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Home My WebLink About193-019. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN n Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: n Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs-of various kinds n Other COMMENTS: Scanned by: ianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si Scblumbepger Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth UIC- lLi3 '-Ö(Cì 05/15/07 NO. 4260 .~ 5- f- l..... I '~\C Company: State of Alaska Alaska Oil & Gas Cons iComm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . Well Job# Log Description Date BL Color CD 03-36 10831325 CH EDIT PDC GR 08/11/04 1 MPL-40 98160 OH EDIT MWD/LWD (REVISED) 03/05/98 4 1 L2-18A 11421036 RST 10/14/06 1 1 A-04 11221855 RST 03/22/06 1 1 06-04A 11320998 RST 08/02/06 1 1 C-24A 11209609 MCNL 06/19/06 1 1 P2-57 A 10831796 RST 04/29/06 1 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 1- ¡"lAY :Jl (~ Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED MAY 1 7 2007 Received by: ~7 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 0 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LO~laska Oil & Gas Cons. Commission STATE OF ALASKA .. 1 a. Well Status: DOiI DGas D Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other - D Stratigraphic ~ Service / ...... 2. Operator Name: 5. Date Comp., Susp., ~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/13/2007 193-019 ¡" 307-052 3. Address: 6. Date Spudded $' 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 04/04/1993 50-029-22340-00-00 .- 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 04/22/1993 PBU 03-36 / 906' FSL, 4381' FEL, SEC. 11, T10N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2170' FSL, 2546' FWL, SEC. 12, T10N, R15E, UM 60.2' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2264' FSL, 2936' FWL, SEC. 12, T10N, R15E, UM 11728 + 8590 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 714172 y- 5936972 Zone- ASP4 12569 + 9170 Ft ADL 028327 TPI: x- 721058 y- 5938435 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 721445 y- 5938541 Zone- ASP4 NIA MD DYes ~No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey NIA MSL 1900' (Approx.) 21. Logs Run: MSFL/DLL/BHCS/CNL/GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH T\IÓ HOLE AMOUttT SIZE Wr. PEFt FT. GRADE Top BOTTOM Top BOTTOM SIZE CeMEttTING RECORD PUtLED 20" 91.5# H-40 31' 111' 31' 111 ' 30" 281 cu ft Arcticset 13-3/8" 68# NT80 31' 3977' 31' 3732' 16" 1517 sx CS III, 400 sx 'G', 165 sx CS II 9-5/8" 47# NT80S 32' 11901 32' 8708' 12-1/4" 1210 sx CI~ss 'G' 7" 29# 13Cr80 11743' 12569' 8600' 9170' 8-1/2" 180 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. ,._...~ 0_;""':__ .... / < Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (M~) PACKER SET (MD) None 5-1/2", 17#,13Cr80 11570' - 11676' MD TVD MD TVD 4-1/2", 12.6#, 13Cr80 11676' - 11741' 11678' 25. ACID, FRACTURE,CEMENTSOtJEEZE,ÊTC. '" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED SCANNED JUL 1 1 2007 11696 P&A wI 36 Bbls Class 'G' 4777' Set Bridge Plug wI Whipstock on Top 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date ofT est Hours Tested PRODUCTION FOR OIL-BeL GAs-McF WATER-BeL CHOKE SIZE GAS-OIL RATIO TEST PERIOD . Flow Tubing Casing Pressure CALCULATED OIL-BeL GAs-McF WATER-BeL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE" 27. CORE DATA Brief ~escriptio~ o~ ~ithology, por~sity, f~actures, apparent dips and presence of oil, gas or water (attach separate ~~). SubmIt core ChipS, If none, state none . , ..1.f..'"~ - ~~i'- t None ~~ Form 10-407 Revised 12/2003 o R \ G \ N f\r.UED ON REVERSE SIDE RBDMS 8Ft MAY 2 1 2007 ~ "'t. h. ,CS\ G 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 12016' 8790' None Shublik 12016' 8790' Top Sadlerochit 12016' 8790' Base Sadlerochit 12517' 9135' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I ~erebY certify that the for~in: is tr~j an~c,r;~ to the best of my knowledge. Signed Terrie Hubble ----1~ ~ Title Technical Assistant Date CS/TJ ID 7 PBU 03-36 Well Number 193-019 307-052 Permit No. I ADDroval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Shane Gagliardi, 564-5251 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Digital Wellfile Page 1 of 2 Well: 03-36 Well Events for SurfaceWell - 03-36 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 03 -> 03-36 Date Range: 25/Feb/2007 to 09/Apr/2007 Data Source(s): AWGRS Description PULL 6" CIW BPV SET 6" TWC RIG JOB API VALVE SHOP set bpv / pre rig T/I/O = 0/0+/100. Temp = S1. AL = None. WHP's (post bleed, pre-rig). OAP increased 100 psi overnight. **CONT FROM 3-21-07 WSR** (pre sdtrk) LRS PERFORMED MIT-T TO 3500 PSI- PASSED. BLED TBG DOWN TO ZERO ** TURNED WELL OVER TO DSO, LEFT SHUT IN** T/I/0=25/20/60. Temp = S1. Bleed OA ( Pre-rig). Bled TBGP to 0+ in 1 min.. Bled lAP to 0+ in 10 min. Bled OAP to 0+ in 45 min. No pressure change in 30 min monitor. Final WHP's = 0+/0+/0+. ***Job Continued From 3-22-07*** T/I/0=0/0/80. ***Assist Slickline*** (Pre RWO) MIT-T to 3500 psi PASSED on 2nd attempt. Pressured tubing to 3500 psi with 404 bbls of diesel. MIT- T lost 10 psi first 15 minutes and 30 psi second 15 minutes for a total of 40 psi during 30 minute test. Bled tubing to 0 psi. FWHP's=0/0/80. 03/21/2007 Loaded crude at FS-1 ***Job Continued on 3-22-07 WSR*** 03/21/2007 Tanker standby ticket. 03/21/2007 ***WELL S/I ON ARRIVAL *** (pre sdtrck) DRIFTED W/ 4.5" CENT & S.B. TO 11,622'SLM , NO SAMPLE. DRIFTED W/ 3.5" CENT & S.B. TO 11,696'SLM , SAMPLE OF WHAT APPEARS TO BE CEMENT. ATTEMPT TO MIT-T HAD 2 TRI-PLEXS BREAK DOWN CURRENTLY STANDING BY FOR PUMP TRUCK ***CONTINUED ON 03/22/07 WSR*** 03/19/2007 CTU #8, Pull PXN,Memory SBHPS, P&A; ...Cont' from WSR 03/18/07... POOH w/ SLB memory PBMS (gr/ccl/pressure/temp). Verified good data. MU and RIH with 2.0" BJN. Tag GLM #4 and could not get past. POOH. MU and RIH with 2.75" OD BDN.Perform down hole squeeze from 11950' Corrected depth, pumped a total of 7bbls of 15.8 ppg class 'G' cement until pressure bump was seen, lay in 27 bbls of cement 1 for 1 to trip tank until all cement was out of nozzle.Puh to safety and pump another 2 bbls to reach a squeeze psi of 2000 psi.Pressure held solid.Drop ball for nozzle and start pumping Biozan and clean down to 11678' ctmd using a total of 78 bbls.POOH Chaseing contaminate with 1% XS KCL to surface, leaving diesel from 2000' to surface leaving 1000 psi on well.(EST.TOC @ 11678' ctmdo402' feet above top set of perf) ***Job Complete**** 03/18/2007 CTU #8, Pull PXN,Memory SBHPS, P&A; ... Cont' from WSR 03/17/07 ... MU and RIH with jars and 3.63" OD JDC hydraulic overshot (w/ 2.31" grapple). Latch and pull prong. POOH. MU and RIH with jars and 4" GS hydraulic spear. Latch and pull XN plug. POOH. MU and RIH with SLB memory PBMS (gr/ccl/pressure/temp).Tag @ GLM #4,made several attempt to work pass glm wino luck POOH.MU & RIH w/ 4' x 11" max od Bow spring centralizers @ bottom of logging tools. ****Job In Progress**** Continued On WSR 03/19/07 03/17/2007 CTU #8, Pull PXN, Memory SBHPS, P&A; MIRU unit. MU and RIH with 2.3" OD JSN. Jet 40 bbls of SBG down to 11705' ctmd and lay in 10 bbls on top of plug and prong, Chase schmoo/fill with 15 bbl pill of 1.5 ppb Bio and POOH chasing returns at 80%. ... Co nt' on WSR 03/18/07 ... 03/13/2007 ***CONT. JOB FROM 3/12/07 WSR*** MADE 2 RUNS W/10' X 3" PUMP BAILER - RECOVERED 6-7 GAL OF FILL. *** TURN WELL OVER TO DSO - LEFT WELL SHUT IN *** 03/12/2007 ***CONT JOB FROM 3/10/07 WSR*** IN THE PROCESS OF PUMP BAILING W/ 10' x 3" P. BAILER, CURRENTLY MADE HOLE TO 11632' SLM ***CONT JOB ON 3/13/07 WSR*** 03/10/2007 *** CONT FROM 3/9/07 WSR *** MAKE ONE RUN W/3" X 10 PUMP BAILER - UNABLE TO UNSTAB AND CHECK BAILER DUE TO TEMP. -41 BELOW. *** JOB IN PROGRESS, GOTO WEATHER HOLD *** 03/09/2007 ***CONT. JOB FROM 3/09/07 WSR*** RAN 3" JUS SD @ 3903' ABLE TO WORK PAST, OOH W/ WHAT APPEARS TO BE PIECE OF PACKING CAUGHT IN PULLING TOOL. RAN SAME TOOL, SD @ 11611' UNABLE TO WORK PAST, PULL 150# BIND (STICKY) TO GET OFF RAN DRIFT W/ 3.67" CENT, 2' X 1 7/8",3.804 GAUGE RING & S. BAILER. SET DOWN @ 11,612' SLM. ONLY FROZEN INJ WATER IN S. BAILER IN PROGRESS OF PUMP BAILING W/ 10' x 3" PUMP BAILER, CURRENTLY MADE HOLE DOWN TO 11635' SLM. GETTING RETURNS OF WHAT APPEARS TO BE SCHMOO IN P. BAILER (ABOUT 3.5 GAL) ***CONT. ON 3/10/07 WEATHER TICKET*** 03/08/2007 *** WELL SHUT IN PRIOR TO ARRIVAL *** (pre sdtrk) IN PROCESS OF RIG UP, PREPARING TO PULL TTP ***CONT. JOB ON 3/09/07 WSR*** Events Source Well Date ,ð,WGRS 03-36 04/09/2007 AWGRS 03-36 03/28/2007 AWGRS 03-36 03/23/2007 ,ð,WGRS 03-36 03/22/2007 ,ð,WGRS 03-36 03/22/2007 AWGRS 03-36 03/22/2007 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AWGRS 03-36 AW~.RS. 03-36 http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 5/2/2007 Digital Wellfile Page 2 of 2 AWGRS 03-36 02/25/2007 T/I/O=SSV/0/200. PPPOT-T (PASS), PPPOT-IC (PASS). (Pre-rig). FMC New Standard; Casing head: 133/8" x 13 5/8" 5M w/ (1) 3" FMC model 120 OA valve. Tubing head: 13 5/8" 5M x 13 5/8" 5M w/ (2) 2" FMC model 120 IA valves. Tubing head adapter: 13 5/8" 5M x 7" SM. Tree: Cameron 7" 5M x 63/8". PPPOT-T: Sting into test void to check pressure (1300 psi), bled pressure to 0 psi (gas). Pump through void until clean fluid was achieved. Pressure void to 5000 psi for 30 min test, no loss of pressure, (PASS). Functioned all LDS, no sign of bent or broken pins. PPPOT-IC: Sting into test void to check pressure (0 psi). Pump through void until clean fluid was achieved. Pressured void to 3000 psi for 30 min test, no loss of pressure (PASS). Functioned all LDS, no sign of bent or broken pins. http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 51212007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-36 03-36 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2007 Rig Release: 5/7/2007 Rig Number: Spud Date: 4/3/1993 End: 4/8/2007 00:00 - 09:00 9.00 MOB P PRE Release rig from P2-15A @ 00:00. Move lliamna Camp, truck shop, and pit module from P2-15A to DS 03-36. Back substructure off well, lay down derrick. Prepare substructure to move, and wait on security to complete escorting Camp to 03-36. 09:00 - 00:00 15.00 MOB P PRE Move rig substructure from P2-15A to 03-36. As of 00:00, substructure is on spine road near DS-02. 4/9/2007 00:00 - 09:30 9.50 MOB P PRE Move rig onto DS-03 well # 36. Spot sub over well. 09:30 - 11 :00 1.50 RIGU P PRE Inspect derrick and prepare ro raise the derrick. Raise the derrick. 11 :00 - 12:00 1.00 RIGU P PRE Spot pits on sub, prepare rig floor to bridle down. 12:00 - 14:00 2.00 RIGU P PRE Pre-spud meeting wI BP WSL, NAD TP, Mud man & rig crew. Rig down bridle lines, rig up Top drive, lines and tongs. 14:00 - 20:30 6.50 RIGU P PRE Change draworks brake bands. Accept rig 20:30 hrs. 20:30 - 23:30 3.00 RIGU P PRE DSM pull BPV & install TWC wI lubricator. Test TWC fl above to 1000 psi - OK. 23:30 - 00:00 0.50 RIGU P PRE FMC function LDS and bleed void on adaptor. Hold pre-spud wI morning crew, BP WSLs, NAD TP, night mud engineer. 4/10/2007 00:00 - 02:00 2.00 WHSUR P DECOMP Nipple down tree. 02:00 - 04:00 2.00 BOPSU P DECOMP Nipple up BOPE. 04:00 - 07:00 3.00 BOPSU P DECOMP Change out lower pipe rams to 4.5" - 7" variable pipe rams. Adjust bell nipple length. 07:00 - 12:30 5.50 BOPSU DECOMP Rig up and test BOPs to 250 psi low pressure, 4000 psi high pressure wI 4" and 7" test joints. Test 5" TIW and dart valves 250 psi low pressure, 4000 psi high pressure. Perform accumulator test. Test annular preventer to 3500 psi. Test witnessed by BP WSL Duncan Ferguson & Nabors tool pusher Larry Wurdeman. Jeff Jones waived AOGCC presence for test. 12:30 - 13:00 0.50 BOPSU P DECOMP RD test equipment and BD choke and kill lines. 13:00 - 15:00 2.00 BOPSU P DECOMP RU Drill Site Maintenance and pull two way check valve w/lubricator. RD DSM. 15:00 - 19:30 4.50 PULL P DECOMP PJSM. Rig up E-line 5 1/2" shooting nipple and pack-off with pump in sub and jet cutting equipment. 19:30 - 21 :45 2.25 PULL P DECOMP RIH wljet cutter. 21 :45 - 23:00 1.25 PULL P DECOMP Log and locate GLM at 11601 '. Position jet cutter and cut 5-1/2" tubing at 11570'. Saw good line movement when tool was actuated. Well bore 'U' tubed when tubing cut. 105 psi on tubing side. Wireline shooting nipple pack-off began leaking. Annulus on vacuum. Pull E-line out of hole. Packoff on shooting nipple continued leaking while pulling wireline out of hole. 1 bbl diesel leaked down outside of shooting nipple. Disposed of diesel from leak down flowline and out to cuttings box. 23:00 - 00:00 1.00 PULL P DECOMP Rig down Schlumberger E-line and pressure control equipment. 4/11/2007 00:00 - 02:00 2.00 PULL P DECOMP Reverse circulate diesel out of tubing into Tiger tank until clean. 126 gpm, 140 psi. total 96 bbl. 02:00 - 07:00 5.00 PULL P DECOMP Circulate methanol and seawater out of 5-1/2" x 9-5/8" annulus w/1 bbl of Safe Surf '0' in 40 bbls 9.8 ppg brine ahead of Printed: 51712007 11:16:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-36 03-36 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2007 Rig Release: 517/2007 Rig Number: Spud Date: 4/3/1993 End: 4/11/2007 02:00 - 07:00 5.00 PULL P DECOMP displacement taking returns into Tiger tank until clean. 126 gpm, 490 psi. 775 bbl 07:00 - 07:30 0.50 PULL P DECOMP Monitor well. Well on slight vacuum. Taking fluid at 9 bbls/hr. Spot and RU Camco spooling unit on rig floor. FMC backout LDS and makeup jt. in tubing hanger thread to pull tubing. 07:30 - 08:00 0.50 PULL P DECOMP Back out lock down screws and pull tubing hanger to floor w/21 OK, SO 185K. 08:00 - 08:30 0.50 PULL P DECOMP LD tbg. hanger. Pump dry job. RD/BD lines. 08:30 - 12:00 3.50 PULL P DECOMP POH laying down 7" tbg. f/11570' t/9356'. PU 160K, SO 135K. LD SSSV. 12:00 - 12:30 0.50 PULL P DECOMP RD control line spooler and clear floor. 12:30 - 13:45 1.25 PULL P DECOMP LD total 79 jts 7" tbg. f/9356' to 8290'. 13:45 - 23:30 9.75 PULL P DECOMP LD 7" x 5-1/2" XO, 204 jts 5-1/2" tbg, 9 GLMs, and 9.13' of 5-1/2" tbg stub f/8290' to surface. Retrieved 55 SS bands. 5-1/2" tubing had no pits or obvious corrosion damage. 