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Home My WebLink About182-178 Imag'(e Project Well History File' Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / '~-- / -/~ 2 Well History File Identifier Organizing (do.el RFCC. AN DIGITAL DATA OVERSIZED (Scannable) · Color items: [3 Diskettes, No. [] Maps: Grayscale items: [] Other, No/Type [] Other items scannable by large scanner Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other ,s, Project proofing BY: ~ BREN VINCENT SHERYL MARIA LOWELl. Scanning Preparation ~ x 30 = BY: ~BREN VINCENT SHERYL MARIA LOWELL DATE: "/ Production Scanning Stage'l PAGE COUNT FROM SCANNED FILE: 15q P~COUNT MATCHES NUMBER IN SCANNING PREPARATION: /"~ YES : BY: Stage 2 NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO BY: BEVERLY BREN VINCE~ARIA LOWELL DATy..~/¢~/ ~. RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ General Notes or COmments about this file: Quality Checked (done) 10125102Rev3 NOTScan ned.wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 182-178 303-077 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20852-00 4. Location of well at surface 9. Unit or Lease Name 855' NSL, 1076' WEL, SEC. 14, T10N, R14E, UM X = 686169, Y = 5930896 Prudhoe Bay Unit At top of productive interval 362' SNL, 2374' WEL, SEC. 23, T10N, R14E, UM X = 684902, Y = 5929648 10. Well Number At total depth 398' SNL, 2446' WEL, SEC. 23, T10N, R14E, UM X = 684831, Y = 5929610 13-13 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool RKB = 89' ADL 028315 12. Date Spudded 11/11/1982 113' Date I'D' Reached I14' Date C°mp'' susp'' or Aband'l 1/25/1982 3/29/2003 115' Water depth' if °fish°re N/A MSL 116' NO' of Completions Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV setI 21. Thickness of Permafrost 9600 9231 FTI 8928 8592 FTI [] Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run DIL / SP / GR, HDT, DIL / SP / BHCS / GR, FDC / CNL / GR / Cai, CCL / GR / CNL, CBL ~, CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 79' 30" 500 sx AS II 13-3/8" 72# L-80 Surface 2586' 17-1/2" 2300 sx Fondu~ 400 sx Permafrost 'C' 9-5/8" 47# L-80 Surface 9201' 12-1/4" 500 sx Class 'G'~ 300 sx PF 'C' 7" 29# L-80 8867' 9597' 8-1/2" 325 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, N-80 8652'-8936' 8822' MD TVD MD TVD (Cut) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9060' P&A w/21 Bbls Class 'G' ~" 8648' Set EZ Drill with Whipstock on top 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL !GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE Bde,f...~..e~c...ri~ion of lith~[,0~!ty, fractures, apparent dips and presence of oil, gas or water. Submit core chis~. m,,,- ,~,' ... No core samples were taken.JUN JUN ?003 Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, nOR, and time of each phase. Sag River 9228' 8876' Shublik 9250' 8897' Sadlerochit 9327' 8970' ONV Contact 9448' 9086' R CE VED JUN 9 4 Ar~ch0rage ~31. List of Affachments: Summaw of Pre-Rig Work and Daily Drilling Repo~s 132. I hereby ceAify that the foregging is true and correct to the best of my knowledge Signed TerrieHubble ~~ ~ Title TechnicalAssistant Date 13-13 182-178 303-077 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drifting Engineer' Phil Smith, 564-4897 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5; Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL Well: 13-13A Accept: 04/21/03 Field: Prudhoe Bay Unit Spud: 04/27/03 APl: 50-029-20852-01 Release: 05/05/03 Permit: 203-036 Rig: Nabors 2ES Date PRE-RIG WORK 03/18/03 T/I/O = 280/320/0. MIT - OA TO 500 PSI PASSED. (CLAMP - PRE RWO). OA FL @ 84' (5 BBLS). PRESSURED OA TO 500 psi with 5.4 bbls of DieseL. STOPPED AT 100 PSI INCREMENTS TO INSPECT TREE. NO LEAKS VISIBLE AROUND TREE OR CLAMP. STARTED 30 MIN TEST. OA LOST 40 PSI IN 15 MIN. RE-PRESSURED OA TO 500 PSI. OA LOST 10 PSI IN 15 MIN AND A TOTAL OF 10 PSI IN 30 MIN. BLED OA TO 0 PSI. FINAL WHP'S = 280/320/0. 03/20/03 T/I/O=SI/320/0 MONITOR WHP'S (POST MITOA). NO INCREASE IN OAP. 03/28/03 MAKE UP BAKER BHA WITH HYDRAULIC RELEASE JDC W/EQUALIZING SLEEVE (OD=2.625"). PT MHA TO 3500PS1. RIH JET OVER IBP WITH 6 BBLS BIOZAN, INDICATION OF THE IBP EQUALIZING. CIRCULATE IN TUBING VOLUME OF S/W. NO LUCK LATCHING IBP. POOH. 03/29/03 PULLING OUT OF HOLE AFTER FAILED FISHING ATTEMPT. DOGS ON JDC WERE STUCK IN THE RELEASED POSITION DUE TO TRASH. RIH WITH SAME MHA & SHORT CATCH HYD JDC. UNABLE TO GET PAST THE TBG PATCH AT 2888' MD, POOH. PICK UP A SHORT CATCH JDC WITH A MULE SHOE BOTTOM & RBIH. INDICATION THAT IBP LATCHED, POOH. AT SURFACE, NO IBP CONNECTED, POSSIBLY DISCONNECTED AT TBG PATCH. MAKE UP NEW MHA WITH BAKER GRAPPLE TOOL. RIH W/NEW MHA. TAG BOTTOM @ 9406'.~OH W/IBP oF, ISH INTACT. MAKE UP MHA W/3" BALL DROP JS NOZZLE (7/8" BALL). RIH TO TD.,~/,~[_E~UMPING 1 Yo KCL DOWN BACKSIDE FOR WELL KILLTOP OFF WITH 89 BBLS CRUDE. LAY IN,~'I BBL~v~'I5.8# CLASS G CMT, 10 BBLS W/AGGREGATE. STARTED OUT GETTING 1:1 RETURNS BUT~D LOSING RETURNS ALMOST IMMEDIATLY AS WE STARTED LAYING IT IN THE ,... CEMENT. LOOKED LIKE WE SQUEEZED APPROXIMATELY 6 BBLS BEHIND PIPE LAYING IT IN. PULLED TO SAFETY. COIL WAS ON A VACUUM SO WE CONTINUED PULLING OUT OF HOLE TO MAINTAIN A CONSTANT WELLHEAD PRESSURE OF 250 PSI, ATTEMPTING NOT TO SQUEEZE AWAY ANY MORE CEMENT. PULLED UP HOLE UNTIL EVERYTHING STABILIZED AND HESITATED FOR 1.5 HOURS. ATTEMPTED TO PRESSURE UP ON CEMENT, PUMPED 1.5 BBLS, PRESSURE CAME UP APPROXIMATELY 30 PSI THEN FELL BACK OFF, HESITATE 1 MORE HOUR. LAUNCHED BALL AND 53 BBLS BIOZAN. STARTED GETTING GAS AT SURFACE AS SOON AS WE STARTED THE CLEAN OUT. 03/30/03 CONTINUE JETTING OUT OF HOLE POST P&A.. RETRIEVE BALL FROM NOZZLE AND STAB BACK ON WELLHEAD TO FIND TOP OF CEMENT. TAGGED CMT TOP AT 9060' CTMD, PRESSURE TEST CEMENT TO 1000 PSI. POOH. FREEZE PROTECT TBG TO 2000' WITH 60/40 MEOH. RIG DOWN. JOB COMPLETE. 04/01/03 DRIFT W/3.10" CENT, TT LOC. LOCATED TT @ 8913' SLM + 11'= 8924' ELM. TAGGED CEMENT @ 9033' ~'~ SLM + 11' = 9044' CORRECTED. PT CEMENT TO 900 PSI W/TRI-PLEX, GOOD. (PRE CHEM CUT / SDTRK). LEFT WELL SHUT IN. 04/02/03 JET CUT 4.5" TUBING AT 8652', WITH A 2-15/16" JET CUTTER, TIED INTO SCHLUMBERGER "BRIDGE PLUG RECORD" DATED 16-SEP-1994, CUT 6' BELOW THE TOP OF THE FIRST FULL JOINT ABOVE GLM #2, TD WAS NOT TAGGED, TUBING TAIL SEEN @ 8936'. TOOL STRING - 2 WT BARS, CCL, SAFE HEAD, 3.0" CAGE CENTRALIZER, JET CUTTER. TOOL LENGTH 20'. SHUT IN. 04/03/03 MIT- T X IA TO 3500 PSI, PASSED. .,. BP EXPLORATION Page 1~1~I~ Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: REENTER+COMPLETE Start: 4/21/2003 End: 5/5/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4~20~2003 10:00 - 15:30 5.50 MOB P PRE Turnkey rig move. Prep rig for move, RDMO C 1 la to center of Pad. Safety meeting w/all personnel for rig move. 15:30 - 20:30 5.00 MOB P PRE Move Sub Base f/C Pad to DS 13, 11.2 miles 20:30 - 00:00 3.50: MOB P PRE Move Pits, Camp and Shop, while Lay herculitefor Sub Base, MIRU on DS 13 - 13a, raise and pin derdck, and cattle chute, bridal dh, pin top drive to blocks, hang bridal lines. 412112003 00:00 - 01:30 1.50 MOB P PRE Finish moving pits, camp and shop to DS 13 01:30 - 04:00 2.50 MOB P PRE Move in, spot pits, camp and shop, spot cuffings tank, Ru electrical hook ups and lines 04:00 - 04:30 0.50 RIGU P PRE i Pre spud meeting, accept rig 0400 hrs, 4/21/2003 04:30 - 06:00 1.50 WHSUR P DECOMP 'Install secondary annulus valve, Ru line from wellhead to cutting tank, taking on seawater. Test surface circ lines. 06:00 - 09:30 3.50 CLEAN P DECOMP Circ freeze protect from well w/8.4 ppg seawater. 210 GPM @ 620 psi. 09:30 - 10:30 1.00 WHSUR P . DECOMP Dry rod BPV. Test from below to 1000 psi. O-K. Blow down surface circ lines. 10:30 - 13:00 2.50 WHSUR P DECOMP ND tree and adapter flange. Terminate control lines. Function LDS. 13:00- 15:00 2.00 BOPSUF P DECOMP NU BOPE. 15:00- 15:30 0.50 WHSUR P DECOMP Install test dart in BPV. 15:30 - 16:00 0.50 BOPSUI; P DECOMP PU & run testjt. 16:00 - 22:00 6.00 BOPSUF P DECOMP Test BOPE to BP & AOGCC regs. 250 psi Iow / 3500 psi high. Test witnessed by Jeff Jones of AOGCC. LD test jt. 22:00 - 22:30 0.50 WHSUR P DECOMP Pull test dart from BPV. 22:30 - 23:30 1.00 WHSUR P DECOMP RU DSM lubricator. Pull BPV. RD DSM lubricator. 23:30 - 00:00 0.50 PULL P DECOMP MU Baker tandem spear. Engage tbg hanger. Unseat same wi 250k. Work 4 1/2" tbg free w/275k. Pull tbg hanger to rig floor. String wt 140k. 4/22~2003 00:00 - 00:30 0.50 PULL P DECOMP LD Baker Tandem 4 1/2" spear. LD tbg hanger. 00:30 - 02:00 1.50 PULL P DECOMP Circ 'Soap' sweep surface to surface. 400 GPM @ 1700 psi. RU 4 1/2" handling equip. RU Camco control line spooling equip. 02:00 - 09:30 7.50 PULL P DECOMP POH LD 4 1/2" tbg. Recover 206 jts 4 112" BTC, L 80 tbg. 9 GLM's, 1 SSSV, 1 seal assy. 20 SS bands. Tbg was only 30% cut by 'Jet' cutter. 09:30 - 10:30 1.00 PULL P DECOMP RD 4 1/2" handling equip. Clean & clear rig floor. 10:30 - 11:00 0.50 EVAL P DECOMP Test casing 3500 psi. O-K. 11:00 - 11:30 0.50 TA P DECOMP PU & MU Baker 'Multi string' casing cutter. 11:30 - 12:00 0.50 BOPSUF. P DECOMP PU test plug & test jt. Test lower pipe rams to BP & AOGCC regs 250 psi Iow/3500 psi high. LD test jt & plug. :12:00 - 13:00 1.00 TA P DECOMP RIH w/'Multi sring' cutter to 169 ft. 13:00 - 13:30 0.50 TA P DECOMP Displace well to 'Dead' crude oil. 126 GPM @ 850 psi. 13:30 - 14:30 1.00 TA P DECOMP PU to 130 ft. Cut 9 5~8" casing. POH LD casing cutter. 14:30 - 15:00 0.50 TA P DECOMP Clean & clear rig floor. 15:00 - 16:00 1.00 WHSUR P DECOMP PU pulling tool. Attempt to pull 9 5/8" pack off. No success. LD pulling tool. 16:00 - 18:00 2.00 TA P DECOMP MU Baker 9 5/8" casing spear. Engage 9 5/8" casing at surface. Work pipe up to 200k, obtain movement. Pull to rig floor. Release spear LD same. 18:00 - 19:30 1.50 TA P DECOMP LD 9 5/8" casing. Recover 100 ft & pack off. 19:30-20:00 0.50 TA P DECOMP RIH w/ muleshoe to 320 ft. 20:00 - 21:00 1.00 TA P DECOMP Reverse circ 'Dead' crude oil. 168 GPM @ 230 psi. Printed: 5/12/2003 11::24:31 AM BP EXPLORATION Page 2~ Operations Summa Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: REENTER+COMPLETE Start: 4/21/2003 End: 5/5/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: N^BORS 2ES Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 4/22/2003 20:00 - 21:00 1.00 TA P :DECOMP Clear rig floor. POH LD mule shoe 21:00 - 22:30 1.50~ TA P ~ DECOMP PU & RIH w/647 ft of 5" HWDP, 13 3/8" RTTS prk w/'Storm' valve. Set pkr @ 120 ft, w/valve @ 110 ft. P/U Wt 60k, S/O Wt 60k. Test below pkr 1000 psi O-K. 22:30 - 23:00 0.50 TA 3 DECOMP Displace well w/'Soap' sweep & clean seawater. 300 GPM @ ,60 psi. 23:00 - 23:30 0.50 TA 3 DECOMP POH LD running tool for 13 3/8" RTTS. 23:30 - 00:00 0.50 TA 3 DECOMP Clear & clean rig floor. 4/23/2003 00:00 - 01:30 1.50 BOPSUi; 3 DECOMP ND BOP. Rack back on stump. 01:30 - 04:30 3.00 WHSUR 3 DECOMP Strip down & remove well head to 13 3/8" csg stub. 04:30 - 00:00 19.50 WHSUR 3 DECOMP Dress 13 3/8" csg stub. Preheat to 600 degrees. Weld on FMC SOW. Cool down head to 275 degrees. Test w/Nitrogen - failed. Identify leak and dress same. Preheat to 600 degrees. Re weld head in leak area. Wrap & let cool down. 4/24/2003 00:00 - 05:30 5.50 WHSUR 3 DECOMP Allow 13 3/8" FMC SOW to cool. 05:30 - 06:30 1.00 WHSUR 3 DECOMP RU test equip, test 1560 psi / 15 mins. 06:30 - 09:00 2.50 WHSUR P DECOMP NU FMC csg / tbg spool. Test 1000 psi / 15 rains. 09:00 - 11:30 2.50 BOPSUF.P DECOMP Drop 'Mud Cross' off of BOP. NU BOP & secondary annulus valve. 11:30 ~ 13:00 1.50 BOPSUF. P DECOMP PU test jt. Body test BOP to BP & AOGCC regs. 250 psi Iow / 3500 psi high. LD test jt. 13:00 - 14:00 1.00 EVAL P DECOMP Test casing to 1000 psi/15 mins. 14:00 - 17:00 3.00 PULL P DECOMP RIH w/retrieving tool for 13 3/8" RTTS. Displace well to 'Dead' crude. 126 GPM @ 170 psi. Latch RTTS, unseat pkr stripping thru Hydril as precaution. POH LD R'I'I'S. 17:00 - 23:30 6.50 TA P DECOMP MU 9 5/8" back off assy. RIH & space out @ 154 ft. Fill pipe w/ diesel. Back off 9 5/8" stub. Initial pressure 5500 psi, final pressure 800 psi. Total of 6.25 turns. 23:30 - 00:00 0.50 PULL :P DECOMP POH LD 9 5/8" back off assy. 4/25/2003 00:00 - 01:30 1.50 FISH P DECOMP Fin LD Back off assy. 01:30 - 02:30 1.00 FISH P DECOMP Clear & clean rig floor. 02:30 - 04:00 1.50 FISH 'P DECOMP MU 9 5/8" csg spear. RIH & engage 9 5/8" csg stub @ 134 ft. Back out w/10 turns. POH LD spear & 28.25 ft 9 5/8" csg w/ collar. Inspect threads on collar O-K. 04:00 - 05:00 1.00 FISH P DECOMP Clear & clean rig floor. 05:00 - 10:00 5.00 CASE P PROD1 RU 9 5/8" csg handling equip. MU Baker 'Screw In' guide w/ collar. RIH w/9 5/8" 47#, L- 80, BTC csg tagged @ 158', screwed into 9 5/8" csg, make up torque 9200 ftlbs 10:00 - 13:00 3.00 CASE P PROD1 RIH w/std of 4" DP inside 9 5/8" casing, displaced dead crude from well with seawater, POH w/std of 4" DP. Clean rig floor, handling tools and equipment. 13:00 - 14:30 1.50 WHSUR P PROD1 Split tubing head f/casing head, PU BOP stack/tubing head -2' 14:30 - 16:00 1.50 WHSUR P PROD1 Install 9 5/8" emergency slips, did not fit, were sifting to high in bowl. Slips were designed for a 12" bowl depth. Casing head SFAL installed had a 10" bowl depth. 16:00 - 17:00 1.00~ WHSUR N PROD1 Pulled and removed emergency slips 17:00 - 18:30 1.50 WHSUR N I SFAL PROD1 Sent emergency slips to Baker machine shop, removed bottom junk ring, and primary seal packing element. Cut and beveled bottom of slips to a 45 degree shoulder. Removed and cut off a total of 2.30". 18:30 - 20:00 1.50 WHSUR N SFAL PROD1 Installed 9 5/8" emergency slips with 200,000 lbs of 9 5/8" Printed: 5112/2003 11:24:31 AM BP EXPLORATION Page 3~ Operations Summa Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: REENTER+COMPLETE Start: 4/21/2003 End: 5/5/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: N^BORS 2ES Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 4/25/2003 18:30 - 20:00 1.50 WHSUR N SFAL . PROD1 string weight. 20:00 - 21:30 1.50 CASE N SFAL 'PROD1 RU casing cutter, cut 9 5/8" casing 6" above casing head, dressed stump for packoff 21:30 - 23:30 2.00 WHSUR N SFAL PROD1 Slacked off stack and tubing head, NU to casing head, break BOP stack at tubing head, install mud cross, NU BOP's 23:30 - 00:00 0.50 WHSUR N SFAL PROD1 MU packoff running tool to a stand of 5" HWDP 4/26/2003 00:00 - 04:00 4.001WHSUR N SFAL PROD1 RIH w/9 5/8" pack-off on 1 stand of 5" HWDP, unable to seat pack-off after serveral attempts, POH, RIH w/pack-off on 1 stand of 6 1/4" DC's, swallowed casing stump, bottomed out on top of emergency slips, lock down groove sitting 3~8" high above lock down studs, unable to run in lock down studs. Consulted w/FMC Anchorage office. 04:00 - 04:30 0.50 WHSUR N SFAL PROD1 Retrieved 9 5/8" pack-off 04:30 - 05:30 1.00 WHSUR N SFAL PROD1 Sent 9 5/8" pack-off to Baker machine to be cut down by 3/8" from bottom, as per FMC recommendations. Notified BP Anchorage base. 05:30 - 06:30 1.00 WHSUR N SFAL PROD1 Install 9 5/8" pack-off, RILDS 06:30 - 07:00 0.50 WHSUR P PROD1 Test 9 5/8" pack-off to 3800 psi, hold for 15 minutes, OK 07:00- 07:30 0.50 WHSUR :' DECOMP Set mouse hole, set wear ring 07:30 - 09:00 1.50 WHSUR :~ DECOMP Body test BOP (tighten upper mud cross bolts) and 9 5/8" casing at 250 psi and 3500 psi, chart and hold for 30 minutes 09:00 - 10:30 1.50 STWHIP 3 WEXIT PJSM, MU Mill Assy, RIH w/BHA to 971', CIO elevators 10:30 - 12:00 1.50 STWHIP :) WEXIT PU 4" DP, RIH to 1936', pipe handler on top drive not working 12:00 - 12:30 0.50 STWHIP :) WEXIT Service Top Drive 12:30 - 13:30 1.00 STWHIP N SFAL WEXIT Trouble shoot Top Drive, CIO pressure switch, pipe handler working 13:30 - 18:30 5.00 STWHIP :) WEXIT PU 4" DP, RIH, tagged at 8788' SLM 18:30 - 20:00 1.50 STWHIP 3 WEXIT Displaced well to 11.1 ppg LSND mud at 13 bpm, 3470 psi, '541 gpm, up wt 190k, dn wt 175k, rot wt 180k 20:00 - 21:00 1.00 STWHIP P WEXIT POH w/1 stand of 4'DP, slip and cut drill line 21:00 - 00:00 3.00 STWHIP P WEXIT POH to 2184' 4~27/2003 00:00 - 00:30 0.50 S'I'WHIP P WEXIT POH to BHA 00:30 - 02:00 1.50 STWHIP P WEXIT POH w/Mill Assy, LD jars 02:00 - 05:30 3.50 STWHIP P WEXIT PJSM, RU~,E'4i~ run 9 5/8" EZ Drill w/CPST setting tool and CCL to,,j~720', ~r, Fh CCL log, spot EZ Drill 4' above collar, set EZ Drill a[864/8~,ELM, had good surface indication of packer settin§~sl~ck off w/E-line, taking weight verifing EZ Drill was set. POT' RD E-line. 05:30 - 07:00 1.50 STWHIP P WEXIT PJSM, PU 9 5/8" whipstock assy, RIH to 83° 07:00 - 08:00 1.00 STWHIP P WEXIT MU MWD, upload tool, surface test MWD at 490 gpm w/1800 psi 08:00 - 09:30 1.50 STWHIP P WEXIT RIH w/BHA to 1041', CIO elevators 09:30 - 13:30 4.00 STWHIP P WEXIT RIH w/BHA on 4' DP to 8640', tagged EZ Drill, filled pipe and functioned MWD at 3283', OK 13:30 - 14:00 0.50 STWHIP P WEXIT Orient whipstock to 16 degrees LHS, set whipstock 14:00 - 18:30 4.50 STWHIP P WEXIT Milled window in 9 5/8" 47#, L-80 casing f/8615' to 8631' WOB 10- 15K, RPM 100 Flow at 487 gpm, 3235 psi Torque on 6 - 7K, Torque off 5-6K P/U 200K, S/O 175K, Rt 180K 18:30 - 21:00 2.50 STWHIP P WEXIT Drill f/8631' to 8647' WOB ~ ~--"-""'-' Io'~'l~w at 487 gpm, 3235 psi Printed: 5112/2003 11:24:31 AM · -- STATE OF ALASKA APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other /' [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I~ Development RKB = 89' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 8. Well Number 4. Location of well at surface 13-13 855' NSL, 1076' WEL, SEC. 14, T10N, R14E, UM X = 686169, Y = 5930896 9. Permit Num_.,ber At top of productive interval 182-178 / 362' SNL, 2374' WEL, SEC. 23, T10N, R14E, UM X = 684902, Y = 5929648 10. APl Number At effective depth 50-029-20852-00 301' SNL, 2263' WEL, SEC. 23, T10N, R14E, UM X = 685012, Y = 5929712 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe 398' SNL, 2446' WEL, SEC. 23, T10N, R14E, UM X = 664831, Y = 5929610 Bay Pool 12. Present well condition summary Total depth: measured 9600 feet/' Plugs (measured) IBP Setat8~ (03/98) true vertical 9231 feet /' / Effective depth: measured 8928 feet Junk (measured) true vertical 8592 feet Casing Length Size Cemented MD TVD Structural Conductor 79' 20" 500 sx Arcticset II 79' 79' Surface 2586' 13-3/8" 2300 sx Fondu, 400 sx Permafrost 'C' 2586' 2586' Intermediate Production 9201' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 9201' 8850' Liner 730' 7" 325 sx Class 'G' ~'' 8867' - 9597' -'""~8534' - 9228' Perforation depth: measured 9228' - 9252', 9254' - 9262', 9270' -9282', 9328' - 9338', 9342' - 9346', 9346' - 9366', 9376' - 9396', 9398'- 9404', 9408'- 9415' true vertical 8875' - 8899', 8900' - 8908', 8916' - 8927', 8971' - 8980', 8984' - 8988', 8988' - 9007', 9017' - 9026' 9038'- 9043', 9047'- 9054' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 to 8936' Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker '3-H' packer~'~-l/2" Otis 'DBE' SSSV Nipple at 2200' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation' 15. Status of well classifications as: March 10, 2003 / [] Oil [] Gas [] Suspended 16. If proposal was verbally approved Service Name of approver Date Approved Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoin~l is true and correct to the best of my knowledge ' ., Signed ei,,,saaoson ~.