVD VERTICAL. DEP TH DEPTHi SEA:DIFFERENCE CORRECTION ; TOTAL.' COORDINATES E . 3664 3878 3987 4097 3648, 3600 16 5 3948, 3900 39 404~,,~ 4000 4208 4148, 4100 60 4316 4248, 4200 68 44~3 4348, ..4300 75 4527 4448, 4400 79 4632 !0 83 4 )0 88 4842 4748, 4700 93 4947 4848, 4800 98 9 11 8 7 9,63 5 162,33 E 16,91 5 237,57 E 21,76 5 280,,58 E 33,06 $ 374,65 E 38,10 5 415,72 E 4 ZL4Z__.~ .........._4..~ O__,._tZ_.E ..................................................... 46,22 S 481,8& E 49,96 $ 512,48 E 57,09 $ 57,5,20 E ~0.57 ,5 607,61 E 5052 4948. 4900 104 _ 5158 5048, 5000 109 5264 5148, 5!00 115 5~70 5248,__5200 122 5477 5348, 5300 128 5584 5448, 5400 135 5691 5548, 5500 142 5798 5648, 5600 150 5905 5748, 5700 157 6013 5848.58__~ 1~ 6120 5948, 5900 172 6227 6048, 6000 179 68,66 S 674,65 E 73,37 5 709,36 E 78,04 $ 744,91 E 82,26 S 781,66 E 85,97 $ 819,18 E 89,48 5 857,50 E 93,41 ,5 896,06 97,7~ $ 934,78 107,51 5 1012,20 112,63 ,5 1049,72 b334 6440 6547 6759 6865 6970 61~8~~ .... 186 6248, 6200 192 6348, 6300 199 644B,_ ,6400 __ZQ~ 6548, 6500 211 6648, 6600 217 6748, ~700 ~ 6848, 6800 227 6948. 6900 232 7048, 7000 ~36 7075 7180 7284 122,68 S 112~,06 E 127,41S 1159,09 E 136,27 5 1229,81 E 140,59 S 1263,87 149,19 5 132~,53 153,48 $ 1359,14 !58~11 $ !!88.7~ ARCO O/G N61-13 MA6NETIC $IN3LE-$HOT SURVEY ~~ ~E~PTH__._.A~D___Q~R DATA FO.R..E_V_ERY EV_E.E._N___,],_O_Q__F__F~T OF ,51JL6EA DEPTHi · ·MEASURED DEPTH · DEPTH SEA DIFFERENCE :coRRE'¢TION : ' TOTAl.' COORDiNATEs:I::I 7388 7148, 7100 240 .... 7__492_ 72.~..B_. ...... 7200 .... :: 7~oo.: 17~.s6 s 7700 5 7906 7648, 7600 258 3 193.79 $ 1547.95 8009 7748. 7700 260 2 199.84 ,: ~:::':. . : : : :: ARCO O/G NG['13· · 79 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE 1000 ' 999, 951, 1,19 S 0,73 W 2000 1999, 1951, 1,67 S 6,08 E 6000~ ..; ;10~ .; ~ 7000 6776, 6728, 146.12 5 1305,93 E 8000 7739, 7691, 199,32 5 1568e62 E HORIZONTAL_ VIEW ARCO OIL 8~ GAS N.G.I. RADIUS OF CURVATURE MAGNETIC. SINGLE-SHOT SCALE I"= !000I AUG. 16~ 1979 CLOSURE S~ TVD= 7934' ~ ;51 E 1828~ TMD= 8200' ALL. DEPTHS SHOWN1 ARE TVD 800- 2BO0 - ~200 VERTICAL SECTION ARCO OIL 81 GAS N.G.i. I:~ RADIUS OF CURVATURE MAGNETIC SINGLE-SHOT SCALE i"= I000! AUG. 16~ 1979 52oo ALL DEPTHS SHOWN ARE TVO. 68oo 7200, 760o TVD = 7934' TMD = 8?_00' SCIENTIFIC DRILLING CONTI~OLS 700 WEST 41st STREET MAGNETIC DIRECTIONAL SURVEY FOR' ****************** * ARCO OIL & GAS * ****************** JOB NUMBER: 11-50-~,IMS-125 WELL NAME: NGI 13 .. LOCATION: PRUD[IOE BAY SURVEY DAYE: 6-21-79 SURVEY ENGINEER: BILL ROCHIN MAGN"STI C DECLINATION: 31.00E MET~tOD OF CALCULATION: RADIUS OF CURVATURE ***DEPTH MEASURED IN FEET*** COMMENTS: *THIS SURVEY IS CORRECT TO THE * *BEST OF MY KNOWLEDGE AND IS * *SUPPORTED BY ACTUAL FIELD DATA.* * CO£qPANY REPRESENTATIVE * COHPLETION REPORT ARCO OIL & GAS MAGNETIC MULTI-SHOT SURVEY RADIUS OF CURVATURE METHOD OF COHPUTATIONS COI'.IPUTED FOR SDC BY F .M LINDSEY & ASSOCIATES 23 JULY 79 WELL NGI-13 K 6 ELEV 48 FT DECLINATION 31 DEG EAST RECORD OF sURvEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 0,00 -~8,00 N O,OOE 2700 0 0 2700,00 26~2,00 N O,OOE 2870 2 30 2869,94 2821,94 566.00E '29~4 4 0 2963.79 2915,79 S86.00E 305>~,, ? 0 30fiG,3fi 3008,35 S81,OOE 3149 ~ 8 30 3147.51 3099.51 3242 8 30 3239.48 3191.48 N84.00E 3335 11 0 3331,13 3283,13 N83.00E 3427 13 45 3420.99 3372.99 NN7,00E 3520 16 0 3510.86 3462.86 N89.00E 3613 19 30 3599,42 3551,42 N90,OOE 3707 20 30 3687,75 3639~75 589,00E 3799 21 0 3773.79 3725.79 587.00~ 3891 21 45 38.59.46 3811.46 S86.00E 3984 23 0 3945.45 3897.45 S85.00E 4075 25 15 4028.50 39~0.50 S65.00E 4168 27 0 4112.00 4064.00 SSG.00E 4259 23 15 4194.37 4146.37 4353 21 0 4281.44 4233.44 S85.00E 4445 17 30 4368.29 4320.29 4539 17 30 4457.94 4409.94 S86.00E 4631 17 45 4545.62 4497.62 S88.00E 4724 18 0 4634.13 45~6.13 S85.00E 4~17 1~ 0 4722.58 4674.58 S~4.00E 4910 18 45 4810.83 4762,83 TOTAL COORDINATES 0,00 S 0,00 0,00 S 0,00 1.70 N 2.62 0.41N 7,76 0.58 S 16.61 1.23 S 28.98 0.15 S 42,68 1.62 N 58,33 3.34 N 77.96 4.17 N 101.82 4.42 N 130.17 4.14 N 162.32 3,00 N 194.8~ 0.95 N 228.36 1.81 S 263.65 5.06 S 300.70 8.27 S 341.52 11.64 5 380e00 15,03 S 415.24 17,67 $ 445.45 19.~9 S 473.63 21.35 S 501.45 23,09 S 529.94 25.84 S 558,54 28.91 S 587.70 CLOSURES STANCE ANGLE O M S 0,00 S 0 0 O W 0.00 S 0 0 0 W 3.12 iN 57 0 0 E 7.77 N 86 54 17 E lb.b2 S ~7 58 16 E 29.01 .5 87 3~ 24 E 42.68 5 89 47 14 ~ 58,35 N 88 24 17 E 78.04 N 87 32 43 E 101.91 N U7 39 6 E 130.24 N 88 3 14 ~ 162.37 N 88 32 17 E 194,91 N 89 7 0 E 228,36 N 89 45 ~4 ~ 263,66 S 89 36 16 E 300.74 S 89 2 8 E 34~,62 S ~8 36 43 E 380.18 S 8~ 14 43 E 415.51 S ~7 55 35 [ 445.~0 S ~7 43 39 E 474.05 S ~7 35 4,1 E 501,90 S 87 33 42 E 5~0.44 S ~7 30 1~ E 559.~4 S ~7 21 0 & 5~8.4~ S S7 11 0 E DOG LEG SEVERITY DEG/iOOFT 0.000 0.000 1.476 1.599 3.227 1.655 0.477 2.688 2.999 2.425 3.765 1.072 0.6~1 0,829 1.354 2.473 1.895 4.135 2.398 3.d04 0,320 0,339 0.409 0,332 o.ao6 SECTION DISTANCE 0.00 0.00 2.44 7.6~ 1~.59 28.96 4Z.49 57.89 77.26 100.92 129.10 161.12 193.65 227,15 262,55 299.74 ~40.68 ~79.30 414.70 445.03 473.29 501.11 529.04 5PU.B7 587.69 ARCO O/G NGl-13 MAGNETIC MULTI-SHOT SURVEY RECORD OF SURVEY ALL CALCULATIONS PERFORM£D BY I ~3 M ELECTRONIC COMPUTER 23 JULY 79 TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D H SUB DRIFT SEA DIREC DEG. 5002 19 0 4897,89 4849.89 S84.00E 5096 19 30 4986.63 4938,63 S83.00E 5188 20 0 5073.22 5025,22 S83,00E 5281 20 0 5160.61 5112,61 S83,00E 5372 21 0 5245.85 5197,85 SB3,0OE 5466 21 15 5333.53 5285,53 $83.00E 5558 22 0 5419,05 5371,05 $84.00E 5652 22 0 5506.21 5458.21 $84.00E 5745 22 15 5592,36 5544.36 S84,00E 5837 22 30 567'7.43 5629.43 $84.00E 5929 22 0 5762.58 5714,58 S85,00E 6021 21 30 5848.03 5800.03 S85,00E 6115 21 0 5935.64 5887.64 S85.00E 6207 21 0 6021.53 5973.53 S85.00E 6300 21 0 6108,35 6060,35 S84,00E 6393 20 30 6195.32 6147.32 S86,00E 6485 20 15 6281.56 6233.56 S85,00E 6578 20 0 6368.89 6320,89 S86,0OE 6668 19 30 6453,59 6405.59 SB5.00E 6760 19 0 6540.45 6492.45 $85,00E 6854 18 30 6629,46 6581.46 S85,00E 6946 18 0 6716.83 6668,83 S84.00E 7039 17 30 6805.40 6757.40 S85.0UE 7132 17 15 6894.16 6846.16 S83.00E 7225 17 0 6983.04 6935,04 SU2,00E 7319 16 45 7072,99 7024.99 $82.00E 7412 16 0 7162.22 7114.22 S82,00E 7505 15 15 7251,78 7203,78 S82.00E 7598 15 30 7341,45 7293.45 S80.OOE TOTAL COORDINATE$ 32.02 $ 617.30 E 35,53 S 648.09 E 39,32 $ 678.95 E 43,19 S 710.52 E 47,08 S 742.15 E 51.21 S 775.77 E 55,04 $ 809,46 E 5~.72 S 844,48 E 62.39 S 879.31 E 66,05 S 914~14 E 69.39 $ 948,82 E 72.36 S 982.78 E 75,33 S 1016,72 E 78,20 S 1049,56 E 81,39 S 1082,74 E 84.27 S 1115.56 E 86,78 $ 1147.49 E 89.29 S 1179,39 E 91,67 S 1209,71 E 94.32 $ 1239.93 E 96.95 S 1270,03 E 99.71S 1298.70 E 102,43 S 1326.93 E 105,33 S 1354,54 E 108,91 S 1381,69 E 112,71S 1~08,71E 116.35 S 1434,68 E 119.84 S 1459.~ E 123,70 S 1483,84 E C L 0 S U R E S DISTANCE ANGLE D M 618.13 $ 87 1 48 E 649.06 $ 86 51 42 6~0.08 711.83 $ 86 31 14 E 743.64 S 86 22 12 E 777,46 $ 86 13 23 E 811.33 S 86 6 34 E 846.52 S 86 1 18 E 881,53 S 85 56 29 E 916.53 S 85 52 2 951.35 S 85 49 2 E 985,44 S 85 47 20 E 1019.51S 85 45 45 E 1052,47 $ 85 44 19 E 1085.79 1118,74 S 85 40 48 1150,77 S 85 40 30 E 1182.77 S ~5 40 13 E 1213,18 $ 85 39 57 E 1243,51 S 85 38 59 E 1273,72 S 85 38 3 E 1302,53 1330,~7 S 85 35 8 E 1358,63 $ ~5 33 11E 13~5,98 S 1413,22 $ 1939,39 S ~5 21 g7 f 146g,gO 14~8.9~ S DOG LEG SEVERITY DEG/iOOFT 0.272 0,545 0,543 O,O00 1,099 0,266 0,~29 0,000 0.269 0,27Z 0,564 0,543 0.53Z 0.000 0.385 0.599 0,301 0,~97 0,569 0,543 0.532 0~553 O,D40 0.32~ 0,284 0,~66 0,806 0.806 0,310 SECTION OISTANC~ 617.45 648.44 679.52 711.32 743,18 777.05 ~10,95 ~46.16 881,18 916,21 9~5,13 1019.20 1052,16 10~b.49 1118.44 1150.46 1182,45 1212,~0 1293.19 1302,21 1330,56 135~,33 13S5,70 1412.97 1~39,16 i~64.19 l~dS,~l ARCO O/G t"lGI-13 F:A(-~NETIC FiULTI-SHOT SURVEY 23 JULY 79 RECORD OF SURVEY ALL CALCULATIONS PERFORF'IED BY I 1'~ ;,'1 ELECTRONIC CO;.iPUTER ,',lEAS, DRIFT DEPTH ANGLE D M 7692 15 0 7785 14 0 7678 14 0 7971 13 30 7986 13 45 TIE -IH WITH 8273 15 0 8368 16 15 8~62 18 ~5 8557 20 30 8652 22 15 ~746 24 0 8~41 26 0 8876 26 30 8950 26 30 [~OTTOM HOLE C TRUE VERTICAL SUB IbEPTH SEA DRIFT DIRLC DEG. 7432.14 7.384,14 7522.18 7474,18 7612.41 7564,41 7702.75 7654,75 7717.33 7669,33 S8(),OOE SS1,00E S78.0OE S75.00E S75,00E SPERRY-SUN i~;MS AT 827 3 MD TOTAL COuRDINATES 127.99 S 1508,19 E 131.83 S 1531.15 E 135.93 S 1553,27 E 141.09 S 1574.76 E 142.01 S 1578,17 E 7995,34 7947,34 577,0OE 159.24 S 8086.62 8038,82 S78.00E 164.78 S 8176.47 8128,47 SSO,OOE 170.18 S 8265.94 8217,94 SSI,OOE 175,44 S 8354,41 8306,41 S83.00E 180,26 S 8440,85 ~392.85 Sb6,00E 183,U0 S 8526,94 84'78.94 S89,00g 185.55 S 855U,33 ~510,33 S68,00E 185,95 S 8624,56 8576,56 S88,00E 187.11 S LOSURE 1900.33 FEET AT S 84 20 57 E 1647,31 E 1672,29 E 1700.03 E 1731.50 E 1765.78 E 1602,52 E 1842.63 E 1858,10 E 1891.10 E CLOSURES DISTANCE ANGLr D M 1513.61 S 85 8 56 E 1536.82 S 85 4 43 E 1559,21 S 84 59 54 E 1581,07 $ 84 52 ~7 E 1584.55 S 04 51 29 E 1654.99 S 84 28 41E 1680,59 S 84 22 20 k 1708,53 S S4 17 0 E 1740,36 S 84 12 51 E 1774.96 S 84 10 15 E 1811,87 S 84 10 39 E 1~51.95 S 84 14 5~ E 1U67,38 S 84 17 5 E 1900.33 S 84 20 57 E DOG LEG SEVERITY DFG/lOOFl' 0.532 1.077 0.780 0.566 1.b67 0,438 1,Di8 2.669 1.