23:30 - 00:00 0.50 PULL P DECOMP RD tbg handling equipment. 4/12/2007 00:00 - 02:00 2.00 CLEAN P DECOMP RU to PU drill pipe and RIH w/9-5/8" scraper. Install wear bushing. Function test rams. 02:00 - 03:00 1.00 CLEAN P DECOMP PU cleanout BHA #1 w/8.5" milltooth used bit, two boot baskets, bit sub and RIH. 03:00 - 08:00 5.00 CLEAN P DECOMP PU 5" drill pipe f/ pipeshed and RIH to 5286' wIno indication of any obstruction. 08:00 - 10:30 2.50 CLEAN P DECOMP POH f/5286' to surface and LD scraper and boot baskets. Boot baskets empty. 10:30 - 13:00 2.50 EVAL P DECOMP PJSM wIWSL, tool pusher, Schlumberger, all hands on rig up and running of USIT logs. RU E-line to run US IT. 13:00 - 18:30 5.50 EVAL P DECOMP RIH. Run USIT log in 9-5/8" casing f/5000' to surface. 18:30 - 19:30 1.00 EVAL P DECOMP RD USIT log. Found cement top 3850' on USIT. No cement found above 3850'. 19:30 - 20:30 1.00 DHB P DECOMP PJSM and RU E-line to run 9-5/8" EZSV CIBP. 20:30 - 22:30 2.00 DHB P DECOMP Correlate GR and set top of EZSV CIBP at 4777' above collar at 4783'. CCL located 10' above top of plug at 4767' when EZSV set. 22:30 - 23:00 0.50 DHB P DECOMP POH w/E-line setting tool. RD wireline. 23:00 - 00:00 1.00 EVAL P DECOMP RU and attempt 4000 psi test on 9-5/8". Use rig pumps to 3000 psi. Switch to test pump and bring pressure to 3650 psi. At 3650 psi pressure bleeding off. Bleed pressure to 0 psi. Check surface equipment. Attempt to test 2nd time with same result. Could not get test pump to take pressure above 3650 psi. Mobilize Halliburton RTTS to hunt for possible hole in casing. 4/13/2007 00:00 - 01 :00 1.00 EVAL P DECOMP Mobilize RTTS. PJSM. RU to RIH w/RTTS. 01 :00 - 03:30 2.50 EVAL P DECOMP RIH with RTTS and set at 547'. Test 9-5/8" casing below RTTS to bridge plug at 4777' to 4000 psi. Dropped 50 psi in 35 min. 03:30 - 06:30 3.00 EV AL P DECOMP RU and test 9-5/8" casing above RTTS at 547' to surface to 4000 psi. Bled off 200 psi in 20 min on 1 st attempt. Pressure back up to 4000 psi and hold for 30 minutes. Pressure dropped off 25 psi in 30 minutes. Pull RTTS up and set at 517'. Test 95/8" casing from below RTTS at 517' to bridge plug at 4777' to 4000 psi for 30 minutes. Pressure dropped off 50 psi on 30 minutes. Printed: 51712007 11:16:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-36 03-36 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2007 Rig Release: 517/2007 Rig Number: Spud Date: 4/3/1993 End: 4/13/2007 06:30 - 07:30 07:30 - 08:15 08:15 - 10:15 10:15 - 12:00 12:00 - 15:00 15:00 - 15:45 15:45 - 17:00 17:00 - 00:00 4/14/2007 00:00 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 11 :30 11 :30 - 12:00 12:00 - 16:00 16:00 - 16:30 16:30 - 00:00 4/15/2007 00:00 - 04:00 04:00 - 05:00 05:00 - 06:30 1.00 EVAL P DECOMP 0.75 EV AL P 2.00 STWHIP P DECOMP WEXIT 1.75 STWHIP P 3.00 STWHIP P 0.75 TWHIP P WEXIT WEXIT WEXIT 1.25 STWHIP P WEXIT 7.00 STWHIP P WEXIT 2.50 STWHIP P WEXIT 0.50 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 2.00 STWHIP P 1.00 STWHIP P WEXIT WEXIT 1.00 STWHIP P 2.50 DRILL P WEXIT INT1 0.50 DRILL P 4.00 DRILL P 0.50 DRILL P INT1 INT1 INT1 7.50 DRILL P INT1 4.00 DRILL P INT1 1.00 DRILL P 1.50 DRILL P INT1 INT1 PU to 517' and retest below RTTS to 4000 psi/30 min. Test above RTTS to 4000' psi/30 min. POH and LD RTTS. PJSM. PU window milling BHA #2 w/9-5/8" Baker Gen II Whipstock/starter mill/window mill assembly, MWD, bumper sub, XO, 9 6.25" drill collars, XOs, 17 jts 5" HWDP. OAL of BHA = 886.45'. Orient MWD to whipstock face at surface. PU bumper sub and nine 6.5" drill collars. PU 17 jts. 5" HWDP + 1 st 5" drill pipe and RIH to 4747'. Orient whipstock to 57 deg left. Tag Z at 4777'. ee anchor set w/20K down and shear brass bolt w/35K down. Pump 50 bbl. HI Vis spacer and displace brine to 9.5 ppg LSND milling fluid 525 gpm, 890 psi. Mill window f4756' to 4777' 120 rpm, 335 gpm, 520 psi, tq 6K, '*' 110 rpm, WOB 5-6K. Recovered 165# metal at 23:59. Pumped 50 bbl Hi Vis Super sweep at 4772'. Mill window/drill OH w/full gage window mill to 4785' and starter mill to 4792'. Work mills through window until slick. CBU w/25 bbl Hi Vis Super Sweep 550 gpm, 1120 psi. Recover 300# metal total for job. Saw cement particles in good quantity across shakers. Attempt to perform FIT to 12.0 ppg EMW w/9.5 ppg LSND mud at 4477' MD/4243' TVD w/550 psi. Shoe broke at 325 psi for 11.0 ppg EMW. RD test equipment. Service top drive and draw works. Pump dry job. POH to HWDP w/milling BHA #2. LD nine 6-1/2" drill collars. LD window mills. Upper window mill gage and in good shape. Pull wear bushing and jet stack. Reinstall wear bushing. MU BHA #3 w/Hughes 8-1/2" HCR503AZ (ser # 7114234), 1.50 deg XP motor, float, ARC LWD, MWD, NM stab, w/2 NM spiral drill collars, NM stab, NM spiral drill collar, saver sub, hyd. jars, ball catcher sub, circ valve, 17 jnts 5" HWDP w/5" drill pipe to surface. (Note: 1 st set of jars leaking oil, picked up new set of jars.) Shallow test MWD equipment. PU 5" drill pipe f/pipe-shed and RIH to 4693'. Orient 30 deg. left, establish ECD baseline 10.23 ppg. RIH through window (TOW 4756', BOW 4773') w/4K SO at 4770' and RIH below window to 4792'. Drill/slide f/4792' to 5540'. 145K PU, 115K SO, 118 ROT, 80 rpm, 513 gpm, 1650 psi on, 1497 psi ofC6K tq on, 6K tq off. ECDs = 10.32 calc/10.68 actual. ADT f/24 hrs = 4.13 hrs. AST = 1.78 hrs. ART =2.32 hrs. Progress = 748'. Drill/slide f/5540" to 5917'. 153K PU, 123K SO, 133 ROT, 80 rpm, 508 gpm, 1690 psi on, 1495 psi off, 8K tq on, 7K tq off. BHCT 89.6F. ECDs = 10.32 calc/10.51 actual. CBU x 2. 502 gpm, 1462 psi. 80 rpm, reciprocate pipe 20'. MW 9.5 ppg. Pump OOH f/5917' to window at 4756' w/1.50 deg BHA #3 for RSS. Printed: Sfl12007 11:16:48 AM TREE = 7" X 6" CARBON WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lV D = 03-36A Actual I SAFETY NOTES: CrN BAKER 60' 30' 2700' 91 @ 12450 113-3/8" CSG, 68#, NT-80, ID = H 3977' MINIMUM ID = 3.725" @ 10,486' XN NIPPLE I 9-5/8" HES EZSV 1-1 .ß81'i;' -<477, I 5-1/2" TBG, 17# TBG CUT H ~; I I' "570 19-5/8" X 4-112" BAKER, PERMANENT PKR Il 11678' I 19-5/8" CSG, 47#, NT-80S H 11901' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 17" LNR, 29#, 13-CR-80 H 11730'-12569' I DA TE REV BY COMMENTS 10/12/06 sTG ORIGINAL COMPLETION DA TE REV BY 2254' 1-14-1/2" HES X NIPPLE, 10 = 3.813" 2900' 1-1 EST CEMENT (06/20/06) 1 4599' 4756' I 9-5/8" X 7" BOT FLEX LOCK LNR HANGER WI ZXP PKR WI 12' TBS H 9-5/8" WINDOW 1 I 10317' 1-14-1/2" HES X NIPPLE, 10 = 3.813" I 10378' 1--f7" x 4-1/2" BOT S-3 10 = 3.88" 1 I 10402' 1-14-1/2" HES x NIPPLE, 10 = 3.813" I 10423' H4-1/2" HES XN NIPPLE, ID = 3.725" 10435' I-1WLEG 4-1/2" 12.6# L-80 9CR, 10 = 3.958" 10428' I 7" X 4-1/2" BOT FLEX LOCK LNR HANGER WI ZXP PKR WI 12' TBS 10588' 1-17" 26# L-80 BTG-M, 0.0383 BPF, ID = 6.2760" COMMENTS TOP 11849 12415 13020 13624 14228 14830 SWELL PACKER SUMMARY Note: ALL SWELL PACKERS ARE 4-1/2" FREECAP I 5.75" RUBBER OD MANDREL LENGTH 18'8" 18'8" SEAL LENGTH 10 10 10 10 10 10 18'8" RUBBER TYÆ FSG-11 FSG-11 FSG-11 FSG-11 FSG-11 FSG-11 CONNECTION TG-II TG-II TG-II TG-II TG-II TG-II 18'8" 18'8" 18'8" 15274' H PBTD 15365' 1-14-1/2" 12.6# t-80 TC-II, 0.0152 BPF, 10 = 3.958" PRUDHOE BAY UNrr WELL: 03-36A ÆRMrr No: API No: 50-029-22340-01 SEC 11, T10N, R15E, 2342.75 FEL 3012.63 FNL BP Exploration (Alaska) ECE~\/E Scblumberger APR 2 U Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth ¡~aska. on &. Gas Cons. Comm~m And10rage U .=S=-Q, ~ ~ 3 -() ( O¡ Well Job# Log Description Date BL 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11 B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y -06A 11628751 MEM INJECTION PROFILE 02109107 1 Z-35 11628753 DEPTH CONTROL LOG 02/10107 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNED APR 2 {) 2007 Date Delivered: c9( 04/16/07 NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ( Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: . . SARAH PALIN, GOVERNOR AI,ASIiA OIL AIQ) GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-36 Sundry Number: 307 -052 Iì Ô.... Ö\ q \v, Dear Mr. Hobbs: &CANNED fES 1 4 Z007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this /~day of February, 2007 Encl. 1Ø\~ Q'\ J)7J 2/1317 en- ~-12-ð7 ~ . STATE OF ALASKA W..s-b"?- RECEIVED ALASKA Oil AND GAS CONSERVATION COMM~ION Þ APPLICATION FOR SUNDRY APPROVAL d/rd FEB ,06 2007 AI k on 20 AAC 25.280 as a Oil & Ga~ r.nn~ ... , 1. Type of Request: ~ Abandon o Suspend o Operation Shutdown o Perforate o Time ExtensionAnchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. D Development D Exploratory 193-019 / 3. Address: D Stratigraphic ~ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~,4G//II 50- 029-22340-00-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 03-36/ Spacing Exception Required? DYes ~No 9. Property Designation: I /10. KB Elevation (ft): 11. Field / Pool(s): i ADL 028327 60.2' / Prudhoe Bay Field / Prudhoe Bay Pool 1 12. PReSENT WELL CONDITION SUMMARY .... ..·>i / > Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12569 , 9170 11728 8590 11728 12559 Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 80' 20" 111' 111' 1490 470 Surface 3946' 13-3/8" 3977' 3732' 5020 2270 Intermediate 11869' 9-5/8" 11901 ' 8708' 6870 4760 Production Liner 826' 7" 11743' - 12569' 8600' - 9170' 7240 5410 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 12080' - 12314' 8836' - 8998' 7",26# x 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 11741 ' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker packer packers and SSSV MD (ft): 11678' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory D Development ~ Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencinq Operations: February 19, 2007 DOH DGas o Plugged ~ Abandoned 17. Verbal Approval: Date: DWAG DGINJ OWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gagliardi, 564-5251 Printed Name Greg HoQbs Title Senior Drilling Engineer ,jf7Þ¿ Date 2(4"./ Prepared By Name/Number. Signature Phone 564-4191 Terrie Hubble, 564-4628 r¡'I/ Commission Use On Iv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ?-ff) _ () fjg.. D Plug Integrity ~BOP Test D Mechanical Integrity Test D Location Clearance Other: L\CJaO ,,'">,.'\ \!::f::)? ~~~ Subsequent Form Required: ,-\CJ ~ APPROVED BY ;,...(5 -01' Approved By: COMMISSl.QNER THE COMMISSION Date Form 10-403 Revised 06/2006 V~ ...... - R80MS F Submit In Duplicate - , cn " ORIGINAC \0.. Be 1 J :1 ¿,Dr . . Obp GÇJJ..~ß.r To: Tom Maunder - AOGCC Date: January 24, 2007 From: Shane Gagliardi - BPXA GPB Rotary Drilling Subject: 03-36 Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well 03-36. Well 03-36 is currently a shut-in trouble WAG injector with a production casing leak. It was drilled in 4/93 and completed 6/93 in Z2, Z3 and the Shublik. The well was acidized and tested at 207 bopd and 4177 bwpd. In 7/93 a cement retainer was set, closing off the lower Z2/22P for water shut off. Perfs in Z2 and Z3 were added in 11/93, 12/93 and the well tested at 955 bopd, 3769 bwpd. Perfs were added to the top of Z3 in 9/94. In 1/96, the well was shut-in for GOR, but brought back online with offset MI injection. A FCO and sand plug was set to 12271' in 4/96. In 5/96, perfs were added in the 27P for pre-WAG injection. The well was converted to a MI injector in 6/96, but did not take gas and the well was re-perfed in the 27P. After a mud acid job, the well took 20 MMCFGPD. In 9/96, the well was swapped from MI to PWI. After running an IPROF, an IBP was set at 12180' to isolate lower injection perfs and more perfs were added to the top of Z3 in 11/96. The well was on production from 11/96 to 9197. From 9/97 to 4/2000, 03-36 was shut-in. In 4/2000, the well was converted to a twinned WAG well with 03-12 and was on MI/PWI injection from 412000 to 7/2004 when it failed an MIT-IA. A 4.5" XN TTP was set at 11728' on 7/19/04 and the well was left shut in. On 8/11/04, a LDL found a PC leak at 8230'. Two OA downsqueezes were attempted in 7105 and 6/06, but failed MIT-OA tests. The plan is to plug and abandon the existing 7" liner from the production packer @ 11,678' to PBTD @ 12,420' md by cutting the tubing at 11,600' which is approximately 78' above the production packer and setting a cast iron bridge plug in the 9-%" intermediate casing at 4,911'. Once the cast iron plug is set, a bottom trip anchor whipstock will be set on top of the plug. The plug will be the second mechanical barrier above the production liner. Pre-RiQ Operations: 1. MITOA to 3,000 psi. 2. Bleed OA, IA and T to 0 psi. Test PPPOT -T&IC to 5,000 psi for 30 minutes. 3. Pull Tailpipe plug at 11,728' md. 4. Run static pressure survey to determine BHP for proper mud weight during drilling operations and BHT for proper cement blend. 5. Circulate out freeze protect and fluid-pack the well to seawater or kill-weight fluid. 6. RIU coiled tubing. RIH and plug and abandon the open perforations (376' from 12,062' - 12,438') with a minimum of 891' (>31 bbls) of 15.8ppg class 'G' cement from PBTD @ 12,569' to -11,626'. 7. Pressure test the cement plug to 3,500 psi for 30 minutes. 8. Drift the 5-%",17#, 13Cr80 NSCC tubing to estimated TOC @ -11,626' md. Tag cement to verify TOe depth. 9. Pull/owest GLM @ 11,601'. 03-36 Application for Sundry ~ -,c.-¡ ..::P- I'( Y' ~ u-"Z<:{ 1 *~ ~~~ ~ .::;' ~ . . 10. Circulate the well to seawater through the GLM until returns are clean. 11. Bleed casing and annulus pressures to zero. Freeze protect to -2,200' md with diesel. 12. Replace GLM @ 11,601. 13. Pressure test tubing to 3,000 psi for 30 minutes. 14. Function all tubing and casing Lock Down Screws. Repair and replace as necessary. 15. Set a BPV. Well house and flow line are not currently installed. Level the pad as necessary. Ria Operations: 1. MI I RU Nabors rig 7ES 2. Pull BPV. Circulate out diesel freeze protection and displace the well to kill weight fluid. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 4,000 psi. Pull TWC. 4. MIRU SWS. RIH with the appropriate jet cutter and cut the 5-W' tubing at -11,580' md. 5. R/U. Pull 5-%" tubing from the cut at -11,580' md and above. Send tubing in for inspection. 6. R/U E-line. M/U 8.5" gauge ring I junk basket I CCL. RIH to 5,000' md. POOH. Run USIT from 5,000' md to surface. 