~ ~ ~,,~-.-------------- Title Senior Drilling Engineer Date ~l~ff, Ot Conditions of Approval: Notify Commissio~n~so representative ma~itness iApproval No. 3 Plug integrity _~ BOP Test ~ Location clearance __ I Mechanical Integrity Test /'~ Subsequent form requir]d 10- ~-~7 T'9...%~' ~O{:)~ '~ ~'o(;') Approved by order of the Commission ~ ~, ~ Commissioner Date ~)/7///P_,~ Form 10-403 Rev. Submit In Triplicate O bp To: From: Winton Aubert - AOGCC Phil Smith - BPXA GPB Rotary Drilling Date: March 6, 2003 Subject: Reference: DS 13-13 Application for Sundry Approval - P&A for Sidetrack Operations APl # 50-029-20852-00 Approval is requested for the proposed P&A of PBU well DS13-13. This well has no existing value in its current state and location. Well 13-13 was originally drilled and completed in 1982 and produced 3000 BOPD at solution GOR. A number of acid jobs were performed on the well and it was hydraulically fractured in 1992. "The well was shut in 1997 due to a Iow oil rate and a high water cut. The sidetrack is required because the current production wells between the injectors, parent well 13-13 and well 13-28, are both inoperable and cannot be returned to production profitably, f Prior to sidetracking to the new bottom hole location, damaged 13 3/8" casing at the screw-on starting head will require repair. After securing the well, the surfa.ce.~casi~g will be removed~below the damaged area and the wellhead will be replaced with a weld-on style'FM~ig bore system. The DS13-13A sidetrack is currently scheduled for Nabors 2ES beginning around mid April 2003, after a K-04B sidetrack. The pre-rig work for this sidetrack is planned to begin after the Application for Sundry is approved and at the convenience of the Wells Group. Scope Pre-Ri;I Work: 1. Install wellhead clamp support ring (procedure on file with drilling engineer and Vetco Gray.' 2. Test the Gray Gen-3 9-5/8" mandrel packoff and t~ubing hanger seals to 5000 psi for 30 minutes. Check the tubing hanger LD$ for proper function." 3. RU Slickline, drift the tubing to 3.0". Recover the IBP from the tailpipe. Tag PBTD. f 4. RU CTU. Fluid-pack the IA and lay a cement aband~t plug from PBTD (or top of fill) to at least 100' above the top perforation. Preferred TOC is ;)Yg~' MD, or_+100' below the tubing,tail above the top perforation. Minimum cem%0t requir~f-(assume top fill at bottom perf): 365'?'14~b'01s 5. Confirm top of cement with slickline tag. / 6. Rig up E-line. Jet cut the 4%" L-80 tubing 6' below the top (35' above the bottom) of the first full joint above GLM #2 at 8701'. This will place the cut at _+8642' MD reference N2ES rig floor, corrected 10' higher than original KB. Schlumberger's 2 15/16" jet cutter will pass through the minimum restriction at the tubing patch. 7. Displace the well to clean seawater through the jet cut and freeze protect the top 2200' MD with diesel. Freeze protect just top 100' if rig i~is less than 3 days from moving onto the well. Pressure test (CMITxlA) to 3500 psi for 30 minutes. "The bottom 4~0' of the 9 5/8" x 13 3/8" shoe is cemented, Arctic Pack fills the annulus above TOC to surface../ 8. Bleed tubing and annuli pressures to zero. If the well passes the pressure test against the abandonment plug, do not set a BPV in the tubing hanger. Secure well. 9. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. DS13-13 Application for Sundry CAINNED ][ Ri.q Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4 %" tubing from cut. 5. Pressure test the well to 3500 psi. Be prepared to pick up an RTTS if casing test fails. 6. Run GPJJB on e-line to 8650'. 7. RIH with Halliburton 9 5/8" composite bridge plug and set at 2000'. Pressure test to 3500 psi. 8. RIH with multi-string cutter. Displace the top 100' of casing with dead crude and cut the 9 5~8" casing in the center of the second joint below the mandrel hanger. 9. Pull 9 5/8 packoff, RIH with spear and recover the cut section of 9 5/8" casing. 10. Make up 13 3/8" storm packer and set just above the top of the 13 3/8" casing stub. Circulate to seawater above the bridge plug. 11. Pick up a 13 3/8" test packer and test the bridge plug to 1000 psi. 12. Drain the BOP stack. ND BOPs and tubing spool. ND and remove casing spool. 13. Remove support clamps from the 13 3/8" casing head and cut off the original base flange. 14. Dress off the 13 3/8" casing stub and install a new bell nipple and FMC Big Bore starting head. 15. Install FMC casing and tubing spools. 16. NU and test BOPs. 17. RIH w/bridge plug recovery tool. Swap the seawater for dead crude and recover the bridge plug. 18. RIH with 9 5/8" back-off tool and back off the cut stub. 19. Spear the cut stub, POH, LD spear and fish. 20. Make up the new top joint of 9 5/8" BTC on a Baker guide sub, screw into existing 9 5/8" casing. 21. Hang off the casing on slips, install packoff and wear ring. 22. Test 9 5/8" casing to 3500 psi again against the bridge plug. 23. Pick up an 8 %" mill and mill the composite bridge plug. RIH to top of tubing stub and circulate the well to milling fluid. POH. 24. RIH with 9 5~8" bottom-trip whipstock and milling assembly. 25. Orient and set bottom trip whipstock such that KOP is at 8625' MD. Mill window, POOH. 26. RIH with 8 %" drilling assembly to top of window. Perform FIT to 12.5 ppg. 27. Kick off and drill 8 %" section (+700') to top of Sag River formation. POH. 28. Run and cement 7" 26# drilling liner. Displace with drilling mud. 29. RIH with 6 1/8" drilling assembly, test casing and liner lap to 3500 psi, drill out the bridge plug and shoe tract. 30. Change out mud to FIo Pro drill-in fluid. Perform FIT to 10 ppg EMW. 31. Drill the 6 1/8" production hole (+1750') as per directional plan to TD well at _11,081' MD. 32. Short trip, CBU, spot liner running pill, POH. 33. Run a 4 ~", 12.6#, slotted x solid L-.80 production liner to TD. Circulate the well to clean seawater at the liner top, POOH. 34. Run 4 %", 12.6# L-80 completion tying into the 4 ~" liner top. 35. Set packer and test the tubing and annulus to 3500 psi for 30 minutes. 36. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 37. Freeze protect the well. 38. Rig down and move off. Post-Ri.q Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-rig Start Date: Estimated Spud Date: 3/13/03 4/10/03 Phil Smith Operations Drilling Engineer 564-4897 DS'13-13 Application for Sundry TREE = GRAY GEN 3 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 89' BF. ELEV = ? KOP = 4600' Max Angle = 29 @ 7700' Datum MD = 9242' Datum TVD = 8800' SS 13-13 Pre-Rig 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2586' /, Minimum ID = 3.250" @ 2888' 4-112" Merla Patch (Set 8/9/92) Chem Cut-8652' I TOP OF 7" LNR Id 8867' SAFETY NOTES: TROUBLE WELL - TX IA COMM, FTS PATCH @ 2888', 3.25" ID MERLA OX X FORM COMM (to 13 3/8" BRADENHEAD CLAMP). SECURED LONG-TERM WITH IBP IN TT. 2200' I~ 4-1/2"OTISDBESSSV NIP, ID=3.813" I 2888' 4-1/2" MERLA PATCH SET 08/09/92, ID = 3~.5.~' GAS LIFT MANDRELS IsTI ~ I~DI D~I~IVLVlLATCHI ~ORTI ~^TE I ~1 1 126951289~1 1 I O~Sl IRA I I I 1 2 14805147991 1 417210170291 22 I OT~I IRA I I I 1 718592182771 21 i0~1 I Ro-~ I I I I 9 18775184481 21 I OTSl IRA I I I 8801' I-~ 4-1/2"BOTmRASSY 8822' I--~ 9'5/8"X4-1/2"BOT3'HR<RI 8917' I--~ 4 1/2" OTIS XN NO-GO NIP, ID = 3.725" I "~' 14-1/2" TBG-PC, 12.6#, N-80, 0.0152 bpf, ID = 3.958" Id 8936' TOC -9050' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9201' 8938' I-I 4'1/2"WL~1 I 8924' I-I ELM~LOGG~01,17/66 I PERFORATION SUMMARY REF LOG: BHCS ON 11/24/82 ANGLE AT TOP PEP, F: 18 @ 9228' Note: Refer to Production DB for historical perf data SIZE SPF I~I'ERVAL Opn/Sqz ' DATE 3-3/8" 4 9228-9262 O 08/09/92 3-3/8" 4 9270-9282 O 08/09/92 3-1/8" 4 9328-9338 O 04/11/84 3-1/8" 4 9342-9366 O 01/17/86 3-1/8" 4 9376-9404 O 01/17/86 3-1/8" 4 9408-9415 O 01/17/86 I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 9597' [~']-~ 9600' 11/28/821 I OR~"'~AL COMPLETION os/19/871 I Rvvo (CHANGEOUT'mG) 11/2o/ooI S~H ICONV~E~O CANVAS 10/2~/011 ~ ICO~'~NS 03/03/03 ~ PGS ~ Proposed Pre-Rig COMMENTS PRUDHOE BAY UNIT WELL: 13-13 PERMIT No: 82-178 APl No: 50-029-20852-00 SEC 14, TION, R14E 2443.26 FEL 396.1 FNL BP Exploration (Alaska) WELLHEAD: FMC BigBore ACTUATOR = AXFI SON KB. ELEV = 89~ BF. ELEV = KOP = 4600 IVbx Angle = 29 @ 7700' E~tum MD = 9242' Datum TVD = 8800' SS 13-13A Pro 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2586' m-~ 4 1/2" 12.6# L-80 IBT tubing 7" 26~ L-80 Liner Top / Tieback 75, I osed SAFETY NOTES: 13 3/8" x 9 5/8" annulus bottom 400' cenqonted. Arctic-Pack above to surface. 2200' Id 4-1/2" X Nipple, ID=3.813" I GAS LIFT MANDRELS ST. MD TVD DEV TYPE VLV LATCH PORT DATE 6 OTIS RA 5 OTIS RA 4 OTIS RA 3 OTIS RA 2 OTIS RA I 9050 OTIS RD 5/8" Whipstock I Window Id 8625' IC'e'i°a'C~' H ~8700' I 14 1,2'BOTPBRAssembly I--t 8801' I ITOPOF 7" LNR i-m 8867,I 91oo' I-I4 1/2" X Nipple 3.813 ID I 9i40' 1-141/2" x 7" Baker S-3 ~ I I 9160, H4 1/2" X Nipple 3.8131D I I 9180' I-1Top41/2"solidxslotted J ) 9330' I-17" 26# L-80 mod-BTC 141/2"wLEG 8936' I IT°Pcern' I-I 19-5/8, ~G, 47#, L-80, ID: 8.681" 9201' ABANDONED PERFORATION SUMMARY REF LOG: BHCS ON 11/24/82 ANGLEATTOP PERF: 18 @ 9228' Note: Refer to Production DB for hbtorioal perf data sEE I s.. I iN.~VAL I Opn/Sqz I DATE I 3-3/8-1 4 I 9228-g415 I s~ 111/01/021 14 1/2" Solid (unce~nted) I-t -9,550'1 141/2"12.6#L-8°siotted I-1 ll,osl' I CA-RD-T-2 - 07/30/97 7- LNR, 29#, L-80, 0.0371 bpf, ID: 6.184" Id 9597' r~---]-1 9600'i DATE REV BY COMMENTS DATE REV BY COMMENTS 11/28/82 ORIGINAL COMPLETION 05/19/87 RWO (CHANGEOUT TBG) 11/20/00 SIS-JH CONVERTED TO CANVAS 10/25/01 RNFFP CORRECTIONS 12/05/02 PGS PROPOSED SDETRACK PRUDHOE BAY UNIT WELL: 13-13A PERMIT NO: 82-178 APl No: 50-029-20852-01 SEC 14, TION, R14E 2443.26 FEL 396.1 FNL BP Exploration (Alaska) GeoQuest I~00 W. International Airport Road Anchorage, AK 9~618-1199 ATI'N: Sherde NO. 897,5 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant I ;3001 Porcupine Drive Anchorage, AK 99501 10/7/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 1-6 ~ ~'"--'- t '~ PERF RECORD (9-20-94) 1 1 ;D.S. 2-lA ~ (~--- I-~ ~ STATIC PRESSURE SURVEY (9-19-94) 1 1 'D.S. ;3-;31 ~. u{ .- c~,-L_ BRIDGE PLUG RECORD (19-1,3-94) 1 1 D.S. 4-2"7~ - (o _~ TUBG CIJITER RECORD (9-1;3-94) 1 1 D.S. 5-4 -~ t~ ~ ~ c~ STATIC PRESSURE SURVEY (9-19-94) 1 1 D.S. 5-19 ~f~ "-'-/~X' STATIC PRESSURE SURVEY (9-20-94) 1 1 D.S. 7-24 ~,'~t.~-~ ~.~ STATIC. BHP SURVEY (9-19-94) 1 1 D.S. 9-26 _ POGLM SEUING RECORD (;9-11-94) 1 1 D.S' 1;3-1;3 c~ ~.. -I'7 ~'/ LEAK DE~ECTION (9-20-94) 1 1 D.S. 15-;37 ~ ~ ~ "7 ~'-~.~ STATIC BHP SURVEY/PERF RECORD (9-15-94) 1 1 D.S. 16-5 ~ I STATIC BHP SURVEY/INJEC PROFILE (9-16-94) 1 1 D.S. 16-14 ~' l "- ~ ~ PROD PROFILE (9-8-94) 1 1 D.S. 16-22 ~'<~-- ~'-~ PERF RECORD (;9-11-94) 1 1 SIG Pleas& sign and retuh~ one copy of this transmittal to Sherrle at the above address. Thank you.' DATE: STATE OF ALASKA ALASKA "AND GAS CONSERVATION CC-'~.41SSlO~ I{IG IN REPORT SUNDRY WELL OPErlATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X , , Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM RECEIVED At effective depth At total depth Alaska 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM ;Anchorage 6. Datum of elevation(DF or KB) 89' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-13 9. Permit number/approval number 82-178 10. APl number 50 - 029-20852 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9600 feet 9231 feet Plugs(measured) Fill @ 9376' MD (9/15/92) Effective depth: measured 9376 feet true vertical 9016 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 500 sx AS II 79' 79' Sudace 2497' 13-3/8" 2300 sx Fondu & 400 sx PFC 2586' 2586' Production 9112' 9-5/8" 500 sx CIG & 300 sx PFC 9201' 8849' Liner 730' 7" 325 sx CIG 9595' 9223' Perforation depth: measured 9228-9252'; 9254-9262'; 9270-9282'; 9328-9338'; 9342-9346'; 9346-9366'; 9376-9396'; 9398-9404'; 9408-9415' true vertical 8876-8899'; 8900-8908'; 8916-8927'; 8970-8980'; 8983-8987'; 8987-9006'; 9016-9025'; 9037-9042'; 9046-9053' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80, PCT @ 8936' MD Packers and SSSV (type and measured depth) BOT 3H packer @ 8822' MD; 4-1/2", Otis DBE SSSV @ 2200' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 798 1200 1080 -- 783 1432 1460 Tubing Pressure 260 258 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended,, Service, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,__~ ¢--~- ~-4/..,d~ Title Sr. Area Operations Engineer Form 10-4~4 ~ev 06/15/88 u/ on"~lq o r'tTlx' r,r,- O.~^! _ Date SUBMIT IN DUPLICATE 13-13 DESCRIPTION OF WORK COMPLETED TUBING PATCH INSTALLATION & FRACTURE TREATMENT OF SAG / SHUBLIK / Z4 7/7/92: MIRU & PT equipment to 4000 psi. RIH w/CT & pumped 5 bbls of gelled sand slurry containing 700 lbs 20/40 mesh sand, & placed a prefrac sand plug to approximately 9366' MD, over the open perforations at: 9376 - 9396' MD (Z4) 9398 - 9404' MD (Z4) 9408 - 9415' MD (Z4) Ref. Log: BHCS 11/24/82. 7/9/92: RIH & tagged top of sand plug at 9377' MD. 8/9/92: Added perforations: 9254 - 9262' MD (Shublik A) 9270 - 9282' MD (Shublik B) Ref. Log: BHCS 11/24/82. Proceeded w/Tubing Patch installation following the add perforating as follows: Loaded wellbore w/Seawater, then RIH w/3.25" ID Merla Tubing Patch, and located the patch over the leaking mandrel at 2895' MD. Set patch at 2888.0 - 2809.5' MD (top to bottom elements). Pressure tested the 9-5/8" to 3500 psi OK. Rigged down. 8/1 I/92: MIRU & PT equipment. RIH w/CT mounted Inflatable Packer, and set packer at 9310' MD (element). Pumped a Perforation Breakdown Treatment, treating the perforation intervals located above the packer, at: 9228 - 9252' MD (Sag) 9254 - 9262' MD (Shublik A) 9270 - 9282' MD (Shublik B) Ref. Log: BHCS 11/24/82. Pumped 120 bbls 1% KCI Water w/Surfactant & Scale Inhibitor @ 6 bpm, followed by 125 bbls 1% KCI Water Flush @ 10 bpm, followed by Shutdown. Released & POH w/packer. Rigged down. 8/14/92: MIRU & PT equipment. through the open perforations located above the sand plug at: 9228 9254 927O 9328 9342 9346 Pumped a Hydraulic Fracture Treatment using 16/20 mesh proppant, RECEIVED Ref. Log: BHCS 11/24/82. - 9252' MD (Sag) - 9262' MD (Shublik A) - 9282' MD (Shublik B) - 9338' MD (Z4) - 9346' MD (Z4) - 9366' MD (Z4) OCT 1 2 1992 Alaska 0il & Gas Cons. Commission Anchorage Pumped 300 bbls 20# Gelled Pre Pad @ 50 bpm, followed by Shutdown. ISIP @ 1200. Resumed pumping 175 bbls Crosslinked Pad w/ESL @ 30 bpm, followed by 320 bbls Crosslinked Slurry w/proppant stages @ 1 - 10 ppg, followed by 142 bbls Flush, followed by Shutdown. Placed a total of 33,200 lbs of proppant into the formation. Rigged down. 8/15/92: Performed a proppant/sand plug fill cleanout down to 9460' MD. Returned well to production w/gaslift & obtained a valid production test. ARCO .~,l~sk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-21-92 REFERENCE: ARCO CASED HOLE FINALS 6-12A?~ff8-6-92 9-44 ?'o-/>~ 8-8-92 13-13 ~ 8-9-92 13-13) 8-9-92 15-12 8-2-92 15-18~~ 8-10-92 ~c ~/~/16-7 8-8-92 CCL Run 1, 5" PFC/GR Run 1, 5" CCL Run 1, 5" CCL/Tubing Patch Run 1, 5" CCL Run 1, 5" CNL Run 5, 5" GR Run 1, 2"&5" CCL Run 1, 5" Please sign and return ~he attach~opy as receipt of data. ECE VE Sonya Wallace APPROVED ATO-1529 Trans# 92193 / Atlas Atlas Arias Atlas Arias Sch Aths Atlas # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED SEP O 3 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA, INC. P.O. BOX i00S60 ANCHORAGE: ALASKA 99_ DATE' 4-t8-9G REFERENCE- ARCO CASED HOLE FINALS 4 -~m~._ 3-")6-o0~. , TEMF' 5-4 3-23-90 TEMP tS-tS 4-2-90 PRODUCTION PROFILE i 4-8 3-29-90 F'I TS t4-33 4-2-90 LEAK DETECTION t5-3 S-22-90 PRODUCTION PROFILE t6-t5 3-3t-90 PRODUCTION PROFILE i7-3 4-i -ge, PITS F'WDW2-i 3-28-90 INJECTION PROFILE PWDWJ-i 3-30-90 TEMF' RUN t, i" RUN t, 5' RUN i, 5" RUN i, 5' RUN i, RUN i, 5' RUN i, RUN t, S' RUN i, 5" RUN i, 2' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA, RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-i529 RECEIVED ./ APR 2 $19gO APPROVED TRANS~ 9~ Anchorage DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL FILES R & D ~--" BF'X STATE OF ALASKA TEXACO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO , ARCO Alaska, Inc.