~47 1.S67 1.935 2.191 1.~38 O,CO0 SECTION DISTANCE 1513.46 1536,69 1559.11 1581,00 158q,49 1654,98 1680,39 1708,52 1740.36 1774,9b lb11,86 1851.94 1~67.3~ 1900.33 ~,RCO O/G NGI-!3 HAGNETIC MULTI-SHOT SURVEY qEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, JULY TRUE MEASURED VERTICAL SUB HD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 148 148. 100 0 0 248 248. 200 0 0 348 348. 300 0 0 448 448. 400 0 0 548 548, 500 0 0 648 648. 600 0 0 748 748 · 700 0 0 848 848. 800 0 0 948 948. 900 0 0 1048 1048. 1000 0 0 1148 1148, 1100 0 0 1248 1248, 1200 0 0 1348 1348. 1300 0 0 1448 1448, 1400 0 0 1548 1548. 1500 0 0 1648 1648, 1600 0 0 17~+8 1748, 1700 0 0 1848 1848, 1800 0 0 1948 1948, 1900 0 0 2048 2048, 2000 0 0 2148 2148. 2100 0 0 2248 2248. 2200 0 0 2348 2348. 2300 0 0 2448 2448. 2400 0 0 2548 2548. 2500 0 2648 2648, 2600 0 0 2748 2748, 2700 0 0 2848 2848. 2800 0 0 2948 2948, 2900 0 0 3049 3048, 3000 0 0 3149 3148. 3100 1 1 3251 3248. 3200 2 1 3352 3348. 3300 4 2 3455 3448, 3400 6 2 3559 3548. 3500 10 4 0,00 0,00 0.00 0,00 0,00 0,00 0.00 0,00 0.00 0,00 0,00 0,00 0.00 0,00 0,00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0,00 0,00 0,00 O,O0 0,28 1,60 0.55 0.44 1,23 0,02 2,00 ~,66 4,32 0.00 W 0.00 0,00 W 0.00 W 0,00 W 0,00 W 0.00 W 0.00 W 0.00 W 0,00 W 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W O,O0 W 0,00 W 0.00 W 0.00 W 0.00 0.00 W 0,00 W 0.00 0,00 W 0.00 W 0.08 E 1.88 E 6,69 f 15,62 28,98 E 43.96 E 61.63 E 84,74 E 112,98 E ARCO O/G NG[-13 NAGNETIC MULTI-SHOT SURVEY 23 JULY 79 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FL)I< GIVEN DEPTHS TRUE CODE ?,~EASURED VERTICAL TOTAL CUU?.DINATES C L ~) S U tx E NANF_ DEPTH DEP TH D I STANCE ANGLE D iq S Su~ SEA TOP SAD 8405 8122,25 166,93 S 1682,73 E BASE SAD 8864 8547.59 185,78 S 1852,77 E 1690.99 S d~ 20 4 E ~074,25 1862.06 S ~6 16 25 E 8499,59 ARCO 0/6 NGI-13 MAG~ETIC MULTI-SHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SU[3 ,SEA DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 23 JULY 79 3665 3648, 3600 16 6 4.33 N 147,63 E 3771 3748, 3700 23 ? 3.47 N 164,90 E 3879 3848. 3800 30 7 1,26 N 223,81 E 3987 3948, 3900 38 8 1,91 5 264.73 E 4097 4048, 4000 48 10 5,85 5 309.95 E 4208 4148, 4100 60 -, 12 9,64 5 359,16 E 4317 4248. 4200 69 9 13.84 S 402.17 E 4424 4348. 4300 76 7 17.10 $ 438,92 E 4529 4448. 4400 81 5 19,67 ~ 470,51E 4633 4548, 4500 85 4 21.37 5 502,06 E 4739 4648. 4600 91 6 23.49 S 534.49 4844 4748. 4700 95 4 26.71 5 566,81 E 4949 4848, 4800 101 6 30,22 5055 4948, 4900 107 5161 5048, 5000 113 6 38,20 $ 669,~1 5268 5148, 5100 120 7 42.63 $ 705,96 E 5374 5248, 5200 126 6 47,16 $ 742,96 E 5481 5348, 5300 133 7 51,86 $ 781.19 E 5589 5448, 5400 141 8 56,26 S 821,01 E 5697 5548, 5500 149 8 60,49 S 861,29 E 5805 5648, 5600 157 8 64.77 $ 901,99 E 5913 5748, 5700 165 8 68,85 $ 942,84 E 6021 5848, 5800 173 8 72.96 $ 982,76 E 6128 5948, 5900 180 7 75,7~ $ 1021.36 E 6235 6048. 6000 187 7 79,10 $ 1059,56 E 6342 6148, 6100 194 7 82,84 5 1097,64 E 6449 6248, 6200 201 7 85.73 5 1135,05 E 6556 6348, 6300 208 7 8~,74 5 1171,79 E 6662 6448. 6400 214 6 91,50 $ 1207,71E 6768 6548. 6500 220 6 94e54 6874 6648. 6600 226 6 97.50 $ 1276e18 E 6979 6748. 6700 231 5 100.74 $ 1308,72 E 7084 6848, 6800 236 5 103,71 5 1340,24 E 7188 6948. 6900 240 4 107,44 7293 7048. 7000 245 5 111.66 5 1401.25 E ARCO O/G '~iFASURED NGI-i3 I-IAG,".~ETIC I<ULTI-SHOT SURVEY DEPTH AND OTHER DATA FOR EVFkY EVEi~ 100 FEET OF SUB SEA DEPTH, 23 JULY 7~ ~EASURED DEPTH TRUE VERTICAL SUB MD-TVD VERTICAL DEPTH SEA DIFFLRENCE CORRECTION TOTAL COORDINATES 7397 7501 7605 7708 7812 7915 8018 8121 8224 8328 8432 ~538 8645 8754 8864 7148. 7100 249 4 7248. 7200 253 4 7348, 7300 257 4 7448, 7400 260 3 7548, 7500 264 4 7648, 7600 267 3 7748. 7700 269 2 7848. 7800 272 3 7948, 7900 276 4 8048, 8000 279 3 8148, UiO0 2~4 5 8248, 8200 289 5 8348, 8300 297 8 8448, 8400 305 8 8548, 8500 316 ll 115,78 S 119.69 S 124.01S 128,70 S 132,89 S 137.85 S 143.95 S 150.21S 156.37 $ 162,43 S 168,48 S 174.39 S 179.93 S 184.01S 185.78 S 1430,57 E 1458,44 E 1485,62 E 1512,24 E 1537,50 E 1561.86 E 1585.46 E 1609,81 1635.05 E 1661.42 E 1690.74 E 1724.94 E 1763,15 E 1805.71 E 1852,77 E ARC() O/G NGI-13 IqAGNETIC F1ULTI-SHOT SURVEY INTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH. TRUE MEASURED VERTICAL SUb DEPTH DEPTH SEA TOTAL COORDINATES 1000 1000. 952. 2000 2000. 1952' 3000 2999. 2951. 4000 3960, ~912, 5;000 4896. 4848. 6000 5828, 5780, 7000 6768. 6720. 8000 7790, 7682. 0.00 S 0,00 0,00 S 0.00 0.17 N 10,,63 2.36 ,5 269.9:~ 31.95 S 616.65 71.68 S 975,09 101,36 $ 1315,18 142,87 $ 1581.40 JULY 79 ARCO OIL 8~ GAS WELL NGI -13 -'- i- MAGNETIC MULTI-SHOT .................... RADIUS OF CURVATURE .................... ! :. SCALE I": 500' JULY 23, 1979 .- ALL DEPTHS SHOWN ARE TVD. .................................... o .......... ~' ' ' ~_ RCO._OIL.8~..GAS, ........ . _ ~" ' WELL NGI-I;5 ~: .... : _'_ ..... ,~ ..... .......... MAGNETIC MULTI-SHOT .... 400 .... i .............. ' ........... ' ............. RADIUS OF CURVATURE ' , ................. _ : ........... SCALE I"= I000' '._:-_::_' : ....... - . ...... 800 ............... JULY 23, ~979 ................ : .... · . 1200 1600 / ._ . , _ 2800 3200 38O0 ............ 4000 4, ALL DEPTHS SHOWN ............. ~ 7200 7600 8000 8400 . - SCIENTIFIC DRILLING CONTI~OLS 700 WEST 41st STREET MAGNETIC DIRECTIONAL SURVEY FOR * ARCO OIL & GAS * JOB NU£,~BE R: 11-50-~4~S-125 WELL NAME: NGI 13 t ,ATION: PRUDHOE BAY SURVE~ DA%~E: 6-21-79 SURVEY ENGINEER: BILL ROCHIN ~AGN~'i~i C DECL~[ NAZI' ION: 31.00E ~,4ET~OD OF CALCULATION: RADIUS OF CURVATURE ***DEPT}{ MEASURED IN FEET*** CO£4M EN'PS: ********************************* *THIS SURVEY IS CORRECT TO THE * *BEST OF MY KNOWLEDGE AND IS * *SUPPORTED BY ACTUAL FIELD DATA.* , ******************* , * COiqPANY R£PRF, SENTATI VE * ********************************* COMPLETION REPORT ARCO OIL G GAS MAGNETIC MULTI-SHOT SURVEY RADIUS OF CURVATURE HETHOD OF COHPUTATIONS COHPUTED FOR SDC BY F M LINDSEY & ASSOCIATES 23 JULY 79 WELL NGI-13 K B ELEV 48 FT DECLINATION 31 DEG EAST RECORD OF SURVEY ALL CALCULATIONS PERFORHED BY I B M ELECTRONIC COMPUTER TRUE ML $, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 0,00 -48,00 N O,OOE 2700 0 0 2700,00 2652,00 N O,OOE 2870 2 30 2869,94 2821,94 $66,00E 2964 4 0 2963,79 2915e79 $86,00E 3057 ? 0 3056,35 3008,35 581,00E 3149 8 30 3147,51 3099,51 N87,OOE 3242 8 30 3239,48 3191*48 N84,00E 3335 11 0 3331,13 3283,13 N83,OOE 3427 13 45 3420,99 3372,99 N87,OOE 3520 16 0 3510,86 3462,86 N89,OOE 3613 19 30 3599,42 3551,42 NgOeOOE 3707 20 30 3687,75 3639,75 S89,00E '-99 2I 0 3773,79 3725,79 $87,00E .~91 21 45 3859,46 3811,46 S86,OOE 3984 23 0 3945,45 3897,45 585,00E 4075 25 15 4028,50 3980,50 $85,00E 4168 27 0 4112,00 4064,00 $86,00E 4259 23 15 4194,37 4146,37 S84,00E 4353 21 0 4281,44 4233,44 S85,00E 4445 17 30 4368,29 4320,29 $85,00E 4539 17 30 4457,94 4409,94 $86,00E 463[ 17 45 4545,62 4497,62 588,00E 4?24 18 0 4634,13 4586,13 585,00E 4817 18 0 4722,58 4674,58 584,00E 4910 18 45 4810,83 4?62,83 584,00E TOTAL COORDINATES O,OO $ 0,00 W 0,00 S 0,00 W 1,?0 N 2,62 E 0,¢1 N 7,76 E 0,58 5 16,61E 1,23 S 28,98 E 0,15 5 42,68 E 1,62 N 58'33 E 3,34 N 77,96 E 4,17 N 101,82 E 4,42 N 130,17 E 4,14 N 162,32 E 3,00 N 194,89 E 0,95 N 228,36 E 1,81 $ 263,65 £ 5,06 5 300,70 E 8,2? 5 341,52 E 11,64 5 380,00 E 15,03 5 415,24 E 17,67 5 445,45 E 19,89 5 4?3,63 E 21,35 5 501,45 E 23,09 5 529,94 E 25,84 5 558,54 E 28,91 5 587,70 E CLOSURES DISTANCE ANGLE D M 5 0,00 5 0 0 0 W 0,00 S 0 0 0 W 3,12 N 57 0 0 E 7,77 N 86 54 17 E 16,62 $ 87 58 16 E 29,01 S 87 33 24 E 42,68 5 89 47 14 E 58,35 N 88 24 17 E 78,04 N 87 32 43 E 101,91N 87 39 6 E 130,24 N 88 3 14 E 162,37 N 88 32 17 E 194,91 N 89 ? 