7. Evaluate USIT for condition of the 9-%" casing. Estimated cement top is 2,900' md. 8. RIH with HES EZSV on E-line. Set bridge plug at -4,911' md elm, as required to avoid cutting a casing collar while milling the window. POH. RID E-line. 9. Pressure-test the 9-%" casing to 4,000 psi for 30 minutes. Record test. Chase leaks down if necessary. 1 O. P/U and RIH with 9-%" Baker bottom-trip anchor whip stock assembly on 5" DP. Orient whip stock as desired and set on bridge plug. Shear off of whip stock. 11. Displace the well to 9.5 ppg LSND based milling fluid. Completely displace the well prior to be inn in millin 0 erations. 12. Mill window in 9-%" casing at ± 4,900' md, plus approximately 20' beyond middle of window. Circulate well bore clean. 13. Pull up into 9-%" casing and conduct an FIT to 12.0 ppg EMW. POH. 14. M/U 8-%" Dir/GR/Res/PWD Power Drive assembly. RIH, kick off and drill the 8-%" intermediate section to -100' above the HRZ with 9.5 - 9.8 ppg LSND. 15. By -10,041' md (-150' above the top of the HRZ) have the entire circulating system weighted up to 10.3 ppg with spike fluid from the MI plant. 16. Continue drilling ahead in the 8-%" hole section to the top of the Shublik, per directional proposal. The Sag River has been eroded by the LCU. Circulate well clean, short trip to window as necessary. POOH. 17. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 18. If necessary, run and cement a 7", 26.0#, L-80 scab liner to within 300' of surface casing shoe as needed to cover any potentially bad portions of intermediate casing indicated by USIT. 19. POOH and LD 5" DP. 20. M/U 6-Ya" Dir/GR bent housing motor wI roller cone bit on 4" DP. RIH to the 7" liner landing collar. Test to 4,000 psi. 21. Drill out the 7" liner float equipment and cement to the shoe. 22. Displace the well to 8.4 ppg Flo-Pro SF drilling fluid. 23. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. 24. Drill ahead to the end of the 8°/100' DLS build section. Should be horizontal at this point. POOH. 25. M/U 6-Ys" Dir/GR/Res PDM 1.5° assembly. 26. Drill ahead to TD per directional proposal. 27. Circulate well bore clean (at least 3x bottoms up) at max rate. Circulate and short trip to shoe as necessary. POOH. 28. Run and cement 4-%",12.6#, L-80, TC-II solid production liner. POOH. 29. RIH with DPC perf guns. Perf intervals for the first MI bulb will be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns. 03-36 Application for Sundry . . 30. R/U and run a 4-1t2", 12.6#, L-80, TC-II tubing completion, stinging into the 4-%" liner tie back sleeve. 31. Reverse circ CI and freeze protect well to -2,200' tvd prior to setting packer. 32. Set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes. Record each test. 33. Set a BPV. 34. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 35. Secure the well. 36. Rig down and move off. Post..Ria Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. 03-36 Application for Sundry TREE = 7" X 6" CARBON WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum ND = . 03-36 CrN BAKER 60' 30' 2700' 54 @ 5426 12115' 8800' SS . 7" TBG, 26#, 13-CR-80, .0383 bpf, ID = 6.276" 113-3/8" CSG, 68#, NT-80, ID = Minimum ID = 3.625" @ 12002'·12154' CMT COLLAR 15-112" TBG, 17#, 13-CR-80, I 3285'·11676' 14-1/2" TBG, 12.6#, 13-CR-80, 11676'·11741' I 9-5/8" CSG, 47#, NT-80S ÆRFORA TION SUMMARY REF LOG: BHCS ON 04/22/93 ANGLEATTOPÆRF: 44 @ 12062' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 6 12062 - 12080 S 10/01/00 12 12080 - 12082 C 10/01/00 6 12082 - 12090 C 10/01/00 12 12090 - 12100 C 10/01/00 6 12100 -12110 S 10/01/00 6 12206 - 12216 C 07/21/96 12 12216 - 12226 C 07/21/96 16 12226 - 12230 C 07/02/96 10 12230 - 12236 C 06/22/96 9 12244 - 12253 S 04/27/96 4 12308 -12312 C 12/11/93 4 12312 -12314 C 11/13/93 6 12330 - 12334 S 11/04/93 6 12382 - 12386 S 11/04/93 6 12430 - 12438 S 07/09/93 17" LNR, 29#, 13-CR-80 I 11730'·12569' DATE 04/29/93 04/29/93 06/27/02 08/09/02 07/29/05 09/23/05 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER BHClTLH ÆRF CORRECTIONS BHC/KK ÆRF CORRECTIONS LDK/TLH OA OWN SQZ KSB/TLH PXN TIP SET (07/19/04) S4NOTES: **CHROME TBG & LNR*** 2245' -17" CAMCO BAL-O SSSV NIP, 10 = 5.937" I 2900' -1 EST CEMENT (06/20/06) -i7" X 5-1/2" XO ST MD 1 3377 2 5592 3 6747 4 7517 5 8289 6 9069 7 9849 8 10631 9 11017 10 11601 11730' GAS LIFT MANDRELS NO DEV TYPE VLV LATCH 3298 35 LB-1 DMY T-2 4737 53 LB-1 DMY T-2 5467 48 LB-1 DMY T-2 5973 51 LB-1 DMY T-2 6464 51 LB-1 DMY T-2 6950 51 LB-1 DMY RA 7419 53 LB-1 DMY RA 7904 51 LB-1 DMY RA 8140 53 LB-1 DMY RA 8504 49 LB-1 DMY T-2 -i5-1/2" PARKER SWN NIP, 10 = 4.656" -i 5-1/2" X 4-1/2" XO I H 9-5/8" X 4-1/2" BAKER, PERMANENT A<R -i4-1/2" PARKER SWS NIP, 10 = 3.813" -14-1/2" PARKER SWN NIP, 10 = 3.725" 4-1/2" PXN TIP (07/19/04) 4-1/2" TUBING TAIL PORT o o o o o o o o o o 12002'·12167' -i CMTCOLLAR, ID = 3.625" I DATE REV BY COMMENTS 06/20/06 DPS/PJC OA OWN SQZ 85% OF RUBBER ELEMENT FROM IBP 10/07/97 ÆRF GUN 07/20/93 I CEMENT RETAINER SET 07/09/93 PBTD DATE 02/03/00 12/23/96 03/30/96 12/23/96 02/03/00 04/29/93 04/29/93 04/29/93 04/29/93 02/03/00 PRUDHOE BAY UNfT WELL: 'ð3-36 PERMfT No: II!¡ 930190 API No: 50-029-22340-00 SEC 11, T10N, R15E. 2342.75 FEL 3012.63 FNL BP Exploration (Alaska) TREE = 7" X 6" CARBON ELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = OatumlVO= 03-3_ Proposed ~NOTES CrN BAKER 60' 30' 2700' 91 @ 12450 2220' --4-1/2" HES X NIPPLE, 10 = 3,813" 2900' --fEST CEMENT (06/20/06) I 113-3/8" CSG, 68#, NT-80, 10 = H 3977' I 9-5/8" X 7" BOT FLEX LOCK LNR HANGER W/ ZXP A<R W/ 12' TBS 1-19-5/8" WINDOW I 4750' 4900' MINIMUM ID = 3.725" @ 10,486' XN NIPPLE I 9-5/8" HES EZSV 1-1 4911' I 10305' 1-14-1/2" HES X NIPPLE, 10 = 3.813" I 10368' H7"X4-1/2" BOTS-3 10=3.88" I I I I I I 10415' 1-14-1/2" HES X NIPPLE, 10 = 3.813" 10415' H4-1/2" HES XN NIPPLE, 10 = 3.725" 5-1/2"TBG,17#TBGCUT H 11600' I 10426' 1-t4-1/2" 12.6# L-80 TC-II, 0.0152 BPF, 10 = 3.958" I 7" X 4-1/2" BOT FLEX LOCK LNR HANGER W/ ZXP A<R W/ 12' TBS 1--17" 26# L-80 BTC-M, 0.0383 BPF, 10 = 6.2760" 10426' 10576' Î 11678' I 9-5/8" X 4-1/2" BAKER, ÆRMANENTA<R SWELL PACKER SUMMARY Note: ALL SWELL PACKERS ARE 4-1/2" FREECAP I 5.75" RUBBER 00 MANDREL. LENGTH 18'8" 18'8" 18'8" 18'8" 18'8" 18'8" 19-5/8" CSG, 47#, NT-80S 1-1 11901' SEAL LENGTH 10 10 10 10 10 10 ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE TOP 14779 14279 13779 13279 12779 12279 RUBBERTYÆ FSC-11 FSC-11 FSC-11 FSC-11 FSC-11 FSC-11 CONNECTION TC-II TC-II TC-II TC-II TC-II TC-II 15279' H PBTD 15365' H 4-1 /2" 12.6# L-80 IBT, 0.0152 BPF, 10 = 3.958" 17" LNR, 29#, 13-CR-80 H 11730'-12569'1 DATE REV BY COMMENTS 10/12/06 STG ORIGINAL COMPLETION OA TE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 03-36A ÆRMIT No: API No: 50-029-22340-01 SEC 11, T10N, R15E, 2342.75 FEL 3012.63 FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 0 5 2006 REPORT OF SUNDRY WELL OPERA TIQNSOiI & Gas Cons. Commission . . RECEIVED 1. Operations Performed: OtherÕ Abandon 0 Repair WellŒJ Plug PerforationsD Stimulate 0 Alter CasingO Pull TubingD Perforate New PaolO WaiverO Time ExtensionO Change Approved ProgramO Operation ShutdownD Perforate 0 Re-enter Suspended WellO 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryO 1Q'Lft1Gn 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceŒj 50-029-22340-00-00 7. KB Elevation (ft): 9. Well Name and Number: 60.20 03-36 8. Property Designation: 10. Field/Pool(s): ADL-0028327 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12569 feet true vertical 9170.3 feet Plugs (measured) 4-1/2" PXN TTP @ 11728 (07/14/2006) Effective Depth measured 12420 feet Junk (measured) Junk @ 12559 & 12564 (7/1993 & 10/1997) true vertical 9009.7 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 36 - 116 36.0 - 116.0 1490 470 SURFACE 3942 13·3/8" 68# NT -80 35 - 3977 35.0 - 3732.4 5020 2270 PRODUCTION 11869 9-5/8" 47# NT-80S 32 - 11901 32.0 - 8708.2 6870 4760 LINER 826 7" 29# 13Cr80 11743 - 12569 8599.7 - 9170.3 8160 7020 "Cþ¡,!tt..r'1Ef\ ,¢-,; "J Perforation depth: ':;""i/ - \~ <,l~ - i""'" "'.;) Ú"" Measured depth: 12080-12100, 12206-12236, 12308-12314) True vertical depth: 8836-8850, 8924-8945, 8994-8998 Tubing (size, grade, and measured depth): 7" 26# 13Cr80 @ 30 - 3285 5-1/2" 17# 13Cr80 @ 3285 - 11676 4-1/2" 12.6# 13CrSO @ 11676 - 11741 Packers & SSSV (type & measured depth): 9-5/8" Baker PERM Packer @ 11678 7" Cameo BAL-O SSSV Nip @ 2245 12. Stimulation or cement squeeze summary: r"IW, Ul.II.... 8Ft 0 CT 0 9 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaoe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casiria Pressure Tubing Pressure Prior to well operation: --- --- 51 --- 865 Subsequent to operation: -- --- 51 --- 900 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ X OilD GasO WAG ŒJ GINJO WINJO WDSPLO Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TSUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr 305-141 Printed Name DeWayne R. Schnorr . Title Petroleum Engineer Signature ~~ . ¿;? JL ¿t Phone 564-5174 Date 1 0/4/06 i7 ( °fGINÞíL . Form 10 404 Revised 4/2004 . . 03-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/03/2006 TestEvent --- Inj Press, psi: 516 Type: PW Vol: 07/14/2006 Set 4-1/2" XN TTP @ 11728' , left well shut-in 06/27/2006 T/I/O=780/0/150 MIT OA (Obtain waiver compliance, post cement job) FAILED Established LLR of 2.0 BPM @ 900 psi for 20 bbls or 10 minutes, Pumped 25 bbls crude down OA, Bled back 4.4 bbls crude. MIT Tubing to 3000 psi. PÞ,SSED Loss 60 psi 1 st 15 min & 0 psi 2nd 06/27/2006 2nd OA downsqz failed, MITOA failed, MIT-T passed to 3000 psi 06/19/2006 OA Down Squeeze. Pumped 10 bbls Meth spear,1 0 bbls DS CW1 01 (surfactant), 280 bbls water flush for OA, 30 bbls of Arctis Set 1 @ 15.7 ppg, displace with168 bbls of crude. Monitor WHPs for 1 hour post. 06/19/2006 T/I/O= Assist SLB Cement w/ OA DownSqz. Pumped 10 bbls Meth ahead of Cement. Pumped 163 bbls Crude to displace Cement. Monitored for 1 hr. Bled OA from 500 psi to 0 psi w/ 2 bbls returns. Turn over to DSO to Monitor. Final WHP's=1450/0/0 06/17/2006 T/I/O=860Nac/140. Temp=SI. Record WHPs (pre-OA DWN SQZ). OA FL @ surface. 05/31/2006 T/I/O=850/vac/450 Injectivity test on OA (AA & waiver for PC leak) - Pump 250 bbls crude down OA to establish inection rate of 5 bpm @ 1150 psi, for 100 bbls. FWHP's=1000/0/200 OS/29/2006 T/I/O=840NAC/480 Load OA injectivity test (AA & Waiver for PC leak) Rig up start bleeding OA psi rig down job postponed Final Whp's=840NAC/440 OS/27/2006 T/I/O=820NAC/950, Temp=SI. Re-depress OA FL if pressure has dropped (pre-down sqz). Initial OA FL @ 2448', TBG & lAP remained unchanged, OAP decreased 270 psi overnight. OA FL decreased 24' overnight. Pressured up OAP from 950 psi to 1400 psi in 1 hr 10 min. Monitored OA for 30 min, OAP decreased 125 psi, OA FL decreased 6' to 2454'. Repeated this process again. OA FL in-flowed 36' to 2418'. Pressured up OA for 2 hrs 15 min and could only achive 1450 psi, shut-in source and shot OA FL. OA FL in-flowed 54' to 2364'. Monitored pressures for 45 min, OAP decreased 140 psi to 1320 psi and the OA FL decreased 48' to 2412'. Bleed OAP from 1280 psi to 450 psi in 4.5 hrs, OA FL 2418'. FWHP=820Nac/450. OS/26/2006 T/I/O=820NAC/980, Temp=SI. Re-Depress OA FL if pressure has dropped (pre-downsqz). Initial OA FL @ 1596' (93 bbls). OA FL decreased 96' overnight. Pressured up OAP to 1300 psi in 100 psi incraments. Monitor pressure for 60 min. OAP FL decreased to 1878', OAP decreased 1250 psi. Repeated this process 4 times. OA FL decreased 864' to 2460' (143 bbls) in todays operation. Left OAP @ 1260 psi overnight. FWHP=820NAC/1260. Page 1 . . 03-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS OS/25/2006 TIO = 750NAC/800. Temp = SI. Re-Depress OA FL (pre-downsqueeze). OA FL dropped 50' to 1405' & OAP decreased 50 psi to 800 psi overnight. Stacked out OAP from 800 psi to 1000 psi with AL from 03-14 (200' of hose needed) in 40 mins. OA FL dropped 40' to 1445'. Monitored 1 hr. OAP decreased 20 psi & OA FL dropped 20' to 1465'. Repeated 3 more times. Depressed OA FL to 1500'. OAP decreased 10 psi during RD to 980 psi. FWHP's = 750NAC/980. OS/24/2006 TII/O=760/vac/850. Temp=SI. Re-depress OA FL if pressure has dropped (pre downsqueze. No change in TBGP or lAP. OAP decreased 140 psi over night. OA FL dropped from 1102' to 1355' over night. OS/23/2006 T/I/O=760NAC/150 Temp=SI Re-depress OA FL for OA downsqueeze. OA FL @ surface. Using AIL gas, pressurized OA to 350 psi in 1 minute. Monitor for 15 minutes. OA FL near surface. Increased OAP to 550 psi. The OAP seemed to "break loose" @ this point. Continued applying AIL to OA for 1 more minute until OAP stabilized @ 550 psi. Shut in and monitor for 15 minutes. OAP decreased 70 psi and OA FL @ 36', Increased OAP to 750 psi in 5 minutes. Monitor for 15 minutes. OAP decreased 130 psi and OA FL @ 114'. Increased OAP to 820 psi in 30 minutes. Monitor for 15 minutes. OAP decreased 40 psi and OA FL @ 450'. Increased OAP to 1000 psi in 50 minutes. Monitor for 15 minutes. OAP decreased 50 psi and OA FL @ 828'. Increased OAP to 1000 psi in 15 minutes. Monitor for 15 minutes. OAP decreased 30 psi and OA FL @ 930'. Increased OAP to 1000 psi in 15 minutes. Monitor for 15 minutes. OAP decreased 0 psi and OA FL @ 1002'. Bled 10 psi back to bleed trailer. Notified DSO not to bleed. Final WHPs=760NAC/990. 12/31/2005 T/I/O= 910Nac/170. Temp= SI. OA FL (pre-down squeeze). OA FL @ surface. 07/31/2005 T/I/O 1620Nac/180 MIT OA. to 2400 psi (FAILED-Never reached Test Pressure) Established a LLR of 2.0 bpm @ 840 psi [Post OA Own Sqz] Started pumping down OA. OAP started to pressure up. OAP reached 600 psi and stabilized there for 5 bbls. Increased rate from 0.3 to 2.0 bpm. . Established a LLR of 2.0 @ 840 psi for 15 bbls. SO, OAP slowly falling down. Monitor for 15 l11ins, OAP= 590 psi. Total bbls pumped =20 diesel Bled OA RDMO Final WHP's 1620Nac/300. 07/29/2005 T/I/O= SSV shutlO/200 Pump 198 bbls crude down OA. for cement Own sqz. 07/29/2005 TII/O Shut-ln/0/375 OA DWNSQZ, Pumped 10 bbl's Methanol, 10 bbl's (OS CW101) Surfactant, 365 bbl's fresh water, 30 bbl's 15.7# Arctic Set Cement, 5 bbl fresh water flush and 198 bbl's of cold crude down the OA. Final T/I/O Shut-ln/0/150. 