~ Prudhoe Ba) _ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 16, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-13, Approval No. 9-990 Dear Mr. Chatterton' Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/TPA/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 13-13)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/'~-"IL AND GAS CONSERVATION C IMISSION 0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM At effective depth At total depth 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM 5. Type of Well Development Exploratory Straagraphic Service 6. Datum of elevation(DF or KB) 89 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-13 9. Permit number/approval number 82-178/9-990 10. APl number 50 - 029-20852 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9600 feet Plugs(measured) 9231 feet Effective depth: measured 9532 feet true vertical 9166 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 500 sx AS II 79' 79' Surface 2497' 13-3/8" 2300 sx Fondu & 400 sx PF 'C' 2586' 2586' Production 9112' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 9201' 8849' Liner 730' 7" 325 sx CI 'G' 9595' 9223' Perforation depth: measured 9228-9252'; 9328-9338'; 9342-9346'; 9346-9366'; 9376-9396'; 9398-9404'; 9408-9415' true vertical 8876-8899'; 8970-8980'; 8983-8987'; 8987-9006'; 9016-9025'; 9037-9042'; 9046-9053' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, N-80, PCT @ 8936' MD Packers and SSSV (type and measured depth) BOT 3H packer @ 8822' MD; 4-1/2", Otis DBE SSSV @ 2200' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Ail(;h0r~.~3 OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 879 2776 203 -- 379 3547 4219 968 -- 609 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~t~~//~--~'-'- Title Operations Engineering Manager Form 10-404 Rev 06/15/88 sDUatBeM/i~i/N~D,~~L i C AT E (~ Drill Site 13-13 Description of Work Performed TREATMENT: OBJECTIVE: INTERVALS: TREATMENT DATE: Zone 4 & Sag River Fracture Treatment To Stimulate the Zone 4 & Sag River Intervals 9228-9252', 9328-9338', 9342-9366', 9376-9393' I 1/24/82) December 9 to 23, 1989 MD (Ref. BHCS 1. MIRU CTU. Placed 9 bbls of sand slurry (1300# of 20/40 mesh sand) across perforated intervals from 9393-9396', 9398-9404' and 9408-941 5' MD (Ref. BHCS 11/24/82). 2. Pulled live GLVs and replaced with dummy GLVs. Loaded the tubing x 9-5/8" annulus with seawater and diesel. Pressure tested the tubing x 9-5/8" annulus to 3000 psi. 3. Rigged up fracturing service company. 4. Pumped propped fracture treatment using gelled water and 16-20 mesh Carbolite proppant at 40 bpm. a. 200 bbls 50# gelled water for formation breakdown test. b. 1195 bbls Cross-linked Pad c. 357 bbls Slurry at 2 to 13.1 PPG (74,800# of proppant was pumped into the well and 66,800# was placed into the formation) d. 1 1 9 bbls 50# gelled water flush MIRU wireline unit. Tagged fill at 8575' WLM. 6. MIRU coiled tubing unit. Removed proppant from wellbore. 7. MIRU wireline unit. Pulled DGLVs and replace with LGLVs. 8. Opened well to flow, gradually increased rate. Obtained valid well test. ARCO ALASKA, INC F'. O. BOX i ANCI4ORAGE: ALASKA 995i e DATE' i -5-90 REFERENCE- ARCO CASED HOLE FINALS 4-5 i i-26-89 4-:22 t i -t 2-89 5-4 tO-i -89 i i -27 9-3-89 i 2-i i i i-i 6-89 i ,3-i S i i -8-89 i J-27 i i -8-89 i 3.29 i i -9-89 i 73-.30 i i -9-89 i4-25 9-i S-89~ i 5-i 4 i 0-27-89 i 7-73 t i - t -89 PLEASE SIGN PERF RECORD RUN i, PERF RECORD RUN i, 5' F'ERF RECORD RUN i, 5' F'ERF RECORD RUN t, 5' F'ERF RECORD RUN i, F'ERF RECORD RUN t, PERF RECORD RUN t, PERF RECORD RUN t, PERF RECORD RUN t, PERF RECORD RUN t, PERF RECORD RUNS D!FF TEMP RUN ~, PERF RECORD RUN t, 5" AND RETURN THE ATTACHED COPY AS RECE'[F'T OF DATA~ HL$ HLS HL'D HLS HLS I-tLS FILS HLS HLS HI_S HLS HL$ HLS RECEIVED BY _:;~~~ .......... ' ' ¥'RECEIVED SALLY I--IOFFECK ER ATO-i 5-29 JAN ! 019 0 Alaska Oil & Gas Cons. ~llO~' R I BUT ]: 0 CENTRAL FILES CHEYRON D&M EXTENSION EXPLORATION EXXON" MARATHON-- ,....MOBIL ~ . APPROVED _~_ '¥RANS-~ 90t~'0S PHILLIPS PB WELL FILES R'& D BPX STATE OF ALASKA TEXACO STATE OF ALASKA .-.... ALASK, I-' L AND GAS CONSERVATION Ct ,VlISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Plugging ~ Perforate X Pull tubing Alter casing Repair well ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM At effective depth At total depth 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM 5. Type of Well Development Exploratory Strafigraphic 6. Datum of elevation(DF or KB) 89' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-13 9. Permit number/approval number 82-178/9-968 10. APl number 50 - 029-20852 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9600 feet 9231 feet Effective depth: measured 9532 feet true vertical 9166 feet Plugs(measured) Junk(measured) Casing Length Size Cemented Measured depth Conductor 79' 20" 500 sx AS II 79' Surface 2497' 13-3/8" 2300 sx Fondu 7 400 sx PF 'C' 2586' Production 9112' 9-5/8" 500 sx Cl 'G' & 300 sx PF 'C' 9201' Liner 730' 7" 325 sx Cl 'G' & 300 sx PF 'C' 9595' True veAicaldepthl 79' 2586' 8849' 9223' Perforation depth: measured 9228-9258'; 9328-9338'; 9342-9366'; 9376-9396'; 9398-9404'; 9408-9415' true vertical 8876-8904'; 8970-8980'; 8983-9006'; 9016-9025'; 9037-9042'; 9046-9053' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, N-80, PCT @ 8936' MD Packers and SSSV (type and measured depth) 4-1/2", Otis SSSV @ 2200' MD; BOT 3-H packer @ 8822' 13. Stimulation or cement squeeze summary ~:~. Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production Qr Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Gasing Pressure 868 2724 141 1280 897 2942 180 1120 . ~ ;~,i'i~;;f~i~;;~..'~, Tubing Pressure 340 359 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas~ Suspended~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~,~'~. ~,~//~/"~ Tit,e Operations Engineering Manager Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE Well' 13-13 Began perforating on November 8, 1989. RU perforating unit and pressure tested equipment. RIH w/gun #1; shot interval 9232'-9252' MD at 4 spf, flowed well to clean-up. POOH, all shots fired. RIH w/gun #2; shot interval 9228'-9232' at 4 spf, flowed well to clean-up. POOH, all shots fired. Secured well, R. D. Ref. BHCS 11/24/82 ARCO Alaska, Inc. Prudhoe Bay ,...,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager ORIGI~AL October 23, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-13, Permit No. 82-178 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 13-13)W1-3 RECE ¥EO ~ov 1 ~ ~ 'An~orsO~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKf ~-'"L AND GAS CONSERVATION C~ MISSIOI~ I:~ 6 ~ ~ j~ L APPLICA I'ION FOR SUNDRY APPROV/ I'S 1. Type of Request: Abandon ~ Suspend ~ Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull ~ubing Variance Perforate ___ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM. At top of productive interval 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM. At effective depth At total depth 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM. 6. Datum of elevation(DF or KB) 89 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-13 9. Permit number 82-178 10. APl number 50 - 029-20852 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 79' Sudace 2497' 9600 feet 9231 feet Plugs(measured) 9532 feet 9166 feet Junk(measured) Size Cemented RECEIVED NOV 1- Oil & Gas Cons. .co. mmlssi Measured ~l~l'a~ue vertical depth 20" 500 Sx AS II 79' 79' 13-3/8" 2300 Sx Fondu & 400 Sx PF 'C' 2586' 2586' Production 9112' 9-5/8" 500 sx CIG' & 300 sx PF 'C' 9201' 8849' Liner 730' 7" 325 sx Cl 'G' & 300 Sx PF 'C' 9595' 9223' Perforation depth: measured 9328 - 9338'; 9342 - 9346'; 9346 - 9366'; 9376 - 9396'; 9398 - 9404'; 9408 - 9415' true vertical 8970 - 8980'; 8983 - 8987'; 8987 - 9006'; 9016 - 9025'; 9037 - 9042'; 9046 - 9053' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, N-80, PCT @ 8936' MD. Packers and SSSV (type and measured depth) BOT 3H Packer @ 8822' MD; 4-1/2", Otis DBE SSSV @ 2200' MD. 13. Attachments Description summary of proposal x Detailed operations program 14. Estimated date for commencing operation November, 1989 16. If proposal was verbally approved Oil X Name of approver Date approved Service .17. I hereby~ertify that the foregoing is true and correct to the best of my knowledge. Signed ,~;~'~'~'/',,~~ Title Operations Engineering Manager 15. Status of well classification as: Gas Suspended BOP sketch x FOR COMMIfi~ION UfiE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Form 10~403 Rev 06/15/88 ORIGINAL SIGNED BY i dl~l~lll::: P ] Appi~val No. . -~ :'. ~.,, ~ ~, ~ Commissioner Date //~/~ ~ 7 SUBMIT IN TRIPLICATE RI~I-IARI') A ~1 Al Drill Site 13-13 Zone 4 and Sag River Fracture Treatment Procedure ARCO Alaska Inc. Proposes the following procedure: . . , , . , . . Remove gas lift valves and replace with dummy valves. Load 4 1/2" X 9 5/8" annulus with seawater. Isolate the bottom two sets of Zone 4 perforations 9398'-9404" MD and 9408'-9415' MD (referenced to the BHCS dated 11/24/82) with a sand slurry to fill casing to 9396' MD. MIRU fracturing service company Pressure annulus to 3000 psig. Pump propped fracture treatment to Sag River interval 9230'-9250' MD and Zone 4 intervals 9328'-9338', 9342'-9366', 9376'-9396' MD(referenced to the BHCS dated 11/24/82) using gelled water and Carbolite proppant at 40 bpm. a. 120 bbl Formation breakdown and shutdown for ISIP. b. 1000 bbl Pad c. 300 bbl Slurry at 1-13 PPG d. 143 bbl Flush RDMO fracturing service company. MIRU slickline unit, tag fill, and replace gas lift valves. Cleanout excess proppant and sand to PBTD of 9532' MD with CTU. Place well on production. RECEIVED NOV ). 1)il & Gas Cons, Gommissio Anchorage 2 C01LED TUBINg UNIT BOP EDU ! PMENT 1. ~:)00 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 RECEIVED Nov 1 Anchorage HIREL]NE BOP EOUIPMENT 1. 5000 PSI '7" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIR[LIN[ RAUS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF STATE OF ALASKA ALASK,~"L AND GAS CONSERVATION C"'--"MISSION ~ APPLICA, ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program Pull tubing Re-enter suspended well Time extension Stimulate Vadance Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 89 RKB feet 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM At effective depth At total depth 399' FNL, 2445' FEL, ,Sec. 23, T10N, R14E, UM 8. Well number 13-13 9. Permit number 82-178 10. APl number 50 - 029-20852 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9600 feet Plugs(measured) 9231 feet Effective depth: measured 9532 feet true vertical 9166 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 500 sx AS II 79' 79' Surface 2497' 13-3/8" 2300 sx Fondu 7 400 sx PF 'C' 2586' 2586' Production 9112' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 9201' 8849' Liner 730' 7" 325 sx CI 'G' & 300 sx PF 'C' 9595' 9223' Perforation depth: measured 9328-9338'; 9342-9366'; 9376-9396'; 9398-9404'; 9408-94i.'¢3' true venial 8970-8980'; 8983-9006'; 9016-9025'; 9037-9042'; 9046-9053' Tubing (size, grade, and measured depth) 4-1/2", 12.~, N-80, PCT Packers and SSSV (type and measured depth) 4-1/2", ~is SSSV 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation NOVEMBER 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby/~ertify that the foregoing is true and correct to the best of my knowledge. /) Signed ~/d~ ~x/,~tf/~~ Title Operatiorls Erlgineerirlg Manager 15. Status of well classification as: Oil x Gas Suspended . Date FOR COMMISSION U~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Original Signed By David W. Johnston lAPPr°val N°. ~Auprovect CoPY Returned ,'~ Commissioner Date Form 10-403 Rev 06/15/88 129 C. M. Hiohtower. 263-4713 SUBMIT IN TRIPLICATE WELL 13-13 SAG RIVER PERFORATING PROCEDURE 1. MIRU ELU and test lubricator. 1 . Flow well on artificial lift to achieve drawdown. Perforate the Sag River interval 9228'--9252' MD (Ref. B HCS 11/24/82) at 4 SPF. 5. Test well. 4 2 2. SO00 PSI ~RE:LJN[ RAMS (VARg~I.I: 3. ~400 PSI · 1/6" LUeRtCATOR 4. SO00 P~d 4 1/t" F~OW TUB[ PACK-orr '~. BOP, ARCO Alaska, Inc. [ Prudhoe BaY,_,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 28, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-13, Permit No. 82-178 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. The proposal includes installation of a special coiled tubing gas lift system. Please see the attached procedure for a detailed summary of the proposed system. Sincerely, D. F. Scheve DFS/CMH/jp Attachment cc: J.S. Dietz, BP J. Gruber, ATO-1478 PI(DS 13-13)W1-3 I ECEtVED AUG 3 019&9 Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA~-"~_ AND GAS CONSERVATION C~ISSION 0 ~ I G i ~ ~ [. APPLICA 'ION FOR SUNDRY AF_ 'ROVALS 1. Type of Request: Abandon Suspend Operation shutdown ~ Alter casing Repair well Plugging Change approved program Pull tubing Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate Other X 6. Datum of elevation(DF or KB) 89 RKB 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM At effective depth At total depth 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM 8. Well number 13-13 9. Permit number 82-178 10. APl number 50 - 029-20852 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9600 feet Plugs(measured) 9231 feet Effective depth: measured 9532 feet true vertical 9166 feet Junk(measured) Casing Length Size Cemented Measured depth True vedical depth Conductor 79' 20" 500 sx AS II 79' 79' Surface 2497' 13-3/8" 2300 sx Fondu / 400 sx PF 'C' 2586' 2586' Production 9112' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 9201' 8849' Liner 730' 7" 325 sx CI 'G' & 300 sx PF 'C' 9595' 9223' RECEIVED Perforation depth: measUred 9328-9338'; 9342-9366'; 9376-9396'; 9398-9404'; 9408-9415' true vertical 8970-8980'; 8983-9006'; 9016-9025'; 9037-9042'; 9046-9053' AUG 0 Alaska 011 & Gas Cons. Comrn[~, Tubing (size, grade, and measured depth) 4-1/2", 12.6~, N-80, PCT @ 8936' MD .Anchorage Packers and SSSV (type and measured depth) 4-1/2", Otis SSSV @ 2200' MD; BOT 3-H packer @ 8822' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation August 1989 16. If proposal was verbally approved I Name of approver Date approvedI Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_ / ~,,/~,~~--~'"~'~--~/' Title Operations Engineering Manager 15. Status of well classification as: Oil x Gas Suspended Date FOR COMMISSION H~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test __ Subsequent form required 10- g-~ 4- Approved by order of the Commissioner ORIGINAL SIGNED BY Approval No¢.. LONNIE C, SMITH Commissioner Approved Copy Returned Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~' DS 13-13 Gas Lift Installation Intended Procedure The coiled tubing gas lift system, as proposed, uses a safety valve which seats in the existing 4-1/2" tubing safety valve nipple, operates off the existing control line system, and closes both the CT and CT/tubing annulus when activated. The CT is hung off in the back pressure valve nipple in the existing tubing hanger. Gas is injected through a special tree (installed above the flow tee) through a retractable stinger which extends through the current two master valves and which seals in the CT hanger. The stinger retracts when the surface control pressure is released, thus clearing the path for the surface safety valve to close. Production is routed in the usual manner; up the production tubing and through the wing section. Gas for lift purposes is injected through the coiled tubing. The system is manufactured by MOTI, a French firm which has made similar installations with jointed pipe overseas. The proposed completion would be the first coiled tubing completion. MOTI has a local affiliate, Production Tools of Alaska. 1. RU WLU, test lubricator, and pull SSSV. Make gauge/dummy run through 4-1/2" tubing to _+ 8900' md. Replace gas lift valves and orifices with dummies. Set plug in XN landing nipple at 8917' and test tubing to 3000 psi. Pull plug and RD. 2. RU pump and lines, test and displace well with seawater. Set BPV, if needed, in hanger and remove swab valve. Pull BPV. RU CTU and test BOPS/lubricator. 3. Run 1-1/2" CT with safety valve and gas lift Valves to _+ 8700'. Install expansion joint and hanger. Land coiled tubing in BPV nipple. Close surface safety valve and RD CTU. 4. Install special gas lift injection tree with retractable stinger and test. 5. Open MV and hydraulically lower stinger to seal in CT hanger. 6. Initiate gas injection down. CT and open SSSV. Place well on gas lift. 7. Allow well to clean up and test. Return well to production. Monitor annular pressures. Well Data SBHP: 3733 psi @ 9242' (8889' TVD, 8800' SS ) SBHT: 223° F @ 9242' Tubing: 4-1/2", 12.6 ppf, N-80 Min ID: 3.725"@ 8917' md Otis XN landing nipple Tubing/casing capacity to top perf @ 9328 md =150.8 bbls H2S: 11 ppm (6-89) RECEIVED AUG o 1989 Alaska 0il & Gas ~;0n$. Commission Anchorage Well, ~ APl#: 5G029-20852-~ .Spud Date: 11-11-82 Completion Date: 11-29-82 Original RKB: 89' Hanger Type: Gray Gen III Top of Sadlerochit: 9327' Maximum Hole Angle: 29" ~knnulus Fluid: 9.6 NaCI/Diesel Reference Log: t Depths are RKB MD to Top of Equipment. Jewelry ~-~'~,rco Alaska Inc. - Prudhoe P'~-~ Field Well Type: Producer New 13a Workover ~ Hanger: 39' Angle Through Sad.: 17a BHCS 11-24-82 4 I/2" Otis DBE SSSV Nipple 1D,,3.813' BOT PBR Assembly BOT 3H Pack~ Otis XN No-go Nipple ID=3.725' BOT Shear Out Sub Tubing Tail 4 1/2" ELM Tubing Tail: 1-17-86 I'h-" ¢ ff' C L 1 220~ 2 8801' 3 8822' 4 8917' 5 8935' 6 8936' 6 8924' 10 Minimum ID: 8917' Offs XN Nipple ID-~3.725" Casing and Tubing Size ~ ~ ~ Bottom 13 3/8' 72~ L-80 0 2586' 9 5/8' 47e L-80 0 9201' 7' :2<)~ L-80 8867' 9597' 4 1/2' 12.6~ ~ 0 8936' Casing Casing Liner PC: Tubing 9 4' 5,6 8 10 Gas Uft Information J~.9.g~ Sin. Mandrel Valve 2895' 1 C)fls MH-VRSTD 4806' 2 Otis Dummy 6199' 3 Otis MH-VRSTD 7210' 4 Otis Dummy 7856' 5 Otis Dummy 8265' 6 Ot~ MH-VRSTD 8592' 7 Otis Dummy 8701' 8 Otis Dummy 8775' 9 Otis MH-VR-SO RA 3/16' 1875 RA 1/4' 1795 RO5 RO5 RA 1/4' 1765 RO5 RA 5/16' Perforation Data Inte~al Zone FT SPF 9328-9338 4 10 4 9342-9'346 4 4 4 9346-~ 4 2[] 4 9376-9396 4 20 4 9398-9404 4 6 4 9408-9415 4 7 4 4-11-84 1-18-86 Aperf 4-11-84 4-11-84 1-18-86 Aperf 1-18-86 Aperf PBTD = 9532' TD= 96C~ DcrlMm 8700' SS = 9137' MD 88(X7 SS = 9242' MD Revision Date: 5-19-87 (GD #47) Reason: Convert to Macintosh Previous Revision: 12-22-86 13-13 6 3 2 COILED 'rUBING UNIT BOP EOU ] PHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5,000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 RECEIVED RUG -~ o 1989 aska Oil & Gas Cons. Commission Anchorage NIREL ]NE BOP EOUIPMENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" L UBRICA'I'OR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF DATE' !2-20-88 REFERENCE: ARCO CASED HOLE F'ZNALS ~ i -4 i i-..58-88 PITS ?,.:Ut.