0 E 228,36 N 89 45 3~ E 263,66 5 89 36 16 E 300,74 5 89 2 8 E 341,62 5 88 36 43 E 380,18 5 88 14 43 E 415,51 5 87 55 35 E 445,80 5 87 ¢3 39 E 474,05 5 87 35 41E 501,90 5 87 33 42 E 530,44 5 87 30 16 E 559,14 S 87 21 O E 588,41 S 87 11 0 E DOG LEG SEVERITY DEG/IOOFT 0,000 0,000 1,476 1,599 3,227 1,655 0,477 2,688 2,999 2,425 3,765 1,072 0,611 0,829 1,354 2,473 1,89~ 4,135 2,398 3,804 0,320 0,339 0,409 0,332 0.806 SECTION DISTANCE 0,00 0,00 2,44 7,68 16,59 28,96 42,~9 57,89 77,26 100e92 129,10 161,12 193,6f 227,15 262,55 299e74 3½0,68 379,30 414,70 445,03 473,29 501,11 529,64 558,37 587e69 ARCO O/G NGI-13 MAGNETIC MULTI-SHOT SURVEY 23 JULY 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B N ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M 5UB DRIFT SEA DIREC DEG, 5nO2 19 0 4897,89 4849.89 584.00E L '6 19 30 4986.63 4938.63 583,00E 5188 20 0 5073,22 5025,22 $83,00E 5281 20 0 5160,61 5112,61 583,00E 5372 21 0 5245.85 5197.85 $83,00E 5466 21 15 5333,53 5285,53 583,00E 5558 22 0 5419,05 5371.05 584.00E 5652 22 0 5506,21 5458,21 584,00E 5745 22 15 5592,36 5544,36 584,00E 5837 22 30 5677,43 5629,43 $84,00E 5929 22 0 5762,58 5714,58 585,00E 6021 21 30 5848,03 5800,03 585,00E 6115 21 0 5935,64 5887,64 585,00E 620? 21 0 6021,53 59?3,53 585,00E 6300 21 0 6108,35 6060,35 S84,00E 6393 20 30 6195,32 6147,31 $86,00E 6485 20 15 6281,56 6233,56 585,00E f-78 20 0 6368,89 6320,89 586,00E c_o8 19 30 6453,59 6405,59 585,00E 6760 19 0 6540,45 6492,45 585,00E 6854 18 30 6629,46 6581e46 585,00E 6946 18 0 6716,83 6668,83 584,00E 7039 17 30 6805,40 6757,40 585,00E 7132 17 15 6894,16 6846,16 583,00E 7225 17 0 6983,04 6935,04 582,00E 7319 16 45 7072,99 7024,99 582,00E 7412 16 0 7162,22 7114,22 582,00E 7505 15 15 7251,78 7203,78 582,00E 7598 15 30 7341,45 7293,45 580,00E TOTAL COORDINATE5 32.02 5 617,30 E 35,53 5 648,09 E 39,32 $ 678,95 E 43,19 S 710,52 E 47,08 $ 742,15 E 51.21 S 775,77 E 55,04 5 809,46 E 58,72 $ 844,48 E 62,39 S 879,31 E 66,05 S 914,14 E 69.39 S 948,82 E 72,36 5 982,78 E 75.33 S 1016.72 E 78,20 5 1049.56 E 81,39 5 1082,74 E 84,27 5 1115,56 E 86,?8 S 1147,49 E 89,29 5 1179,39 E 91,67 5 1209,71 E 94,32 5 1239,93 E 96,95 5 1270,03 E 99.71 S ~298,70 E 102,43 5 1326,93 E 105.33 5 1354,54 E 106,91 5 1381,69 E 112,7! 5 1408,71 E 1~6.35 5 1434,68 E 119,84 5 1459,48 E 123,70 5 1483.84 E C L 0 S U R E 5 DISTANCE ANGLE D lq 5 618.13 5 87 1 48 E 649.06 5 86 51 42 E 680,08 S 86 41 7 E 711,83 $ 86 31 14 E 743,64 $ 86 22 12 E 777,46 5 ~6 13 23 E 811,33 S 86 6 34 E 846,52 5 a6 i 18 E 881,53 $ 85 56 29 E 916,53 S 85 52 2 E 951,35 S 85 49 2 E 985.44 & 85 47 20 E 1019,51 $ 85 45 45 E 1052,47 S 85 44 ~9 E 1085,79 S 85 42 2 E 1118.74 S 85 40 48 E 1150.77 $ 85 40 30 E ~182.77 & 85 40 [3 E 1213.18 $ 85 39 57 E 1243,51 $ 85 38 59 E 1273,72 $ 85 38 3 E 1302.53 S 85 36 33 E 1330.87 S 85 35 8 E 1~58,6~ $ 85 33 11E 1385.9~ 5 85 29 34 E 1413.22 S 85 25 32 E [439.39 5 85 21 ~? E 1464.40 5 85 18 2O E 1488.98 5 85 14 4 E DOG LEG SEVERITY DEG/IOOFT 0,272 0,545 0,543 0,000 1,099 0,266 0,829 0,000 0,269 O,272 0,564 0,543 0,532 0,000 0,385 0,599 0.301 0,297 0,569 0,543 0.532 0,553 0,546 0,329 0,284 0,266 0,806 0.806 0.310 SECTION DISTANCE 617,45 679,52 711,32 7~3,18 777,05 810,95 846,16 881,18 916,21 9~1,04 985,13 1019,20 1052,16 1085,49 1118,44 1150,46 1182,4~ 1212,86 12~3,19 1273,40 1302,21 1330,56 ~358,33 1385,?0 1412.97 1439.16 1~6~.19 1~8.81 ARCO O/G NGI-13 MAGNETIC MULTI-SHOT SURVEY JULY 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 7'92 15 0 7432.14 7384.14 $80.OOE . J5 14 0 7522.18 7474.18 $81.OOE 7878 14 0 7612.41 7564.41 S78.00E 7971 13 30 7702,75 7654e75 $75.00E 7986 13 45 7717,33 7669.33 S75.00E 127.99 S 1508.19 E 131.83 S 1531.15 E 135.93 S 1553.27 E 141.09 S 1574,76 E 142.01 S 1578,17 E TIE -IN WITH SPERRY-SUN HMS AT 8273 MD 8273 15 0 7995.34 7947.34 S77.00E 8368 16 15 8086.82 8038.82 $78.00E 8462 18 45 8176.47 8128.47 SSO.OOE 8557 20 30 8265.94 8217,94 S81.OOE 8652 22 15 8354.41 8306.41 S83.00E 8746 24 0 8440.85 8392.85 586.00E 8841 26 0 8526,94 8478.94 S89,0OE 8876 26 30 8558.33 8510.33 $88.00E 8950 26 30 8624.56 8576.56 S88.00E 159.24 S 1647.31 E 164.78 S 1672,29 E 170.18 S 1700e03 E 175.44 S 1731.50 E 180.26 S 1765.78 E 183.80 S 1802.52 E 185.55 S 1842.63 E 185.95 S 1858,10 E 187.11 S 1891,10 E Bc ,'OM HOLE CLOSURE 1900.33 FEET AT S 84 20 57 E CLOSURES DISTANCE ANGLE D M S 1513,61 S 85 8 56 E 1536.82 S 85 4 43 E 1559,21 S 84 59 54 E 1581.07 S 84 52 47 E 1584,55 S 84 51 29 E 1654.99 S 84 28 41 E 1680.99 S 84 22 20 E 1708.53 S 84 17 0 E 1740,36 S 84 12 51 E 1774.96 $ 84 10 15 E 1811.87 S 84 10 39 E 1851.95 S 84 14 58 E 1867,38 S 84 17 5 E 1900.33 S 84 20 57 E DOG LEG SEVERITY DEG/iOOFT 0.532 1.077 0.780 0.566 1.667 0.438 1.918 2,659 1.847 1.867 1.935 2.191 1,538 0.000 SECTION DISTANCE 1513.46 1536.69 1559.11 1581.00 1584.49 1654,98 1580,39 1708.52 1740,36 1774.95 1811,86 1851e94 1867e38 1900,33 ARCO O/G NGI-13 MAGNETIC ~IULTI-$HOT SURVEY 23 JULY 79 INTERPOLATED TRUE VERTICAL DEPTH$~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL TOTAL COORDINATES C L 0 S U R E NAME DEPTH DEPTH DISTANCE ANGLE D M S SUB SEA TOP SAD 8605 8122.25 166.93 S 1682.73 E BASE SAD 8864 8547.59 185.78 $ 1852.77 E 1690,99 S 84 20 4 E 8074,25 1862.06 S 84 16 25 E 8499,59 ARCO O/G NGI-13 MAGNETIC MULTI-SHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 23 JULY 79 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFER£NCE CORRECTION TOTAL COORDINATES 148 148. 100 0 0 248 248, 200 0 0 348 348, 300 0 0 448 448, 400 0 0 548 548. 500 0 0 648 648, 600 0 0 748 748. 700 0 0 848 848, 800 0 0 948 948, 900 0 0 1048 1048, 1000 0 0 1148 1148, 1100 0 0 1248 1248. 1200 0 0 1348 1348, 1300 0 0 1448 1448, 1400 0 0 1548 1548, 1500 0 0 ~ 1648 1648, 1600 0 0 1748 1748. 1700 0 0 1848 1848, 1800 0 0 1948 1948, 1900 0 0 2048 2048, 2000 0 0 2148 2148, 2100 0 0 2248 2248. 2200 0 0 2348 2348. 2300 0 0 2448 2448, 2400 0 0 2548 2548. 2500 0 0 2648 2648, 2600 0 0 2748 2748, 2700 0 0 2848 2848. 2800 0 0 2948 2948. 2900 0 0 3049 3048. 3000 0 0 3149 3148. 3100 1 1 3251 3248, 3200 2 1 3352 3348, 3300 4 2 3455 3448, 3400 6 2 3559 3548, 3500 10 4 0.00 $ 0,00 $ 0,00 $ 0.00 $ 0,00 $ 0.00 $ 0,00 $ OjO0 5 0,00 $ 0,00 S 0.00 S 0.00 S 0,00 S 0,00 $ 0,00 S 0.00 $ 0.00 S 0,00 5 0.00 S 0,00 5 0,00 S 0o00 5 0.00 S 0,00 $ 0,00 S 0,00 S 0.28 N 1,60 N 0,55 N 0,44 S 1.23 S 0,02 S 2.00 N 3.66 N 4,32 N 0,00 W 0,00 W 0,00 W 0.00 W 0.00 W 0,00 W 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W OeO0 W 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,08 E 1,88 E 15.~2 E 28.98 E 43.96 E 61.63 E 84.74 E 112,98 E ARCO O/G NGI-13 MAGNETIC MULTI=SHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 23 JULY 79 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORD INATE5 ~665 3648, 3600 16 3771 3748, 3700 23 7 3879 3848, 3800 30 7 3987 3948, 3900 38 8 4097 4048, 4000 48 10 4208 4148, 4100 60 12 4317 4248, 4200 69 9 4424 4348, 4300 76 7 4529 4448, 4400 81 5 4633 4548, 4500 85 4 4739 4648, 4600 91 4844 4748, 4700 95 4 4949 4848, 4800 101 5055 4948, 4900 107 5161 5048, 5000 113 6 5268 5148, 5100 120 7 5374 5248, 5200 126 5481 5348, 5300 133 7 5589 5448, 5400 141 8 5697 5548, 5500 149 8 5805 5648, 5600 157 8 5913 5748, 5700 165 8 6021 5848, 5800 173 8 6128 5948, 5900 180 7 6235 6048, 6000 187 7 6342 6148, 6100 194 7 6449 6248, 6200 201 7 6556 6348, 6300 208 7 6662 6448, 6400 214 6 6768 6548, 6500 220 6 6874 6648, 6600 226 6979 6748, 6700 231 5 7084 6848, 6800 236 7188 6948, 6900 240 4 7293 7048, 7000 245 5 4,33 N 147,63 3,47 N 184,90 1,26 N 223,81 1,91 S 264,73 5,85 $ 309,95 9,64 S 359,16 13,84 S 402,17 17.10 S 438,92 19.67 $ 470,51 21,37 $ 502,06 23,49 26.71 5 30,22 S 600,20 33,9Z S 634,57 38.20 S 669.81 42.63 S 705,96 47.16 $ 742,86 51.86 S 781.19 56,26 S 821,01 60,49 5 861,29 64,77 $ 901,99 68,85 $ 942,84 72,36 5 982,76 75,73 S 1021,36 79,10 ~ 1059,56 82,84 S 1097,6~ 85,73 S 1135,05 88,74 S 1171,79 91,50 $ 1207,71 94,54 5 1242,51 97,50 $ 1276,18 100,74 S 1308,72 107,44 S 1370,95 111,66 5 1401,25 ARCO O/G, N&t-13 MAGNETIC MULTI-SHOT SURVEY MEASURED DEPTH :AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 23 JULY 79 TRUE MEASURED VERT!.~AL SUB MD-TVD VERTICAL DEPTH, DEPTH ~EA DIFFERENCE CORRECTION TOTAL COORD INATE5 7397 7148. 7100 249 4 7501 7248, 7200 253 4 7605 7348. 7300 257 4 7708 7448, 7400 260 3 7812 7548. 7500 264 4 7915 7648. 7600 267 3 8018 7748. 7700 269 2 8121 7848. 7800 272 3 8226 7948. 7900 276 4 8328 8048, 8000 279 3 8432 8168. 8100 284 5 8538 8248, 8200 289 5 8645 8348, 8300 297 8 8754 8448. 8400 305 8 8864 8548. 8500 316 11 115,78 119,69 124.01 128,70 132,89 137,85 143.95 150.21 156.37 162,43 168.48 174,39 179.93 184.01 185.78 1430.57 E 1458.46 E 1485,62 E 1512.24 E 1537,50 E 1561.86 E 1585.66 E 1609.81 f 1635,05 f 1661,62 E 1690,76 E 1724,96 E 1763,16 f 1805,71 E 1852,77 f ARCO O/G NGI-13 MAGNETIC MULTI-SHOT SURVEY 23 JULY 79 INTERPOLATED VALUES FOR EVEN ZOO0 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES. lO00 1000. 