07/25/2005 TII/O=120/0/400 Load OA with 104 bbls crude. Established LLR of 4 BPM @ 1500 psi for 25 bbls. Bled down OA. FWHP's=60/0/800 07/21/2005 T/I/O=SSVNac./400, Temp=SI. fA FL@ 42' (1 bbls), OA FL @ 768' (54 bbls). Page 2 . . 03-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 20 Neat Methanol 12.6 60/40 Methanol Water 20 Diesel 908 Crude 655 Fresh Water 20 Surfactant (DS CW101) 60 15.7# Arctic Set #1 Cement 1695,6 TOTAL Page 3 TREE = 7" X 6" CARBON WELLHEA D = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = crvv BAKER 60' 30' 2700' 54 @ 5426 12115' 8800' SS 03-36 . 7" TBG, 26#, 13-CR-80, .0383 bpf, 10 = 6.276" 113-3/8" CSG, 68#, NT-80, ID = I Minimum ID = 3.625" @ 12002'-12154' CMT COLLAR 15-1/2" TBG, 17#, 13-CR-SO, I 3285'-11676' 14-1/2" TBG, 12.6#, 13-CR·SO, I 11676'-11741' 19-5/8" CSG, 47#, NT-80S ÆRFORA TION SUMMARY REF LOG: BHCS ON 04/22/93 ANGLEATTOPÆRF: 44 @ 12062' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 6 12062 - 12080 S 10/01/00 12 12080 - 12082 C 10/01/00 6 12082 - 12090 C 10/01/00 12 12090 - 12100 C 10/01/00 6 12100 - 12110 S 10/01/00 6 12206 - 12216 C 07/21/96 12 12216 - 12226 C 07121/96 16 12226 - 12230 C 07/02/96 10 12230 - 12236 C 06/22196 9 12244 - 12253 S 04/27/96 4 12308 - 12312 C 12/11/93 4 12312 - 12314 C 11/13193 6 12330 - 12334 S 11/04/93 6 12382 - 12386 S 11/04/93 6 12430 - 12438 S 07/09/93 DATE 04129193 04129/93 06/27102 08/09/02 07/29/05 09/23/05 17" LNR, 29#, 13-CR-80 I 11730'-12569' REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER BHClTLH ÆRF CORRECTIONS BHC/KK ÆRF CORRECTIONS LDK/TLH OA OWN saz KSBITLH PXNTIPSEr(07/19/04) SAFETY NOTES: **CHROME TBG & LNR*** 2245' 47" CAMCO BAL-O SSSV NIP, ID = 5.937" I 2900' -1 EST CEMENT (06/20/06) 47" X 5-1/2" XO I GAS LIFT MANDR8...S ST MD TVD OEV TYÆ VLV LATCH PORT DATE 1 3377 3298 35 LB-1 DMY T-2 0 02/03/00 2 5592 4737 53 LB-1 DMY T-2 0 12/23/96 3 6747 5467 48 LB-1 DMY T-2 0 03/30/96 4 7517 5973 51 LB-1 DMY T-2 0 12/23/96 5 8289 6464 51 LB-1 DMY T-2 0 02/03/00 6 9069 6950 51 LB-1 DMY RA 0 04/29/93 7 9849 7419 53 LB-1 DMY RA 0 04129/93 8 10631 7904 51 LB-1 DMY RA 0 04/29/93 9 11017 8140 53 LB-1 OMY RA 0 04/Z9/93 10 11601 8504 49 LB-1 DMY T-2 0 OZ/03/00 -15-112" PARKERSWN NIP, 10 = 4.656" -15-1/Z" X4-1/Z" XO I -19-5/8" X 4-1/2" BAKER, ÆRMANENT PKR -14-1/2" PARKER SWS NIP, ID - 3.813" I -14-1/2" PARKER SWN NIP, ID = 3.725" I 4-lIZ" PXNTIP f07119:04) (0'7/19;200') 4-1/2" TUBING TAIL 11730' 12002'-12167' -1 CMT COLLAR, ID = 3.625" I 85% OF RUBBER ELEMENT FROM IBP 10107/97 ÆRF GUN 07/20/93 CEMENT RETAINER SET 07/09/93 PBTD PRUDHOE BA Y UNIT WELL: ~03-36 ÆRMIT No: ~1930190 API No: 50-029-22340-00 SEC 11, T10N, R15E, 2342.75 FEL 3012.63 FNL DA TE RBI BY COMMENTS 06/20/06 DPS/PJC OA DWN SQZ BP Exploration (Alaska) ) ) ,,-'" 'rb (t ! 'I I ~F I ill if I\'0 ill /~ nr;ï (:-'~ I: )~ '~. '. !: I' 1\\/\\;1, '~. il p-iJ / I1.J \,L ¡ ¡ / !u \; '^'~<\\,\ ! , \ I ¡ r r , :' 1 I' "",J\j ~ Lri,J ~'Jl) j-~ f.,·.liì..'\ " f ðJ \ lll\ " / I )' / FRANK H. MURKOWSKI, GOVERNOR AlASKA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Carlson Petroleum. Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 9951 9-6612 \~?J..o\q Re: Prudhoe Bay 03-36 SCANNED: JUN 1 4 2005 Sundry Number 305-141 Dear Mr. Carlson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum. field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a 'day or weekend. A person may not appeal a Commission decision to Superior,ourt unless rehearing has been requested. ~ DATED this~day of June, 2005 Encl. bp ') ) R E· ,("', r=. ~ 'h..1! ~ r) . ',¡" -' ~ I.,~~ ~~ \~ ! ~:\'~""'. ~ ~ . :\.), 1,,:~~',R'¡'L' '~¡;i:W~: P , ,:# "I UN 0 6 [005 June 3, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: AIi11~~G~ Io,i': ,~~. ~ ~ '~~: ~ '~~ ~~ ¡; ~ 0 n RE: Sundry Notice for 03-36 OA Downsqueeze BP Exploration Alaska, Inc. proposes to do the following wellwork to obtain an injection waiver for well 03-36. Step Type Procedure 1 0 OA FL depress 2 F OA cement down squeeze / 3 F MIT OA after WOC DS03-36 is an injector which requires a waiver for TxlA communication. In order to / waiver the well for injection, an OA down squeeze must be performed. CITOA on 12/04/04 failed with a LLR of 2.5 bpm at 900 pSi.Xhis program is designed to pump a /' column of cement from the shoe to approximately 500 feet above the shoe for waiver compliance. 08/02/04: MIT-T Passed to 3000 psi /' 08/11/04: LDL found PC leak at 8230' MD 11/23/04: LNFT-IA Failed, 3.75 gpm * 12/04/04: Brine load IA. 12/04/04: CITOA Failed. LLR = 2.5 bpm @ 900 psi. Looks like a blown shoe. 12/09/04: LNFT-IA Passed *" 12/13/04: Depressed OA FL to 2380' /' The procedure includes the following major steps: 1. DHD Shoot fluid levels and record WHP's 2. DHD Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as required. " 3. F OA cement down squeeze / 4. F MIT OA atter waiting on cement (WOC) Please contact Brian Carlson at 564-5046 with any questions. Sincerely, Brian H Carlson ~lf~ A&X Pad Production Engineer OP·:,.\Ct1\IAL ; '~ , ~ ¡ '.J C(ti & ,'1,,0 C \tJ6A- ft:/7/ZttOr; ) STATE OF ALASKA -r s h/7 / 5 ALASKA OIL AND GAS CONSERVATION cOMMlsslo~FCE,lvED APPLICATION FOR SUNDRY APPROVÄL 'O"~ 2005 20 AAC 25.280 JUN u StratigraphicD Service ŒJ 9. Well Name and Number: 03-36 /" 1 O. Field/Pool(s): Prudhoe Bay Field / Prudhoe OilPool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 12420 9009.7 MD TVD 1. Type of Request: [J Suspend [J D RepairWell g] D Pull Tubing D Abandon Alter Casing Change Approved Program 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 60.20 KB 8. Property Designation: ADL-028327 11. Present Total Depth MD (ft): 12569 Casing Total Depth TVD (ft): 9170.3 Length Size CONDUCTOR LINER PRODUCTION SURFACE 80 826 11869 3942 20" 91.5# H-40 7" 29# 13CR80 9-5/8" 47# NT80S 13-3/8" 68# NT80CY~ Perforation Depth MD (ft): 12206 - 12236 12308 - 12314 Perforation Depth TVD (ft): 8924 - 8845.2 8994 - 8998.6 Packers and SSSV Type: 7" TIW Packer 4-112" BOT Perm Packer 7" Cameo BAL-O SSSV Nipple 12. Attachments: Description Summary of Proposal ŒJ Detailed Operations Proç¡ram 0 BOP Sketch 0 14. Estimated Date for Commencing Operation: ./ June 20, 2005 Date: /1 Operation Shutdown Plug Perforations Perforate New Pool 4. Current Well Class: Development D top 36 11743 32 35 bottom top 116 12569 11901 3977 Tubing Size: 7 " 5-1/2 " 4-1/2" " D D D ð:ha~k Oil &. ~¡t¡s.r~omr.-Commiss¡o!1 Perforatet::.:]~ CD I r.J-vvmverlJ Other D StimulateD Timef~J~qr8~ÊJ Re-enter Suspended Well D 5. Permit to Drill Number: 193-0190 /' Exploratory D / 6. API Number ,/ 50-029-22340-00-00 Plugs (md): None Burst Junk (md): 12559,12564 Collapse 36.0 8599.7 32.0 35.0 bottom 116.0 9170.3 8708.2 3732.4 470 7020 4760 2270 1490 8160 6870 5020 26 # 17# 12.6 # Tubing Grade: Tubing MD (ft): 13CR80 30 13Cr80 3285 13Cr80 11676 3285 11676 11741 Packers and SSSV MD (ft): 11752 11678 2245 13. Well Class after proposed work: Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD AbandonedD ~ µ6ft- WAG I..!.I GINJD 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Etrian Carlson / ~ ~~1rt-¿/, ~. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD 1(' - 4L~4 . / '/ ~ Form 10-403 Revised 11/2004 Mechanciallntegrity Test D Service ŒI ,/ Contact Wlf\W.OO-.... WDSPLD Prepared by Garry Catron 564-4657. Brian Carlson Title Phone Petroleum Engineer 564-5046 6/6/05 Sundry Number: 305""-1 W Location Clearance D RBDMS BFL JUN 0 8 2005 BY ORDER OF t. h...,h /' THE COMMISSION Date: ,. Tf ~ C)R\GINAL SUBMIT IN DUPLICATE 1REE= T' X6" CARBON WELLHEAD = 'ÄcfUA:fB'f:f;;;''''''ëlw'13ÄKER 'RB^:'-E['Bì--; ..w,,,_,.,,,,, ,," ..,,,, """'SÕ,' BF':à EV~' ... .. ... ..... .... . "30; k6Þ';' .. ... "'2700ï .~~~~.~I~.~......~~..~.~~?? O:itum IvD = ....... 1?1.1~:, O:itumTVO = 8800' SS 7" TBG, 26#, 13-ffi-80, -{ 3285' 0.0383 bpf, 10 = 6.276" 113-3/8" CSG, 68#, NT-80, 10 = H 3977' ) 03-36 (' ") I SAÆTY NOTES: - ~- ~ L Minimum ID = 3.625" @ 12002'-12154' CMT COLLAR 15-1/2" TBG, 17#, 13-CR-80, 1-13285'-11676' 1 ~ , ZZ 14-1/2"TBG, 12.6#, 13-CR-80, 1-111676'-11741'1 1 9-5/8" CSG, 47#, NT-80S H 11901' r--. ÆRFORA TION SUMv1ARY REF LOG: BHeS ON 04/22/93 ANGLE AT TOP ÆRF: 44 @ 12062' .. Note: Refer to Production OB for historcal perf data SIZE SPF INTER\! AL Opn/Sqz OATE 6 12062 - 12080 S 10/01/00 12 12080 - 12082 C 10/01/00 6 12082 - 12090 C 10/01/00 1212090-12100 C 10/01/00 6 12100-12110 S 10/01/00 6 12206- 12216 0 07/21/96 12 12216 - 12226 0 07/21/96 16 12226 - 12230 0 07/02196 10 12230 - 12236 0 06/22196 9 12244 - 12253 S 04/27/96 4 12308-12312 0 12/11/93 4 12312-12314 0 11/13/93 6 12330- 12334 S 11/04/93 6 12382 - 12386 S 11/04/93 6 12430 - 12438 S 07/09/93 l7" LNR. 29#, 13-ffi-80 H 11730'-12569' 1 [)/\lE 04129/93 04129/93 12112100 02115/01 06/27/02 08109/02 REV BY COMrvENTS ORIGINAL COMFlETlON LAST WORKOVER CONVERlEO TO CANV AS CORRECTIONS PERF COffiEeTIONS PERF COffiEeTIONS SS-JLH DA. CAp BHCAlh BHe/KK r ,- ... 2245' 1-iT' CAMCO BAL-O SSSV NIP, 10 = 5.937" I 3285' 1-iT' X 5-1/2" XO 1 GAS LIFT tv1A f\DRELS ST MO WO DEV TYÆ VLV LATCH FORT DA.lE 1 3377 3298 35 LB-1 OM'( T-2 0 02103/00 2 5592 4737 53 LB-1 OM'( T-2 0 12123/96 3 6747 5467 48 LB-1 OM'( T-2 0 03/30/96 4 7517 5973 51 LB-1 OM'( T-2 0 12123/96 5 8289 6464 51 LB-1 OM'( T-2 . 0 02103/00 6 9069 6950 51 LB-1 OM'( RA 0 04/29/93 7 9849 7419 53 LB-1 OM'( RA 0 04/29/93 8 10631 7904 51 LB-1 OM'( RA 0 04/29/93 9 11 017 8140 53 LB-1 OM'( RA 0 04/29/93 10 11601 8504 49 LB-1 OM'( T-2 0 02103/00 11621 ' 1-15-1/2" PARKERSWN NIP, 0 =4.656" 11676' 1-15-1/2" X4-1/2" XO 1 11678' 1-19-5/8" X4-1/2" BAKER. PERtv1AN8'JTPKR 11711' 1-14-1/2" PARKERSWS NIP, 0 =3.813" 11728' 1-i4-1/2" PARKER SWN NIP, 0 = 3.725" 11741' l-i 4-1/2" TLBING TAIL I 11730' 1-1 ELMOTTLOG NOT AVAILABLE 1 112002'-12167' 1-1 CMTCOLLAR, 10 =3.625" 1 " 12559' H 85% OF RUBBER ELEM8'JT FROM IBP 1 0/07/97 " 12564' H PERF GUN 07/20/93 1 Ii 12420' H CENlENT RETAINER SET 07/09193 12569' H PBTO OATE REV BY COMrvENTS PRUOI-DEBAY LNIT WELL: 03-36 PERMIT t\b: 1930190 A R t\b: 50-029-22340-00 SEe 11, T10N. R15E, 2342,75FEL3012.63 FNL BP Exploration (Alas ka) RE: Review of Wells wlFailed MITs - 13-22,03-36, NK-38, P2-34 ') ') Subject: RE: Review of Wells wfFailed MITs - 13-22,p3-36,NK-38, P2-34 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Wed, 27 Oct 2004 19:51:35 -0800 To;:'Ja~esRe~g<jim_regg~admin~state~ak.U$>. . .. . ... . , . .... .~.. . .. .. .. . C<!.{Winton G Aubert <winton ~aubert@a~in.state.ålc.us>~. "NSU,: A-pW:WeIJ' IntøgritYE:rigiriee*~~: . <N$UJ.illWWellIntegrityEngineer@BP:.çorri> .. ... ....... : ::. ... ... ., . . . f'~~~~ Hi Jim, Here are updates to three of the wells requested. I am still looking into P2-34 but wanted to respond with the information I have at this time so that these reviews can be closed out. 13-22 failed an MITIA on 7/21/04 while the well was shut-in and on a vacuum. The plan has been to repair a gate valve, put the well on injection, and repeat the MITIA with the well on injection. The repair work has been completed and this well is on the schedule for an MITIA this week. The AOGCC inspector will be contacted to witness the test if possible. 03-36 failed an MITIA and passed a MIT-T on 8/2/04. An leak detection log confirmed a production casing leak at 8230' md on 8/11/04. Plans are to submit a request for Administrative Approval once M-38 AA has been approved to include any additional information required for the AA. NK-38 was not added to the monthly injection report given the plan is to workover the well instead of apply for Administrative Approval. The injection valve was opened on 9/19/04 to freeze protect the tubing and flowline for the winter. Please let me know if you have any additional questions. I will follow-up with P2-34 within the next few days. Thank you, Anna Dube -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Tuesday, October 26, 2004 4:57 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Review of Wells w/Failed MITs We just completed a quarterly review of wells with MITs that failed and have identified 4 that need some clarification regarding status: 1) *PBU 13-22*; failed MIT 7/21/04; SI after MIT and well was added to monthly injector report; our database shows 3 days injection in September (26,996 bbls water); what is the status of request for administrative approval? [According to September Monthly Injector Report, tbg integrity was to be restored prior to placing on injection, and MIT was planned for 9/23/04; nor record of either] 2) *PBU 03-36*; failed MIT 8/2/04; well was added to monthly injector report; our database shows injection in August (9 days; 2,080 bbl water) and September (5,379 bbl water); what is the status of request for administrative approval? 3) *PBU NK-38*; failed MIT 7/12/04; well has not been added to monthly injector report; data provided to Commission indicates 32 bbls water injected (1 day) during September; what is status of this well and follow-up to failed MIT? 4) *PBU P2-34*; MIT 7/13/04; the Commmission carries this as an incomplete MIT (thus, requirements of 2 year testing for monobore injectors per AOGCC policy have not been satified); MIT is incomplete because only the upper 6,400 ft of the well (perfs at 13,000 ft) has been evaluated for mechanical integrity; it is also unclear if the well carries a waiver from 20 AAC 25.412 (packer within 200 ft of perfs) ; this well should be added to the monthly injector list. lof2 <>:::t' 0 c::J N G'-1 0 >' 0 Z 0 W Z z « ü en 10/28/20048:00 AM RE: Review of Wells w/Failed MITs - 13-22,03-36, NK-38, P2-34 ." 20f2 ') ) I'd appreciate an updat~ ðf the 4 wells so we can close out our review. Jim Regg AOGCC 10/28/20048:00 AM MEM ORAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ?~ ~ (-ö(CIf P.I. Supervisor \ '" ¿ t1 FROM: Chuck Scheve Petroleum Inspector DATE: Thursday, September 02, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03-36 PRUDHOE BAY UNIT 03-36 Src: Inspector Reviewed By: P.I. Suprv ,S~2- Comm Well Name: PRUDHOE BAY UNIT 03-36 API Well Number: 50-029-22340-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS040902 I 25229 Permit Number: 193-019-0 Inspection Date: 8/212004 Rei Insp Num: mitCS04080200000I Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 03-36 Type Inj. N TVD 9]87 IA 2350 2300 P.T. ]930]90 TypeTest Test psi 2138 OA Interval OTHER P/F F Tubing 2920 2920 Notes: A plug had been set in the tubing below the packer. The tubing was pressure tested and demonstrated good integrity. An attempt to test the IA failed with a leak rate established of I bbl per min at 2350 psi. No test used for IMIT category applies. NON-CONFIDENTIAL " Thursday, September 02, 2004 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '\) td COIl/lOA- P.I. Supervisor K,t ð DATE: Wednesday, August 04,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03-36 PRUDHOE BAY UNIT 03-36 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv J~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 03-36 API Well Number: 50-029-22340-00-00 Inspector Name: Chuck Scheve Insp Num: mitCSO4080200000 I Permit Number: 193-019-0 Inspection Date: 81212004 Rei Insp Num: . Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 03-36 Type Inj. N TVD 9187 IA 580 590 580 580 P.T. 1930190 TypeTest Test psi 2138 OA 0 0 0 0 Interval OTIlER P/F ?* Tubing 20 3000 2920 2920 Notes: A plug had been set in the tubing below the packer. The tubing was pressure tested and demonstrated good integrity. An attempt to test the IA failed with a leak rate established of I bbl per min at 2350 psi. -f~- -\ Wednesday, August 04, 2004 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Super\ i~or ----., ~e(Î 7/lb/CY1 DATE: Tuesday. Jul) 13. 200~ Sll BJ ECT: t\ 1ech3n1cal I ntegTlI) Tests BP EXPLOR..o\ TION (ALASK..~'I INC FROM: John Spaulding Petroleum Inspector 03-36 PRUDHOE BAY UNIT 03-36 Src: Inspector Reviewed By: PJ. Suprv .::JP,~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BA Y UNIT 03-36 Insp Num: mitJS04070~ 160306 Rellnsp Num: API \Vell Number: 50-029-22340-00-(1(1 Permit Number: 193-019-0 Inspector Name: John Spaulding Inspection Date: 7/3/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 \\Ii n. Well 03-36 Type Inj. s TVD 9187 1..\ .no 2170 2171) -170 P.T. 1930190 TypeTest SPT Test psi 2139 OA Inten'al -IYRTST P/F Tubing I 1300 1300 I J(lO 13üü Notes: MITlA failed. LLR 0.7 BPM @2170 psi Tuesday. July 13,2004 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Pedorate_ Pull tubing _ Alter casing _ Repair well _ Other _X (squeeze) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 60 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4370' FNL, 4380' FEL, Sec. 11, T10N, R15E, UM (asp's 714172, 5936972) 03-36i At top of productive interval 9. Permit number / approval number 3106' FNL, 2737' FEL, Sec.12, T10N, R15E, UM (asp's 721056, 5938439) 193-019 At effective depth 10. APl number 50-029-22340 At total depth 11. Field / Pool 3013' FNL, 2343' FEL, Sec. 12, T10N, R15E, UM (asp's 721445, 5938541) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12569 feet Plugs (measured) PBTD tagged (10/29/2000) @ 12230' MD. true vertical 9170 feet Effective depth: measured 12230 feet Junk (measured) true vertical 8941 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 1 1' 20" 281 cubic ft AS 1 1 1' 1 1 1' Surface 3917' 13-3/8" 1516 Sx cs III, 165 Sx cs II, & 3977' 3732' 400 Sx Class G Production 11841' 9-5/8" 1210 Sx C~ass G 11901' 8708' Liner 839' 7" 180 Sx C~ass G 12569' 9170' Perforation depth: measured 12206'- 12236'; (12248'- 12252' previously squeezed but leaking); 12308' - 12314'; true vertical 8924' - 8945'; (8953' - 8956' previously squeezed but leaking); 8994' - 8998'. Tubing (size, grade, and measured depth) 7", 26#, 13CR-80 Tbg @ 3285' MD; 5-1/2", 17#, 13CR-80 Tbg @ 11676' MD; 4-1/2", 12.6#, 13CR-80 Tbg @ 11741' MD. Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" BAKER PERMANENT PACKER @ 11678' MD. 7" CAMCO BAL-O SSSV @ 2245' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11180 . - 1115 Subsequent to operation 12935 - 1784 15. Attachments 16. Status of well classification as: · '. · Copies of Logs and Surveys run m Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service WAG 17.1 hereby certi~J:laJ)the foregoing i~-~jn, d correct to the best of my knowledge. ;Signed Title PS 03 Surveillance Engineer -Date Daniell'e ~ ~."~' ~' '~ - '"' ~ ' Prepared by Paul Rauf 564-5799 ~,\ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 03-36i DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE FOR PROFILE MODIFICATION Date Event Summary 9/28/2000: 9/30/2000: 10/01/2000: 10/02/2000: 10/03/2000: 10/05/2000: 10/06/2000: 10/07/2000: 10/08/2000: 10/29/2000: RIH & tagged PBTD @ 12254' ELM. MITIA to 1900 psi - passed. Performed an Acid Wash / Cement Squeeze for Profile Modification as follows: MIRU CTU. PT'd BOPE. RIH w/CT & fluid packed well w/1% KCL Water. Tagged PBTD @ 12250'. Pumped a Gelled Sand Slurry containing 2850 lbs of 20/40 mesh Carbolite to place an isolation sand plug over the following perforations: 12206' - 12236' MD (Zone 2) Reference Log: BHCS 4/22/1993. 12248' - 12252' MD (Zone 2) previously squeezed but leaking 12308' - 12314' MD (Zone 2) Made a final TOS tag @ 12152'. Injection test: 5 bpm @ 860 psi. Reciprocated an acid wash across the open perforation target interval located @: 12062' - 12072' MD (Zone 4) 12080' - 12110' MD (Zone 4) Pumped: (a) 10 bbls of 80% Diesel - 20% Xylene @ 2.0 bpm, followed by (b) 30 bbls of 12% HCL o 10% Xylene - 3% Acetic Acid @ 2.0 bpm, followed by (c) 48 bbls of 1% KCL Water overflush Final injectivity 2 bpm @ 550 psi. Pumped 10 bbls of Neat Class G Cement, followed by 50 bbls of Class G Cement w/Fibers, followed by 26 bbls of Neat Class G Cement to sqz off the perfs mentioned above. Placed 55 bbls of cement behind pipe @ a max sqz press of 1000 psi. Contaminated cement w/Biozan & cleaned out to 11980'. Completed cleanout. POOH. FP'd well. Trapped 500 psi on wellhead. RD CTU. WOC. RIH & tagged TOC @ 12002' ELM. MIT'd tubing to 1000 psi - passed. MIRU CTU & PT'd equip. RIH w/3.62" Chomp mill & milled cement plug to 12152'. Milled cement & sand to 12175'. POOH w/chomps mill. RIH w/nozzle & FCO'd to 12271'. POOH w/CT. RIH w/3.65" mill & milled to 12288.5' (85% rtns). Milled to 12324' - lost rtns. POOH. RIH w/CT & jetted down to 12280' w/good rtns. Swept hole w/Biozan & performed injectivity test (2 bpm @ 975 psi). Pumped 20 bbls of DAD Acid f/12260' to 12200. Overflushed w/100 bbls of water. Resultant injectivity was 2 bpm @ 540 psi. POOH. RD CTU. Placed well on PWl. RIH & tagged PBTD @ 12230' SLM. Obtained representative injection data. RECEIVED l OV 0 9 2000 Page 1 Alaska 0it & Gas Cons. Commiseion A~ch0~age ON OP- BEFORE .CEMBER 01 2000 c:LOglXMFII,M.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X (Prod->lnJector Conv) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 60 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service~x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4370' FNL, 4380' FEL, Sec. 11, T1 ON, R15E, UM (asp's 714172, 5936972) 03-36i At top of productive interval 9. Permit number / approval number 3106' FNL, 2737' FEL, Sec. 12, T10N, R15E, UM (asp's 721056, 5938439) 193-019/(399-243 signed 12/3/1999) At effective depth 10. APl number 50-029-22340 At total depth 11. Field / Pool 3013' FNL, 2343' FEL, Sec. 12, T10N, R15E, UM (asp's 721445, 5938541) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12569 feet Plugs (measured) PBTD tagged (4/10/2000) @ 12254' MD. true vertical 91 70 feet Effective depth: measured 12254 feet Junk(measured) true vertical 8958 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 111' 20" 281 cubic ft AS 111' 111' Surface 3917' 13-3/8" 1516 sx cs Hk 165 sx Cs ,, & 3977' 3732' 400 Sx Class G Production 11841' 9-5/8" 1210 sx c~ass G 11901' 8708' Liner 839' 7" 18o sx C~ass G 12569' 9170' Perforation depth: measured 12062' - 12072'; 12080' - 12110'; 12206' - 12236'; (12248' - 122252' previously squeezed but leaking). true vertical 8823' - 8830'; 8836' - 8857'; 8924' - 8945'; (8953' - 8956' previously squeezed but leaking). ~Tubing (size, grade, and measured depth) 7", 26#, 13CR-80 Tbg @ 3285' MD; 5-1/2", 17#, 13CR-80 Tbg @ 11676' MD; 4-1/2", 12.~6~3CR~80 Tbg @~.,1 Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" BAKER PERMANENT PACKER @ 11678' MD. 7" CAMCO BAL-O SSSV @ 2245' MD., ~!;_~i'~ {~) I~ L.j;~:~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) ~' !~"~i ~, -~ ~ ' ~ : ' Treatment description including volumes used and final pressure · ;~ .i':. !:ii; ~:, .... 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (Shut In - High GOR) Subsequent to operation 17000 1500 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations ._X Oil __ Gas ~ Suspended __ Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gordon Pospisil Prepared by Paul Ra~f 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~ 03-36i DESCRIPTION OF WORK COMPLETED CONVERSION FROM PRODUCER TO WATER ALTERNATING GAS (WAG) INJECTOR Date Event Summary 2/01/2000: 2/02/2000: 2/03/2000: 2/04/2000: 2/06/2000: 2/29/2000: 4/10/2000: 5/01/2000 - 5/14/2000: 5/17/2000: RIH &tagged PBTD @ 12257' ELM. Set Whiddon Catcher @ 12217'. Pulled GLV's station 10 & 1. Pulled station #5 GLV. Loaded IA w/330 bbls of Inhibited Seawater. FP'd w/MEOH Water. Dummied GLV stations 1,5, & 10. Pulled Whiddon Catcher. Recovered metal bands f/failed IBP. MITIA to 3000 psi - passed. PPPOT-T to 5000 psi - passed. PPPOT-IC to 3000 psi - passed. MITOA failed. SBHP/FBHP survey. Tagged PBTD @ 12254' ELM. Performed surface drillsite facility modifications. Well 03-36i twinned w/03-12i. Converted from a shut in high GOR producer to a WAG injector. Placed well 03-36i initially on water injection. Obtained representative injection data. Page 1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS il 1. Type of reqUest: Abandon_ Suspend__ Operational shutdown _ Re-enter suspended well~'~l~t~)il Alter casing _ Repair well _ Plugging _ Time extension _ _ ""' __~.,,~R~rs'on~ Change approved program _ Pull tubing _ Variance _ Perforate AIIL;llU~ c~)¥h er _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_X RKB 60 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4370' FNL, 4380' FEL, Sec. 11, T10N, R15E, UM 03-36 At top of productive interval 9. Permit number / approval number 2173' FSL, 2544' FWL, SEC. 12, T10N, R15E, UM 93-19 At effective depth 10. APl number 50-029-22340 At total depth 11. Field / Pool 3013' FNL, 2343' FEL, Sec. 12, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12569 feet Plugs (measured) Tagged PBTD @ 12259' MD (10/29/1996) true vertical 9170 feet Effective depth: measured 12259 feet Junk (measured) true vertical 8961 feet Casing Length Size Cemented · Measured Depth True vertical Depth Conductor 111' 20" 281 cub~ ~t AS 111' 111' Surface 3917' 13-3/8" 151S SxCS m, 165 sxcs ,, & 3977' 3732' 400 Sx Class G Production 11841' 9-5/8" 121o Sx Class G 11901' 8708' Liner 839' 7" 18o Sx Class G 12569' 9170' ORIGINAL Perforation depth: measured 12062' - 12072'; 12080' - 12110'; 12206' - 12236'; (12248' - 122252' previously squeezed but leaking). true vertical 8823' - 8830'; 8836' - 8857'; 8924' - 8945'; (8953' - 8956' previously squeezed but leaking). Tubing (size, grade, and measured depth 7", 26#, 13CR-80 Tbg @ 3285' MD; 5-1/2", 17#, 13CR-80 Tbg @ 11676' MD; 4-1/2", 12.6#, 13CR-80, Tbg @ 11741' MD. Packers & SSSV (type & measured depth) 9-5/8' X 4-1/2" BAKER PERMANENT PACKER @ 11679' MD. 7" CAMCO BAL-O SSSV @ 2246' MD, 13. Attachments Description summary of proposal ___X Detailed operations program m BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: December 15, 1999 16. If proposal was verbally approved Oil __X Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Danlelle Ohms @ 265-1501 Signed //~~..~.~ ~ Title: ARCO Engineering Supervisor Erin Oba i Prepared b~/ Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditio[~ ~Q~i~roval: Notify Commission so representative may witness iNO~3~ o"J~.e(~ Plug integrity_ B..OP Test __ Location clearance i I Appr°val n°'~2~'~''''(~ ~-~ !~¥ ~:~.~.~ ~.~ Mechanical Integrily Test~, Subsequent form required 10- ~O ~ ~oZr of the Commission Commissioner /C~ ' Form 10-403 Rev 06/15/88 * SUBMIT IN TRIPLICATE Well 03-36: Conversion from Producer to WAG Injector Reason for Conversion The conversion of 3-36, from a shut in producer to a WAG injector, will provide support to Wells 9- 01 and 9-02 in the Victor and possibly Tango. Both wells are currently on-line, however, offset injector 9-20i has been suspended from MI injection since 8/97 due to annular communication problems. Frontsim has indicated significant quantities of unswept oil in this area. Reserve benefits will be realized from the injection of water and MI into this new pattern. This conversion only requires facility modifications and thus is relatively Iow attainment cost for the additional reserves. In addition, the conversion would allow for the option of 9-20i to become a Romeo only water injector. Scope of Work In order to convert this well to injection service, Well 3-36 will be twinned with Injector 3-12. The existing production and gas lift facilities for Well 3-36 will be disconnected and abandoned in place. Only one well can be on MI service at a time for the flow meter and choke valve in the EOR module to work properly. The conversion will free up a production and gas lift slot in the manifold building for another potential production well. Wellwork associated with this conversion will include dummying the GLV's, pulling the dummy in the bottom station to load the backside with water and a diesel cap and replacing the dummy, then · performing another MIT. An IPROF on water injection will be obtained to determine whether or not profile modification will be necessary. There is a 25% chance that a squeeze of the existing open perforations will be necessary in the event that the injection profile is top heavy. Additional perforations will most likely be added in the Tango and Upper Romeo Sands in the future. RECEIVED EC, O 1 1999 Alas~ Oil & Gas gons ~.,om~,~ 6 5 4 3 , I 2 cO~LED TUBINI~ UNIT BOP E0U ] PHENT 1. ~000 PSI ?. WELLHEAD CONNECTOR IrLANOE 2. 5000 PSI 4 1/16' PiP[ RAMS 3. 