-i i., ,,,~ 6-3 i i -,f 8-"8 F'RODUC:T''''~' ' iLE :,_..,~ F'ROF ::?U:~'".:' · 9-.~:,.2 ~i -",, .~:-!' .--:,_oo,:. ,.,..: Tt,,'.!AL BLIF.'.;".."T TDT-F' i:,::U,'-~ i, ~-'~i '~ -i 2 i, ')-4-88 ,::-, ,:, ¢, ',--, , , ,-- ",' :[ r~ e-,~ F'~:..'nr.."'"' ~' r-;:i~N i, .... P.~,F,,'r,.:!r'T ON PF..",'_)F:' r. .... "'- 4 i i -i 6. -' ~'.J =::: ...... - ..... ..'-] i h.'Ui'..! I ..- : '.~ '~' '~ ..:, - '~ ~i i '- '~ 7 - '':'- ..... ',' ..:"~ i.J ~:, i;, r)i-"' ...... . _ : -.::,S F'RODUi:i ~ ........... Li_~" ',:;.'1 IN i , ~-~i 6-6 i '~ -2i 88 r-"r"Pn~"'-rZL')N '"'""'- ........ '" ~:'~:"J' , , ~ ~ ~'...,, ~-,..:,..- ~ !' .."'.:i...:. P .L i_. ~.:. ~'..,_,~-. ~ ; ~"' 'i-',' -','?'- i '~ -:'.-"8-:'-':~'~ F'P,"3 D~ ~F:T T-':"N r-'""-'"'" C'l.,..U, ..... .~. i...,'"' i:;.'! IN 'i · ~... i....r._. · ~ Ot.--.JDW-NW i i-i5--,::,"":'4 PIT,F, ~'UN,..i., · -'"'- AND TURN THE A"-FACi4ED 'C--''~r', .... PLEA,z,,- Z'[fS-N RE , .;:;. ¥ A;~: F:.ECEIF"F OF: r',~,'r'A, CE- - DEC-2 ,,,.~ v ,,- A N l ~.~ Oil & G;~ `con~l..Commission ~"t. A L L_ Y i-J 0 F F E C i< E R ""'"~"~;'~ ~-cli0rage Ai-O_.~ ~'--., o ; .~.'.'",.L..." , ,,,-,,.~ ~._,,... r i 6 AF'PROVED DISTRIBUTION .,.,,- I;. :l _..'. _:- · ~"' ~'.:i i'4 '"' "-.' C A iff C t] £: C i.-i I...' A ,,"-'i L'. · -....... ;..,.; ~'. C A hi C .......... L: ~'::i i'"," i...' i..: (_':AMC:C- r'Ai .... ";'i ,...' ~ :.z · ,,.r:r:- ' '"' PHILLIPS -.- _.,- NTRAL ~ILES ~ CHEVRON F'B WELL FILES "~ . D & M R & D · ,-'" EXTEN S'- T PkU_ ,.... E.~,F ,_OR~ T I 0 N ~ ,.~ A F' C. -,- bXXUN :,": ~'~'TATE F!F'... ALASKA MARATHON. ~ T~'vACO,...., ~: MOBIL ARCO A].A,S'KA, .TNfl),. I:',0., B[)X t ANCH[)RAF.; F.'., A]...A,~K A g'954 RF"FFiRFNCE': ARCO F'~'ESSI..!RFi DAI'A i 6-4 F(HP-FI i. FIEI 1' N(; ~S'AD l FiNl'* BHF'--.~TAI' 1' F: (;RA))T F. NT BHF'--,~'F A 1' .T C ~RAD.T EiWT ~ REF'I.A[;E,t~ BHF'-FI..OW.TNF., F.,RADIF".NT ON 'FRAN2MII'I'AI. $RF).,'..).~ TSSI)FI) 4..-8-FIR F:'I.FA,.%E.r. ,.~.TGN AND I:~F-.:TUF~N THE ATTACHED COF'Y ~S' F,'E'CFTF"F rll::' DATA. RF'[;.F."TVED BY HAVE A NICE P PEGGY BENNETT~/~.k~Oi[&Gas~°nS"- -" ~' I'RAN2 ~R B..t.t? ~ AF'F'Rf.)VEI)_ )) 12TR I BI. IT .T ,FIN FiAMF:F) CFNTRAI.. FILES ~: F'XTENYTON E'x'P[. ORATION · ~' FXXf'iN MAR, AI'HFIN ,~.~- MOB I I. F"H I I...I... l F'S F'R I,.IEI.. I.. FII. .~AF'F: ,q'.TAI'F, £1F:' AI..A..?KA TE×ACF) ARCO ALASKA, INC. P.O. BOX t0'3360 ANCHORAGE, ALA£KA 99510 - ~.-~8-88 DATE t o o REFERENCE' 2-2,3 9-30 9-36 47-9 PLEASE ARCO PRESSURE DATA 2-7-88 ~-30-B8 ~-24-88 2-2-88 2-2-88 t-20-88 ~-2t-88 2-3-88 '2-t-88 BHP--FLOWING GRADIENT BHP--$TATIC GRADIENT BHP--$TATIC GRADIENT BHP--STATIC GRADIENT BHP--$TATIC GRADIENT BHP--$TATIC GRADIENT BHP--FLOWING GRADIENT BHP--SI'ATIC GRADIENT BHP--$TATIC GRADIENT GN AND RETURN THE ATTACHED COPY AS RECEIPT CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 TRAN£ ~88728 APPROVED DI£TRIBUTION CENTRAL FILES CHEVRON · ,- D & M EXTENSION EXPLORATION T EXXON MARATHON '~ MOBIL PHILLIPS F'B WELL FILES R& D SAPC £TATE OF ALASKA TEXACO asia Otl& Gas Con . Anchorage ARCO Alm~l~a, P.O. Box Anchorage, Ala.skm DATE: 9-3;~--8'? REFERENCE: ARCO Cased HoLe Final .~.~3-7 9--20-87 Bof~o0~ Hole ,~fafic F're~ure Run 2, 5" ~-..~ 9--2~-.87 Bo~om HoLe ~"$a~ic f:'re~.sure Ru~ 2, ~~ 8-~ ~ 9-2~-87 CET Rurl t8-.it 9-2~-87 CBT Ru~'~ i, fi" ~ t3-~4 9-t 9-87 No i se/Te0~pera t ur8 ~ Alask~ 0ii & Gas Cons. P, nm,~ v ~ HAVE A NICE DA ~L---'~."'"~'" v,, ~ u~s uons. Comm/ssJo~ ~ch0rage Record.s F'r ocm~or ATO-t 529 TRAN$ ~87~05 Approved OZ'$Tf~;I B U T.I.['.iN CentraL Fi Le~ T Phi LLip.~ Chevron F'B Well I~i les D & M R & I) Exfela.sion Exploration j ~; ~ ~ ~$ate of ALaska E x X 013 ~ Marafhon ~ Mob i L -~-". STATE OF ALASKA ALASK,. ,.)IL AND GAS CONSERVATION COMM._ _,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO A]aska; Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 855'FSL, 1076'FEL. Sec.14, T10N, R14E, UM At top of productive interval 362'FNL, 2374'FEL. Sec. 23, T10N, R14E, UM At effective depth At total depth 399'FNL, 2445'FEL, Sec. 23, T10N, R14E, UM 11. Present well condition summary Total depth: measured true vertical 9600 feet 9231 feet Plugs (measured) 5. Datum elevation(DF or KB) 89' RKB 6. UnitorProperty name Prudhoe Bay Unit 7. Well number DS 13-13 8. Approval number 82-178 9. APl number 50-- 10. Pool Effective depth: measured 9555 feet true vertical feet 9188 Casing Length Size Structural Conductor 79 ' 20" 500 SX Surface 2586 ' 13-3/8" 2700 SX Intermediate 9201 ' 9-5/8" 800 SX Production Liner 730' Junk (measured) Perforation depth: measured Cemented 7" 325 SX 9328-9338'; 9342-9366'; 9376-9396' true vertical 8970-8980'; 8983-9006'; 9016-9025' Tubing (size, grade and measured depth) 4½", 12.6#, N-80 @ 8931' Packers and SSSV (type a_nd measured depth) Otis SSSV @ 2200'MI); BOT 3-H Packer @ 8822'M]) Measured depth 79' 2586' 9201' 8867-9595' ; 9398-9404' ; 9037-9042' ; 9408-9415' ; 9046-9053' 029-20952 Prudhoe Bay Oil Pool True Vertical depth 79' 2586' 8849' 8533-9223' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 1510 830 50 220 1670 835 40 220 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Submit in Duplicate WELL OPERATIONS REPORT ARCO Alaska, Inc. completed an EDTA Acid wash/Matrix treatment on DS 13-13 on 3/29/86. A Coiled Tubing Unit (CTU) was used to perform the operations in the following manner: . Be o , . Moved in and RU CTU and pump trucks on 3/~9/86. RIH with coiled tubing to 9415'MD. Wash perforations with 8700 gallons of NaAEDTA solution while reciprocating coiled tubing from 9415'MD to 9328gMD. POH with CT, replacing CT volume with diesel. Shut-in well for 12 hours. Obtained a valid well test. JLB/72 ARCO Alaska, Inc. Prudhoe Bay ~-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 5, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-13 Permit No. 82-178 Emclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JLB/icc Attachments cc: Sohio Alaska Petroleum Co. File Pi(DS 13-13)W1-3 12/JLB ARCO A~aska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-178 3. Address 8. APl Number PO Box 100360, Anchorage, Alaska 99510 50- 029-20852 4. Location of Well 855' FSL, 1076'FEL, Sec. 14, T10N, R14E, UM 362'FNL, 2374'FEL, Sec. 23, T10N, R14E, UM 399' FNL, 2445'FEL, Sec. 23, T10N, R14E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 89' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [~¢ Abandon [] Stimu latio n Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. intends to perform an EDTA Acid Wash/Matrix treatment on DS 13-13. A coiled tubing unit (CTU) will be used to perform these operations in the following manner: 1) Move in and RU CTU. 2) RIH with coiled tubing to 9415'MD. 3) Wash perforations with 2000 gallons of NA EDTA solution while reciprocating 2 coiled tubing from 9415'MD to 9328'MD. 4) PUH to.9328 and pump 160 bbls of EDTA, displacing CTU with diesel. 5) POH with CT, replacing CT volume with diesel. 6) Shut-in well for 12 hours. 7) Obtain well test. RECEI'VET) Alaska Oil & ~as ~ons. ~mm~9~lon 14. I hereby/~rtify that the f, gregoing is true and correct to the best of my knowledge. Signed ~/~ ~ Title Operations Engineering ManagerDate The space below for Commission use Conditions of Approval, if any: Approved by 'Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 -r ..... T z~-,-=(q,,/Amn I zlqC) ~C~q-Z12z~5 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay' .lineering Post Office Bo>. 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' DS 13-30 DS 13-26 DS 13-14 DS 13-13 DS 13-8 DS 13-5 Permit No. 82-101 Permit No. 82-74 Permit No. 82-171 Permit No. 82-178 Permit No. 81-148 Permit No. 81-103 Enclosed are the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosures cc' SOHIO Alaska Petroleum Co. File PI(DS 13-30)W1-3 PI(DS 13-26)W1-3 PI(DS 13-14)W1-3 PI(DS 13-13)W1-3 PI(DS13-B)Wi-3 P1(DS13-5)Wl-3 ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~(X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UH At Top Producing Interval: 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UH At Total Depth: 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 89' RKB I ADL 28315 12. 7. Permit No. 82-178 8. APl Number 50- 029-20852 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-13 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stim ulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [~X Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 01-17-86. RU perforating unit and pressure tested equipment. RIH w/select fire gun #lA, shot interval 9398-9404'MD and 9408-9415'MD (4 spf) and w/gun #lB, shot interval 9342-9346'MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 11-24-82 14. I hereby/qertify that,t, he foregoing is true and correct to the best of my knowledge. Signed Z(~'~~.~'~----~--~ Title Operations Engineering Mgr. The space below for Commission use Date Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 R~v 7-1 -RO) · STATE OF ALASKA .-"- ALASKA?iL AND GAS CONSERVATION C{_..,i'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIl_X~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] -- 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 82-178 3. Address 8. APl Number Post Office Box 100360~ Anchorage~ AK 99510 50- 029-20852 4. Location of well at surface 9. Unit or Lease Name 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM 13-13 At Total Depth 11. Field and Pool 399' FNL~ 2445' FEL, Sec. 23, T10N, RlbE, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 89 ' RKBI ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 11/11/82 11/25/82 11/28/82I N/A feet MSL 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set [ 21. Thickness of Permafrost 9600'MD,9231'TVD 9532'MD,9166'TVD YES ~ NO [] nioDle @2200 feet MDI 1900' (aDgrox.) 22. Type Electric or Other Logs Run DIL/SP/GR. HDT. DIL/R?/RHCS/GR. FDC/CNT./GR/C~]_ CCT./C.R/CNL. CBT. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" 500 sx AS II 13-3/8" 72.0# L-80 Surf 2586' 17~" 2300 sx Fondu & 400 sx P~rmafrost C 9-5/8" 47.0# L-80 surf 9201' 12k" 500 sx Class G & 300 sx Permafrost C 7" 29.0# L-80 8867' 9597' 8%" 325 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4~" 8936' 8822' 9328- 9338 'MD 9376- 9396'MD 9342-9346 'MD 9398-9404'MD 4 spf 9346-9366 'MD 9408-9415 'tv[]) 26. ACI D, FRACTUR E, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8971-9054 'TVD Ref: BHCS 11/24/82 N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) F1 nw~ng DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 02/01/86 TEST PERIOD I~ 277 143 12 37 517 Flow Tubing Casing'Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 248 N/A 24-HOUR RATE I~ 1619 837 70 27.0 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A - ~,1, .-. ,.~ ,';;~ ...... · ,~., ,'5 (i~r; . ,. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " GEOLOGIC MARKERS : - - - . , ..... FORMATION TESTS -. . .. . NAME Include interval tested, pressure data, all fluids recovered and gravity, . ' MEAS..DEPTH TRUE VERT. DEPTH GOR, and time 0f each phase. . Top Sadlerochit 9327 ' 8970' N/A O/W Contact 9447 ' 9085 ' Base Sadlerochit Not Reached 31. LiST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~~ Tit,eOper.En~r.M~r. Date ., INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on 'all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showin9 the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. ~-~.. Prudhoe Bay E leering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-1 DS 13-2A DS 13-3 DS 13-4 DS 13-5 DS 13-8 DS 13-12 DS 13-14 DS 13-26 DS 13-29 DS 13-30 DS 13-33 DS 13-34 Permit No. 78-60 Permit No. 83-21 Permit No. 78-62 Permit No. 78-63 Permit No. 81-103 Permit NO. 81-148 Permit No. 80-142 Permit No. 82-178 Permit No. 82-171 Permit No. 82-74 Permit No. 83-43 Permit No. 82-101 Permit No. 82-106 Permit No. 82-136 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:BSM:vh RECEIVED. Enclosure cc: SOHIO Alaska Petroleum Co. File P1 (DS 13-1)W1-3 P1 (DS 13-2A)Wl-3 Pi(DS 13-3) W1-3 P1 (DS 13-4)W1-3 PI(DS 13-5)Wl-3 P1 (DS 13-8)W1-3 Pi(DS 13-12) Wl-3 ARCO Alaska, Inc. is a Subsidiary of AllanlicRIchfleldCompany PI(DS 13-13)Wl-3 PI(DS 13-14)W1-3 Pi(DS 13-26)Wl-3 PI(DS 13-29)W1-3 Pi(DS 13-30)W1-3 PI(DS 13-33)Wl-3 Pi(DS 13-34)W1-3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [~× OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 855'FSL & 1076'FEL, Sec. 14 T10N, R14E, UM At Top Producing Interval: 362'FNL & 2374'FEL, Sec. 23, T10N, R14E, UM At Total Depth: 399'FNL & 2445'FEL, Sec. 23, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 89' RKB I ADL 28315 12. 7. Permit No. 82-178 8. APl Number 50-- 029-20852 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate well 13-13 at selected intervals within the Sadlerochit sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and cleanup operation. Proposed Perforation Intervals: 13-13: 9342-9346' MD 9398-9404' MD 9408-9415' MD Ref: BHCS 11-24-82 RECEIVED JAN ! 3 1986 14. I hereby ce, r-t~ify that the foregoin~q is true and correct to the best of my knowledge. Si§ned ...... Title Operations Eng±neering Mgr. The space below for Commission use Date Conditions of Approval, if any: Approved by. jiJllJilIA/ -~. ~ Approved Copy I~eturr~cl By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Teiept~one 907 276 1215 DATE: MAY 14, 1985 REFERENCE: ARCO PRESSURE DATA /6-2 STATIC GRADIENT 4-28-85 CAMCO /6-7 STATIC GRADIENT 4-28-85 CAMCO / 7-7A STATIC GRADIENT 4-27-85 CAMCO ~7-13 STATIC GRADIENT 4-27-85 CAMCO /7-14 STATIC GRADIENT 4-27-85 CAMCO /7-16 STATIC GRADIENT 4-29-85 CAMCO /7-25 STATIC GRADIENT 4-27-85 CAMCO /13-3 STATIC GRADIENT 4-25-85 CAMCO /~13-4 STATIC GRADIENT 4-25-85 CAMCO ./'13-13 STATIC GRADIENT 4-25-85 CAMCO 13-14 STATIC GRADIENT 4-25-85 CAMCO /13-17 PF0 w/LISTING 10-29-84 SCH j13-23A FLOWING PRESSURE GRADIENT SURVEY j13-27 STATIC GRADIENT f13-29 STATIC GRADIENT 4-25-85 CA~MCO 4-25-85 CAMCO /14-9B ~TATIC GRADIENT 4-26-85 14-19 STATIC GRADIENT 4-26-85 14-26 STATIC GRADIENT 4-26-85 ~'~PLEASE SIGN AS RECEIPT OF DATA. CAMCO CAMCO ·CAMCO W/LISTING 10-27-84 SCH RECEIVED BY PAM LAMBERT AT0 i429C TRANS ~lO%hevron D& M Expl. Services · Ext. Exploration Exxon Marathon Mobi 1 Mobil E & P Phillips PB Well Files R& D Sohio State of Alaska Texaco ARr''r'-'~,., A Lm:~.km, Inc F:'. O ~ Box Anchorage, Aim~km DATE' December 21 , 1°E'4,- , REFERENCE' ARCO F'res~u. re DaCa 9-6 I 6-I f -84 ~ 2-4 I I 12-8B J~ ~o ~,4 I °-2~ 12-2i i 1-30 84 ';= ~ I~ 1-84 i 2-~=~, i 2-t -84. 12-26 i 2-3-84 ~. ,., i -3-84 ..... -] -84 i 3-~ I~-4 I !-i7-84 t 3;-6 i i -t 9-84 i ~-7 t t -! 7-84 i~-t3 11-i9- i3-14 i i-I°-R4 I a-i,. ~° I i -~, 6-84 t 6-i o_I / ~ o-o .--22-84 t 6-9 3-1 9-84 ' I i - ' 9-84 i 7-5: ~-' i 9-84 F'BU c, ,.~ U.'F vey S't;,.ai'ic Gradieni' Si'at'l'c G. radier,~ $'fa!'ic C. radien'? £;i'at'ic Gradie'n't SCat'lc E--red i eh± S: t a 't: i c Gradie'nt' Zeal'it -E~radien't- Si'mt'it Cfradie'n'f 31'al' i c 6'red i eh!' 5:'l:.a-t: i c Grad i e'n+. S'fat'ic Gradient' 5.'!:a I' i c C;r`sd i ~'t'ai' Jc Grad ient S;tat'ic Grad ie'nt Si'at-ic 6-radieni' S¢,.a't:ic Gr`8dien't' F'DD PBU Survey Sl'a'l:ic 6-radi ."{:ta'l:ic Grad ie'n,'l: F"F;U £' ur S:!'ai'ic: Ol~adient F'Leaz~e sign. and reCur'n -'t-,he a't:'l:ached copy as receip'f r.~.,,...ei vecl By___ l<e[ Ly Nc:Far La'nd ATO- i 429F Alaska Oil & Gas C;~ns. Anchorage DA Ca hic o C a fllc cz, Ca ~Ac o Ca ff~c o C a i1'~ c o Ca m c o Ca mc o Ca mc o C a m c o C a m c o C a rn c: o C a ~'n c o C a m c o C ,8 m c: c.', Ca mc o O'f. i .s' C a m c: o CP., hlC: 0 [i: a m c: o of da!'a., I),. ~' S 'f,' R _I BI .. IT .. T nN .. Ch ev-r E:.,.-.'p i....::.:,ra't' io'n Serv'ce:=-. E x -~: e r,, -'< i c, ~ E × r.:, [ ¢:,r `8 't' i o'n h_XXO!] Oei'ty Mob i [ Mobil ",": & F:' Phi !. I. i ps' F'ruclhoe Bay We l. l. R & D :'.,'oh i c:, · f' .I. 4-- . ,¢. :a :ce o'F Al.a.sl<~'., F:'i Al?CO A La:..'.'l<~, Inc, I"-',.0, Box ~r30S6~ A'nchor'age, A L ~.'.: I< ~ 995~ e R FZ I::' E R E N C E ' A F;.'. C 0 F:' r' e.-'-.- :~ u.'r' e D a t: a i: 'l: a t ic S u.'r' v e y D S i ..... 8 '/ ...... .... ,..~. - 9-'-i ,::,--84 S!'a'.l: i,z Su'r'vey D~S~ iq ..... 26? 9 .... i4--84 St-a'i:ic SL~'rvey D .-. ,?, i ,."ii, .... t "'" 9-" i .... ~i:.: 4 S i: e I::' R a i' e i) a f. a 6 .... :i. 6 ~ '-',:'. ..... i 2--:iii: 4 (P ~" e x.~: ~. .... 'r' :.', .~:: a L L 0 'F ~.:f!' '->~' ~ · ('~Pt.e~re :~ig'n a'nd 'retu'r'n the at~ached copy a~: 'Fec.:eiF~'l: Recei ye,::! By ............. ~ ~ ;'- "-- :' : '~'' ~- ~ Ke 1. I.'x' i'"~cFa'F Land A T 0 .... t 4 2 9 I::' · . TRANS',. -..,_~. 3 C ~3 ill c o C a m c ,:::, DA C ..-':'~ m c o C .:Ti/ii C C a m ,.':: cz, .. Ca mc o C L.i fl'l C '") i..,. !.J 0 'f d :':'~ i: a ~ i) I S T F;,' I B U T I 0 N Fi I. es ARCO Alaska, h. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Cased Hole Finals D.So D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. ~ ...' ,,~ · D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S.