952. 2000 2000. 1952. 3000 2999. 2951. 4000 39~0. ~912. 5000 4896. ~8~8. 6.000 5828, 5780, 7000 6768, 6720, 8000 7730, 7682, 0.00 S 0.00 W 0.00 S 0.00 W 0.17 N 10,63 E 2.36 S 269,93 E 31.95 S 616.65 E 71,68 $ 975,09 E 101.36 S i315.18 E 142.87 $ 1581.40 E ARCQ OIL. &. GAS. WELt_ NG1-15 MAGNETIC MULTI-SHOT RADIUS- OF CURVATURE SCALE I"-- 500~ ,JULY 25~ 1979- . . ALL DEPTHS SHOWN ARE TVD. TV0=8625' TMD=8950' 4O0 800 -- 1200 ~O00- Z400 - 2800 5200 5500 ,~ .... · 7600 -~ - 8000- -,~ WELL. MAGNETIC' MULTI-SHOT RADIUS OF CURVATURE SCALE !"= IO00' JULY 23, i IALL DEPTHS: SHOWN ARE_ TvD. TVD: 8625' TMD= 8950' SCILNTIFIC D}~ILLING CCNTROL$ 700 WEST 41st STREET GYROSCOPIC DIRECTIONAL SUEVEY FOR ,. ***************.~** * ARCO OIL & GAS * ****************** ~: NUMBER: 11-50-GYM3-3841 ~L NAME: NGI 1~ : i~.AT~-ON: PRUDHOE BAY .. . F. VEY- DATE: ?-7-79 qEY ENGINEER: PHIL GRAFFT ~O REFERENCE BEARING~ SS0-00E THANK YOU *T.qIS SUR~EY IS CORRECT TO THE *BEST OF MY KNOW, LEDGE A[{D. IS *SUPPORTED~BY ACT_UA~ FIELD DATA. * # . _ -' o * C O[:~ pA~,~y PEPS, ESE!~iTAT IYE ****************************** CO!IPLE" T I ©N RE:PORT CYROSCOP ]C 5URVCY COMPUTCD FOR SDC [~Y F ~..J L INDSEY ~ ASSOCIATES R[COI:{D OF SURVEY ALL CALCULATIONS PCRFO~<NLD BY I L~ ~4 LLLCTRONIC COf'jjDuJ'LJ'( TRUE D!:]IFT VERTICAL ANGLE 5UR SEA OIRL:.C [)EG e 0 O 0 O.i.; 0 IO0 O 0 100,OO 200 0 0 20O,O0 300 0 0 ~ 00, U O t+Ob O O D O () O 0 500 · O C; 700 0 0 7UOeO0 800 O U 80 O · g 0 1 (: 0 !.~ 9 0 1 ¢J O 0 · C, 0 '48,00 N O,OOE 52,O0 N 152,00 Ii 0,OOE 252,00 N 352,00 N O,OOE ~52~00 N 0~00~ 552 · 0 0 652,00 i,l O.OOg 952.00 N 1100 0 0 1100,00 1052,00 13au 0 0 1300,00 1252,00 N O,OU[ I ~{,)0 0 0 ~OOIGO J]5~eOO N O.OOE 1500 0 u lbO0,O0 I~SZ.OO t', O.UUg 1600 0 0 1600,00 1552,00 N O.OOE 1ToO 0 u 1700,00 1662,00 N l~OO 0 0 IBO0.OO 1752.00 N O,OOf 1900 (; 0 19OO.O0 1852.00 i'i 2OO~.~ 1 0 1999.99 1951,99 2100 1 0 2099.97 2051,97 N62.OOE 2300 1 0 2299,96 2251,9b NbS.00ff 2~UO 0 O 2399.95 23b1.95 t-, O.00E TOTAL C ' '"' (,) O t..~ u 1 NAT ES CLOSURES OlSTA;iCE ANGL~ O H S DOt; LEG 5EVLRITY DLG/IOOFI SECTION 015 TAaC L 0 · OO 0,00 0 · OO 0,00 u, C 0 0,00 0,00 O* OO 0.00 O,00 O,OC ) 0 · 0 0 O,OO u.OO O, O0 O,OO d,O2 ~:tCO O/G' ~'.IGI-13 GYP, OSCOP lC RE "t k..,k,,) OF SURVt~Y ALL CALCULATIONS PERF(It~I<ED UY I :9 t,~ ELECTRONIC ., JULY TRUE ~EASo DRIFT VERTICAL ~LHTH A;.,3~ l. [ D f_-iP Ttt D M SU,5 DR I F T SEA DIRL. C DEG. 2500 1 0 2499.95 2451.95 a75.00E 260(:, 0 45 2599,94 2551,94 S I.OOE 2700 0 (~ 2699,93 2651,93 Il O,OOE 2800 2 0 2799,91 z751,91 S61,COE 2900 3 0 2fi99.~2 2851,8Z SbB,O0~ 3000 6 f) 2999,50 2951,50 S78e00['. 31OO 7 30 3098,80 3050,80 N89.00[ 3'5011 lC) 30 3296.~5 32~8e45 NS~eOOE 3400 13 15 3394,30 33fl6,30 N~7.bOE 3500 16 0 3491.O5 3443,05 NBS.bO[ 3600 20 15 3586.07 35~8.07 NSq,OOE 3700 21 0 3679,66 3631,66 589,0OE 3~O0 20 30 3773.17 3735.17 N89.0OE 3900 22 0 3866.37 381~,37 565.OOE 4000 25 0 3958.06 3910,06 Sc. 5.()OL 4100 27 0 4(')47,94 3999,94 284.OUE 4200 25 O A137,~1 4059,81 S~4.0L>L 4300 2P 0 4229.51 41BI.51 44(.)0 18 0 4323,46 4275,46 S86.00E 450{) 15 0 4418.56 4370,56 460U lB 0 4513,67 4465.67 S86,OUL 4700 1R :} a608,78 4560,76 Sd7.OOE 4')t)U 1~ 30 47,)~.58 ~750.58 Su6.0Oc 5000 lO ~; 4893,27 4845,27 5100 19 0 4987,82 4939,82 S56,0U~ - .) 5300 21 O 5175,75 5127,75 5~4,50E TOTAL :3.85 N 3,O6 N 6,40 3,06 r.i 6,82 3.~0 N 8,O7 1,92 N 12,00 0,36 S 19,~9 1.49 $ 31,17 0,76 S 45,06 O,B1 N 2.~4 N 82,01 ~,22 3,3~ N 138,34 2,74 N 173,56 2,74 N 208,98 1,48 N 245,19 1,99 ~ 2~4,91 6.19 S 328.54 10,77 S 372,13 1~,b9 S ~11,~2 17~2B S 445.91 ldeb2 S 476.78 19.~3 S 507,67 20.78 S b38,5~ 22.69 24.91 S Z'l.4~ $ ~33.5U 29.98 S 665,9b 32,60 S 099e2~ 35,bl S '13~. lO C L 0 S u R E ~ D I STA;.iCE ANOLb 6,59 N 54 10 12 E 7,09 t'.i 64 27 0 k . 7,48 i'i 65 48 313 E 8.92 N 64 ~7 1~ E 12.15 N O0 5~ 51 L 19.50 S 88 5~ 15 f ~5,07 ~ g9 1 ~ a 61,50 a a9 14 I~ E I07,29 N U8 16 40 E 173.58 N 69 5 ~7 E 209,00 N d9 14 50 [ 245e19 N ~9 ~9 14 ~ 2~4.91 b 09 ~5 56 L 446,24 S 87 fl6 bO L 4'17,1~ S b7 ~5 44 E 5'~8.~ S 07 47 22 t ~7u.25 S 87 q3 7 E 6ul,97 S o7 ~7 41 E bS4,0v S b7 31 l~ L ~50.a3 S b'l 25 lb E 699.vV 5 t~7 1'~ ~o E 734,97 5 87 1Z Jb [ 0(,>3 LEG Si:vEal TY DEG/luOFT 1.000 0.ZSI 3,00a 1,004 2,000 2 ,'156 2.,751 4,261 0.750 0,b57 1 · 720 3 ,,JOO 2,011 2,uO0 4,o01 0.927 0.30'3 O,J09 i,) · u,511 O, 326 I ,u07 1.OO2 ~b.;C T I O,'i' D 1S TAaCL 4,t~9 6,03 '/.bi 11,72 19,42 31.15 44,d~ 61,04 BI,2B 106.27 137.17 17~.f5 Z07,47 Z43,60 ~27,~0 411.00 44b,1~ 476,ol 50b.81 568,93 6oU · 64 b.~2.7'1 C05.31 69~.67 733.69 ARCO 0/~' NGI-13 CiYRCS, COP 1 C SUf,~ VEY 16 .JULY 79 R£.CORD CF SUh, VE.Y ALL CALCULATIONS PERFOk>',tC~ i:~,Y I b ;,~ ~LLCTaONIC CC;..:~IJILrt TRUt! F",EA.S, ,{;RIFT VJ~RTICAL SUFt DFc I FT SEA DIRL. C TOTAL 830i:J 15 O 8017. t~. 7969,,18 S73,0UE 8z, 00 18 0 8113.05 !~;06.5,05 573,0UE 8500 20 0 82()7,5g 8159.59 STO.00L 8bO0 23 0 8300,63 ~252,63 578.50E ~700 23 0 8392.6~ t~3q~,bB S62,0uE 8HO0 25 0 8~84,03 ~36,03 556.00E Bg00 25 0 857~,66 ~526.66 SSb.OOE 8929 25 0 8600.94 b552.9~ 5~6.00E 6950 25 0 8619.97 ~571,97 586.00[ HOLE' CLOSURE 191f~,24 F'f:Tt, r AT S 83 49 6 E C L 0 b IJ R L .b ~ l STAi~C t. ANGLL D M 5L~Vt.R i TY DLG/100F T 1,~67 D l 5 TAI',;,C L 1676.82 17'1D,24 1~97,12 1~09,37 ,~[~CO O/C. NGI-i3 C',YR'DSCOPiC SL;f',~¥[Y 1¢) JULY 7!;, R[.CORJ) OF SLJ['~V~iY ALL CALCULAT1OI,;S P[iI~FO~{,v. EL) BY I ~s ;.'. E~L~.'..CTRC,"~IC COhF,'LJTLi~ TRU.C !.IF/',S. [')RIFT VERTICAL DLP T~.( ANGLF DEPTH 5LJB [)R, ! F T St.A l,>l RCC DEG,. 5400 21 0 5269.11 hZ21.11 585.00E 5500 21 45 536Z.23 5314,,23 585.0OE 5bO0 22 0 5455.03 ~407.03 585.00~ 5700 22 15 5547,67 5499.67 SUS,00[ 5~00 22 0 56~0,~0 ~592,~0 S~S,OOE 5900 2~ 0 57~2.69 ~6b~,69 S~35.00[ 6UO0 21 ~5 5825.16 5777.16 S~5.00L 6100 22 15 5917.~8 5869,8~ 5d~.OOE 6200 21 u 6UlO,a~ 5962,8~ S~4,0~E 63C0 21 0 610b.19 605b.19 S86,00E 6~00 2C 3(.) 6197.11 61~9,71 6500 2() 30 6291,~7 6243,37 S~7.COE 6600 19 30 6385,34 6337,34 6700 20 O 6419.46 6431.46 6~00 19 30 6573,5P 6525,58 Sfi4,0O[ 6900 19 O 6~67,99 ~019.99 7COt) 18 0 6762,82 6714,82 7100 17 0 6858,19 6~10,19 S79,00E 7200 ]6 ~0 6953e94 0905,94 7~00 16 U 7049,95 7001,95 479,00[ 7400 15 45 7146,14 '~09a.14 7500 16 0 7242.32 7194.32 576.50~ 7500 16 0 7338.45 7290.45 STq,OOi 7700 15 J 7434.B1 7~6,fil 574,00[ 7800 1~ 45 75B1.68 748B,6fl S75,00~ 7900 14 o 7628,7G 7580,76 S76,00L fiU[)O 19 o 7725,9g 7677,99 ~76.0U[ ~lOO ~3 45 7~2B.28 7775.2~ ST~,OUL 820D 14 (J 7920,36 7872,36 S74.00E TOTAL CO01{DINATE$ 39.08 S 769.79 42.26 $ 8G6,10 48.79 S a~Oe73 52,07 a 91~,25 55.41 S 956.~7 58,7'~ g 994e29 62.92 S 1031.58 66.17 S 105B,23 69.29 S 1103,93 71.15 5 1139,~1 72.~7 $ 1174,30 74.0Z S lzOa.47 75,34 S 1242.2~ 77,99 02,30 S 1308,60 U7.Sl S 1339.fl5 93.54 S 98.~0 S 1397,70 103.90 S 1425e22 115,39 12Z.40 $ 1505.3b 129,77 136,40 142,41 148.U6 S 153.26 S lb23.37 159,o6 S C L C, S O R rJ S D I S i A;'.;C u A,NGL r. 770.78 ~(,7,20 9~7.96 IO'IO.ZB 1106.10 1141.5~ 1176.54 IZ10.74 1244.52 127~.30 1'311.19 13~2,72 1372.56 1~01,~9 1~29,00 1456.1~ 1~.20 ~91u.~2 1536,5~ 150o,9~ I607.6~ 1630,59 LL~ ,SE v fi< ! TY 100F 0,17V 0,750 0,250 U,ZSO 0,2.50 1 ,O00 1,250 0,520 i,Z50 0,717 0 · ~ fi 0 1.014 0,530 O.P93 ~.01e 1 0.50o 0.506 O.Z61 u.Z7b 1,OoO 1.251 O,Zb? 1,uO0 0.750 0.342 SLCT lot~ Ol b TAt,~C E 769.P2 910.5Z 994,84 1U~2,29 1069e~b 1104,9'1 1175.29 1243.13 1276.90 130').U6 1400,21 1455.35 1>0~,7~ 1~60,61 1607,47 1630.43 1654.19 ARCO O/G NGI-!3 GYF~OSCOPlC SURVEY ~'.~CASUi:{i.'O D[PTH AND C, TH~.:R L.;ATA FOR LV~:,F(Y EVi::N 100 FLLT OF ~Ub 5LA i)LP'lri, 16 JULY 79 jnB ~ 3~,1 TRUE :,'~EASt,~kE9 VCRT ICAL $Ui3. ~,![:,-TVD VENT ! CAL l)i;" P T H [)LPTH 5~A D l FFt'.,~ £NCE CUR,Rf'.. C T l ON l C;~TAL C.bOi~ D lkATE ,5 148 148 · 100 '~ ~ 2 O0 348 348, 300 5 q B 54 ~, 500 7~B 748, 700 848 ~48, 800 948 94~, 900 1.04a 1048. IOOU 1148 1148, 1100 12~8 124~, 120U 134H I~4H. 130C) 1448 14~8, 1400 15~] 154e, 1500 1646 1648, 1600 1748 174~, 1700 lg4~ 1948. 1900 20~ 20~8, ~000 2148 2148, 2100 2243 2248. 2200 2348 2348. 2300 2448 2448, 2400 25~ 254~. 2.500 24>49 264~. 2600 274~ 2748. 2700 2h~ 284~. 2800 Z94f; 294~, Z9OO '3()49 304~. 30('0 ~J50 3148. 31~0 '~25l 3248. 3200 ~53 ~4~. 3BOO 9455 3448, 3400 3560 3548. 3500 O, O0 O,OO O,OO 0,00 O,O0 O. O0 O,OU u, Ou 0,00 0,82 2e92 3,40 2,74 0,57 1.19 1,25 O. 03 2,07 0,00 0,00 0,00 0,00 0,00 0,00 0.00 0,00 0,00 0.00 O,O0 O,O0 0.00 O,O0 0.00 O,OO 0,00 0,06 1,~Z 2,80 3,71 ~,,88 4,91 6,09 6,70 7,00 9,7~ 37,ua 52,96 71.68 9b.31 124,94 , C, Yt~OSCL3PIC Sb~v[ Y c. VFRY L~VEN 100 F~[T OF ,SUb .SEA L),CF)iti. JULY 79 TRuE VFRTICAL SU[3 b!O-TVu DEPTH ,SEA VtiRT I CAL CO~.RE C T ION TUTAL '5779, 3989 4 ! 