5000 PSI 4 1/6" liYD~L~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS .~. ~ PSI 4 I/~," BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 1 ' D RECEIVE 1999 NIREL ]NE BOP EOU l PMENT 1. 5000 PSi ?" W£LLHr. AD CONNECIOR rLA~0[ 2. 5000 PSI WlRELIN[ RAMS (VARIABLE SIZE) 3. ~DDO PSI 4 1/6" LUBRICATOR 4. 5000 PS~ 4 ~/6" fLOW TUBE PACK-Orr ARCO ALASKA, INC. SSSVNIP ............................... Tubing Casing ....... : XO Tubing Casing Gas Lift MandrelJalve 1 Gas Lift Mandrel/Dummy Valve 2 Gas Lift MandreVDummy Valve 3 Gas Lift Mandrel/Dummy Valve 4 Gas Lift MandrelNalve 5 Gas Lift MandreVDummy Valve 6 Gas Lift Mandrel/Dummy Valve 7 Gas Lift Mandrel/Dummy Valve 8 Gas Lift Mandrel/Dummy Valve 9 Gas Lift Mandrel/Valve 10 NIP SQZ XO Tubing PKR NIP (4-1/2" Parker SWN ....N..ip.p!.e) ............................................................. Liner TTL Perf ....-."~ Perf ...... CMTRET FISH 1999 A d omge Prudhoe Bay APl: 500292234000 Orig Compltn: 4/29/93 SSSV Type: Last W/O: 4/29/93 Annular Fluid: 7.2 Diesel/8.5 SW Ref Log Date: 4/22/93 Reference Log: BHCS RKB: 60 ft. Last Tag: TD: 12569 ftKB Last Tag Date: Max Hole 54 deg @ 5426 Angle: 03-36 Angle @ TD: 48 deg @ 12569 Rev Reason: Update Perf info Last Update: 9/23~99 Depth Comment 11728 11728' MIN ID = 3.725" (4-1/2" Parker SWN Nipple) .G~!..N~i ,,, ...:.., :~~, :~. : :: Date Note Depth TVD Type Description 2245 2245 SSSVNIP 7" Camco BAL-O SSSV Nipple 3285 3222 XO Crossover 7" x 5-1/2" 11621 8518 NiP 5-1/2" Parker SWN Nipple 11676 8554 XO Crossover 5-1/2" x 4-1/2" 11678 8556 PKR 9-5/8" x 4-1/2" Baker Permanent Packer 11711 8578 NIP 4-1/2" ParkerSWS Nipple 11728 8589 NIP 4-1/2" Parker SWN Nipple 11741 8598 TTL 4-1/2" Tubing Tail 12420 9070 CMTRET Cement Retainerw/20' Cement on Top (Set 07/09/93) ID 5.937 0.000 4.656 0.000 0.000 3.813 3.725 0.000 0.000 Depth Description Comment Date 12559 FISH 85% of Rubber Element f/IBP 10/7/97 12564 FISH Perf Gun 7/20~93 Size Weight Grade Top Btm Feet Description 9.625 47.00 NT-80S 0 11901 11901 Casing 7.000 29.00 13CR-80 11730 12569 839 Liner Size Weight Grade Top Btm Feet Description 7.000 26.00 13CR-80 0 3285 3285 Tubing 5.500 17.00 13CR-80 3285 11676 8391 Tubing 4.500 12.60 13CR-80 11676 11741 65 Tubing Stn MD TVD Man Man VMfr VType Mfr Type 1 3377 3298 OT LB-1 CA R-20 P 2 5592 4737 OT LB-1 CA RD 3 6747 5467 OT LB-1 CA RD 4 7517 5973 OT LB-1 CA RD 5 8289 6464 OT LB-1 CA R-20 P 6 9069 6950 OT LB-1 OM D-14R 7 9849 7419 OT LB-1 OM D-14R 8 10631 7904 OT LB-1 OM D-14R 9 11017 8140 OT LB-1 OM D-14R 10 11601 8504 OT LB-1 CA RDO P VOD Latch Port TRO Date Vlv Run Commenl 1.5 T-2 0.250 1920 12/22/96 1.5 T-2 0.000 0 12/23/96 1.5 T-2 0.000 0 3/30/96 1.5 T-2 0.000 0 12/23196 1.5 T-2 0.250 1923 12/23/96 1.5 RA 0.000 0 4~29/93 1.5 RA 0.000 0 4/29/93 1.5 RA 0.000 0 4/29/93 1.5 RA 0.000 0 4/29/93 1.5 T-2 0.375 0 12/23196 Interval TVD Zone Status FeetSPF Date Type Comment 12430-12438 9077- 9082 ZONE C 8 4 7/3/93 APERF Cement Ret 2,ZONE lB 12248 - 12252 8953 - 8956 ZONE 2 C 4 4 11/4/93 APERF SQZ Perf 12248 - 12249 8953 - 8954 ZONE 2 C 1 4 12/11/93 APERF 12249 - 12252 8954 - 8956 ZONE 2 C 3 4 12/11/93 RPERF 12308 - 12312 8994 - 8997 ZONE 2 C 4 4 12/11/93 APERF 12064 - 12070 8824 - 8828 ZONE 4 O 6 4 9/14/94 RPERF 12215 - 12217 8931 - 8932 OWC,ZONE O 2 4 4/11/96 APERF 2 12248 - 12252 8953 - 8956 ZONE 2 C 4 4 5/23/96 APERF SQZ Perf 12226 - 12236 8938 - 8945 OWC,ZONE C 10 4 6/22/96 RPERF 2 12382 - 12386 9044 - 9047 ZONE C 4 6 7/20/93 IPERF 2,OWC 12312 - 12314 8997 - 8998 ZONE 2 C 2 6 7/20/93 IPERF 12330 - 12334 9009 - 9012 ZONE 2 C 4 6 7/20~93 IPERF 12064 - 12068 8824 - 8827 ZONE 4 O 4 6 7/24/93 RPERF 12312 - 12314 8997 - 8998 ZONE 2 C 2 6 7~24/93 RPERF 12068 - 12070 8827 - 8828 ZONE 4 O 2 6 7~24/93 APERF 12249 - 12253 8954 - 8957 ZONE 2 C 4 6 7/24/93 APERF 12094 - 12098 8845 - 8848 ZONE O 4 6 7~24/93 APERF 4,ZONE 3 12090 - 12094 8843 - 8845 ZONE O 4 6 7/24/93 APERF 4,GOC 12226 - 12236 8938 - 8945 OWC,ZONE C 10 6 5/23/96 APERF 2 12216-12230 8931-8941 OWC,ZONE C 14 6 7/2/96 APERF 2 12206 - 12226 8924 - 8938 OWC,ZONE C 20 6 7/21/96 RPERF 2 60/120 PH 60/120 PH 60/120 PH ISO w/IBP ISO w/IBP ARCO ALASKA INC. SSSVNIP Tubing Casing Tubing Casing Gas Lift Mandrel/Valve 1 Gas Lift Mandrel/Dummy Valve 2 Gas Lift Mandrel/Dummy Valve 3 Gas Lift Mandrel/Dummy Valve 4 Gas Lift Mandrel/Valve 5 Gas Lift Mandrel/Dummy Valve 6 Gas Lift Mandrel/Dummy Valve 7 Gas Lift Mandrel/Dummy Valve 8 Gas Lift Mandrel/Dummy Valve 9 Gas Lift MandrelNalve 10 NIP SQZ XO Tubing PKR NIP 11728' MIN ID = 3.725" (4-1/2" Parker SWN ....N..!pp!...e) ............................................................. Liner TTL Perf ...... ,.~ P~r~ .....~/ Perf ...... CMTRET FISH FISH v" Prudhoe Bay 03-36 Interval TVD Zone Status Feet~PF Date Type Comment 12080 - 12100 8835 - 8850 ZONE O 20 6 11/1/96 APERF )WC,GOC,ZOI 3 12062 - 12082 8823 - 8837 ZONE 20 6 12/6/96 IPERF Pre Sqz 4,OWC 12090 - 12110 8843 - 8857 ZONE O 20 6 3/18/97 APERF 4,GOC,ZONE 3,OWC Interval Date Type Comment 11253-12252 11/4/93 SQZ 12064-12386 11/4/93 SQZ 12430-12438 11/4/93 ISO 12308 - 12314 4/11/96 ISO 12330 - 12334 4/11/96 ISO 12382 - 12386 4/11/96 ISO 12064 - 12253 4/27/96 SQZ LARC 12206-12334 10/7/97 ISO RECEIVED "'-"" STATE OF ALASKA AL,-,,..,KA OIL AND GAS CONSERVATION COMMISSIOr~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate.__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: !5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development _X 60' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 906' NSL, 4381' WEL, Sec 11, T10N, R15E, UM. 3-36 At top of productive interval: 9. Permit number/approval number: 2173' NSL, 2544' EWL, Sec 12, T10N, R15E, DM. 93-19 At effective depth: 10. APl number: 50-029-22340 At total depth: 11. Field/Pooh 2268' NSL, 2934' EWL, Sec 12, TION, R15E, DM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12569 feet Plugs (measured) Bridge Plug at 12170' MD (seal). true vertical 9187 feet Effective Depth: measured 12170 feet Junk (measured) true vertical 8918 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 281 cuft Arcticset 111' 111' Surface 3946' 13-3/8" 1517 Sx CS III, 3977' 3737' 400 Sx CI G, & 165 Sx CS II Production 11869' 9-5/8" 1210 Sx CIG 11901' 8734' Liner 826' 7" 180 Sx CIG 12569' 9170' Perforation Depth measured 12062- 12110'; [Isolated below Bridge Plug: 12206-12236'; 12308- 12314'] true vertical 8823 - 8857'; [Isolated below Bridge Plug: 8934 - 8957'; 9012 - 9017'] ~E~EIV~,D Tubing (size, grade, and measured depth) 7", 26#, 13 Cr-80, Tbg at 3285' MD; 5-1/2", 17#, 13 Cr-80, Tbg at 11676' MD; /' "~'~ 0 4-1/2",12.6#,13 Cr-80, Tbgat11741'MD. ,-~.r'--~ 31997 Packers and SSSV (type and measured depth) Baker Perm Packer at 11678' MD; Camco Bal-O SSSV at 2245' MD. '~J'a$~'a Oil & Gas Cons. Oommiss Anchorage 3. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) ORIGINAL 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 212 1988 3222 - 291 Subsequent to operation 243 2023 3891 - 298 15. Attachments '16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil_X Gas _ Suspended _ Service _ 17. I hereby certify that the Ioregoing is true and correct to the best of my knowledge. Signed ¢.~(.,4~ ~. ~ Title: Engi,eering Supervisor Date ¢--/- ¢' 7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 3-36 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/18/97: MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 20' of perforations as follows: 12090 - 12100' MD (Z3) Ref. Log: BHCS 4/22/93. 12106- 12110' MD (Z3) Added Perforations: 12100- 12106' MD (Z3) Ref. Log: BHCS 4/22/93. Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. Anchorage STATE OF ALASKA ALASKA'- AND GAS CONSERVATION CO,v~,vllSSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown Stimulate X~ Plugging Perforate 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 906' NSL, 4381' WEL, Sec. 11, T10N, R15E, UM. At top of productive interval 2173' NSL, 2544' EWL, Sec. 12, T10N, R15E, UM. At effective depth At total depth 2268' NSL, 2934' EWL, Sec. 12, T10N, R15E, UM. 12. Present well condition summary Total depth: measured true vertical 12569 feet 9187 feet 5. Type of Well Development X~ Exploratory Stratigraphic Service ORIGINAL 6. Datum of elevation(DF or KB) 60' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-36 9. Permit number/approval number 93-19 10. APl number 50 - 029-22340 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Bridge Plug @ 12170' MD (seal). Effective depth: measured 12170 feet true vertical 8918 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 281 cu ft Arcticset 111' 111' Surface 3946' 13-3/8" 1517 sx CS III, 400 Sx CI G, & 3977' 3737' 165 Sx CS II Production 11869' 9-5/8" 1210 Sx Class G 11901' 8734' Liner 826' 7" 180 Sx Class G 11730 - 12569' 8617 - 9170' Perforation depth: measured 12062 - 12100'; [Isolated below Bridge Plug: 12206 - 12236'; 12308 - 12314'] true vertical 8823 - 8852'; [Isolated below Bridge Plug: 8934 - 8957'; 9012 - 9017'] Tubing (size, grade, and measured depth) 7", 26#, 13 Cr-80, @ 3285' MD; 5-1/2", 17#, 13 Cr-80, Tbg @ 11676' MD; 4-1/2", 12.6#, 13 Cr-80, Tbg @ 11741' MD. Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker Perm Packer @ 11678' MD; 7" Camco BaI-O SSSV @ 2245' MD. 13. Stimulation or cement squeeze summary 14. RECEIVED Intervals treated(measured) see Attached FEB 10 199 Treatment description including volumes used and final pressure Representative Daily Averaae Production or Injection Da~asKa uii ' - - Atich01 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure '~)ing Pressure Prior to well operation 171 1924 1366 - 285 Subsequent to operation 262 1201 2399 315 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 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 ~'~ "~h. ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date .2- ~'- 7 '7 SUBMIT IN DUPLICATE 3-36 DESCRIPTION OF WORK COMPLETED MUD ACID STIMULATION TREATMENT I/1 7/9 7: A Fullbore Mud Acid Stimulation was performed for cement filtrate damage removal as follows: MIRU & PT equipment to 4500 psi. Pumped the treatment fluids through the open perforations located above the IBP at: 12062 - 12100' MD (Z3) Ref. Log: BHCS 4/22/93. Pumped: a) 50 bbls 2% NH4CI Water @ 5.1 bpm, followed by b) 57 bbls 50% Diesel / 50% Xylene @ 5.1 bpm, followed by c) 25 bbls 12% HCI w/10% Xylene, followed by d) 23 bbls 2% NH4CI Water w/BAF Diverter, followed by e) 25 bbls 12% HCI w/10% Xylene @ 5.0 bpm, followed by f) 54 bbls 9% HCI- 1% HF, followed by g) 55 bbls 12% HCI w/10% Xylene @ 5.1 bpm, followed by h) 126 bbis 2% NH4CI Water w/5% Musol @ 5.0 bpm, followed by i) 400 bbls Crude displacement, followed by j) 10 bbls Diesel, followed by k) Shutdown. Rigged down. 1/26/97: Pumped Scale Inhibition treatment. Returned the well to production w/gas lift & obtained a valid production test. RECEIVED FEB 10 1997 Alaska Oit ~: i:~;~:~ r;.~n~ commission Ar~ui'lor~g~ , ' STATE OF ALASKA " ALASKA LhL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pulltubing AItercasing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 906' NSL, 4381' WEL, Sec. 11, T10N, R15E, UM. At top of productive interval 2173' NSL, 2544' EWL, Sec. 12, T10N, R15E, UM. At effective depth At total depth 2268' NSL, 2934' EWL, Sec. 12, T10N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 6O' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-36 9. Permit number/approval number 93-19 / 96-68 10. APl number 50 - 029-22340 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Tot~tl depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 12569 feet 9187 feet Production Liner Plugs(measured) Bridge Plug @ 12170' MD (seal). 12170 feet 8918 feet Junk(measured) Length Size Cemented Measured depth True vertical depth 80' 20" 281 cu ft Arcticset 111' 111' 3946' 13-3/8" 1517 sx CS III, 400 Sx CI G, & 3977' 3737' 165 Sx CS II 11869' 9-5/8" 1210 Sx Class G 11901' 8734' 826' 7" 180 Sx Class G 11730 - 12569' 8617 - 9170' Perforation depth: measured 12062 - 12100'; [Isolated below Bridge Plug: 12206 - 12236'; 12308 - 12314'] true vertical 8823 - 8852'; [Isolated below Bridge Plug: 8934 - 8957'; 9012 - 9017'] Tubing (size, grade, and measured depth) 7", 26#, 13 Cr-80, @ 3285' MD; 5-1/2", 17#, 13 Cr-80, Tbg @ 11676' MD; 4-1/2", 12.6#, 13 Cr-80, Tbg @ 11741' MD. Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker Perm Packer @ 11678' MD; 7" Camco BaI-O SSSV @ 2245' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ,jAN 21 1997 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 210 2311 6238 - 83 560 574 Anchora3e Tubing Pressure 315 272 15. Attachments Copies of Logs and Surveys run ,, Daily Report of Well Operations X 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 '~~ ~'1~. ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date /-' //-/-'¢7 SUBMIT IN DUPLICATE 3-36 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE & MI STIMULATION PROJECT A Vertical MI Stimulation project is in progress on 3-36. Due to the extended time length involved in this project, an interim summary is given here to report project operations performed to date. A later report will follow the remaining project operations. 415196: RIH & tagged PBTD at 12327' MD. 418196: RIH w/CT & pumped 7 bbls of gelled sand slurry containing 1500 lbs of 20/40 mesh sand to spot an isolation sand plug across the bottom open perforation interval located at: 12308 - 12314' MD (Z2) Ref. Log: BHCS 4/22/93. Tagged final sand plug top at 12271' MD. POOH w/CT. Rigged down. 4/1 1/96: RIH w/perforation gun & tagged TOS at 12258' MD, then PU & shot squeeze perforations at: 12215 - 12217' MD (Z2) Ref. Log: BHCS 4/22/93. Used a 3-3/8" carrier & shot 4 spf at 60/120 degree phasing at balanced pressure. 4127196: A Pre MIST CTU Cement Squeeze was performed as follows: MIRU CTU & PT equipment. RIH w/CT while loading the wellbore w/Hot Seawater. Tagged TOS at 12258' MD, then PU & pumped 37 bbls of Latex Acid Resistive Cement to squeeze the open perforation intervals located above the sand plug at: 12064 - 12072' MD (Z4) Ref. Log: BHCS 4/22/93. 