- data. 3-6~-/ 6-10-84 Diff Temp 3-19--~ 5-25/26-84 Spinner Survey 3-22- 6-29-84 Spinner Survey 6-10f 7-4-84 Temp Log 7-3-- 7-6-84 Temp Survey 7-18-~ 7-4/5-84 Spinner 7-24' 4-19-84 Spinner 9-18--- 6-21-84 Diff Temp 12-15--~ 4-13-84 Spinner 12-18- 4-14/16-84 Spinner 13-1/''' 6-17-84 Diff Temp 13-10~-6-22-84 Temp Log 13-12-~ 6-18-84 Diff Temp 13-13J5-31-84 CFS/Spinner 13-16J~4-12-84 Diff Temp 13-27'''~ 6-2-84 CFS/Spinner 13-28--- 6-3-84 CFS/Spinner 13-28-.~- 6-3-84 Temp Survey 13-28---7-8-84 Temp Log 13-33'~' 6-22-84 Diff Temp 13-33-" 6-23-84 Spinner Log 14-3~/ 6-30-84 Diff Temp 14-21- 7-7-84 Caliper Log 14-24j 3-25-84 Caliper Log 14-34-~' 5-19-84 Spinner Log 17-10-/ 6-17-84 Diff Temp e sign and return the attached copy as Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" GO Run 1 5" Camco Run 1 5" GO Run 1 5" Go Run 1 5" Camco Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 4 5" Camco Run 1 5" Camco Run 1 5" Camco receipt of Kelly McFarland ATO-1429F · Trans. #301 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil ,4!aska Oil ~ [-;as Q:~s. (,cmn~ssio~ Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, In,.. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 13, t984 Reference: ARCO Pressure Data m.s. m.s. D.S. D.S. D.S. D.S. m.s. m.s. m.s. m.s. 7-19~. 6-15-84 - 6-15-84 12-8B~--'6-18-84 12-9 · ~-~'~6-18-84 13-4 ~ 6-17-84 13-12 ~ 6-17-84 13-13 L~' 5-31-84 ~ 5-31-84 13-14; 6-20-84 13-27 .... 6-2-84 6-4-84 13-28-- 6-3-84 6-4-84 13-29 6-1-84 6-2-84 14-12 6-16-84 18-2 ?'~ 4-25-84 ~"- 4-25-84 PBU Common Static Static Static Static PBU Common Static PBU Common PBU Common PBU Common Static PBU Common Data Base Report Survey Survey Survey Survey Data Base Report Gradient Data Base Report Data Base Report Data Base Report Data Base Report Otis GO GO GO GO GO GO Camco GO GO GO GO Camco -a ~ nd return the attached copy as receipt of data. Friday the 13th is back again, have a safe one! Kelly McFarland ATO-1429F Trans. f~266 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon 'Getty Marathon Mobil x0bil E & ? Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio Sl:al:e of Alaska ARCO Alaska, Inc. ~--~ Prudhoe Bay _.~gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 30, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-13 Permit No. 82-178 Enclosed is the Revised Completion Report for work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/WT/lmh Enclosure cc: SOHIO Alaska Petroleum Co. File PI(DS 13-13)W4-3 JUN 0 4 Alaska 011 & Gas Cons. Commission A~,,.'; :.:L~rage ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASK .)IL AND GAS CONSERVATION (, _,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] REVISED 2, Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-178 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20852 4. Location of well at surface 9. Unit or Lease Name 855' FSL, 1076' FEL, Sec. 14, TiON, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM DS 13-13 At Total Depth 11. Field and Pool 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 89' RKBI ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/11/82 11/25/82 11/28/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9600'MD,9231'TVD 9555'MD,9188'TVD YES~ NO [] Nipple @220(~eet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR, HDT, DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CCL/GR/CNL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE !TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf. 79' 30" 500 sx AS II 13-3/8" 72.0f~ L-80 Surf. 2586' 17~" 2300 sx Fondu & &OD .~x Pprm~rnst C 9-5/8" 47.0~ L-80 Surf. 9201' 12~" 500 sx CI~.~.~ ¢. ~ ~ .~;× P~rm._~_~ro~t C 7" 29.0# L-80 8867' 9597' 8%" 325 sx Class O 24. Perforations open to Production (MD+TV© of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEP. TH SET (MD) PACKER SET (MD) 9328-9338' MD (10') 4 spf 8971-9036' TVD 4~" ~q~&' 9346-9366' MD (20') 9376-9396' MD (20') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Ref: BHCS 11/24/82 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A · 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing', gas lift, etc.) I Flowing Date of Test' Hours Tested PRODUCTION FOR OILoBBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4-16-84 4.2 : TEST PERIOD ~ '636 534 18 50 1027 Flow Tubing Casing Pressure . CALCULATED 01L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 415 N/A 24-HOUR RATE I~ 3238 3326 102 27.0 28. CORE DATA Brief description o¢ lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None J U N 0 ~ ~!'i84 . Alaska 0il & Gas Cons. Commissio~ gnchora~o Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .~ ..... . . . 30. ' i .:: GEOLOG. iCMARKERs - - ": ~ ' · - ' ' FORMATION TENTS ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. : Top Sadlerochit 9327' 8970' N/A O/W Contact 9447' 9085 ' Base Sadlerochit Not Reache~ 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 7~~., '~~.. Title Regional Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". STATE OF ALASKA '~ ~ ALASK,.. OIL AND GAS CONSERVATION . /MMISSION WELL COMPLi;TION OR RECOMPLETION REPORT AND Classification of Service Well 1. Status of Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number .AJ;OD _Al ~.~r,a, Z_t~. R2-17R 3. Address 8. APl Number P.O. ]3ox 100360, Ancl~raqe, ~]a.~ka 99510 5°-r~29-2C~352 4. Location of well at surface 9. Unit or Lease Name 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, IIM Pn]d}~ Ray. At Top Producing Interval 10. Well Number 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM nc 1'~-1~ At Total Depth 11. Field and Pool 399' FNL, 2445' FRr,t Sec. 23, T10N. LI4E. L~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ~Lq~ Bay 04_1 l:tx)l 89' 1RKB AD" 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/11/82 11/25/82 11/2R/R2 I N/t'A feet MS L I 1 17. Total Depth (MD+TVS) 18.Plu'gBa'ckSepth(MD+TVS) 19. D'irec~ional Survey,I 20. SepthwhereSSSV set I 21. Thickness of Permafrost 9600'tvD,9231'TVD 9555'_I~D.9188'TVD YE,~ NO [].I _~m1¢',,. ...... fagQc~feet MD ] 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED __?n" 91.5~ H-./!0 ~ga?f. 79' 30" .,,,~=~ ~. ...... ~ ~- 7" 29.0.a, T.-mm 8867 ' 9597 ' ~" 325 ~ C! ;~-.qS C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) spf ~z_,, o¢,~_, ~,,-,, 9328-9396' iVD 4 =. ~,~ 8971-9036' ~VD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. :Nsf: ~ 11/24/82 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Flc~ng DateofTest Hours Tested PRODUCTION FOR OtL-BBL GAS-MCr WATER-BBL CHOKE SIZE GAS-OIL RATIO 4-16-84 4.2 TEST PERIOD I~ 636 534 18 50 1027 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCr WATER-BBL OIL GRAVITY-APl (corr) Press. 415 N/A : 24-HOUR RATE I~ 3238 3326 102 27.0 28. CORE DATA MAY 2 5 Alaska Oil & Gas Cons. Commission ~,nch0ra..u.e Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE -' '" - GEOLOGIC MARKERS ':'" . : : " . ; ;: - :': '" i.' ' FORMAT!QN'~Es'I~'S NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl~t 9327' 8970' N/A O/W ~ct 9447 ' 9085' , Base Sadlerod~t Not Rsad~l -- 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing'is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc.,~'-~, Post Office ~; 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S. 3-19/ D.S. 3-22/ o o -3/ DS 32 D.S. 4-1" D.S. 6-4f D.S. 6-7/ D.S. 6-18 D.S. 6-23 D.S. 7-20 D.S. 7-21 D.S. 7-22 D.S. 7-24 D.S. 7-25/ D.S. 7-26' D.S. 12-7A/ -D.S. 12-15 D.S. 12-18 f D.S. 13-13 D.S. 13-15 D.S. 13-16 D.S. 13-33 D.S. 18-7 / '/~P1 ea se sign 4-9-84 Static Camco 4-9-84 Static Camco 4-9-84 Static Camco 3-17-84 Static Camco 1- 25 - 84 PBU GO 1-25-84 Common Data Base Report 1-15- 84 PBU GO 1-15-84 Common Data Base Report 12-27-83 Horner Plots w/listing Sch 8-11-83 Horner Plots w/listing Sch 4-18- 84 PBU Camco 4 - 29- 84 PBU DA 4-20-84 PBU Camco 4-20-84 Common Data Base Report 4-20-84 PBU " Camco 4-21-84 Common Data Base Report 4-22-84 PBU Camco 4- 28- 84 PBU DA 4-14-84 PBU Otis 4-14-84 Common Data Base Report 4 - 13- 84 ~BU Camco 4-13-84 Common Data Base Report 4-15-84 PBU Camco 4-16-84 Common Data Base Report 4-12-84 Static DA 4't3-84 PBU DA 4-12-84 Pressure Draw-Down Camco 41-5-84- Static DA 3-14-84 PBU DA 3-14-84 Common Data Base Report and return the attached copy as receipt of data. Kelly McFarland · ATO- 14 29F Chevron D&M Trans. ~ 187 Have A Nice Day! ~ D_ISTRIBUTION ~._~~- /...)~...~,:.. ~'" ?. ~' .", ~ 0/1 Drilling Phillips ~'~ Exp. Services Prudhoe Bay Well Fzies Ext. Exploration R & D Exxon Carolyn Smith Getty Sohio Marathon State of Alaska ARCO Alaska, Inc?---. Prudhoe Bi ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 2, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-11 Permit No. 81-76 DS 13-13 Permit No. 82-178 DS 13-33 Permit No. 82-106 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 13-11,13,33)W1-3 RECEIVED MAY 0 !984 ~:~,lasKa Oil 8, Gas Cons, Commission Anchorage ARCO Alaska, Inc. la a Subsidiary of AllantlcRichfieldCompany ~__. STATE OF ALASKA ALASF' )IL AND GAS CONSERVATION . ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UM 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 89' RKB ] ADL 28315 7. Permit No. 82-178 12. 8. APl Number 50-- 029-20852 9. Unit or Lease Name Prudhoe Bay Unit 10. WelINumber DS 13-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 4/11/84. RU perforating unit, pressure tested surface equipment. Unloaded tubing and annulus using gas lift. RIH w/gun #1, shot 9376-9396' MD, 4 spf (20' Ref: CBL 11/28/82), flowed to facility for clean-up, monitored rate and took shakeouts. POH, all shots fired. RIH w/gun #2, shot select fire 9346-9366' MD, 4 spf, and 9328-9338' MD 4 spf (30' Ref: 11/28/82), flowed to facility. POH, all shots fired. RD. Ran SSSV. Secured well 4/20/84. RECEIVED MAY 0 !984 AlasKa Oil & Gas 6ons. Commissi( Anchorage : 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for CommiSsion use Regional Engineer Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, in( Prudhoe Ba~ Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 15, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 13-2A D.S. 13-11 .D.S. 13-13 D.S. 14-13 D.S. 14-14 Permit No. 83-21 Permit No. 81-76 Permit No. 82-178 Permit No. 81-101 Permit No. 81-102 AttaChed are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS/TKKW/lmi At t achment s cc: Sohio Petroleum ARCO Ale~l(~. Inc. t~ ~ S[~bsldlary of AtlenllcRIc3fleldComp~ny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-178 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20852 4. Location of Well 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, DM 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 89' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate} Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposedwork, forAbandonmentsee20AAC25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional draw- down be necessary to unload the wells, it may be flowed to a tank for initial clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Intervals Ref: BHCS 11/24/83 9328-9338' 10' MD 9346-9366' 10' MD 9376-9396' 20' MD 10' TVD 10' TVD ..... 19' TVD 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Z~~ 2 ~--~"~' Title R~'~ cm~ 1 The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER ~.pproved Cot>, ~urned By Order of the Commission Date Form 10-403 Rev_ 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post O ffice/Lc.~,360 Anchorage ,ca 99510 Telephone 907 277 5637 February 23, Reference: 1983 Arco Cased Hole Finals D.S. 7-15 11-14 -82 Run 1 D.S. 13-9 -2-2-83 Run 1 2-1-83 Run 1 D.S. 13-13 11-28-82 Run 1 ACBL/VDL/Signature CBL Temperature Log ACBL/VDL/Signature 1! 11 1! DA GO GO DA lease sign and return the attached copy as receipt of data. · Kelly McFarland AFA-403 Trans. ~ 159 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY ":'STAT~~~"' ...... ~__~ DALLAS 2 ~ )!38~{ CAROL I NE. AS, MI I~H3~ Oas [;:'}ns Commis:;i~,r~ A.'-:?hora~e "- ARCO Alaska, Inc. Post Office [' 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for December on these drill sites' 1-24 13-14 1G-7 2~1'1 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 ' Also enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-iOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Si ncerely, P. A. VanDusen District' Dril 1 ing Engineer PAV/JGL28'llm Attachments .. Oil ,?-,, Gas [:3ns, Cornrnisl;ju:,~ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ,~--' STATE OF ALASKA ALASK. _L AND GAS CONSERVATION L MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOC 1. Status of'Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-178 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20852 4. Location of well at surface 9. Unit or Lease Name 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, UN '~ Prudhoe Bay Unit , At Top Producing Interval VERIFIED ; 10. Well Number 362' FNL, 2374' FEL, Sec. 23, T10N, R14E, UM, -_~ iSurf. ;: , 13-13 At Total Depth t~' H. L__~----'-]._ J 11. Field and Pool 399' FNL, 2445' FEL, Sec. 23, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 89' RKBI ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 11/11/82 11/25/82 11/28/82I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+TVD) 19. DirectionaISurvey 120' Depth where SSSV set 21. Thickness of Permafrost 9600'MD,9231'TVD 9555'MD,9188'TVD YEslX-I NO [] ~Nipple (~ 2200 feet MD 1900' (approx) 22. Type Electric or Other Logs Run D IL/SP/GR, HDT, DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CCL/GR/CNL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" 500 sx AS II 13-3/8" 72.0# L-80 Surf 2586' 17-1/2" 2300 sx Fondu & 400 sx Permafrost C 9-5/8" 47.0# L-80 Surf 9201' 12-1/4" 500 sx Class G & 300 sx Permafrost C 7" 29.0# L-80 8867' 9597' 8-1/2" 325 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 8936' 8822' None 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested. PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure ICALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24'HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,JAN t 4 1¢83 Alaska 0il & Gas Cons. Commission Anchorage Form 10~407 Submit in duplicate Rev. 7-1-80 GRU1/WC11 CONTINUED ON REVERSE SIDE ,. ;. :;.--?,'__ ~!s .!';.;;..:'.!;.hGEOLOGIc 'M-)~R-i~E'-RS ':.(:!!!/~,_:.~i.~! '~; .-;.~:': i! "-'; };:' 7; :>(:~;' ':' ':.:?.: ,:'{.'.: ' ;'--:.t. :: "':." !' {: FORM~&:FiON T'i~Ts. '" .... . .." . : . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .. . Top Sadl er'ochi t 9327' 8970' O/W COntact 9447' 9085" N/A _ Base Sadlerochit ' , Not Reached . __o . . ; . : ; · . · · · .. 31. lIST OF ATTACHMENTS' ' Drilling History, Gyroscopic Survey {2'copiea) 32. I hereby certify that the foregoin§ is true and correct 'to the best of my knowledge Signed "~~~ Title ^rea Dr''''n§ Eng'nee~)ate l'/ll~C~l~ ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injectior~, water injection, steam injection, air injection, salt water disposal,.water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. 'Item 16 and 24: If this well is comPleted for separate production from more than one interval (multiple completion), so state' in item 16, and in item 24 show the prodUcing intervals for onlY the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". DS 13-13 DRILLING HISTORY NU 20" Hydril &'diverter. Spudded well @ 1430 hrs, 11/11/82. Drld 17-1/2" hole to 2600'. Ran 61 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2586'. Cmtd. 13-3/8" csg w/2300 sx Fondu and 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9205'. Ran DIL/SP/GR f/9178'-13-3/8" shoe; HDT f/9178'-8378'. Cont drlg to 9215'. Ran 216 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 9201'. Cmtd 9-5/8" csg w/500 sx Class G. Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9590'. Ran DIL/SP/BHCS/GR & FDC/CNL/GR/Cal f/TD to 9-5/8" shoe cont w/CCL/GR/CNL to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C, & 126 bbls Arctic Pack. Cont drlg 8-1/2" hole to 9600' TD (11/25/82). Ran 18 jts 7" 29#/ft, L-80, BTC csg f/8867'-9597'. Cmtd 7" lnr w/325 sx Class G. Drld cmt to 9555' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Ran CBL f/9555'-8867'. Ran 4-1/2" completion assy (including GLMs) w/tail @ 8936' & pkr @ 8822'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel. Dropped ball & set pkr. Nipple for SSSV @ 2200'. Secured well & released rig @ 2400 hrs, 11/28/82. Gyroscopic survey ran 12/11/82. JG' sm 12/30/82 GRU1/DH11 Alaska Oil & ~as Cons, OOm~nission ~nchora~e ARCO ALASKA~ INC. IlS 13, WELL. NO: 13 GM'S dOB NO: A1282RO342-6!G . F'IRI_.IEd.-IOE BAY, NORTH SL. OF'E, ALAL=;KA G M'.:"; 0-I;) ~:.;00 1,1[I .~;I.j RV E;'¥'OR: %1AFlN DA;[E....RLIN: 1 CAMERA. I',1(): 1/-,44_ :7.'::4 DEG ~/1_1 NO: .,:.";' ?i '='._ ,,, .-,'-'" GYRO Nh:_ /-":"-." FORESIOH'r: N 16 13 W VERTICAL SECTION CALCULAT: · RECORD OF SURVEY RADII_I:_=; OF ['z:URVATURE METHOD ARCO ALA!SKA., INC. COMPUTATION PAGE NO. D'._=; 1:37 WELL NO: 1:3 GMS ,10B NO: A1282RO:34'.2-6!G t:IhtE DATE F:'RI_IE~HOE BAY~, NF'iR'FH SLOF'E -, ALA'.--;I<A 0'.::,': 0:'::: 5F.': 17-DEC-82 1 ................ 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E~. 18.21 S 6.4 54 E 16.90 E 18.62 S 65 11 E 17.11 E 1E:.78 S 65 37 E: 0.81 0. ,4 0.40 ('). 2:':!: ,, ~.._t 0 15 S 24 0 E 0 0 0 0 I 0 .'_:: 64 0 W i 15 S 25 OW I 0 S 72 0 W 100. 3699.88 100. 3799.88 100. 3899.88 lOC). 3999.86 100. 4099.84 -5.55 :3610. 88 -5.46 3710.88 -4.66 :3810.88 - 2.7 ::: 3910.86 -0.84 4010.84 7..95 S 17.20 E 18. '.~. ?]_ S /:. 5 I 1 E 0 . ,..'-'.... '= E:. 1~ © 17 2'-7~ E I'T;. 11 S 64 45 E 0 '-'~ 8.54 S 1/-,. 5¢)_ _ E 1:::_..._,_,."i-,,':, '.E; 62 :'::'-.-~_. E 1 . ()0. 9.91 S 15. 15 E 18.10 '.E: 56. 49 E 0.79 11.17 '._=; 1:'::.72 E 17·70 S 50 50 E 0.'.-7~:3 1 15 F-; 5'? C) W 100. 41'Fy?. .. 0.76. 4110.82 11.9'.-} S 11.'.