0 0 4211 4426 4531 4636 4741 4952 5164 5270 5B77 559Z 57O0 5~0 R 602 5 ~2 6347 645t~ 6667 677 ~ 6S79 70~] 9 7194 72q~ 3748. 3700 25 3848. 3800 32 39aB. 3900 40 4048. 400(1 52 4148, ~100 ~248. 4200 72 ~348. 4300 78 4548. ~500 88 4648. 4600 4748e 4700 99 4948, 4900 110 5048. 5000 115 51~, 5100 122 524R, 5200 129 5348, 5300 136 544~. 5400 1.~4 5548, 5500 152 56~8, 5600 5748, 5700 169 5840, 5800 176 5948. 5900 1~ 60~fl. 600g 192 61~8, blO0 199 624~, 6200 206 6348. 6300 212 6448, 640(; 21~t ~548, 6500 225 664~, 6600 231 b748. 6700 230 6~4~. 6~00 241 704.~. 700° 250 7 7 7 12 11 9 6 5 5 6 5 6 7 7 7 9 7 7 7 6 7 5 4 2 · 95 2.62 2,03 1,59 6.19 11,25 15,22 17,7a 18,82 19.~6 21,~9 Z3.73 26.14 28.9U 3q.~7 4~.25 40,79 55,97 59.54 6],57 70.~Z 'lI,8V 73,65 74~ 93 ~l.d5 80,87 92'. 93 103.79 199,50 237,77 ZSO,]0 :~7b,73 419,11 45:3,~7 5~,78 551.26 564.57 61e,02 652,27 6U6,99 600.~6 921.2~ 962,fl1 1003,40 1043,53 1120,61 1194,99 1230,8~ 120O.S7 l~O1,7S 13~4,97 1306,20 1395,97 142~,b7 E E E E £ E E E [~ E. E £ [ t .E £ £. ~. ! L A S t!i':~ ~'! ~'5 D E' P T H A t,; D O T i i E R bA TA CYr;OSCOP IC SUi'~V[-.Y "VtitY ~.::V6. N 100 t~''tET OF ~,Ui~ SLA JULY TRuE t,;E A 5',Ji'~ E P VC t;: T I CAL :),:. P T H b E P T SEA Plb-TVD Vt/L'~ T 1CAL D 1F F'CRii,qC[ COF~RECT I Oi'; TOTAL CL)Oi~D If;ATE 7402 714a, 7506 72~!~. 7610 734a. 7714, 7920 76~8. B023 77~8. 6125 '8437 ~ 14B, 8651 834~. 71CO 253 3 109 ?200 2.5fl 5 73L),O 262 4 123 7400 266 7500 26~ 2 l 37 7600 272 4 14~ 770o 2'14 7800 277 3 7900 2~0 3 160 ~000 2~3 3 ~lO0 2a8 5 ~200 295 7 1~ d300 303 d 195 ts~O0 312 9 200 ~ 500 32 3 11 2 .46 5 1452.5~ ,1~ 5 1507,9fl · ~3 5 155~.63 .27 ~ l~OS.flO · 55 S 1629,18 · gb 5 X653,21 ,67 5 167~.dl ,76 S 1'108,93 ,73 5 1'143.91 .Uti S 1764,~7 6YROSCOP!C; 5URV[]Y NT[-RPC)LAT~b VALIJ£S FO;i=.: [V['N ]000 FILET OF' i~i£ASURE[') DEPTH. TOTAL CO0~,~D INATE $ 2000 19~,9, 1951, 3000 2999, 2V51, 4000 3958. 3910, 5QO0 489~, 4845, 6090 5825, 5777, 7000 6762, 6714, 8000 7725- 7677, O,OO S 0,61 t'~ 0,51 0,36 S 19,49 Z7~3 S 633,50 58.73 S 9~. 29 87,81 S 1339,8~ 1[~ JULY 79 JnB !l ARCO OIL 8~ GAS - .... -i .......... 8500 L.~ .. ........... "' ; '~00 ............ I ·7600, ........ ~ ............... ,...--, ....~ ...... RCO OIL & GAS ............ : .............................................. , . . : .......... { ..... WELL NGI-13 I ...... I! ...... :~- ........... ~-' GYROSCOPIC SURVEY --: ........... ,~--~-~---F-' -.~--- RADIUS. OF CURVATURE ; .......... ; ................... .... ~I ' ':"':-; .......... ,JULY 17, 1979 .... ; ' ' ,, · :-_~SCALE: t"= 500': -'--~ - ~ ....... ~ ......... _ ~ ................ : . . : ! ~ ...... ~ . ; - ~ ~ ~ ~ - --! .... ~ ' ! - -. ~ - .t . . /ii .... '"' ~ '~ i .... ;" ~" - ~ ' ' · .. ~ ........... _.? :; !i ' '. ....... ,~ ..... ; ~f ..... f .i ..... :. ...... ; ......... ' ~.t' ............ ! ..................... ALL DEPTHS SHOWN ........... ..... ~ ...... ~ ......... : .... ,, ........1 i ARE TVS. ! TVD=8620' TMOn8950' July 27, 1979 Reference~ Enclosed is a Directional Survey' for the following well: N,G,I., 13 6/21/79 ~lti~-Shot Survey please sign and return the attac]~ed copy as receipt of da.ta~ VerT. t~ul~~ yours, R.. A, Bellinger . . North Engineering TF4~NSHITfAL # 241 DISTRIBUTIOX' Nort]t Geology Drilling Eng. Manager Ceology State of A].aska Mob i ]. Getty Soh i o Pi~ i l I ip:~ Po:-;[ O,,tue.,,>o~.. 3 ,:% f'~ c" - ,1or,.,, ~In 3 k.--t 91:510 'falepho:"~e .907 2;'7 553? July 27, 1579 Reference ~ t'~closed are Directional Surveys fOr the following ARCO wells' 7/10/79 GyroscopiC Survey Gyroscopic Survey Please sign and return the attached copy as receipt o:f data.. Very trulyyours, R, A., Bellinger North. Engineering TK/:~dNSMITTAL-# 240 '<,:',: .'.7. :;,;,:>)':¢ 7., I IS I'RIICJ I I0× North (;eology Dri 11 ing Eng. Manager Geology State of Alaska Mobil Getty Sohio ,Xlarat]~on Phil ] Chevron ARCO Oil and Gas. Company Alaska D?-'4ct Post Offic Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 SAMPLE TEANSMI TTAL SHIPPED TO' State of Alaska · Division Of Oil & Gas conservation 3001 PorCupine Dr. Anchorage, Ak. 99501 Attn: Wm. VanAllen DATE: July 181979 OPERATOR' ARCo '. SAblPLE TYPE' core chips S/~qP LES SENT: 8255 8256 8257 8258 8276 8277 8311 8312 8313 NAME' North Ga-s Inj. #13 NUMBER OF BOXES' one UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORbl TO: ARCO OIL ~ GAS CO. P. O. BOX 560 ANCHORAGE, ALASKA 99510 ATTN' DICK BROOKS ARCO Oil and Gas Company ia a Division of AtlanticRichlieldCompany ARCO Oil and Ga: ~mpany Alaska Post Office Box 360 Anchorage, Alaska 99510 Tdephone 907 277 5637 July lO, 1979 Mr. Hoyle H. Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject'~ Permit No. 78-91 ~"-DS 12 1, Permit No 79-23 F?I, Co,',¢a--I j I ~x'~_. I .... J STAT TEc I S~¢,T ~EC--' EONFER~ - -~ FIEF: Dear Sir' Enclosed is the Monthly Report of Drilling Operations for the above-mentioned wel 1 s. Very truly yours, P. A. VanDusen District Drilling Engineer PAY'cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-20347 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL [~ GAS F--1 Gas Injection WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360 Anchorage, Alaska 99510 NGI #13 4. LOCATION OF WELL 489'N f 840'E of S~I cr Sec 1, TllN, R14E, UM 10. FIELD AND POOL, OR WILl)CAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec l, TllN, RI4E, UM 12. PERMIT NO. 78-91 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES 1N HOLE CONDITIONS. Report of Operations for the Month of June, 1979 Spudded well @ 0400 hrs 6/9/79. Drld 17½" hole to 2733'. Ran 13-3/8" csg to 2709'. Cmtd w/4800 sx Arcticset II cmt. Did 60 sx top job. Installed & tstd pkoff Drld shoe & 10' new hole. Tstd formation to 12.5 ppg equiv MW. Drld 12-1/4" hole to 5417'. Ran multishot. Undercut & sidetracked @ 4155' to avoid NGI #5. Drld to 8040' Ran 9-5/8" csg w/shoe @ 8015'. Cmtd w/700 sx Class G cmt. Dwnsqz~.t.hru lo~er FO w/300 sx Arcticset I cmt. Did Arctic Pack job thru upper FO. Drld shoe & 10' new hole. Tstd formation to 12.5 ppg equiv MW. Drld 8½" hole to 8255'. Ran GR log. Drld to 8276'. PU core bbl. Core #1, 8255-8277', rec 4'; core #2, 8276-8284', rec 2.2'; core #3, 8284-8311', rec O; core #4, 8311-8318', rec 3'. LD core bbl. As of June 30, drld 8½" hole to 8875'. TITLE District Dril 1 ing Engr. DATE 7/10/79 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Alaska Oil and Gas Conservation Commission Hoyle H. Hamilton Chairman of the Commission Lonnie C. Smith ~ Commissioner Ben LeMorman Petroleum, Inspector June 13, 1979 B.O.P.E. Test on ARCO's ~]GI-13 Sec. 1, TllN, R14#, UM Prudhoe Bay Unit Saturday, June _9 - I departed my home at 5:00 PM for a 5:30 PM showup and 6:30 PM showup for Wien Flt #19 for Deadhorse arriving via Fairbanks at 8:55 PM. I proceeded to ARCO's Well DS 12-1 for upcoming B.O.P.E. Test, the subject of a separate report, Temperature +40°F, cloudy, light wind. Sunday, June 30 - Standing by for B.O.P.E. Test on DS 12-1. ~q~da~,.~un~ 11 - B.O.P.E. Test on DS 12-1 completed at 9:20 PM. I proceeded immediately to ARCO's NGI-13 where I met with ARCO Drilling Foreman Kirk I,~ite and Parker Rig #141 Too!pusher Tom Black. Tests began at 11:00 PM with the shoe on the 13 3/8" at 2709'. Kelly cock, upper pipe rams, outside valve on the kill line, and three valves and six flanges in the choke manifold tested to 5000 psig. Lower Kelly valve, inside valve in the kill line, and three valves and six flanges in. the choke manifold tested to 5000 psig. Check valve in the kill line and the remaining two valves and four flanges in the choke manifold tested to 5000 psig. The manual adjustable choke ~as free moving and the Swaco superchoke actuated. HCR valve and inside valve in the choke line tested to 5000 psig. The lower pipe rams would not test and it was decided to replace the rams. Tests were suspended at midnight. ~sday., Ju.ne~g - Several additional attempts to test failed and at 2:00 AM it was decided to replace the entire preventer. Tests were again suspended. Tests resumed at 9:30 AM but the replacement preventer would not test and it was decided to change out the test joint. Still, the preventer would not test so the doors were opened and the ram block carriers closely inspected. It was found two different type carriers were installed and a call went to Parker's yard for matched type 70 ~carriers with new 5" rubbers. Tests were again suspended. Tests resumed at 1:30 PM with the lower pipe rams finally testing to 5000 psig. Annular preventer then tested to 3000 psig. Accumulat~pressure was 2750 psig. With the pumps off both ram type pipe preventers and the annular preventer closed and the HCR valve opened simultaneously. Accumulator pressure fell to 1200 psig. The pump was then turned on and accumulator pressure increased 200 psi in one minute, twenty-two seconds. ~2 backup bottles tested 1825, 1850, 1875, and 1875 pmig. ~ile pullimg the test joint to test the blinds I toured the location which was well organized, rig in good repair,reserve pit well built, and the well sign was in place. Finally, blind rams teste~ to 5000 psig and both dart and ball type floor valves were in place. Tests 'were concluded at 2:00 P~ and a field inspection report prepared with a copy given to Kirk l~ite, a copy mailed to Bob }lines, and the original attached to this report. I departed Deadhorse via Wien Flt. #20 at 9:35 PM arriving in Anchorage via Fairbanks at 11:50 PM and at my home at 12:20 In summary, I witnessed successful B.O.P.E. test on ARCO's NGI-13. Drlg. Permit No. Opera tor~ x~ Satisfactory Type Inspection Yes No Item (~/~Location,General (~() (~() (~- ( ) (~-t () () () () () () () () () () () () () 1. Well Sign 2. General Housekeepin,g t. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. , , , ( ) Final Abandonment -ka Oil and Gas Conservation Comm Field Inspection Report We 11/~m Sec Represented by/~,~:,~, ~:lx~,3~_-- Name & Number Satisfactory Type Inspection Yes No Item (~-)~'BOPE Tests (~- ( ) (~y ( ) (~() (~)- ( ) (~)- ( ) (.~- ( ) (~)~ ( ) (~- ( ) (~-' ( ) (~- ( ) (~)-- ( ) (~)- ( ) (~- ( ) 15. ~asinq set @~0~ 16. le§~'fluid-(~Wtr~.-( )mud ( ) oil 17. Master Hyd. Control Sys.~>ompsig 1 8. N2 btl s .~,z_'Da~,/~/~l~s i ,g 19. Remote Controls 20. Drilling spool-~"outlets 21. Kill Line-(~"Check valve 22. Choke Flowline (~CR valve 23. Choke Manifold No. valvs~flgs/'~ 24 Chokes-(~emote( )Pos.(~dj 25. Test Pluo-(~/~llhd( )csg( )none 26. Annular Preventer,.~'~;¢?psi.~ 27. B1 ind Rams.~S-~-~:,psie ( ) ( ) ll. P&A Marker (~.~ ( ) 28. Pipe Rams ( ) ( ) 12 Water well-( )capped( )plugged (~ ~( i 29. Kelly & Kelly-cock~.~,psig ( ) ( ) 13. Clean-up ('~ ( ) 30. Lower Kelly valve.,~.~__~_psi? ( ) ( ) 14. Pad leveled (~)~' ( ) 31 Safety Floor valves-(~V (.~art Total inspection observation time ~ hrs/d~=~s Total number leaks and/or equip, failures Remarks days or when ready ARCO Oil and Gas Cornpany Alaska f}~. e,=-.m Post Of fie ~x 360 Anchorage. Alaska 99510 T(:leph~)ne 907 277 5637 May 31, 1979 Mr. ttoyle Hamilton State of Al aska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Well Surveys at IiGI Location Dear blr. Hamilton' We qave evaluated the planned well paths fo nd ¥t14 with reference to interceptions with all applicabl~'-~-i's~Eing wells. Adequate clearance has been planned at each interception point to safely drill the proposed wells. The existing well bores at HGI #5, NGI #10 and West Bay State #1 have been evaluated to determine the Ellipse of Certainty (EOC), considering the accuracy tolerance of the existing surveys. The well currently being drilled at NGI #14 has crossed some ~950' vertically above the NGI #10 wellbore. After considering 'the accuracy tolerance of surveys, for NGI #14, the minimum distance between the EOC for NGI #14 and West Bay State #1 is +250'. The next well to be drilled is NGI #13 which approaches three existing wellbores. Considering a 'typical EOC based on the accuracy tolerance of anticipated surveys for NGI #13, the minimum distance planned between the EOC for NGI #13 and NGI #10 is J~184' The minimum distance planned between the EOC for NGI #13 and NGI .~5 is ±167'. NGI #13 is planned to be ±2300' vertically below NGI #4. To date complete reevaluations of NGI wells l, 2, 3, 4, 5 and 10 have been completed. All surveys checked have been found to be within reading tolerance of human error; i.e., all hole inclination values are within _+~o and bearing direction values are within ~!:3o. The reevaluation is continuing and all wells drilled at the NGI pad will be reviewed. A preliminary investigation indicates there will not be any conflict between the existing wells and the proposed wells-for WGI. When the reevaluation is cor. tpleted, a detailed ARCO Oil and Gas Company is a DivisiOn of AllanticRichfieldCompany Mr. Hoyle Hamilton May 31, 1979 Page 2 analysis will be conducted to determine the minimum distance between the existing EOC for appropriate NGI wells and the EOC for proposed wells. A sketch of the NGI and WGI pads indicating the drilled or planned bottom hole locations is attached for quick reference. Also included are 1" = 50' plan views of the NGI pad showing the individual drilled well paths and planned well paths. A 1" = 50' plan view of part of the NGI #14 well path is shown which includes the West Bay State #1 well. Additional plan 'view sketches of the WGI wells will be sub- mitted as they are completed. Sincerely, P. A. VanDusen District Drilling Engineer PAV:CSA:cs Attachments cc: P. B. Norgaard w/Sketch I R. A. Crosky w/SketCh I L. M. Sellers w/Sketch I H. C. Heinze w/Sketch I J. A. Rochon w/Sketch I BOTTOM tIOLE LOCATIONS AS DR1LLED OR PROPOSED ONGI Locations //~ WGI Local~ions <~]> West Bay State #1 / I / /! /Z ARCO Oil and Ga, ompany Alaska Region Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May Il, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: ermit No. ~"~t~t'~qr~, Permit No 78-91 78-92 Dear Mr. Hamilton' Enclosed please find a Sundry Notice along with the as-built surveys outlining the correct surface locations for the above mentioned well s. Very truly yours, P. A. VanDusen District Drilling Engineer PAV' cs Enclosures .. ! ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 RE~t- I- l?0-73 Submit °'1 ntentlons" In Tripllcate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drlll or to deepen Use ",APPLICATION FOR PERMIT---" for such proposals.) ~. O,L F1 GAs F--I Gas Injection WELLI I WELL ii OTHER 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P.O.. Box 360 Anchorage, Alaska 9951 0 4. LOCATION- OF WELL. At su trace 489'N & 840'E of SW cr Sec l, TllN, R14E, ug 13. ELEVATIONS (Show whether DF, RT, GR, etc,) 5l 'RKB 14. Check Appropriate Box To Indicate Nature of Notice, 'Re 5. APl NUMERICAL CODE 50-029-20347 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. · NGI #13 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 1, Tl lN, R14E, UM 12. PERMIT NO. 78-91 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MU LTI PLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ,~LTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* {Other) (NOTE; Report results of multiple completion on Well Completlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The correct surface location for the NGI #13 well is 489'N & 840'E of SW cr Sec l, TllN, R14E, UM as shown on the enclosed as-built. The estimated location shown on the Permit to Drill should be changed to reflect the as-surveyed location. 16. I hereby certify that the f~oregoing Is true and correct 5./l]/79 {This space.for State ~,~,~.,~.,e~:,;~d~_' ~ [ S~ ~ N E ~ APPROVEDBY ' G. SMITH See Instrdctions On Reverse Side / Approved ':.:':-,:~'Y i;, Returned · ' f';:~ .... ~ SEC · 40 8 , · .q sec¢ion · -~ 101~' SECTION Jo89' /2 1114' i] 59' ........ well ~OTE: WELL , ~ ~-8U'-- .HS~e~ CE~T/~,' OF SURVE P"~iU~ L*,.-- STER~D ~t~u SURVEYiN~- tN THE STATE O~ 4L~SKA AND REPReSEnTs ~ LOC~TioN SURvE~H4T THIS OR UND~R My SUP ~N D OT 'ERVISION ' M4DE D HER DET , 4~O ~ By ME EXlSTIN6 WELL OR CONDUCTOR PIPE ' .-BUILT WELL NO. i LAT. LONG, 70~19,'36.129" Y 5 ",7l 148 2850.0,6,, ~, WELL NO. 2 ~ i :~/ L A t 70o,c,, ~ ... ~t~ !7, O. 762" Y 5, 971 516.90 X 687 322.06 z LA T. 700 19'38.441" ,, Y 5 971 635.76 LONG· 148o28,51.493 X 687 294.09 ~V WELL NO. 4 LA77 LONG, 70°~ 19'39,596" 1'¢8 ~' 28'52.223" Y 5 971 750.62 X 687 266.18 WELL /~"0. ,5 LAT LONG, 2'0°/9'40.740.9'' 148 °28'52' 947" Y 5 971 X 687 238.47 WELL NO. 6 LAF. 70°;9'41 908" LONG. 1~8o Y 5 971 984.2, 28'55.682', X (;87 WELL. N (.. 7 LAT. 70°' 19:4305 LONG. 14~o~ · J" r~ ~ 54.412" Y 5 / 82.4 7 WELL NO. 8 LAT. 70° 19'44 2i0" LONG /460~8'55. f26" Y 5 '~72 2;7.07 X ~7. ":5.06 WELL NO. 9 t. A T. ?0o ,, ,~, , ,L9 45.370' LONG 148o28,55.850,, Y 5 97'2 3~4.51 X C,87 /2~7.31 WELL NO IO LA~ 70°/9'46.5/9" 'r 5 972 450.53 '¥ (;87 WELL NO. I I LAT · 70° /9' 4 7. 6 75" LONG., t48o28,57'319'' Y 5 972 567, X 687 071, ~ WELL NO. 12 LAT. 70°/9'48.830" ~lG. 148o28,58.044,, Y 5 972 684. il No. 13 X 687 043. 