12090 - 12098' MD (Z3) 12215 - 12217' MD (Z2) 12244 - 12253' MD (Z2) Placed a total of 21 bbls of cement behind pipe at 3000 psi maximum squeeze pressure held 1 hour. Contaminated cement w/biozan & jetted contaminated cement from wellbore down to 12245' MD. POOH w/CT. Rigged down. 4130196: RIH & tagged PBTD at 12268' MD. 5/23/96: RIH w/perforation gun & shot 10' of Add Perforations at: 12226 - 12236' MD (Z2) Ref. Log: BHCS 4/22/93. Used a 3-3/8" carrier & shot perfs at 6 spf at 60 degree phasing at overbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. 6/12/96: RIH & tagged fill at 12112' MD. 6/1 8/'96: RIH w/CT & jetted biozan for fill cleanout down to 12265' MD. 3-36 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE & MI STIMULATION PROJECT 6/22/96: RIH w/perforation gun & shot 10' of Reperforations at: Ref. Log: BHCS 12226 - 12236' MD (Z2) 4/22/93. Used a 3-3/8" carrier & shot perfs at 4 spf at 60/120 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. 7/2/96: RIH w/perforation gun & shot 14' of perforations as follows: Reperforated: 12216 - 12217' MD (Z2) Ref. Log: BHCS 4/22/93. 12227- 12230' MD (Z2) Added Perforations: 12217- 12227' MD (Z2) Ref. Log: BHCS 4/22/93. Used a 3-3/8" carrier & shot perfs at 6 spf at 60 degree phasing at overbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. 7/21/96: RIH w/perforation gun & shot 20' of Reperforations at: 12206 - 12226' MD (Z2) Ref. Log: BHCS 4/22/93. Used a 3-3/8" carrier & shot perfs at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. 8/1 7/96: Performed an Acid Stimulation Treatment w/Packer to improve MI rates as follows: MIRU CTU & PT equipment. RIH w/inflatable packer & inflated to set packer element at 12181' MD, to isolate upper squeezed perforations from treatment fluids. Pumped fluids to treat the open perforation intervals located below the packer (intervals listed above). Pumped: a) 105 bbls 2% NH4CI Water, followed by b) 46 bbls 50% Diesel/50% Xylene @ 1.8 bpm, followed by c). 25 bbls 12% HCI w/10% Xylene, followed by d) 5 bbls Benzoic Acid Flake Diverter stage 1, followed by e) 25 bbls 12% HCI w/10% Xylene, followed by f) 4 bbls Benzoic Acid Flake Diverter stage 2, followed by g) 25 bbls 12% HCI w/10% Xylene @ 1.8 bpm, followed by h) 53 bbls 9% HCl - 1% HF @ 2.1 bpm, followed by i) 23 bbls 12% HCl w/10% Xylene, followed by j) 150 bbls 2% NH4Cl Water Overflush w/5% Musol @ 2.4 bpm, followed by k) Shutdown. Deflated & POOH w/Packer. RDMO. Placed the well on miscible injection from 8/18/96 - 9/27/96 & injected a total of 1.58 BCF of MI. 3-36 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE & MI STIMULATION PROJECT 1 0/4/9 6 · Performed an Injection Profile Log that indicated all injection was entering squeezed perforations. Tagged PBTD at 12251'MD. POOH. RD. Returned the well back to production 10/16/96. I 1/1/96o RIH w/perforation gun to perforate 20' as follows: Added Perforations: Reperforated: 12080 - 12090' MD (Z3) 12098 - 12100' MD (Z3) Ref. Log: BHCS 4/22/93. 12090 - 12098' MD (Z3) Ref. Log: BHCS 4/22/93. Used 3-3/8" carriers & shot the perfs at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. RD. 1 I/2 1/9 6 · RIH & set a Permanent Inflatable Bridge Plug in the 7" liner at 12170' MD (seal) for Water Shutoff. POOH w/running tool. Rigged down. I 216196' RIH w/perforation gun & lightly tagged IBP top at 12162' MD, then PU to perforate 20' as follows: Added Perforations: / 12062 - 12064' MD (Z3) Ref. Log: BHCS 4/22/93. 12072 - 12080' MD (Z3) 12064 - 12072' MD (Z3) 12080 - 12082' MD (Z3) Ref. Log: BHCS 4/22/93. Reperforated: Used 3-3/8" carriers & shot the perfs at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Placed the well on production w/gas lift & obtained valid welltests. An Acid Stimulation is planned for the well in the near future. 6/13/96 NO. 10237 Company: Alaska Oil & Gas Co~'ls Comn'~ Attn: How:~rd Oa~:land 3001 Porc,pine Drive Anchorage, AK 99501 Field: Prudhoe B~y ~ GeoQUest ~'; ~rO 0 W' International Airport Road Anchorage, AK 99518-1199 ~ ATTN: Sherrie Anadriil .An~drill An~drill Floppy Well Job # Log Description Date BL RF Sepia Surw.~y Program Perforn'~a~"ice Disk Calculation Letl:~.~r D.s.,,,!-!,1 :~,,:~.,~'? 96103 ............... ~r)UAL BURSTTDT-P 960401 1 1:).S. 1-4 . ] ~ ~2.(, .. ?ERF RECORD _ 960528 1 ,i~.S.' 1.8 ? ~-. A,~ INJEC PROFILE 9 6 0 51 9 I 1 ~.S. 2-3A %-- ,i-/~, p.RQDPROFILE .. 960..531 I I ...................... D.S. 2-3A ..~{~"- ['i~. .... DU.A. LBURST. TDT-P(BoRAX) 960601 ....... !. I ............... D.S. 2-leA..qF. I~... PRODPROF!I-E 96051.8. .. ! .... I .......... ~3"S. 2-32 ~- tit GAS DETECTION 960530 I 1 'D.S. 2.35 ~i. hi.? LEAK DETECTION 960525 I 1 ..... 'I~'.S.: 3-~'4 .'J~l, o~,t' PERi=REcoRD ..... 96~'526 I ...... 1 ~.S."3'36 ~.5i:.5' I{ , 'i pERFREcORD 960~523 ....... i"i ........ , .... 1 ....... ' ....... i ', ..... , ........ .~.S. 4-29A.. ~5-!../"/.~ PER, RECORD ...... 960516 1 1 .............. D.S...5'5.A .. ~.'f- Olt, DUAL .BURST T'DT-p (BORAX) 9.60520 1 1 ........... O.S. 5-11 77- 0}o. C.HEMICAL cU~I'TER RECORD .., 960528 I I ,, , 1~'S."7-6A ,, .eF.-!</7 DUAL BURST TDT'P (BORAX) 9605.1,5 ,, ! I ,, , I~.S. 13-06 ~- ~( .... INJEC.pROFILE 9.6,0524 I I ............. ~).S. 13-18 ~';k- ~ )1' INJECPROFILE 960527 I 1 D.,~S. 15-OSA ~). ~t .~,~ I.EAKD..ETECTION ... 960526 1 I ..... p.S. 15-28 ~j~.ol~" LEAK DETECTION ...... 960516 I I ...... D.S. 15-32 ~,t 0~'7 ..PERFRECORD 960517 1 I .. ~'O.S. 17-21 ~',~,. ./,Z~'" ._I.EAKDETECTI('---)~_ 960519 1 1 .............. i~D.S. 18-31 ~..ll2ff I]UALBURST..T,)T-P(B'~)RAX) 9.6,0521 !.,, 1.......... SIGNED: ...... :~ t DATE: Please sign and return cna copy of this tra~,smittal to Sherrie at the above address. Thank you. RLCEIVFD 1. Type of Re'c~uest: STATE OF ALASKA ALASKA iLAND GAS CONSERVATION C£ .'MISSION 'APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well ,,, Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate X Other X 6. Datum of elevation(DF or KB) 60' RKB feet 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 906' NSL, 4381' WEL, Sec 11, T10N, R15E, UM. At top of productive interval 2173' NSL, 2544' EWL, Sec 12, T10N, R15E, UM. At effective depth At total depth 2268' NSL, 2934' EWL, Sec 12, T10N, R15E, UM. 5. Type of Well Development X Exploratory Stratigraph ic Service ORIGINAL 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-36 9. Permit number 93-19 10. APl number 50 - 029-22340 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 12569 feet 9187 feet Plugs(measured) PBTD Tagged @ 12307' MD (4/3/94) Effective depth: measured 12307 feet true vertical 8994 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 281 cuft Arcticset 111' 111' Surface 3946' 13-3/8" 1517 Sx CS III, 400 Sx G, & 3977' 3737' 165 Sx CS II Production 11869' 9-5/8" 1210 Sx G 11901' 8734' Liner 826' 7" 180 Sx G 11730 - 12569' 8617 - 9170' Perforation depth' measured 12064 - 12072'; 12090 - 12098'; 12248 - 12252'; 12308 - 12314' true vertical 8824 - 8830'; 8863 - 8869'; 8971 - 8974'; 9013 - 9017' Tubing (size, grade, and measured depth) 7", 26#, 13 Cr-80 @ 3285' MD; 5-1/2", 17#, 13 CR-80, Tbg @ 11676' MD; 4-1/2", 12.6#, 13 CR-80, Tbg @ 11741' MD. Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker Perm Packer @ 11678' MD; 7" Camco Bal-O SSSV @ 2245' M D. 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation April, 1996 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢..~,~..~ /)'~. ~ Title Engineering Supervisor FOR COMMI~;~ION H~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Original $ignea By David W, Johnston Approved by order of the Commissioner 15. Status of well classification as: Gas ,, , K LblVED Suspended . .. MAR 2 7 1996 At~s~ Uil & GaS L:OD'~, OOmfP,,Ss;o;~ Anchcrscje ^ppro, ve~ Copy Approval No.~ ~,..._ ~ ~ ,.,,.,,,,re;ss;cheF .... Date Form 10-403 Rev 06/15/88 JWS cc' JWP. SUBMIT IN TRIPLICAT% MI DS 3-36 Stimulation Treatment Intended Procedure Objective: Squeeze off existing perforations. Inject approximately 2 BCF MI, followed by 1 MMB produced water. Plugback and re- perforate top of Victor interval. Intended Procedure: 1. Add perforations from 12,215'-12,217' for remedial cement repair. 2. Squeeze off the current perforations. 3. Perforate the bottom 10' of zone 2B, from 12,226'-12,236' 4. Inject approximately 2 BCF of MI at 20 MMCFPD or higher. 5. Inject approximately 1 MMB water at 20 MBWPD or higher. 6. Sand back the well and recomplete at the top of Victor, from 12,090'-12,100'. 7. Bring well back on line and resume production. RECEIVED I~,~AR 2 7 199G A~sk~. Oil & P~,~ P..o;',c.',. Ccmmis,o[o~ March 27, 1996 5 2 CO I L £D TUB INt~ UN I T BOP £gU 1 PHEW? 1. ~)C)00PSI 7' W[LLHEAJ~ CONNECTOR FLAJ~dGE 2. 5000 PSI4 1/16" PIPE 3. 5000 PSi4 1/6" HYDR~LIC SLIPS 4. 5000 PS!4 1/6" SHEAR 5. 5000 PSi4 1/6" BLIND RAJAS 6. 5000 PSi4 1/16" STUrFIHG BOx 4 2 H ! REL ! NE BOP EG, U ! PHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR rLANG[ ~ 2. 5000 PSI WIRELINE RAJAS (VARIABLE SIZE) i ,3. 5000 PSI 4 1/6" LUBRICATOR , 4. ~000 PSI 4 1/6" FLOW TUB[ PACK-OFF 1 I AO,3CC l'llnd'¥v'¥dua] We'l'l ,3 e o '1 o g i' c a 1 H a t. e r" '¥ a '1 :~ I n v e n *1-.: ,o r" y PERkllT DATA T DAI,e~PLIJ8 9 3 ..... 0 1 .~' 5 8 ...... :, 5 7 93. -" 0 i 9 407 9,'.3 '~019 D/,', I 1... Y WaL.~ .... 93 ...... 0 I 9 S!.Ji:?VEY 9 3 "' 019 S U RVE V 9 :if, .... 019 C N L/' (...'i R 93 ..... 0 'I,.~.,c~ D l.... I.... /H S F l .... -~ ..... ~~ F L. 93 ...... 0 'J 9 P E R F 9 3 .... 0 1 9 P a R F 9... ,..:,':' .... 0 i 9 F'E R F: ~.~ D L L.. / B ::'2 S/CNTH ,.o-.R~. C OI,'1F' D A T'E ~' 06 29 "- 93 ~ILLING t-'tlSTORY ~,~ I-..I [ .... D I RECTION.AI~. ~ HWD DIRECTIONAl. ~ 01--I~ R I ~2&B~ ~,., OH.~RI~2&51~ ~t-.I., R 1 .., 2 & 5 93 .... 0 I 9 1 93 ..... 0 '19 1 ~) 0 -- 93 .... 0 I 9 PERF ~ 1 1650 ..... ' l 2S40 ,2! % " :::, .:).... 019 P E R F L I 1550 .,- '1 o 24 0 'i ::, l ,a F( ~' ,,. oLIIELINE) 2000 I 37 usz"r' ~RLIN I ~ 5 ~ liSZT... ~1~5~, I1700 .... Page:.'. '1 Da"l.:e: 04/'11/9 DA'FE ..... RECVD 08/3 1/1 08/'13/1993 08/I 3/1993 08/3 1/1993 05/' 'J {'] ,/ 'i 993 1 r')...~:: ..... / 'i (.) / . , / / · ..... 08/"31 / i r"~ .... 8 ,,, / 3 0 '1 / i Z~./ i 99 ~'.~ 'i 0,/07/'i 99 02/' 01/' I 99 ,~. 0.3/' 'I ,9 / '199 (% ..:~ 3 .... 019 W e '1 'i J'"i 0 STATE OF ALASKA ALASKA ~!-AND GAS CONSERVATION CC'-'"AISSION REPORT UF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X 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 906' NSL, 4381' WEL, Sec. 11, T10N, R15E, UM At top of productive interval 2173' NSL, 2544' EWL, Sec. 12, T10N, R15E, UM At effective depth At total depth 2268' NSL, 2934' EWL, Sec. 12, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 60' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-36 9. Permit number/approval number 93-19 10. APl number 50 - 029-22340 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12569 feet Plugs(measured) PBTD Tagged @ 12307' MD (4/3/94) true vertical 9187' feet Effective depth: measured 12307 feet true vertical 8994 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 281 cu ft Arcticset 111' 111' Surface 3946' 13-3/8" 1517 sx cs 111/4oo sx G/165 sx CS II 3977' 3737' Production 11869' 9-5/8"' 1210 sx CIG 11901' 8734' Liner 826' 7" 180 sx CIG 11730-12569' 8617-9170' Perforation depth: measured 12064-12072'; 12090-12098'; 12248-12252'; 12308-12314' true vertical 8824-8830'; 8863-8869'; 8971-8974'; 9013-9017' Tubing (size, grade, and measured depth) 7", 26#, 13 Cr-80 @ 3285'; MD, 7"x 5-1/2" x-over @ 3285' MD, 5-1/2", 17#, 13 CR-80 @ 11676' MD; 5-1/2" x 4-1/2 x-over @ 11676' MD, 4-1/2", 12.6#, 13 CR-80 @ 11741' MD Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker Permanent pkr @ 11678' MD, 7" Camco Bal-O SSSV @ 2245' MD 13. Stimulation or cement squeeze summary R E C ElY E D 14, Intervals treated(measured) See attached. NOV - 1994, Treatment description including volumes used and final pressure kt~ska 0il & Gas Cons. Commission Representative Daily Averaqe Production or Iniection Data Aflch0r~.,,~ Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 384 962 2387 1574 9097 5410 Casing Pressure Tubing Pressure -- 255 336 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 ~'~-~,~ Form 10-404 Rev 06/15/88 1235/14 cc: KZ, JWP Title Sr. Op. Engineer Date SUBMIT IN DUPLICATE 3-36 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/14/94: MIRU & PT equipment. Added perforations: 12070 - 12072' MD (Z4) Reperforated: RIH w/perforating gun & shot 8' of perforations as follows: Ref. Log: BHCS 4/22/93. 12064 - 12070' MD (Z4) Ref. Log: BHCS 4/22/93. Used a 3-3/8" carrier & shot 4 spf at 180 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED ~'OV - 1 1994 A. taska (JlJ & Gas Cons. Commission Anchor;: .. GeoQuest IS00 W. International Airport Road Anohorage, AK 99518-1199 ATTN: Sherrte NO. 8975 Company: Alaska Oil & Gc~ Oons Corem Attn: Larry Grant 3001 Porcupine Dflve Anchorage, AK 99501 10/7/94 Field: Prudhoe Bay Well Log Deecription BL RR Sepia RF Sepia Mylar D.S. 1-6 ~ ~"'----~ .~ PERF'RECORD (9-20-94) ...... . 1 ~ 1 D.S. 2-1A' ' ~(~--I I ~ STATIC PRESSURE SURVEY (9-19-94) 1 1 D.S. 3-31 ~ ~ .-- c:j-'L_. BRIDGE PLUG REC:ORD (9-13.94I) .... 1 1 D,S. 3-36 '~'~.--J ~' PERF 'RECORD (9-~4-94) . ''1 1 D.S. 4-2"~/~ - /c~_~ TUBG CUTTER RECORD (9-13-.9.4) .... 1 ' ' 1 D.S. 5.4 .... .~af _ ~ c~. STATiOPREssuRESuI~VEY(9-19-941) 1 1 ..... D.S. 5.19 ~-C( .----/~, STATIO pRESSURE sURVEy (9.20-94) ' . 1 .. 1 ...... D.S. 7.24 ~ 5 -~. (~ ~ STATIC BHP SURVEY (9~ 19-94) 1 ......... 1 ...... D.S. 9-26 ~ L/'" 3 ~ POGLM SETTING'RECORD (9-11-94) 1 1 D.S. 13-13 ~'; '~- "1 "7 ~ LEAK DETEOTION (9.-20~94) ....... 1 '1 ..... D.S. 16.~ STAr!a,, BHP SURVEY/~N~E_a PROFILE (9-16-94) ....1,, ' 'i' ',',' '] ,' 1..... -, , D.S. 16-14 '~ | --- ~, ~ PROD PROFILE (9-8-94) .... 1........ 1 , D.S. 16-22 ~-~--- .~-I PERF RECORD (9:11-94) .... 1 1 ,, . SIGNED: DATE: ~ ~ CD ~ Plea d retu opy of thle trane itt I t h rrle at the above addreee. Thank you.- ~ .~ ARCO Alaska, Inc. Date: Subject: From/Location- Telephone: To/Location: Feb 25, 1994 P.O. Box 100360, ,, .,orage, AK Transmittal #: 94024 ARCO Static Pressure Surveys John E. DeGrey/ATO. 1529 (907) 263-4310 Distribution Well iLog Date Number[ (M-D-Y) 2-3 ! 