-24 E 16..92 S 4-4 53 E 0.:36 2 15 '._=; 50 0 W 101'). 429'~.77 :3..9~ 4210.]Z7 13.76 S 'F~.4.5 E 16.69 S 34 29 E 1.0:2: '---2 15 '.E; 5 5 15 S 54 0 W 1¢)0. 44::;"?.47 14.26 4410.47 20.:31 "..F.=: 1.27 E 20.:35 ..~: :3 :'::9 E :'-':. C) :I. 9. ("). S 47 0 W 100. ..,.....,,, =,",,",.-.,.=.. 1-¢,_.,.~. 26.51 45o':'.,'.. . -68 · 28.19-S ............,.,'='_.27--.- W ............ 29.38 ...... S_16_ 21 W 3 .8_4_._. ARF:O ~LAt'"'";F:::~, INF:. F:OMF'I_ITA'f'ZON F'AGE I',10. :;;it -- .-- ~"1 ." -i - ,-'1 --- --" · ' "l DS 1:3, WELL NO: , 1.~,.';' GMS ,_IUB~ NO: AI.~.:,z',RO.;.4~,=L4G TIME, ,][A]'E F'RUI-U-IF~F_ BA¥~ NCU~'I'H $::LOF'E, AIASK~ C)9.: (-)::.,.: ._'=,'z',.., ! 7-[ EL.-,:.,,:: MEASURE:"T~ DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C: T A N O U L A R C L 0 S U R E' DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRI:...IION SFVERITY FEE"F, D M D bl FEET FEET ....... EEET .................... E.EET .............................................................. F....",EE]: EEET ................. n M 4'700. 1 o 0 c..~ 45 ._ 7 4.607 ':":' ':;:' 4 W 4.4. · : .... 7 ('} W 10 ('~ 4 A 91.. ':'", ~' 42 '-'"- '-' · :,._, .:, 21 02 W 47 '.-"::: '::' '-'/- 4::30C~, 1.5 C~ S 3'-F: ON 100. 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W 100.. ?,2A.~ 46 2:-'.:4 '-":' '= 'Z. ............ 234..73 :, ,.,,::, 5400. 21 45 c. 45 0 W 100 · ~'-"=;'-' '"'/' 271 5 A ~':' ~ ":-~ ""/- ~' .. . ,:, J .....:, .. 10 W ..... ,..:,._o.,, ...... ~.,.,.-,.~-, ~10.75 c: 171.65 W 271 '-'c ¢' '-'¢~ '-' ")'-' ""-' % ":'":' 7 .......... ._,.:,6.'. · I W 72 4 W .S.S¢)C} 21 4.5 S 44 0 W 1 O0 54~ 1 15 .:,t o. Pl... 1 15 ..._,. 18 .., '.~7.62 :'::08 · .:.'"' :::':.'~_. ,_':' .... ,4 .-,.,.,. 03 '"' "' S '""'"'" = ':~ - · . ...... 5/_-.00. 21 45 ::; 45 .0 Wr. 100. Msz~ A3 c, zL,--, '-;':-, = ='=' ~,:,..,. ~ W 34,5.~:.6 '-' 1~:: W 1 · 07 0.37 0.4.5 0. :37 0.37 570(). 21:30 S 46 0 W 5800. 21 15 '.E: 46 0 W 5900. 21:30 S 46 0 W 6000. 21 30 S 46 0 W 6100. 22 0 S 36 0 W 10 5636.9! 289.44 S i 5730. '~_ i .-i .-i 10i ..,a ... ,_-,. 1 5S; 16.27 100. 6101.45 566.80 6012.45 424· 78 S 100. 619:3. 16 606. :39 6104.16 457.44:3 100 6284 69 646.~'° ~._,. 4 4:3 S . . .: ..... 61 ~ :' 69 90. 10o.. 6376 .1 .:.'-' A:qA_ _ _. 60 6287. 13 ~ c, :-,_ - _. -~.o. ...... 8 100. 6467.49 .-7~7.02. 6378.4~P - 556.4~ S 100. 6558. 'P :3 100. 6650.64 100. 6742.60 1 A0. ~ .... . . :..:,.:,4 74 100. 6727.04 767.20 646'P. 9:--: 806.83 6561.64 845. ?0 6653.60 884.60 6745.74 922.96 6838.04 5:3'.P. 65 S 622 11 o 6~."~ :::::' S ~':'.=, 13 S , ,_, ._ · 715./.-..5 S 249.8:3 W 6.09 W .31 W ',.67 W .95 W 382·3:E: 8 40 4:_:: W 418.69 S 41 15 W 4.55· (])2 S /I-1 38 W 491.57 S 41 5:'-:: W 528·57 S 41 54 W · _',7._,. 29 W :.:, :, 6.82 .... 41 ..'. ,.., W 3':]8. ll 6 W 606.46 S 41:2 W 421.26 W 646.52 S 40 40 W 444.77 W 6:36.:34 S 40 21 W ~. g'~ .-, ,~_1 · ' 4:.o..: .... W 727 :':-:7 '.3 40 '=, W 491.60 W 514.75 W 537.84 W 560.96 W 584.3:3 W '767.69 S :37 49 W 807.46 S 2:9 36 W 846.66 S :::'P 26 W 885.48 :::; :39 19 W '72:3.'P:3 S 39 14. W 0.45 0.25 0.25 0.0(') :::. 73 1. :]:1 ('). ~- - ._, 0.00 C). 48 0.41 0 ,, 25 0.64 0.25 0.4.6, 0.4.6 100. 7019.60 960.77 6'.-}30.60 100. 7112.23 91,~8l 43 702:3.23 100. -7204.28 10:37.39 7115.28 100. 7295.00 107'?. 13 7206.00 100. 7384, :39 11 Z.3. Z.3 , ........ 74.5. ¢)7 c. 77:]:. 06 .:.'-' 8 0 0.2 ¢). o._, :327· 79 S e .~.~ · 37 c- · _-:,_ ._ z-.c')8 21 W 9/-. 1 :::c') ¢' '=:':~ 14 W 63:3.40 W 9'F'T~. 41 :s; :.::9 20 W 661.50 W 102:8.22 S :-_-:9:35 W 6'~3.25 W 1079.'7:3 S :39 57 W 728.55-W 1123.59 S 40 25 W 0. ? 1 Ic.' 2.17 2.40 '2. 18 ARCO AI_ASKA., INC, CCIMF'L.rT'ATION F'AGE NFl. "1'-' ' '-' F ' '": f3MF.:: ,_tOB NCI.' A 128:':.:'R(3c_-:42-QC.~ TtME .... DA:T'E ...... ' 1...:, 1.::., HEL. I_ NJ, 1._, ' ....................... · c,~ ,'~ ~ .... · ~'~, *-, F'RI_IDHI:IE BAY., NI]RTH SLFIPE~, ALASKA 09: 0:3: .... :.., 17-[EL.-,.-,..,:: TRUE MEA.C:LIRED DRIFT DRIFT COURSE VERTIr':AL VERTICAL '.::UBSEA R E C T A N 0 U L A R C L. 0 S LI R E DOOL. EZG DEP'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD L: El 0 R D I N'A T E $ DISTANCE DIREF:"I"ION SEVERITY FEET D M D M FEET FEET .... FEET ....... F'EET ............... FEET FEET D M DG/100F']' 7700. 29 0 S 55 0 W 100. '7472,58 1169.23 73:33.58 :2:82.75 S '766.93 W 1169. :37 S 40 5?/ W 1. :31 7800. 28 45 S 56 0 W 100~ 7560,15 1~t6~ t, 6 7471...1,,5 '~1.0,,~,,t0,,,S 806.72 .W 1216,17 S 41 3:3 W 0,54 7900. 28 0 S 56 0 W 100. 7648.1:3 1262.24 7559.13 936.67 S 8.46.12 W 1262.25 S 42 6 W 0.75 8000. 27 0 S 56 0 W 100. 7736.83 1307.02 7647.83 962.4.9 S 884.40 W 1307.12 S 42 35 W 1.00 8100. 26 15 S 56 0 ,W 100~ 7826~23 t3.D0~48 77:~23 98,7,~,~]-.8 92, t-.,56 W t:350.7~] ~. 4:3 1 · W O. 75 8's..'00, ":'5 0 '.--; 56 0 W 100, 7916, 2:9 1 '=":.,'":'." 41 . 782'7, :'::9 1011,74. ¢' ':) ~ , '- '-. :_; .,:.._ W 1..,:..._ ...._ . ...... .., .-.._,7 41 W 1 ,~ 92 ';' ':: 4 ..... 1(,),.-,4. ,. ,,:3,,,..,_-, ~,'-T.,'l ,'79 W 14:?:3,4:3 4,:3 4'7 W 1 ()0 8:300. 24. 0 "" 56 ~') W .100, 8007.38 1432, 6:3 791"" 'A'"' "-' g'- '-' · _, 0 ,~i . . # . F-:4¢~() ":'":' 0 ¢' 57 ¢) W 100 ,-,(-~o~ '"'¢ .).:,6 ~"'" ¢' rr-.,p] S 4,4 7 W 1 <.,:, ..... : ......... _ :,. :,.'. . ¢)g.. 1471 , 21 o)10.09 1¢= . .:,.-_ .... 1...~.._, 04 W 147:2 . ":'5._,... . ( )._,7 :3 ._,(J, ?. 6:2'-: 0() ::: .'.-'] C) O ":'"':'0 '.3 :$7 ,r) W 100 81 -'?/1 4:_::, 1 .~Ot:: 15 ':: 1 ')'-' ~' '- (..,::. 4:3 1 (:)77.7:3 '.:; I ' '= I W 1 C-; 44. :27 W 1 .,:., ... # _ . . . n c, 6 <.)(.). ,-".' 1 1 ~ S ~8_ O"W t (:)('.") ,. b~o4.,..44 ."'""" 1 ~;,4~.=' '--= · ~4 o1~' '-.~.~,,.~..44": 1. U,~.~, ,~,,",' '- ="' ,..,,.",'-' t ('~).:.~'"'". "W 1.~.~4..."-',, 60 'S 44 ~ (")., 84 870 (). 2('). 45 S ._, '='''.-.~ 0 W 8800. ...'::'c). 15 ._,':' ~':~._ .. 0 W :--:'F/00. 17/ 4:5 :_:: 6C) 0 W '7000. 19:2:0 S 60 0 W 9100. 1:3:30 S 61 0 W '.::/200. 18 15 .c; 62 0 W 9:30C). 1'7 4.5 S 6:2: C) W 9. 4 (')_ (').. 17 (')_ c.._, 6 :]-: 0 W 9.'-."; o (") . 17 c). ._,':' 6 :R_ ('). W )O,JECTE.O TO PBTB ':/~"-'= ~ ._ ._1 ._1 ....... l-]' 0 S 6:3 () ~ 1 17 1116.30 .'3 1118.7'7 W 1580.4:3 :2:45 4 W 0.6:2 B.79 W 1614..45 W 0. 1151 .26 W 1647.63 8 45 39 W 0.61 .34 W 1680. 19 ::i; 4,5 56 W 0.25 68 W 1711.72.. :~ 46 1.3 W 1.05 100. 8849.07 1736,.50 8760.07 1199.56 S 1263.38 W 174-2.15 S 46 29 W 100, 8944.18 -1765.41 8855.18 1213.83 S 1290.-?9 W 17'71.87 S 4.6 46 W 100. 9039.62 1793.27 8950.62 1227.39 S 1317.40 W 1800.56 S 47 2 W 100. 9135.25 1820.54 '.:.~046.25 1240.66 S. 1343.45 W 1828.69 S 4'7 1'7 W 0.40 0.5? 0.75 C). 00 55. 9187.:E:4 1835.54 9098.84 1247.96 S 1:357.78 W 1844.17 S 47 25 W 0.C)0 '.-:/60 C). 17 C) S 6:3 0 W 45. ':.-,' 2 :':: C). 88 1847. ::: 1 ? 141. :2::3 125:3.9:3 tS 1:36'F/..50 W 185/:,. :2:.5 :3 4-'7 :"41 W 0.0 C) F' I NAL. CLOSI_IRE - El I REC'T' I ON: D i STANCE: . .:_.E_..:. W S 47 DEGS :2:1 M INS 2O `"' f-"-' 1:356.85 FEEl" - ., · ARCO ALASKA~ INE:,,, ' D'..:.'; 1 ::ii',., WE L.L I',10: 1. :2: GMS ,JOB NO: A .1. 2::::2RO:':-:42--QG PRUIT. IHOE BAY, NORTH SLOPE, ALASKA GMS, (?-'?500 MD, '.:_:;URVEYOR: ,..IAFIN DATE,.RUN: DEC=8.2 CAMERA I',10: 1/..:,4.4 34. DEG A/U NO: 25:9 :2:" GYRO NO: /_-,32 I::'OF~E-':'S I GHT: N 1 ~.'.-, ;t :3 W : , , RE~E:F,R[1 OF INTERF'E'LATE[" sLIRv D.:, 1 ":' ~ WE L L N r'i: t 5: r'~ M'S. r':OMF'U'I'ATION F'AGE Nr-i. :1. 0 9: 0 7: ! :1. 17 - D E C - :F.':':2 MARKER ........ 'T' RLIE .:,t..IB.>E A .............. Cl":lI.)E:' ................ M E'] A SI._IR E D VE R T I C A L MIl- ]" V D VF R 1' I C:A L. R E r-L: -[' A N G I..I L. A R C: L 0 'F.; I_1 R E VE R"r I C A L.. .............. NAME .................. I"I.F.'"F:"I'H lIEF'TH D I FF.' I.. El- FH f': i.]1 i]1 R [) I N A '1' E '.F.:; D I './i;'I'AI',II]:E D I RECT I ON 'FI.-t I C:I<NE'.~;:i~: ,..lB .,_lA 'I'OF' SAG RIVER "r'o F' ::i;HUB L. I K A 'I"OP SHIJBI_IK B F E E T F'- E E T F:' E.:. E T F E E'F F:' E E 'l' · F E E T D M , 9 (") 42.0 (") ::.': 6'P 9. :3 :':: :34':-.". 7 861 C). :7.: :3 11 '75.22 S 1 '.'-Z 19.25 W 9140.00 87'.-)2. 13 :347.9 8703. 13 1:1.'.-:J0.54 S 1246.76 W 9229.00 88'76.66 :2:52. :2: 8'787.66 12(")3. '70 S 12'71. :33 W ?250.00 8:::96.63 353.4 8807.6:3 12('_')6.70 S 1277.09 W 1/_-,'P :F.:. 4:3:_:: 4. 6 5: W 1723.89 S 46 19 W 17 ?;. ("),.. 7 7'::',.., 4./-,_ :": 4 W 1.'757.01 S 46 3-1 W ) T 0 F' '.F:; FI U B I_ I K C T CI P S A D I_ [-- R 0 C H I T O/W CONTACT PBTD 9292.00 89:::.:/:,. 57 .355.4 884'7.5'7 1212.69 S 1288./_-,0 W 1. '7/:,9,, 49 F2; 4/_-, 4.4 W 9:::2'7.0(') 8969. '~'.5 ::-.':57. 1 8880. ?5 1217.49 $ 12'P'7. '.:.)8 W 1.77'~., 61 :S 46 5(") W . 9420.(")0 9()58.74 361.::: 8969. '74 1230.()4 F: 1:322.61 W 1806.18 S 47 5 W 9447.00 '.:.'/(}84. 56 :362.4 8',-.-':P5.5/::, 1 '.:2:.'-.'::3.6:7: S 1 :::29./.:-,4 W 1 ::: 1 :'3.7:::: 9555.(')0 9187.84 :.:.:67.2 9(')98.:i:4 1247.~'i:)/:, '..:4 1:':-:t';7.7::: W 1844,17. TD '~')/-,o(") (-')0.92:2:0 '-'"" 369 1 9141 88 1'-'.=~""' 9':: S 1:2:/:,,.?~ 5(} W ...... · . 0,-, · ............... :".I 't:?~: 1 :.':,' si/% '::'.=; ¢' 47:31 W -- -- -- i! l.,. '., -~: . __:___L : · ~_:__:_: ........ ::Z¥::: :::'.::'::lk-_ NAL :STAT]: ON ,. : : i: .... _~. ~-------j---~-~: k-- ...........-i-: ..... - ..... ~ ......... ! ................. SOUTH '1~3'; 9] 'WESTi 1369.i50: : ~ ~: _ : _ ..... ~ ........ ~ ..... cLO~RE .1856+85 S ~7.3T 20. ~.~ ........ <: ---: ~-:~--, I : . : : I- ........ ~ ......... ~ ........ ~-'::::] ........ ~ , ...... ~ ......... ~ · : ' : ! ; : ; ~ . i ~ ' ~ :.-~: ~ ' - .... ~ 4- : ......~ ~ ...... :_:_4 .... :---~ ....................... ~ .......~;- ..... ~ ......... · .... : ' : ~ : i ~ . ~ ~ ' 7-I_ _~ ~ ;. ; : .~ _ ' . L .... ;~_~ ; ' i ' ~ = , ~ . ',-~ i ~' .~, I ~ , j ~ ~ ] : ~-- ~ ~= '~' ........ ~ i' ~ i ~ ! ! , ~ i I ~ ~ ~ ~ .... : , ~ O~ : ~ ~ ~ i I i D~IJU~ i '.. ~ ; ~ ; ; i i i. ~ J ' ' j ' ~ : .. , , ~ . : , . · i , , ~_~ , , ~ i ,. , + i : , i · J i . ' ~ - .:-- - ~ooo~_ : ~i': ,A~ i~ii i,~ ,,,,~i'"~,,i .... , ::, .... ~-' -~ !~ ::'- -~% : ** ; ~ i i ; : . : ~ ', ; , ' i , ~ ' , , : :.~~ ~i ~.4 - _ .... -- C~ ;'; . .~ ......... ~..; ........ :-4 ~ ~ · , :.~ ~ : ~'~ ...... ' --- .... ~ , , · ] ............ : ; i , .... ~ - '' ]; ~' ' ' ............. i .......... I '. ' ~~--~:~--=-:~ ~ ~: . ~ J: : ................. : ............... ~ ...... ' : 7Z:::'L: _. :Z.-XT":Z. ::~X':.'X:::.'j. ':::~---i~~ ~ ~ :_= ..... ., . ~-'-~.~, :~ ~: :L :-~ :~_~ ~ :-:: ::-h---=¢~_c~: ..... :' :~::_:~.----'-b:~::~:::::~.'c;, ~: :: ~-'::}~ ~~_j ..... ~ ...... ::::::::::::::::::::::::::::::::::::::.::::.::::::::_..::::::.:___ .... / ] , : ~ ~ : , ' : , ' --- -~-- : ..... SuggeSted form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. ' ' O~e. rator, W~i 1-Name'and Number Reports 'and Materials to be received by: /~--_~--~ Date .Required Date Received Remarks , . Completion Report Yes /- Well History Yes / Samples ~ ~ . .... ~ · Co~e Chips Core Descripti°n ,,~.-_ r __ / ,~.~.. __Registered Survey P let , y ~ J /O- 5. 5' ~'~' ~. ~' /< _ Inclination S~ey ~) ~' ~ ~/~. .. Dire~ional ~ey. 7~~; ~--./~--~ ~ ~~ .?~ ~, Drill St~ Test Re~s . ~u~on T~t Re~s ~~ ~ ~. ....... ~.~ ~. ~s R~, Yes STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX ARCO Alaska, Inc Post Office ;x 360 Anchorage. Alaska 99510 Telephone 907 277 5637 January 11, Reference: 1983 Arco Cased Hole Finals DoS o D.S. D.S. D.S. D.S. · D.S. D.S. D.S. D.S. D.S. D.S. 1-18J 11-13/14-82 13-6~ 12-4-82 9-4/ 12-8-82 13-13 ~'~11-12-82 11-3 ~- 12-16-82 11-6/ 11-6-82 12-9-- 12-2-82 13-6~ 12 -3-82 14-15'~12-21-82 14-21/ 11-7-82 15-11f12-3 0-82 15-13~11-28-82 Spinner Diff Temp Log CH CNL Collar Log Spinner CCL & Perf Log CNL/GR/CCL (CH) CBL/VD Spinner CCL & Perf Log .spinner CFS/Spinner Run 1 Run 6 Run 4 Run 1-3 Run 3 Run 1 Run 1-4 1! 5" 5" 5" 5" !! 5" 5" !! Run 1 5" camco GO Sch GO Camco 5" GO Sch Sch Camco 2" & 5" Gl- Camco GO ase' sign and. return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. 9 035 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompanv EXXON MOBILE GETTY D&M STATE OF ALASKA DALLAS ARCO Alaska, Inc. Post Office BC,,'-~60 Anchorage, A ,a 99510 Telephone 907 277 5637 January 3, 1983 RE' ARCO Cased Hole Finals D.S. 13-13 12-7-82 Radioactivity Log Run 1 D.S. 13-21 12-4-82 Perf. and Collar Log Run 1 D.S. 6-3 11-29-82 CH CNL Run 7 . sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Camco Camco SCH Trans. #006 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompan-,' EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS _ Alaska Oil &AnchomgeGaS Cons,, Co/amiss/on ARCO Alaska, Inc. Post Office ,F~ 360 Anchorage. ska 99510 Telephone 907 277 5637 December 16, 1982 RE: ARCO Open Hole Fi nals D.So 13-13 11-21/24-82 DIL-SFi: D.S. 13-13 11-24-82 D.S. 13-13 11-25-82 D.S. 13-13 11-24-82 D.S. 13-13 11-24-82 DoS. 13-13 11-21-82 D.So 13-13 11-25-82 DoS. 13-13 11-21-82 BHCS CPL/Cyberlook FDC/CNL/GR (Porosity) FDC/CNL/GR (Raw) High Resolution Depmeter Profile Caliper Arrow Plot from Cluster Program Run 1 W/listing Run 1 & 2 2" & 5" SCH Run 2 2" & 5" SCH Run 1 2" & 5" SCH Run 2 5" SCH Run 2 5" SCH Run 1 5" SCH Run 2 5" SCH SCH ase sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Tnans. #658 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS ARCO Alaska Inr_ iR ~ R~JhRirti~rv nf Atl~ntir-Rir-hfi~,lrtl~.nm.~_~n:, ~:, _o. r~nn I;ofls. Gommission ARCO Alaska, Inc. Post Office B~"-'~-60 ~Anchoi~ge, A, ,a 99510 Telephone 907 277 5637 December 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 300! Porcupine. Drive Anchorage, AK 99501 SUBJECT State Reports Dear Mr. Chatterton' Enclosed are monthly reports for November on these drill sites' 1-22 13-6 1-23 13-11 1-24 13-13 6-24 13-14 7-15 1C-9GI 7-16 1C-IOGI 12-19 1E-24 12-20 1E-25 WSW-6 WSW-7 WSW-8 Also enclosed are well completion reports for' 1-21 1G-4 6-23 WSW-4 13-15 WSW-5 18-10 WS.24 1F,7 The survey for 2-22 needs to be .reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the informatiOn on the WS 24 well is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV:JG'sm Attachments GRU1/L3 ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA t..,L AND GAS CONSERVATION CC .MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ]~ Workover operation [] 2. Name of operatOr 7. Permit No. ARCO Alaska, Inc. 82-178 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 5o- 029-20852 9. Unit or Lease Name UM Prudhoe Bay Unit 4. Location of Well atsurface 855' FSL, 1076' FEL, Sec. 14, T10N, R14E, 5. Elevation in feet (indicate KB, DF, etc.) 89' RKB 6. Lease Designation and Serial No. ADL 28315 10. Well No. 11. Field and Pool Prudhoe Prudhoe Bay Field Bay Oil Pool For the Month of. November , 19 8 2 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1430 hrs, 11/11/82. Drld 17-1/2" hole to 2600'; ran, cm~d & tstd 13-3/8" csg. Drld 12-1/4" hole to 9205'; ran logs; cont. drlg to 9215' Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 9590'; ran logs. Cont.'drlg to 9600'TD; ran, cmtd & tstd 7" csg. Ran CBL & 4-1/2" completion assy. Secured well & released rig @ 2400 hrs, 11/28/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft,H-40,conductor set @ 79'. Installed w/500 sx AS II. 13-3/8'",72.0#/ft,L-80,BTC csg w/shoe @ 2586'. Cmtd w/2300 sx Fondu & 400 sx Permafrost C. 9-5/8", 47.0#/ft,L-80,BTC csg w/shoe @ 9201'. Cmtd w/500 sx Class G. 7", 29.0#/ft, L-80, BTC csg f/8867'-9597'. Cmtd w/325 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/GR f/9178'-13-3/8" shoe HDT f/9178 ' -8378 ' DIL/SP/BHC~S/GR & FDC/CNL/GR/Cal f/TD to 9-5/8" shoe cont w/CCL/GR/CNL to 13-3/8" shoe 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~~¢'~~"~~ TITLE Area Drill~g Engineer PATE 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate DS 13-13 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1430 hrs, 11/11/82. Drld 17-1/2" hole to 2600'. Ran 61 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2586'. Cmtd 13-3/8" csg w/2300 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EM~ - ok. Drld 12-1/4" hole to 9205'. DIL/SP/ GR f/9178'-13-3/8" shoe; HDT f/9178'-8378'. Cont drlg to 9215'. Ran 216 jts 9-5/8" 47#/ft', L-80, BTC csg w/shoe @ 9201'. Cmtd 9-5/8" csg w/500 sx Class G. Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9590'. Ran DIL/SP/BHCS/GR & FDC/CNL/ GR/Cal f/TD to 9-5/8" shoe cont w/CCL/GR/CNL to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C, & 126 bbls Arctic Pack. Cont drlg 8-1/2" hole to 9600' TD (11/25/82). Ran 18 jts 7" 29#/ft, L-80, BTC csg f/8867'-9597'. Cmtd 7" lnr w/325 sx Class G. Drld cmt tc~ 9555' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBLm Ran 4-1/2" completion assy~w/tail (including ~) @ 8936' & pkr @ 8822' Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp!~ced tbg to diesel. Dropped ball & set pkr. Nipple for SSSV @ 2200'. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 2400 hrs, 11/28/8 2. JG' llm 12/06/82 Post Office Box 360 Anchorage, ~-""-~ka 99510 Telephone 9~ _77 5637 December 9, 1982 RE' ARCO Magnetic Tapes i'''~-(r~_/~, D S 1 23 11-23-82 D.S. 12'20 11-24-82 Open Hole ECC 1532 Open Hole #66117 D.S. 13-13 11-24-82 Open Hole #66120 D.S. 7-15 11-10-82 Open Hole #66037 D/A SCH SCH SCH Run 1 Run 1 & 2 Run 1 Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Trans. #651 _ . DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS EXPLORATIJ)I~, -~ ~: ~' i" r" ! ';! i'. F~ · ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompanv MEMORANDUM TO: T p,U. FROM' Stale of Alaska ALAS_V~A ,OIL ~D CAS CONSERVATION COMMISSION ~ / ' DATE: November 22, 1982 C..~"~~ r ton Cha~~ ~. :~ FILE NO: 108A/I Lonnie C. Smith Comm~ s si oner O~ P~e.n L~ Norman Petroleum InspeCtor TELEPHONE NO: SUBJECT: Witness BOPE Tests on ARCO's DS 13-13 Sec. 14, T10N, R14~, U['4 Prudhoe Bay Unit ~uesd._ay~. Nove~m_be~r ~9_,1_9.8_2 - I departed my home at 12:20 p.m. for a 12:50 p.m. showup and 1:50 p.m. departure via Alaska Airlines flight #61 for Deadhorse arriving at 3:30 p.m. ~:~ather: -21"F, clear, li~c~.t wind. Wednesday_,_ Novembe_ ~r_ 10, 198_2 -BOPE tests on Sohio's B-20 %~re completed, the subject of a separate report. ROPE tests on ARCO's DS 1-23 were completed, the subject of a separate report. _Thursday,_ Npvember 1.1.,. 