700 19' -~ ,, '~bL983 ~48028 58,774 Y 5 972 800.7I WELL No. 14 LAT 7 o , 687 015.51 · Y 5 972 917.24 WE I T NORTH INflECTioN SITE LOCATED IN PROTRACTED PREPA R ~ Y I.M. HEWIT T V. LOUNSBURY 8 ASSOc ' SCALE CHKD. BY_~ G,.____~D, B LOOSE 816' 840' 865 89o_' 915' section line 965' 989 1014' SECTION 12 1039' ~064 1089 114 S E C T'~'W 1139' LEGEND EXISTING WELL OR CONDUCTOR PIPE NOTE: WELL NO.I TOP PAD ELEV. ,= 18.4 FT. ABOVE MLLW AS-BUILT, REVISION No. 2 ARCO AFL No.292265 HVL No. 30-NIS-75 OF .SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE_CO..RRECT. , .- BUILT WELL NO. I LA T, 70°19'56,129`` LONG. 148°28'50.016" Y 5 '~71 400.07 X 687 350.54 WELL NO. 2 .L A T. 70° 19' 57.284" LONG, 148° 28"59.762" y~,¢' 971 516.90 X 687 322 06 WELL NO. 5 LAT. 70° 19'38,441" LONG. 148°28'51.493`' Y 5 971 6,53.76 X 687 294.09 WELL NO. 4 LA'F 70° 19'59.596" LONG, 148°28'52223'' Y 5 971 750.62 X 687 266. f8 WELL NO. 5 LAT TO° 19' 40.749" LONG, 148°28'52.947'' Y 5 971 867.11 X 687 258,47 WELL_ NO. 6 LAT. 70° ;9' 41 908" LONG. 148° 28'5~.682'' Y 5 971 984.28 X 687 210.54 WELL_ N(.. 7 LAT 70c 19',43.052" LONG, 148°2854.412" 972 099.94 687 ~ 82.47 WELL NO. 8 LAT. 70019'44210`` LONG, .!4~028'55.t26'' Y 5 :~72 2/7.07 X 687 55.06 WELL NO. 9 LAT. 70° 19' 45.~70" ' LONG. i48°28'55.850'' 972 33431 687 127.31 WELL. NO, t0 LAT, 70° ~9'46.519 LONG. /':~-5;° 2~' 56.589'' 972 450.575 (;87 099.!4 WELL NO. Il LAT. 70° 19' 47. 675" LONG.. 148° 2.8'57'. ~ ~9'' Y 5 972 567,37 X 687 071.18 WELL NO, 12 LAT. 70° 19'48. 830" LONG. 148028'58.044" WELL No. 1:5 , LAT. 70° 19 49,9875" LONG. 148°28 58.774 WELL No. ! 4 LAT. 'TO° I 9' 51.136" LONG. 148°28 59,492, Y 5 972 684. II X 687 043.43 ¥ 5 972 800.7'1 X 68'7 015.51 Y 5 972 917'.24 X 686 988.02 ATLANTIC RICHFIELD CO. WELL I THUR 14 NORTH INJECTION SITE LOCATED ;N PRO 'RAC'rED PREPARED HEWlTT ~ LOUNSBURY ~ ASSOE .Z2~ W. 6TH.AVE.., ANCHORAGE~ ALASKA : :. ...... : ...... DATE OCT 9, 1975 SCALE ~": 300' LOOSE CHKD. BY G. D. FIELD BK .... LEA~ F May 2, 1979 Re · Prudhoe Bay Unit NGI No. 13 Atlantic Richfield Company Permit No. 78-91 Mr. P. A. VanDusen District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen: In light of the information-contained in the Sundry Notice dated April 10, 1979, the Commission now requests that core chips be submitted on the subject well. Very truly yours, Hoyl% }{. Hamilton Chairman of the Commission AflanticRichfieldCompany , North American Producing Division North Ala' District Post Offic~ mlo× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 10, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject- NGI #13 Permit No. 78-91 Dear Mr. Hamilton' Enclosed please find a Sundry Notice outlining our change of plans for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosures Form ! 0-403' ~REV..~-A 0-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) APl NUMERICAL CODE 50-029-20347 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OIL F"l GAS n-I OTHER Gas Injection WELLI .1 WELL 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS'OF OPERAT°R 9, WELL NO. P.O. Box 360 Anchorage, Alaska 99510 NGI #13 4. LOCATION O~ WELL At surface 492'N.& 846'E of SW cr Sec.1, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approx. 76'RKB Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudh0e Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 78-91 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company prOposes to-core approximately 60' in the Put River Sand. This sand should be encountered between -7965' and -8015'SS. When coring is complete, a repeat formation tester wll be run to collect fluid samples. The bottom hole loca- tion and the casing program will remain the same as submitted on the orignal Permit to Drill. 16. I hereby certify that the foregoing is true and correct · (T.,. spac. for st.te o.lcel)t~,l~A[ $[~(Ei) TITLE Di stri ct Dri 11 i ng Eng i neer DATE. 4/10/79 APPROVED BY ,,i BY 10{~NIE O. SMITII TITLE CONDITIONS OF APPROVAL, IF ANY: See Instructions On Reverse Side DATE.. -? ,~, _ · Conservation E~ecemb~r 7, 1978 ~e: Prudhoe~hay Unit ~I Atlantic Richfield Company Permit ~o. 78-91 ?~r. P. A. VanDusen District Drilling Engineer Atlantic Richfield Company P. O. ~ox 3~0 Anchorage, Alaska 99510 Dear Sir: i2nclosed is the approved application for permit to drill the a~ve referenced well at a location in Section 1, Township Range 14E, UP~-~. i~eti sa~ples, core chips and a ~ud log are not required. A direction s~rvey is require~. ~any rivers in Alaska and their drainage syste~.s have ~en classified as important for the spa%~ning or migration of anadromous fish. Operations i~. these areas are subject to AS 16.50.870 and the rec~ulatations promulgated thereunder (Title 5, Alaska Administrative Code}. Prior to commencing opera- contac._ec~ by the }labitat Coordinator's office tions you may k~ ~ ~ Depar~ent of Fish and Game. P ~ of .o~Iution any waters of the State is prohibited b~, l~ 46 ~a~ter 3, Article 7 and th~ regulations pro~ulagated th~re- under (Title 18, Alaska .Administrative Code, Chapter 70) and by the Federal Water Pollution ._ontroz .let, as amend~ed Prior commencing op~erations you ~ay be contacted by a representa- tive of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Depar~nt of Labor is ~ing notified of the issuapce of this perm it to o.r 111 .,.0 ai~ us in scheduling flel .~ ~ork, %~e ~goutd appreciate your ~r. P. A. VanDusen Prudhoe Bay Unit N~! ~Jo. 13 -2- notifying this Ff' . ...... o ..... lee within 48 hours after the well i~ spu~e~. ~te ~ould also like to be notified so that a representative of the division ~ay be present to witness testing of blowout preventer equipment before surface casin~ shoe is drilled. In the' event of suspension or abandon~ent, p]oase ..... 9'ive this o=I3.ce adequate advance notification so -~.+~at ~ve v~ay have witness present. Very truly yours, f~[ovle ~f ~ami~ t~ Chairman Alaska Oil & Gas Conservation Cor~ittee Enclosure cc: Department of Fish and Came, ~ta!>itat Section w/o encl. Department of Environmental Conservation w/o/enc!. Department of Labor; Supervisor, Labor La~? Compliance Division w/o encl. AtlanticRich~ie~dCem~>any· . _~ ~ Alaska Re~i~ '* A~chorage, A~sska 99510 Telephone 907 277 5637 November 28, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #13 Dear Sir' Enclosed herewith is our Application for Permit to Drill NGI #13 and a $100.00 filing fee. An As-built survey will be sent as soon as it is available. Very truly yours, P. ^. VanDusen District Drilling Engineer PAV:jh Enclosures SUBMIT IN TR ATE Form 10-401 (Other instruct~ .s on REV. 1-i-?1 reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [~ DEEPEN [] b. TYPE OF WELL OIL GAS OTHER 2. NAME OF OPERATOR Atlantic Richfield Company SINGLE ZONE [-'l &'r".'L, , = MULTIPLE I--"l ZONE ~ 'U 3. ADDRESS OF OPERATOR P. O. Box 360, ^nchorage, ^laska 99510 E s t ~.' LOCATION OF WELL Atsurface 492'N & 846'E of SW cr Sec. 1, T11N, R14E, UM At proposed prod. zone O'N & 2640'W of SE cr Sec. 1, T11N, R14E, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOTM OR POsT OFFICE* 9 miles north of Deadhorse, Alaska API 50-029-20347 6. LEASE-DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN ALLO'I~EE OR TRIBE NAME 8. UNIT FARbl OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. "'~GI #13 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Sadlerochit 11. SEC.,T, R., M., (BOTTOM tiOLE OBJECTIVE) Sec. 1, T11N, R14E, UM 12. 14. BOND INFORMATION: nE Statewi de Surety and/or No. Federal Insurance Co. #8011-38-40 ~o.nt $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 51' RKB 2640' 1660' 16. No. OF ACRES IN LEASE 2560' 19. PROPOSED DEPTH 8631' TVD (:9570' MD) 17. NO,ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START January 1, 1979 23. PROPOSED CASING AND CEMENTING PROGRAbl SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH ...... Quantity of cement 32" 20." 94 H-40 80 250 sx PF II to surface 17-1/2" 13-3/8" 72 MN-80 2700 Circ to surface - Approx 5500 sx 12.-1/4" 9-5~/8" 47 80&95 8600 1000+-. cmt.' column on 1st staqe p~ 300 sx on 2nd stage. ... 8-1/2" 7" 2'9 N-80 9570 Approx. 350 sx. US¸ Atlantic Richfield Company proposes to directionally drill this well to ±9570'MD (±8631'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week & operationally tested each trip. A string of 7" 29# N-80 tubing, packer & necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reporte on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. ~ ~O~ SPACE DESC~BE PROPOSED PROG~M: If propo~l is to deepen ~ve data o~ present productive zone and pro~sed new productive zone. If propel is to q~ or dee~n d~ecfion~y, ~ve pertinent data on subs~ce locations and measured and true verti~ depthg Give blowout preventer pro. am. 24. I hereby' ~y that ~/~oregoi;~/s True and Correct DATE 11/22:/7--8 TITLE Dist. Drl g. Fngr. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES [~.~O DIRECTIONAL SURVEY REQUIRED [] No CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES ,.,~iNO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO.. 7 ~-' ~/ APPROVAL DATE December APPOVED BY ~~----'~ ~ TITLE. C~i 27m~vl 6/ ' f ~' ' *See Instruction On Reverse Side 7, 1978 DATE 12/7/78 . ~s Ne R~rks 4. Is well *-c'ated pro[~r dSstance ~rc~ property line ......... ~ .... 5. Is we~l locahed proper dist~ce frem other wells .......... 6 Is sufficient ~dedicated acreage available in this 7. Zs we~l ~¢ be devSae:d ....................... ~ .... I~ o~r~tor the one7 a~ec~ed ~arky ................ .0. D~e~ o~r~ter have a ~nd 5n ~rce ................. L1. 5s a conse~a[ion order needed ................... ]2. Is adminisLrative approval needed ........ ......... 13. is conductor string provided .................... ~ Item Approve Date 4. Is enough cement used to circulate on conductor ~td surface .... Will cement tie in surface aa~d intermediate or production strings · ~. Will co?,eht cover all kno~ productive horizons .......... ~ t7. Will surface casing protect fresh water zones ........... ~ kS. NL].i ail c'asing give adequate safely in collapse, tension L9. Ekes ~ON{ "-:nve sufficient pressure rat~g - Test to ~0 oD psig · 20. ~fe.s D~.~_~2q r:: '.,roved Pi~ of ~ration ............... __ Ccmf.:a ny lk':- O (3) Admin. ( ,/:'~' ApProval Rec~nded: Ceo!~: ~ ~qineering: ~vi sed 4/14/78 Well Histo.ry File APPENDIX Information of detailed nature that is not particulady 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 APPENDIXi No Special'effort has been made to chronologically organize this category of information. DRESSER Al'LAS 716 TAPE FORMAT EO.J.~.?iJA.!._.....CON~!_.5..I.8......... O.F.........A .~.~.E.A.D...g.H.....B.E C 0 RD .. C 0 N I A I N I N G P E R T I N E N T ....... FOLLONED BY THE DATA RECORDS, -[H£ HEAmE~ gEC~g~ OF. EACH CU_R..,~g .... !,B[...,.,.DA!6,_,,.FOH..CUB~E 1 IS FOLLOWED BY THE DATA SIZE MAY BE COMPUTED BY THE FEE~ : NUMBER OF SAMPLES OF EACh. CURVE PER RECORD(I.E, I25) -~F IELD FIELD DESCRIPTION POSITION !.ii 'iii. ii iii J - S T A R T S TOP · 1 EPILOG COMPUTATION NUMBER t ~ FP , 3 WELL NAME 85 16~ AN , 5 FILLER 167 168 , 7 I'APE STARTING DEPTH 2~9 252 FP · 9 DATA LEVEL SPACING 257 260 FP 261 262 INT , CHAR. N OF BYTES, * 80 · 80 2 2 * 80 * ~ · 2 * 2 26~ · 268 FP ~ * 276 8 * ***************************** OF FILE MARK. THANKS, ECC N.JMBE. R 59q, O0 ARCO OIL AND GAS .... NGI 15 .... LIBRARY ...............................~RUDH~:`~.```.`.~`~`~!~`.=`=::.`i~`:~`:~i;~.~V~;~¥:`.S~`2~T~?;:~!?...~.~¥~..F~`~F`.AY . S_EC ,.1. ~IN-_ i~-E ''2'':'; .............. }~';-2~'2-S-':-'"':"?='7'-';:'":.NORTH ....... ';:}SL ........ 0~ E, A ~ ASKA 3 CUR~ES : ................... ............ ~,,R,0.L:F'=T'"'?~'- .......... ':' -. _. . .~. 0 00 --'%'SFT"F; ........... 7F;O T¥'"'~¥TT'¥""-'¥':'??FS:"¥':'-"':'"¥7'":'"'"¥"--:'0 TO - 8~O0, O LEVEL ~PAC~NG 0.5000 .................. :"-V'""'?:'::":?"'"~'S:":~¥':'?':"' :::-"-"' -¥~"::';' ?':':'-"-'%::~¥" ¥;?S'--S--'c='''': '-'-' T: ...... ' ....... : ..... ............ :':"-~-77S '~ 7 S'. S' .~'.'~': '~. ':.: ~" ~' ~. '~"~'.~' .':.'.~ '.'.'. 'S' '~"~/S'S', '.'~ ~,' 'S ~.-~"7~:~.~'. 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'736 l). 500 6098. ~57 -O. 055 1455.000 0.5O0 609t~. 357 -0. o55 455. 000 ~.771 0.500 :15'1 -0.055 455.000 500 ] 57 -0.~55 000 70 ? 500 ]57 -0.~55 000 o60 CbbH GR N C !q L NCNL C t., [., 8 GR NPhl Cbh8 NPH[ NC Nb i'd p H t FC Hb ro C i,J b C Lb8 r,~ C a b Ci.~bd GR h C !.~ b CLL, 8 NPHI {~ C N L V g 1.~ U 1:. 2~9.102 51.219 47. 998 3o.:1. 1.50 1 !3 1.0u0 289.102 51.219 ~1.998 i512.000 2~9.10:2 51.219 ~1.99~ 3t53. 150 I ~8'? ,000 289.1u2 51.219 ~1.998 303.750 lqqo.uO0 2~9.102 5i.219 4'1.998 363.750 1433.000 289.102 51.219 4'1.998 i~90.000 289.102 51.219 4'7.998 303.750 289.102 51.219 3e3.?~0 1520.o00 4 t O0 o 000 :i 0 ti 0 . 000 ~t 9 £~ 0.000 :~ 80 t). 37".0 ()00 36 (') (1 . 00 (') ~500.000 Gk GR F C H b SP GP GR GR F ('7 I,~ FCNL SP G~ GR GR G~ GP G GR i~ C I'~ b ,5 F' GP G t: (; R V A b o E, 59.844 5E.031 2.11.5 31.047 3~6.250 -u~,. 625 59.844 58.031 2.115 28.500 -o4.625 59.844 58.031 2.11.5 308. 750 -~4.625 59.84,4 58.0 31 2.115 31.141 30 b. 25 () 59.844 5~ 2.115 37.~44 40~. 75O -64.~25 59.~4.i 58.031 2.115 54.531 231.]75 ,.,. b 4.625 59.844 58.031 2.115 295. 500 -6.4 .t25 59.~44 58.031 2.115 254.750 C C l J L D CALl ¢I 1,[) C I~LD CAI, I ClbD C L b D C ,h b i NHAT C C L b V CALl 1.~ b A T aPH 1 C 1.bD C L [, D CALl Clbb C i, b CALl i'~PH 1 iL I b D C L b [.; C 3, 1~ [ C 1 hD C J,,, L CA I., t O 22 742 770 29.6 ] 0 i-~. 022 ~ .742 ~ .770 52 0. 022 ~. 742 3.770 54. a 07 2g.6~0 0. {)22 ,~. 742 3.77O 29.63o O. O 2 2 8.742 3.7 70 40.23 :) {.). 022 8.742 3.7'10 65,729 q).022 ~.742 3 · 770 5~.~39 t_t. 022 8.752 3.770 49.94! C:LL8 [.) [~ i4 kJ i~ C t'~ iL., C I D C N L C I ht~1 C 1., I., 5 t31;,! H u C D H H U i) H H U ;i C ixl L C 12 H H t; o. 5 <) 0 h098. 357 -0. bbs 1455.000 0.5 o O 609~. ~5 1 -0. 055 I 4bb. 009 ~.023 0. b 0 6098. 357 -0.h55 ~ 455. 4.152 0. 500 609u. J57 -0. 855 1455. 0. bO0 t: 09 ~. 357 -0. 555 lz~55.000 3.4,i5; 0. 500 e, oga. :lb 7 -0.o55 455.0o0 a.b99 O. 500 b098.35 7 -0. 055 I 455.<)00 4. 359 0.5 () 0 ~098. 35 7 t 455. Out: :~. 922 GR N C N b NPH[ i~ C N b C bbi~ GR NPHi F'C i~i b I'1C N L, Cbb8 oPHI PC '4 b NC .,.lb C b h 8 (;lq N P H l FC N b ~CNb Chh8 F C i~l b Cbb8 GR C b b 8 ~C~ b VALUE 269.102 51.219 g7.998 ~O3.750 1255.000 2~9.102 51.2:19 ~7.998 i330.000 289.102 51.219 41.998 303.150 289.1132 51 19 3 b 3.7 5 0 1427.000 289.102 51.219 41.99~ 3o3.?50 127~.000 2u9.102 5i.219 ~1.998 363.750 1289.000 2~9.102 51.21.9 {,53. 750 ] 330.u00 2~9.102 ~ .i !. 9 30 3. l~O 1275.000 31 00. OOfL) ,109{}, 000 2_ 9 U 0.00 O GP G P GR ? C N .[, SP GR k'C N b P (;F: OF:, G~ P. C i'.i l; 59. 52.031 2.115 19.25O -~4,625 58.031 2.115 36.4~69 287.500 -~4.625 59. 58.0.3! 2.115 ]38.250 -64.625 58.031 d.1t5 39.31~ 309, -64.625 59.844 2.115 ~.297 6.750 -e, 4.o25 5 9. ~ ,41 58.031 2.115 · ~4.28 1 308.2%o -e4 .~;25 59.844 2.1t5 20.547 ]40. 250 26 C L b i) CALi C CLbP r~ P H I C ] 1., [.) C I., b L ~ C A L [ N i:'id I C 1 I:D C[l, blJ C AL 1 N P h 1 C i L D C 1., b 1) C t.. 1., 1 raP, AT C l. bD C b b t.? N P ti ] CII,D ChI,D CAb] h P :'41 C 1 L b C i, ~_,, I) C~,Li 29.630 0. 022 8.742 3. '770 ,1.1 .966 29. e> 30 o. o 22 8.742 ~.. '77 ,') 53.414 29. e~ 30 0.022 3.770 29.~30 0 8.742 5 3. o 22 7.42 ~.770 ~O~ 29.e, 3o 8.742 3.770 55.~55 3.7 '70 () 8.742 ~. '779 e.,2. '~1 l t) .~: H i.J NCNb ~",: }-/k, 'i Cibra [J PFiu CI1 fa C L L ~ k;CNL {-~ P ~ C l C I,.L b C I b H C L L 5 C C L L 5 tt C !L' L, :4 t,;, h C t [: 0.500 b098. 357 -0. v55 455.00O 3.529 u. 50 O eng8. 357 -0.~55 1 455. 000 4.094 0.500 6098.35 7 -0. h5b ! 455. 000 0.500 009~. 357 -0. 655 1455.009 ~.121 0.500 6098.357 -0. t. 55 I 955. 000 o, 500 6098. J57 -0.e55 1 lb5. '4.2i5 ~J. 500 6{)9~ . 35 455. 0. %00 4.535 bi p~ ..... t. ~ Gl}"{ P C ¢,11~ r~C NL GR N P H L ~'CNb N C i'4 b C b b 8 NC CbL~ GR :',J P' H 1 ~ C r~t b C bL.,8 !,l p H 1 C [., L, ~ G~ ~x!P H j. f~ C i,~ b :sPHi ftC fib V Al..,tJt, 2e9.1o2 51.219 47. ~98 3~3. 750 1 o59.0O0 289. 102 47. 998 303.750 2~J5.000 Z~9.102 51.219 Jo3. 750 289.102 51.219 l'i .998 t3bb.O00 2B~.102 5t .219 3~3. 750 ! 3~ !. 2e9.102 363. 750 1207. 000 2~'~.102 51.219 41.99 ~ 3013. /bi) i531.000 2~9.1u2 3o 3. 750 l GF 59.844 59.03:1 2.115 19.0:~7 :Z40. 250 CIbD C L b D CALl v 4 Di~.E 29.r~30 u. 022 8.742 '~. 770 C C v 0.500 ~o98. 357 · -0. t:,, 55 1455.000 4. 742 Cl.,b8 N P t..~ I FC Nb i~,~ C tub VAbU~ 289.1 O2 51.21.9 41.998 2. 1 . 000 1024 't ,() ;5 t %i:.. 1 D L P T ~HC ~C AP[ ~: 0 AP 1 0 52 0 32 AP[ 0 0 o 0 0 0 AL UE -999. 52.9Ob 22..875 106.81 3 70.81 ~ 22 .isa 46. 71 71. ~ 2 5 71 .e, 25 ';l .t, 25 7 ! . 625 71 .fi25 '7 1 71 .625 71 .~5 71 .625 71 71 7! .e~25 95.750 1 o ~. ~ .750 84. O 0 0 77.75O 5~. ~75 SA. ~'75 5~, ~'7~ 5~. ~75 58. ~75 5~. ~ 75 5~. ~75 5H. ~'75 5a. ~75 5~. ~ 75 5a, b~. ~75 5~. ~ 75 5~. ~ 75 5~. %75 6C~90.0()0 5900. 5'80O. O00 5700. OOG 5600.000 55 u 0.0 0 0 S 4O0, 5 ~uO. 5000. 000 4qt~O. 000 4700.00 4 b O 0,000 ¢5G'0 0~n !400. 4 ~2G O, 000 4 000. (; 00 ~ 700. 000 ~bO0.00() ~ I. '11. /1, '7 1 . 625 71 .b25 71 .~25 71 .b~25 71.625 71 71. 71. 71. 71 7 ~. 7! 7~ '71. 7 ~ .b25 7 I. ~2~ 7) .b25 t't. 625 7 it')O0. 000 270 (), U 00 2605.500 GP D T I) T L,,E NGTH: 79/ 7/18