1.98_2 - BOPt.' tests on ARCO's Euparuk 1E-25 were completed, the subject of a separate report. _F_r_iday, Novemk~_r 1..2, 1982 - Standing by on DS 13-13. _Saturday,. Novembgr~, _1.3, ..... !982 -BOPE tests on ARCO's DS 13-13 began at 2:35 p.m. and were completed at 3:45 p.m. DOPE inspection report is attached. ~pnday, _~7ovembe.r 1~4~ !982 - DOPE tests on ARCO's DS 12-20 ~re completed, the subject of a separate report. I d~eparted Deadhorse via Alaska ~rlines flight #66 at 9:45 a.m. arri%~ing in Anchorage at 11:25 a.m. and at my home at 11:55 a.m. In summary, I witnessed successful DOPE tests on A-RCO's DS 13-13. O&G #4 4/81 ~TATE OF ALASKA ALASKA OIL & GAS CONSERVATION CCMMISSION B .O.P.E. Inspection Report .Inspector Operator Representative Wel 1 ~ ~ / ~ Location: Sec ~/~ Pril linq Contractor # I ? U~ /~/~caslng Set @ ~--~ ft. Rig # '-~-/ .Representative _~!~ Location, General Well Sign C~neral Housekeeping Reserve pit Rig ACCUMULATOR SYSTEM Ful 1 Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge PressUre Attained: Annular Preventer Blind Rams Choke Line Valves__ H.C.R. Valve Kil 1 ~,~ ne Valves ~ Check Valve Test~Pressure psig psig min / ~ sec. min ~A sec. N2 _~_~a.~, ~__.~f~ 7~O5 .~~sig Controls: Master ~ ~ Remote _FS~ Blinds switch cover Kelly and Floor Safety Valves Upper -Kelly Test Pressure Lower Kelly Test Pres sure Ball Type___~/_~_Test Pressure Inside BOP~est Pres sure Choke Manifold No. Valves No. flanges Adj ustab le Chokes / Hydrauically operated choke Test Tim~' /?z.~. hrs., days and Test Pressure Test Results: Failures. ~2) Repair or Replacement of failed equipmmnt to be made within Inspector/Ccmmission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector~ October 28, 1982 ~:r. Ma~ A. Ma jot Area Drilling ~-ngineer ARCO Alaska, Inc. P. O.-Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 13-13 ~.CO Alaska, Inc. Permit ~o. 82-178 TXON R14E UM Sur. Loc. 855'NSL, 1076'WEL, Sec. 14, , , . ~- 2374'~.~L, Sec. 23, T10N, R14E, UM. Btmhole Loc. ~3'S~L, Dear ~r. Major: Enclosed is the approved application for F~rmit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of reco~red core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5.). If available, a tape containing the digitized log information shall be submitted on all logs for copying except e~pe-rimental logs, velocity surveys and di~ter sur%~ys. ~any rivers in Alaska and their drainage systems have been classified as important ~ r ... ~_o_ the spa~u~inc~ or migration of anadr~ous fish. O~ratiorm in these areas are subject to AS 16.05'870 a .c the regulations promulgated thereunder (Title 5, Alaska Administrative Code)-. Prior to comn':encin9 oF~rations 5~ou may-be contacted_ by the Habitat Coordinator's Office, F~partment of Fish and C-.aF~. Pollution of any _~ters of the State is prohibited b~- AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Ad~%nistrative Code, Chapter 70) and by the Federal ?::ater Pollution Control Act, as amended. Prior to commencing o_-peration~ you m~y be contacted by a re~:resentative of the Department of Enviror~..~ental Conservation. aid us~ in'zcheduling field work, please notify tbis office hours prior to commencing installation of the blowout Mr. Mark A. Major Prudhoe Bay Unit DS 13-13 -2- October 28, 1982 prevention equipment so that a representative of the Comn~ssion may .be- present to witness testing of the equip~nt before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event :of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Very truly yours, ~. V. Chatterto~ ~ Chairman of ~ Q~D~?~ ~ ~-~ ~-.~-~.~ ..... Alaska Oil and ~s Conser~tion C~mission Enclosure cC.' Department of Fish & Game, ~abitat Section w/o encl. Departmsnt of Environmental Conservation w/o encl. C~ { ARCO Alaska, I~''-~' Post Offi .ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 22, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 13-13, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 13-13 and the required $100 filing fee. Attachments to the application include ~>a plat detailing the section and plan views of the proposed wellbore;~ proximity plat showing t~subject wellbore's position to the nearest well drilled~-an as-built location plat; ~and a sketch and description of the BOP equipment; an~ sketch and description of the surface hole diverter system. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: 1 lm Enclosures GRU1/L21 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ' ALASKA OIL AND GAS CONSERVATION C~,,vlMISSlON PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH lC SINGLE ZONE [~ MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 855' NSL, 1076' WEL, Sec. 14, T10N, R14E, UPI At top of proposed producing interval 510' SNL, 2300' WEL, Sec. 23, T10N, R14E, UPI At total depth 593' SNL, 2374' WEL, Sec. 23, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 89' PAD 49' ADL 28315 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 5-1/2 Mi. NW Deadhorse miles 2980 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9642' MD, 9232' TVD feet 2560 19. If deviated (see 20 AAC 25.050) I2o.Anticipated pressures KICK OFF POINT 4500 feet. MAXIMUM HOLE ANGLE 25 oI (see 20 AAC 25.035 (c) (2) 9. Unit or lease name Prudhoe Bay Unit 10. Well number DS 13-13 11.Fieldandpool Prudhoe Bay Field Prudhoe Bay Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 3-12 well 120' @ 2700 feet 18. Approximate spud date 11/12/82 3600 psig@.__~ Surface 4500 _psig@~997,2 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE i Hole Casing Weight B0" 20" 91.5# 7-1/2" 13-3/8" 72# 2-1/4" 9-5/8" 47# 8-1/2" 7" 29# CASING AND LINER Grade Coupling H-40 Welded L-80 I Butt I L'80 /Butt { L-80 /Butt I 22. Describe proposed program: SETTING DEPTH Length MD 80' 35' I 35' 2566' 34' I 34' 9218' TOP TVD 33' ~ 33' 691 ' 8951' 18604' MD BOTTOM TVD 110' 110' 2600'12600' 9251'18877' I 9642' 119232' QUANTITY OF CEMENT (include stage data) 275 sx PF to surf 2300 sx Fondu + 400 sx PF 500 sx G 1st Stage 300 sx PF I 2nd Stage 400 sx Class G Cmt ARCO Alaska, Inc., proposes to directional'ly drill this well to 9642' MD (9232' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well, ~hi~---we44~. The distance to the nearest completed well will be 120' at the surface; the proposed well will not have a closer wellbore intersection anywhere downhole. ~ F; C E~ V E D 23.1 hereby certify that the foregoing is true and correct to the best of my knowledge OCT 2 5,1982 m The spac~ Cel0w f0r'Com~ ~se ....... An:3h0ra~ .... CONDITIONS OF APPROVAL Directional Survey required [ 50-- O b~- ~ ~'~ Samples required I Mud log required ~YES 1~¢ O II--lYES ~NO Permit number _ ~ I Appr~l date APPROVED BY Form 10401 GRU2/PD11 APl number ~Ly ES [--INO SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 28, 1982 by order of the Commission Submit in triplicate 14 T ION1, R. 14'E., VI(-'IMITY /,&AP WELL #[l Y = b,930,662.454 ,'--~ = 686,224. ]6'i LAT = 70°]:2'57.016'' ~ LO ...... ! '48 _9 .52.., 6-3,..~,~ ( ~_.2~ c.,~.~.~,,~ ;".,ox ~t. ev. 4e.o~' WELL..fi2 Y = 5,930,780.310 X = 686, I96. [70 LAT = 70o12' 55. 850" N~~LD!'iG = 148°29'52.235'.,~L WELL ~.:~3 ~ ~,930,896. ~4 X = 656, !68.56 LAT = 70°12'58. 168" WELL ~I4 Y = 5,93i,013.00 X = 6S6, 140.60 LAT = 70°]2'53.3i7'' _~' ~ON~= = ~48~29 ~4.909 . WELL g ~5 . = 5,93I, [30. 18 X = 686, I ~3.02 L~T = ';0°13'00. 476'' ' .'~ F' -- .-0 ' T ,~:.,.l= - I4o 29 55. ,2~ ?;ELL ~5 r' = 5,937,24~.68 ~ ~nT ~0 13'01.o-8 ~&r... ~- "% ~ ~LONG = [48°29'55.856'.' m~ r49th ~ ~* [~ ~~~_ ~.'; % ~,.~z~-s ~;Z;;¢' SURVEYING IN THE S,AT: OF ~SAA AND THAT ,HIo P~AI .,, ~:.._ ...-~? ~. ~ ~ ~:~ ....... _ ' ~- - '~ REPRESENTS AN AS-BUILT SURVEY ~ ..... ~, ,~ ~;~0~ADE BY ME, AND THAT ALL AND OTHER DETAILS ~ NO_R.THNORTH AMER."C. AN P~t.¢DUC,.NG DlVl:qtON I ; ~ ..... -- 'x " ' ,4.78 - 13-5/8" BOP STACK DIAGRAM I ANNULAR PREVENTER ) BLIND RAMS ? ) PIPE RAMS SPOOL ~-~ PIPE RAMS Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and' bypass valves on manifold. 4. In each of the following tests, first hold a~250 psi low pressure test for a minimum of 3, minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe r 8~llS o 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. 5/13/81 SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM _TNC'. SCHEMATIC ......---lO" HYD. OPR. BALL VALVE .,,~~ WE,L,L BORE (SEE DETAIL) / ..~ IO' HYD. OPR. BALL,,VALVE / /"/" I ALL 90* TURNS ARE TEE" ~ ] CUSHION ,,___ RESERVE PIT AREA NOTE · FLOWLINE DR ILL ING RISER F 20" 2000 PSI WP ANNULAR PREVENTOR ',,, r-J L_,..---r-- I 0" HYDRAULIC IO" DIVERTER LINE ~ 5 Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 20260102 COIL TUBING GAS LIFT SYSTEM I. Objective The coil tubing ge~ lift technolngy 811ova to ~tart __~ec~__ndary recovery phe~e vithout pulling out the completion. A ga~ injection tubing is run i neide the production tubing ~nth gas lift mandrel~ attached to it. 2. Safetu At the level of the sub surface safety valve landing nipple a concentric ~afety valve is.. attached to the macaroni to perform downhole shut in on both production line and gas injection macaroni. At surface a retractable stinger for the ga~ injection is installed in the christn'm~ tree cr~ to allow the 2 m~ter valves to be cloaed thu~ stopping injection and production. A mi ni tree is i n~talled on top of the christrnes tree to have control on the ga~ injection. During all the running and pulling step~ the veil is entirely under control vith a I)~itive -the coil tubing BOP Meals around the coil during surface operatione. -the bottom check valve is preventing back flow through the coil. Killing the veil is only a rodondant ~afety barrier. ~. Runnino seouencp Prior to run the concentric string the completion integrity rill be controlled. A gauge outter ~rill be run to make sure that the gas Eft mandrels oan pass freely. A 5000 P~I pressure test ~rill be omnpleted on the oontrol lines of the safety valYe to verify that the seal bores are Continuou~ coil tubing allows to run under pres3ure but for ~afety rea~one we recommend to kill or balance the veil to have it alvay3 under control i n the event of an owkvard situation. The christmas tree configuration vi11 be modified rernoving the owab valve as this one can't be cloa~l once the coil is ir~talled. This vii1 contribute in keeping the final tree vithin rcoaannable heigM.This christnm3 tree modification viii be carried out under relevant company safety policies. The first coil tubing run rill be to land the coil tubing banger into the the BPY receptacle in order to obtain an accurate nneesurement (X) between receptacle and top BOP. Second run rill be to locate the noyo of the SCSSV topple lowering the GLM valve + expansion joint. The GLM valve vi11 be run without pocking~ to render the hydraulic locldng sy3tem imperative. Once these lengthe~ are acquired ve can proceed in running the concentric tubing. A check valve needa to be attached to the end of the coil to prevent back flow vhile cutti ng the coil to i n~tali the .na__~ lift side ._noc~ket and ~afety valve. # iii Inetall the check bottom check valve at the end of the coil Vith a slim e~,81i n~ connection, run through coil tubing BOP and pre,~urc te,~t the check valve*connection ~j~i n~ clo,~d BOP and cl__r, aed__ meater valve. Run in until the space out of the first 988 lift rnandrel is reached; this vii1 be according to g8~ lift design. Closa siip~ and pipe rarne, bleed off pree~ure if any and disconnect 5" risar. Pick up injactor+ risar pvi ng s._,._,~ce__-__- tocut the coil. Inetall theg~ lift mendrel on the coil tubing belov the riaer, lover carefuliq~ the coil+ rnandrel to connect on to the coil from the Vel1. Once the connection is ~ up connect the 5" rlsar,open BOP and run unUI next nmndrel. Same pr _oc~__ure Viii apply for the aafetqj valve Vith the 2 feet stroke expaneion joint acre~ above t~ ~1~. A pressure t~ ~11 ~ ~rd~ o~ prior to att~h t~ val~ on t~ ~il ~m~ in t~ ~P. A t~tiq plq ~11 ~ i~tall~ at t~ ~flom oft~ ri~r, applyiq t~t pr~ure in tM d~r viii mnfirm ~iiq in~dtg of t~ ~fetg ~1~ a~ 811 t~ ~n~tio~ up When the 5C55V nipple i4~ nearly re~ched the coil tubing hanger vii1 be connected to the coil ming aame pr__~__ures. (space out viii be ~_~-_ din9 to the 2 dummy runs). The pre~ure activated running tool vill be attached to the coil from the injector then latched on the hanger. The' 2 control line~ viii be flushed Vith clean oil then the concentric tubing Viii he levered untii the safety valve land~ into the landing nipple.Further running Vill cleae the e×peneion joint until the hanger ~eats it the BP¥ profile. Prassure applied to the opening li ne vii1 open the valve and activate the locking mechenism. Pre~ure vill al~o be applied on the balance line to confirm the valve is properly in place (this line has r~ functio~ vith the I'~OTI safety valve). When t .he~.~_. tests are proven sc_u~__-_~fuli teneion Viii be opplied to confirm the valve is properly locked. The running tool release Viii be activated to leave the string in place. When the running tool is pulled above the tree the m~ter valve can be The mil tubing unit can nov he ri~xl dovn. The edaptor flange can ~ re~ from tM tr~, t~ mini tr~ ~11 ~ imtai1~ on t~ tr~ a~ ~n~t~ a~ it. Hinl tr~+ tel~opic atilt pr~ure in~dtg ~n ~ ~nfirm ~th a pr~ure ~t ~i~t t~ c1~ ~ter ~1~. To atad t~ Ii~ tM 2 ~r ~1~ ~11 ~ first o~ t~n t~ ~ti~r ~11 ~ I~r~ by appl~ a~ ~in~ni~ o~ni~ prmure. ~ pr~ure ~11 ~ inj~t~ into t~ inj~tion ~ntdc p~or ~ attempt to o~n t~ ~ub ~u~ ~fety vai~ (~ e~~ feaze ~H ~. O~ t~ ~11 i8 '~q ' t~ ~ ~n ~ o~ a~ t~ ~11 ~ put into pr~tion. 4. Pullin§ seouence When the retrieval of the concentric is env~e~g~d,the veil vill be killed by direct ._rnaca__roni circulation. The control and balance lines viii be bled off to zero. The lock releasing plug Vii1 be dropped into the coil and pressure applied above it. Once the circulation is ~tablished this prove~ the lack releasing sq~tem has vorked correctly. Should the plug failed to hold the pres,sure or a leak take place in the tele-_~c_~_ pic stinger it rill not be pea~ible to operate the valve releasing mechanical. The mecbenical releaae sub operated by Vire line Viii be activated to dieconnect above the valve then the upper pert of the lock viii be unecreved Vith right hand turns to rel__~e_~ the lock. The stinger Vill be retracted once the opening pree~ure is bled off. Once the stinger is fully up the h~lraulic master valve can start to close. The mini tree vith stinger can be removed. The coil tubing unit Vill be rigged up vith the same pras~ure equipment configuration and Vith a pulling tool attached to the end of the coil to latch on the coil hanger fishing neck. SPg 16536/1 DOWN HOLE SAFETY VALVE FOR CONCENTRIC COMPLETION SPE J.L. GEYELIN TOTAl. C.F.P Copyr~ht 1987..~>¢let¥ of Pett~eum Engineers kBSTP~C~ Gas lift is a widespread method of artificial lift. However, on wells where there is no provision for Side Pocket Mandrels one way to avoid a heavy work over, is to run a macaroni string inside the existing tubing ; gas can be injected via the macaroni and the lifted fluid flowed through the tubing-macaroni annulus. On offshore wells, regulations or Company policy may impose the use of Surface Controlled Subsurface Safety Valve. This paper describes a new type of $C-SSV, run as an integral part of the macaroni string, which will close the macaroni string and the tubing-macaroni annulus. Associated equipment to set the SC-SSV in place and to seal the macaroni string system in the Chrlsmas-tree is also covered in the paper· In addition, field experience on over 30 offshore wells equipped with such a system is related. I~fRODUCTION The major Indonesia offshore oil fields of Handil and Bekapa[ have been operated by TOTAL Indon~sie since 1973. As a result of the large number of reservoirs, (250 different zones were classified), wells are completed with a dual string tubing 3 ~ x 3 ~. Early standard dual completions did not have any facilities for future artificial lift development ; as gas reservoirs were available, gas lift was selected for activating non flowing wells. Starting in 1979, wells were completed with dual strings equipped with side pocket mandrel so as to act 6as-lift valves -by wide-line techniques. For wells completed during the 1973 - 1979 period, different methods.had to be implemented because no heavy work-over ie - replacing dual tubing - had to take place. Alternative methods to flow the gas from the annulus to the string were selected : · Using a Circulating device such as SSD already in the completion. · Punching a hole in the tubing wall and if necessary setting a 5/8" gas-lift valve between straddle pack off set by wire-line. · Using a macaroni as an inner concentric completion set in place with a snubbing unit. SPE 16536/2 OOWN FIOLE -'::Aia~T~ VALVE FOR CONCENTR~rc COH~LI~TON Each of these solutions had limits : · Circulating devices were not present on both strings and most of the time this valve was too deep to be reached with the maximum available gas pressure. · Punching a hole and fitting a capsule mandrel-type valve was not always suitable because this caused permanent damage to the tubing and also involved lengthy and delicate wire line operations and it created an obstruction for further wire-line operations down below the injection point. · Running a macaroni inside the tubing for injecting gas necessitated the removal of the down ho~e safety valve and was not satisfactory from a safety point of view ; company rules implies the use of SC- SSV on both production and gas injection paths in wells located offshore. A SC-SSV able to close on the macaroni tubing and on the macaroni- tubin~ annulus was developed by TOTAL-CFP for this purpose. D~RIFTION OF SAFETY YAL~E In addition to complying with the specifications of standard SC-SSV valves, the safety valve - code name GLM for Gas Lift Macaroni - had to meet the following operatio~al requirements : · to close on produced effluent and injected gas with a metal to metal sealing, · to be run as a part of a 1.66 inch macaroni string, · to be set and actuated in a 2.81 inch landing nipple formerly used for a SC-SS¥, · to withstand 30 000 lbs of weight below the valve, · bo be retrieved in the same operation as the macaroni string, · to feature a back up unsetting mechanism, · maximum setting depth = 980 ft, · working pressure = 3000 psi, · H2S and CO2 service The two innovatory' key-elements were : a) A lock able to hold a downward force of 30 000 lbs and an upward force of 37 200 lbs (corresponding to a 6 000 psi design pressure on a 2.81 inch seal bore). b) A return spring located in an hydraulic oil chamber preventing the spring from contact with the well effluent. JoL, seg 16536/3 GLM Lock concept - Setting and retrieving a GLM of a safety landing nipple with a wire-l£ne type lock was not adapted because the macaroni string between the valve and the Christmas-tree prevent from the use of standard running, pulling or Jarring tools. - To overcome this difficulty a specific lock was designed (Fig. 1) ; the top No Go lock features a floating piston, that will move up when pressurizing the control line, pushing a locking sleeve that will secure the locking dogs in an outer position. A snap ring will hold the locking sleeve in place thus preventing the Locking dogs from collapsing ; the safety valve will remain locked whether the control line is pressurized or not (Fig. 2). The unsettlng of the GLM valve is obtained through a right hand rotation of the top part of the macaroni string an~ a straight pull that will disengage the locking sleeve to the top allowing the locking dogs to collapse freely. - A differential area between the floating piston and the flow tube piston allows the floating piston to move first when applying pressure in the control line. GLM - SCSSV concept - The general concept derives from the traditional principle of a wire-line retrievable flapper type ; a flow tube piston moves down because of hydraulic pressure to open the valve ; closure is performed through a return spring. The flapper sealing is achieved with a metal to metal seal backed up with elastomer seals. GLM separated flow paths concept - Two separate flow paths (gas injection and well fluid production) must be created. For-simplification and reliability, the closure is to be performed through one closing device only. The continuity of the inner concentric string is performed with the ~junction of a sliding stinger ; the stinger is attached to the flow tube piston by blades. The continuity at top of the stinger is obtained with a polish face/o'ring set up allowing for movement. ! The continuity at bottom of the stinger is performed in t~e open position through the stinger- sealing nose located at the 'bottom .. connexion to the macaroni string. INSTALLATION PROCEDURE Upon selection of a well for a concentric gas-lift installation (Fi~. 5), the installation procedure is as follows : - The SC-SSV is removed with wire-line tools from the safety landing nipple. SPE 16536/# DOWII HOLE SiFET¥ VALVE FOIl CONCENTIilC COMPLIi'I'ION - An hydraulic snubbing unit is installed above the bandidate well and is used to run the macaroni string in the well. As the reservoir performances are not always fully accessed, a testing and appraisal phase is sometimes performed ; during this phase, a plan concentric string is run in and gas injected into the macaroni in order to determine the well potential and the gas lift design parameters such as the deepest injection point allowed by the kick off pressure available on the well site. During this step a dummy run of the concentric string fitted with a No Go ring is performed to locate precisely the depth of the landing safety nipple for the initial installation of a concentric gas lift system in the well. - Based on the reservoir characteristics, calculations are performed by computer to define precisely sensibility to reservoir pressure, to water cut and consequently the depth of the capsule mandrels and the setting of the unloading valves. - The final inner concentric completion is installed during a two step operation : · the macaroni string equipped with capsule mandrels, gas-lift valves and GLM valve is run in hole with a running /pulling tool (overshot type) connected to the polish bore level ; the string is no-goed in the safety landin& nipple and the control line activated to lock the valve in its nipple ; after bleeding off the control line, a pulling test ensures that the valve is correctly locked in place. The running / pulling tool is then disconnected from the polish bore and pulled out of the well. The top of the polish bore has been spaced out in order to be just below the tubing hanger to allow for an eventual BPV. The well can be closed at the Christmas-tree and the snubbing unit rigged down. · an additional mini-Christmas-tree (composed of a wellhead · ..adaptor, hanger flange, production valves) can be installed on top of the Christmas-tree ; after the Christmas-tree valves are open, the macaroni spacer pipe and its hanger plate are lowered, through a packing type of seals located in the well head adaptor, and sting into the polish bore ; once the hanger plate has been secured to the wellhead,adaptor, the well is ready for opening and for production as per Fig. 5. ~. · - The opening and closure of the GLM valve is obtained by using the same surface facilities as those used to operate the former wire- line retrievabie SC-SSV. A built-in equalizing device can be added if necessary although this feature was not requested by TOTAL Indon~sie as a high pressure gas network is available on the field and used to equalize pressure above the flapper before opening. When the valve is open, gas can be injected to lift the well effluent. It has to be noted that when the valve is closed, communication is established between the concentric string and the tubing. " ' J.L. GEY~LIN SPE 16536/5 - Similar to the setting procedure, the retrieving sequence is based on a two step operation : · After bleeding off the well or killing if necessary, the GLM valve is closed ; the additional mini-Christmas-tree with the macaroni spacer pipe can be removed and the master valves of the Christmas tree are closed. · The 'snubbing unit is to be ~installed above the well and the pulling / running tool is lowered and connected onto the polish bore ; right hand rotation is applied to the pulling tool to rotate the upper part of the GLM valve ; a straight pull will then free the locking dogs allowing to retrieve the concentric completion. FIR3.B EXPF. RIF~CE The GLM valve was designed, built, and bench tested in 1983. Field testing - started in 1984. During the debugging phase, some problems were encountered on : - the lock system : the original lock was a snap type of expanding dogs that were locked in place by a weight down set ratched system ; although the setting sequence worked well~ the unsetting operations were to be more difficult· The locking system was completely redesigned and led to the present lock as described in this paper, - the sealing of the stinger at its bottom part (in open position) revealed a problem as the elastomer seals tended to be washed out during the gas passage, thus creating a communication between the gas path and the well effluent path at the GLM depth.. A new sealing device using resilient seals was designed and implemented successfully. T-he concentric string is run in by means of a 150 000 lbs long stroke hydraulic snubbing unit. The testing / appraisal phase must achieve a 6 to 8 hours stabilized flow at optimum depth ; the concentric string used for this phase is equipped with bottom hole pressure'recorder 3000 psi range. . ! The final design of the concentric completion features from 1 to 3 capsule mandrels and an open ended macaroni string. A typical example of a cgncentric gas lift completion is shown in Fig. 6. With a 1100 psi available kick off pressure, the depth of the capsule mandrels ranges from 2450 ft to 5800 ft depending on the number of mandrel used. The installation of a concentric gas-lift string including the testing / appraisal phase and well killing average 5 days with a snubbing unit working 12 hfs a day. SPE 16536/6 DO~ HOLE $~'ET~ YAL~/E FOR CONCEI~RIC COMPLETION Once the concentric completion is in place, the GLM valve is hydraulically operated with 1500 psi pressure above the wellhead shut-in pressure ; since the standard surface control panel to operate the wire-line retrievable SC-SSV is rated at 3000 psi, that last value is not modified and the GLM is operated with the same pressure. Maximum production of a well lifted through a concentric gas-lift completion reached 1640 BLPD. One average well yields 411 BOPD with 930 SCF/BBL total GLR and 60 % water cut ; the gas injection rate is about 415 MSCF/D. ~uring 1986, the concentric gas-lift completion with the GLM valve has been implemented on 33 wells ; however as some of these wells had poor productivity or ~howed a sharp increase of water cut, the concentric completion was pulled out of hole. A concentric completion operation is considered successful when the oil production can be maintained at 250 BOPD for 2 months ; at present 17 wells meet this criteria. The cumulative oil volume produced with concentric completions equipped with GLM valves was about 500 000 Bbls in 1985 and 660 000 Bbls in 1986. Additional advantages ~ecame apparent with the macaroni installation. One such advantage is an alternate solution to tricky well equipped for common annulus dual gas lift when one string tends to absorb gas to the detriment of the second string : in this case, a standard gas-lift in production casing annulus is performed on one string as the other string is equipped with a concentric completion. CONCLUSION - A new type of SC-SSV has been developed which makes it possible to produce wells to be equipped with a concentric completion in safe conditions. - This equipment permits to beneficiate fully of the advantages of the macaroni string such as : , · resizlng the production string for' low producer without a>heavy work-over, · . separating dual gas lift wells into 2 single gas lift strings, · permanent kick off for wells tending to die, · chemical injection at bottom of tubing. ACKNOWLEDGF~ The author wished to thank TOTAL Indon~sie in Balikpapan and DIAMOND BOART PRODUCTION France for their assistance in gathering the information for this paper. I ! I I I I I I i I I I I I I I I I i I I I i I Connexion to macaroni slrin[,. Landing safety nipple L.H. thread for unsetting Locking dogs Locking / Unselting sleeve Flowtube Floating piston Chevron packings Control line inlet Fig. 1 - HYDRAULIC LOCK LANDED IN NIPPLE i I I I I I I I I i I I I I I I I I I I I i I ! ! I i ! I i ! ! i I I ! Locked dogs Locking sleeve up position Snap ring Floaling piston up position · Control line under pressure Fig.2 - ItYDRAULIC LOCK SET IN NIPPLE Top connexion to · macaroni Stinger Hydraulic lock Floating piston Chevron packings Control line inlet Flowtube Slinger Return spring Flapper sealing Flapper Stinger sealing Bottom connexion Io macaroni Fig.3 - SAFETY VALVE IN CLOSE POSITION Top connexion to macaroni Hydraulic lock Floating pislon Control line under pressure Fiowtube Stinger Return spring Flapper Bottom .connexion to macaroni Fig.4 - SAFETY VALVE IN OPEN POSITION Gas injection Liquid production Hanger flange Packing seal Well head adaptor Christmas tree' Tubing hanger Tubing Spacer pipe Sliding seal assembly Polish bore Conlrol line Safety landing nipple GLM Safety valve Capsule mandrel Capsule mandrel Coneent.ric maeh'roni string .Tubing siring Production casing Packer Fig.5 - TYI'ICAL CONCENTRIC GAS-LIFT INSTALLATION Macaroni string 1.66"-2.4 ppf 2.81" Landing nipple . . GLM Safety valve Capsule mandrel w/ 5/8" valve Capsule mandrel w~ 5/8" valve Open ended string Upper perforations Lower perforations. Depths of concentric string Ft ( BRT ) GLM valve First mandrel Second mandrel: 3575 Macaroni shoe : 4073 i : 360 : 2460 Fig.6.- TYPICAL CONCENTRIC GAS-LIFT COMPLETION G, ~n,eral runninq set UP Stripper 5' ID riser 1/16 5 BOP Blind rams Shear rams Pipe rams Slips rams Check valve installatio!l Ga~ lift mandrel connectiol~ Safer7 valve connection Hanger installation Surface e(~uipment inst~!,l~tion ~ rcle.scopic stimpr injectioe tree rig up W,ell on stream, Surface shut in _ . Sub surface shut in Well on stream _ _ Final christmas tree 4.562" GAS LI. FT SAFETY VALVE /' DIAMANT SUBSURFACE SAFETY VAL~ · G D CONC NTP. lC STroNG Companion hanger flange Well head adaptor Christmas tree Injection T Gas inlet Flow line Control line COMPANION HANGER FLANGE The spacer pipe is made up to this flange, which is bolted to the well adaptor flange when the spacer pipe and G locator (placed ~t the lower end of the spacer pipe) is correctly located inside the polished tube. SPACE PIPE Is the link between the companion hanger flange and the upper concentric (via the polished tube and the G locator). Spacer pipe (3 locator Polished tube . Upper Conu'ol line ""'"" c = '. · '~ 'D.B. oval mandrel WELL HEAD ADAPTOR FLANGE Bolted in place of the tree cap flange (for WL connection), this flange ensures the sealing on the spacer pipe during its installation or removal. The sealing between companion hanger flange and well head is ensured by a ring gasket. All these sealings can be checked after assembling by applying outside pressure through an appropriate fitting in the flange. G LOCATOR Made up to the lower end of the spacer pipe, it receives' the chevron packing, ensuring a good seal and a correct adjustment inside the polished tube. INJECTION T It can be either all threaded type or flanged type assembled on the isolation valve placed above the companion hanger flange. A manual valve is adapted at a lateral inlet . (gas injection inlet) which can, under request, be doubled by an automatic shut-in valve monitored by a pressure variation in the gas pipe (high-low detector). A bleed off valve can be installed on the other lateral inlet. The upper part of the T can receive either a valve and its adaptor to measure the gas pressure or a tree cap to install a wireline lubricator (depending on the diameter of the concentric installed). L PULLING/RUNNING TOOl. ............. i Handling pipe POLISHED TUBE The lower part of the polished tube is made up to the upper end of the upper concentric in order to have the fishing neck located at 50 cm (1.7 ft) under the tubing hanger, after the latching of the safety valve. This position is defined by the running of the dummy. The fishing neck permits the transmission of a rotary movement (via the 4 studs machined from the solid) and has a pulling capacity at least equivalent to the elastic limit of the concentric string used. The interior of the tube is polished over a 1 meter length (3 ft) in order to receive the sealing elements of the "G" locator allowing correct adjustment of the upper concentric with respect to the christmas tree and avoiding any expansion problems due to temperature variation during production (see completion drawing, Page 10). When the polished tube is disconnected from the handling pipe, a BPV can be installed, if needed, in the tubing hanger. Pulling runnmy tool Tubing . hanger · Lrmer part. stud .~. . · - ' Fishing-neCk' ._ . · . THE RUNNING/PULLING TOOL This tool is designed to both run and pull through the fishing neck of the polished tube, the gas-lift assembly system with the BOP stack installed. A box thread identical to that of the concentric has been cut in order to connect the handling pipe. The J slots cut in the body transmit both torque and traction to the fishing neck studs. An outside sleeve prevents the deformation of the J slots, in case of overstressing. This assembly is designed to support a pulling capacity equivalent to the elastic limit of the concentric string used. The release of the running pulling tool is obtained by a 1/4 left turn when the weight of the concentric string is released. Polished tube - : Upper ¢oncenm¢ CHECK LIST FOR NEW WELL PERMITS Company " Lease & Well No. /~ ITEM APPROVE DATE (1) Fee (2) Loc /<2 thru 8) (,~hru ii) 10. : 11o (4) Casg (12 thru 20) ( 5 )' B 0 PE jj~Y~ J~- P4~ (21 thru 24) YES NO Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line ................ ~,~ 4. Is well located proper distance from other wells 5. Is sufficient undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included ............ ,. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait .......................... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ........ ' Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ................ , .... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... diverter syst required ' Is a em .......................,........,.,.... Are necessary diagrams of diverter and BOP equipment attached ....... ~O'~ . - Does BOPE have sufficient pressure rating -Test to ~7gr~ psig .. ~F~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. R~4ARKS ~ 06' vs6D~ Additional Remarks: o Geology: Engineering: =IWK _ ~ LCS -- BEW ~ fVA~ J K T~--"~RAD JAL~.HTM -- HJH '--~ ,, rev: 08/19/82 INITIAL GEO. UNIT ON/OFF' POOL CLASS STATUSAREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. 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