6-5-93 2-5 i7-21-93 3-8 I 11-22-93 3-19 f 1-3-94 3-34A i 11-22-93 I 3-35 I 12-7-93 3-36 i 7-24-93 4-12 f 11-17-93 4-31 I 1-3-94 Tool Type Run, Sc~e Static Press Sun/, ! 5II Contractor Sch Static Press Surv, " Sch Static Press Surv, " Sch Static Press Surv, " Sch Static Press Surv. " Sch 5-12 6-19 7-7A 7-8 9-49 11- 16ST1 11-17 I 11-26-93 2-16A I 11-8-93 13-14 7-2-93 13-14 7-2-93 14-01 11-25-93 14-6 I 11-25-93 14-18 11-26-93 14-38 12-4-93 4-39 12-4-93 15-6 5-28-92 5-15 7-5-93 15-16 8-26-93 5-1e i 10-26-93 5-23 9-23-93 6-12 I7-21-93 6-17 12-29-93 16-18 i7-18-93 16-22 I7-18-93 17-1 i11-23-93 7-13 8-27-93 I 18-29A 5-19-93 4-32 I 9-8-93 4-41 I 11-21-93 I 7'21'93 i 11-28-93,,_ Static Press Surv, " Sch Static Press Sun/, " Sch Static Press Surv, " Static Press Surv,. Static Press Surv. Sch " Sch " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Sun/, 7-21-93 Static Press Surv. " Sch 9-2-93 Static Press Surv. " Sch 9-14-93 Static Press Surv. " Sch 9-5-93 I! II Sch Static Press Sun/. Static Press Surv, Static Press Sun/. Static Press Surv, Static Press Surv, Static Press Sun/, Static Press Surv, Static Press Surv, Static Press Surv, Static Press Surv, Static Press Sun/, Static Press Sun/, Static Press Sun/, Static Press Surv. Static Press Surv, Static Press Surv, Static Press Sun/. Static Press Sun/, Static Press Sun/. Static Press Sun/. Static Press Sun/, Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch " Sch ARCO AlasKa, Inc, Is a Subsidiary of AllanllcRIchflel~K~ ARCO Alaska, Inc. Date- Subject: From/Location: Telephone: To/Location- P.O. Box 100360, , ~horage, AK Jan 28, 1994 Transmittal #: 94016 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 99510,a~ ~' Well Number 1-3 1-11 1-22 2-29A ~ 3-2 3-16 8~-I &~ 3-22 ¢%3-22 ~k3-22 3-35 3-36 4-13 5-35 ~ 5-35 9-13 9-30st 11-24 iLog Date · (M-D-Y) ! 1-14-94 i 1-14-94 i 1-13-94 i 1-18-94 ~ 1-19-94 ! 1-15-94 i 1-10-94 !1-19-94 I 1-16-94 ~ 1-10-94 i 1-21-94 i i, 1-20-94 ! i 1-15-94 i 1-18-94 ! 1-18-94 i 01-14-94 ., ! 1-22-94 ! 1-19-94 I 1-17-94 cl'~-I,A%! !2-_1_6A ~~94 ~;q-',ur0[~, 15-7 ! 1-22-94 15-7 i 1-17-94 ~-~--t'~r~i 17-13 ! 1-8-94 ~)..~0i 18-1 i 1-20-94 Number of Records:24 ,,~John E. DoGroy PBOE Document Control Tool Type i Run, P0(cLm ¢.~ ~. Scale i Tubing Puncher'i 1 5" Perf Record I 1, 5" ~ Bridge Plug ~ ¢~1, 5" Sch CNL i~ 1, 5" Sch ~k Bridge Plug ~ 1, 5" Sch Leak Determin/~1¢~, 5"/T~.~ Sch Pe~ Record i ' 1, 5'~ Sch . ~6~ Bnd~e Plug ~ 1, 5" Sch LeakDetermin ~6~l,~&"t T~ Sch Leak Detect )~ ~ 1~,;,~?~ ~,~ch Peal Record '~ ' 1, 5'~ ~ Sch Prod Profile~,j ~,~,, 5" ~ ~/~c~ ~,'~ Ini Profile IB~Se~ing~j'' 1',,~",, ~' Sch PmdLo~ i 1,2&5 ~ Sch Leak Detect/~'~l~'~p~{~,Sch CompI Recor8 'i i' 1, 5 '[ ~ch Leak Detect/~(~ ~ "~'~ Tubing CuUer '~ ~, 5" *(Y schSCh CompI Record ~ 1, 5" Sch Tubing Cu~er ~. 1, 5" Sch Tubing Puncher ~1, 5" Sch Patch Se~ing ~ 1, 5" Sch Dual Burst TDTP ~ 1, 5" Sch Contractor Sch Sch Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ~:i'.istate of AlaSka~ Mobil RECEIVED FEB 0 A,~ska Oil & 8as Oons. Commission Anchorage Please acknowledge receipt by signing and returning a copy of transmittal. By: ~ ~,/./~-;. ~ ~ Date: ARCO Alaska, inc. Is a Subsidiary of AtlantlcRIchflsidCompany ___.. STATE OF ALASKA ALASKA( 'AND GAS CONSERVATION CO[ ISSION 1. 'Operations performed: operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. I~ame of Operator 5. Type of Well 6. Datum of elevation(DF Development X ARCO Alaska, Inc. Exploratory 60 RKB 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 906' NSL, 4381' WEL, Sec. 11, T10N, R15E, UM 3-36 At top of productive interval 9. Permit number/approval number 2173' NSL, 2544' EWL, Sec. 12, T10N, R15E, UM 93-19 At effective depth 10. APl number 50 - 029-22340 At total depth 11. Field/Pool 2268' NSL, 2934' EWL, Sec. 12, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12569' feet Plugs(measured) true vertical 9187' feet Effective depth: measured 12520' feet true vertical 9153' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 281 cu ft Arcticset 111' 111' Surface 3946' 13-3/8" 1517 sx cs 111/400 sx 'G'/165 sx CS II 3977' 3737' Production 11869' 9-5/8" 1210 sx Cl 'G' 11901' 8734' Liner 826' 7" 180 sx Cl 'G' 11730-12569' 8617-9170' Perforation depth: measured 12090-12098';12248-12252';12308-12314'; ' ' ~'' true vertical 8863-8869';8971-8974';9013-9017' Tubing (size, grade, and measured depth) 7", 26#,13CR-80 @ 3285' MD, 7" x 5-1/2" x-over @ 3285' MD, 5-1/2",17#, 136R-80 @ 11676' MD, 5-1/2" x 4-1/2 x-over @ 11676' MD, 4-1/2", 12.6#, 130R-80 @ 11741' MD Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker Permanent pkr @ 11678' MD, 7" Oamco BAL-O SSSV @ 2245' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. .,Representative Daily Average Production or Injection [;)ata OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 583 4879 3752 -- 265 Subsequent to operation 485 ~ 3854 3831 -- 251 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations x Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, ,- ........ ,44 ........ - ~ Title FS-2 Senoir Engineer Date I Z~o (~ ~- REPORT OI= SUNDRY WELL OPEHATIONS Form 10-404 R~ v 06/15/88 SUBMIT IN DUPLICATE ~. E_aLY REPORT OF WELL OPERA ,)NS DS 3-36 Perforating Operations' ARCO Alaska, Inc. perforated DS 3-36 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 12/11/93 The intervals perforated were the following: 12248' - 12252' MD and 12308' - 12312' MD (Reference Log: SWS BHC$ dated 4/22/93). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating' operations on 12/11/93. RU perforating unit, pressure tested BOP's and lubricator, okay. SI well, RIH, opened well to flow and perforated 12308'-12312' MD at 4 SPF, logged up and perforated 12248'-12252' MD at 4 SPF, POOH, and confirmed all shots fired. (ref: SWS BHCS of 4/22/93).Rigged down and secured well. RDC: 1/14/94 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-3-94 REFERENCE: ARCO CASED HOLE FINALS ~-11 12-18-93 CNL (itt) 1 ~7.7_O--~ Oe2 0 Run 1, 5" Sch ~r~-9-9 1-18 12-12-93 Leak Detect }~'~ }i~'~} ~r¢~r' Run 1, 5" ~00 -~?~Cc Sch ~-?C_~-22 12-03-93 Perf Record ~'~(~0 --{05oO Run 1, 5" Sch ~7____~-Z~5_1-25 12-17-93 Prod Proflle/%~o ~e~i~ )~]6r~Runl, 5"ctS0o~e0~zO Sch ~..~L2-6 12-05-93 Perf Record ~%~a~_1%tlli5 ' Run 1, 5" Sch ~2L-~, 2-22 10-22-93 TDTP (depth corrected) Run 1, 5" ~C0O-' ~5~0 Sch -~3-4 12-20-93 In/ Proftlel~,O ~e~n~l@¢¢$$ Run 1, 5" ~0Oo -'l'~qo Sch -36 12-11-93 Perf Record I ?~oq/~ -- {7_~10 Run 1, 5" Sch - ~/~-//7~ 4-1 12-06-93 Perf Record ~c~0 -~/$~O Run 1, 5" Sch -r~_~._4-1 lA 12-13-93 Perf Record ~ 9~ ~ 0 -' I ~¼00 Run 1, 5" Sch ~-~-;%7 4-23A 12-14-93 Dual Burst TDT-PJ/b~ , , Run 1, 5" q'~0 -~%~-~ Sch ~??_~_4-31 12-11-93 Prod Proflle~f,~,~i~),~%)/~,a} Rtml, 5"q%~-~! Q Sch ~? _[~___4-41 12-14-93 Perf Record ~l~aC '~%'~C ~ 1, 5" Sch .~.?~_!~ 5-28 12-10-93 Dual B~st~T-P [(} , I ~ 1, 5" ;ou'2'C -~0'~-*? ~ Sch 1,5 ,~ u .... ~.-~ Sch _[f?; ~j} ..... 6-16 12-15-93 Prod Profll~ [5~,q } ~} ~;~*~'~ 1, 5" ~7 ~;9C ~ q"t c C Sch '~ ~ C, /9-1 12- 5-93 Mak Detectj ~5i~'~ i~t'~.c/O~ [i~ 1, 2"&5" C'~' c ~- l c ;~ C~ch ~ ~-1 12-9-93 M~ Detect/~-~C.¢% ~C~>, F~{ ~e~ I, l"&5" ~?~C, - i~h [c CtL5 ~9~'! _9-20 12-19-93 MI In/ ~oflle/.~. ?~. ~ ~ ~1,5"q~C'--~¥~ Sch '~9-29 12-13-93 M~ Detect [~'9{}~'~ lNa%l C~ ~ 1, 5" ~C~~ ~l~' Sch ~-SSA 12-17-93 CNL/C~& ~0~ ~qq~ ~ 1, 5" Sch ~-36A ~ 12-17-93 Du~ B~t~T-P/GR ,. _ i~ 1, 5" ~050-~}q-q.~ Sch ~Z-iq'l _9-51 12-07-93 Prod ~oflle~?,dl~[ ~C~~ 1, l"&5" 0-- {~ Sch ~~ 1-12 12-06-93 ' ProducUon} ~O ~e{ ~es/~c~d, ~ l, s" ~0- ~z~ 5Sch ~~11-13A 12-14-93 Pwd Proflle/5~ [Y~F{ g~{~r~ 1, 5" q~50- }~q Sch ~4-1 12-5-93 ~G Cutter ~0 ~~q ~ 1, 5" Sch ~~ ~-~ 12-4-93 ~ Detec~on ,~5['~~/,~ 1, ~, 5"~" ~> ~- ~ ~ - 12-10-93 M~ Detection {Va~l~~ ~ 1,~&5"~ I~o Sch · ~~ ~16-29A 12-18-93 PeffRecord l l?oo-iZE~ ~ 1, 5" Sch ~~18-29A 10-19-93 ~ (dep~ co~ected)~ ~ ~1' 5" ~~/c~- ~ Please si~ ~d retm ~e at~hed cppy ~ ~ceipt of ~. . , - .... / ~, 'd~ I - ~ CENT~ F~ES ~ P~L~S ~ C~~ON ~ ~O8 GEO~GY ~ BPX ~ E~ON ~ STATE OF A~.~~ ~ MOB~ The correct well name is 4-1lA and the corrected API# is 50-029-20286-01 The correct well name is 4-31 and the corrected API# is 50-029-21334-00 The correct well name is 18-29A and the corrected API# is 50-029-22316-01 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: ARCO CASED HOLE FINAI~ ~ 1-03 11-23-93 --1-15 11-20-93 --2-32 11-27-93 q-~--3-16i 11-19-93 ~3-24 11-11-93 q%-~5-3-25A 11-22-93 q~- iq ~3-36 11-13-93 ~:IIA 11-20-93 lA 11-20-98 ~'~,~ ~ 4-22 11-17-93 4-30~ 11-13-93 5-06 11-27-93 5-12 11-27-93 5-26 11-27-93 5-31 11-28-93 ~Cc~ 6-12A 11-12-93 q~ 6-18 11-17-93 ~ ~.~'% 6-22A 11-16-93 9-03 11-20-93 13-~8 ~-16-93 ~9i ~4-0~ ~-15-93 9~ 14-04 11-16-93 ~Z-~? 14-23 11-16-93 Il 14-31 11-12-93 ~c 15-o3 ~ ~-~ ~-93 ~ 16-07 11-13-93 ~5-~9 16-20 11-13-93 l?q 17-13 11-20-93 ~ 18-23A 11-17-93 18-29A 11-23-93 Perf Record [~0 '-iii) iD ,Run 1, Prod Profile ~l~.} {~$ i'Te-~i>}~0Run. ~ 1, Inj ~ofile/~,,~}~e.~l~ 6c R~ 1, ~od ~ofile/~r~~ ~a~/~amR~ 1, Perf Record I~0--[~q'O R~ 1, SBT/GR/CCL )0%q0-11~b~ R~ 1, ,->~ i~;~ ,~ R~ 1, Perf Record ~%-Li; ~i c,c i R~ 1, Prod ~ofile ;~4':',~ ~ i~,';~ V~ ~-~F" ~'R~ 1, Perf Record ~¥~C ~ c~i¥ R~ 1, Perf Record ~c? !;~ -*-, ~. ~; ~ ~' R~ 1, Perf Record Perf Record '.-. ::: :>~; - ~ c.*;;':. R~ 1, Packer Setting Rec R~ 1, Perf Record I c'oci C ~ i b~'~ C R~ 1, ~ Detectl~-ceSlT?~ql~aiC~ R~ 1, D~I B~st TDT-P/~ R~ 1, TBG Cutter ~ ~00 - 10t 0v R~ 1, Packoff GLM ~' ~}c ,.. R~ 1, Perf Record ~- I~*! ~ R~I, Perf Revord ~ 10' ~.. R~ 1, USiT{10C~olor,~ ~0--~?a0 R~ 1, Perf Record q~-qS~ R~ 1, Please Sign and return the attached copy as receipt of data. ,E EIVE Have A Nice Day! John E. DeGrey ATO-1529 5" Sch 5"9~:0 '- q 5 c 0 Sch ~' 70 -IL~ Sch ~' ~lO -~q55 Sch ~' Sch 5" Atlas 5" Atlas 5" Sch 5" Sch 5" ;:/x~c --,'c,~ Sch 5" Sch 5" Sch 5" Sch 5" Sch , ' .~ ~ ~ ~ Sch 5" '~ L:-r.-,.~ 5" Sch 5" ~ ~ ~Tta Sch ~'9~ ~5~ Sch 5" Sch ~' Sch ~' ~V0~ qgq0 Sch 5' ~ ~q ~Z5 Sch ~' ~ - ~Ol ~ Sch 5" ~ Sch ~' Sch ~' Sch 5" Sch 4~_~ oi/ ,~ sos c~ ; . "'/ "., ' %."'/o;?' APPROVED .... c '?¢', ,. ~s~ 94004 ' # CENTRAL FILES # CHE~ON # BPX # STATE OF ALASKA # PHILLIPS # ANO8 GEOLOGY # EXXON # MOBIL * The corrected API# for 18-29A is 50-029-22316-01 STATE OF ALASKA - ALASKA t !AND GAS CONSERVATION CC IISSION REPORT OF SUNDRY WELL OPI--HATIONS 1. Operati(~hs performed: Operation shutdown Stimulate Plugging Perforate X 2. Name of OPerator Pull tubing Alter casing ARCO Alaska, ~nc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 906' NSL, 4381' WEL, Sec. 11, T10N, R15E, UM At top of productive interval 2173' NSL, 2544' EWL, Sec. 12, T10N, R15E, UM At effective depth At total depth 2268' NSL, 2934' EWL, Sec. 12, T10N, R15E, UM ,,, Repair well 5. Type of Well Development Exploratory Stratigraphic O~her X, 6. Datum of elevation(DF or KB) 62' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-36 9. Permit number/approval number 93-19 10. APl number 50 - 029-22340 feet 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 12569 feet 9170 feet Production Liner Plugs(measured) Retainer/cmt cap @ 12420' MD 12376 feet 9040 feet Junk(measured) Length Size Cemented Measured depth True vertical depth 80' 20" 281 CU ft Arcticset 111' 111' 3915' 13-3/8" 1517 sx CS III, 400 sx CI G, 3977' 3729' & 165 sx CS II 11869' 9-5/8" 1210 sx CIG 11901' 8653' 826' 7" 180 sx Cl G 12569' 9170' Perforation depth: measured 12090-12098'; 12248-12252'; 12308-12314' true vertical 8843-8848'; 8952-8955'; 8993-8997' Tubing (size, grade, and measured depth) 7", 26#, 13 Cr-80, NSCC Cr Tbg @ 3285' MD; 5-1/2", 17#, 13 Cr-80, NSCC Cr Tbg @ 11676' MD; 4-1/2, 12.6#, 13 Cr-80, CrTbg @ 11741' MD Packers and SSSV (type and measured depth) Baker Perm Packer @ 11678' MD; 7" Camco BaI-O SSSV @ 2245' 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 In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 85 ~.-"' 68 5201 583~ 4879 3752 KI:LrlVEL) DEC 2 1 1995 At~ska 0il & Gas Cons. Commission Ancn0rage Tubing Pressure -- 272 15. Attachments 16, ,Status of well classification as; O01)lf~ Of t,..CtOel aln~l ~tJl'Veya ri, In ....... Daily Report of Well Operations ..._ OiI.Z~ Gas ..._. Suspended _._. Service 17, '1 ~erebY eertifY t-I~at the foregoing is true 'and COrrect t° the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 265 1083/7 AJB cc: SW, JWP Date SUBMIT IN DUPLICATE 3-36 DESCRIPTION OF WORK COMPLETED ACID STIMULATION W/PACKER & CTU CEMENT SQUEEZES FOR WATER SHUTOFF 6/28/93: Shot Initial Perforations at: 12064 - 12068' MD (Z4) 12094 - 12098' MD (Z3) 12244 - 12248' MD (Z2) 12430 - 12438' MD (Z2) Ref. Log: BHCS 4/22/93. 7/3/93: RIH & tagged PBTD at 12440' MD. 7/6/93: MIRU CTU & PT equipment. RIH w/CT mounted Inflatable Packer & inflated element to set packer at 12388' MD, then pumped an Acid Stimulation through the perforations below the packer (see above). Pumped 5 bbls 1% NH4Cl Water, followed by 27 bbls 12% HCl, followed by 50 bbls 12% HCI - 3% HF, followed by 445 bbls 1% NH4Cl Water displacement. Deflated packer & POOH w/CT & packer. Rigged down. 7/9/93: A CTU Cement Squeeze w/Cement Retainer for Water Shutoff was performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/1% KCI Water & Crude, then RIH w/CT mounted Cement Retainer. Inflated & set the Cement Retainer at 12420' MD. Pumped 10 bbls Latex Acid Resistive Cement through the retainer, to squeeze the lower perforation interval (listed above). Disconnected CT from Cement Retainer & pumped an additional 35 bbls Latex Acid Resistive Cement on top of the Retainer, to squeeze the perforation intervals above the retainer. Pressured up to 2500 psi maximum squeeze pressure, & held 2000 psi for 90 minutes to place a total of 21 bbls of cement behind pipe. Contaminated cement w/biozan & jetted cement from wellbore down to 12400' MD. POOH w/CT. Rigged down. 7/13/93: RIH & tagged PBTD at 12428' MD. 7/20/93: Added Perforations: 12330 - 12334' MD (Z2) 12382 - 12386' MD (Z2) Ref. Log: BHCS 4/22/93. 7/24/93: Added Perforations: 12068 - 12070' MD (Z4) 12090 - 12094' MD (Z3) 12249 - 12253' MD (Z2) Ref. Log: BHCS 4/22/93. Reperforated: 12O64 - 12094 - 12312 - 12068' MD (Z4) 12098' MD (Z3) 12314' MD (Z2) Ref. Log: BHCS 4/22/93. RECEIVED DEC 2 1 t993 Ai~ska Oil & Gas Cons. Commission Anchorage 3-36 DESCRIPTION OF WORK COMPLETED ACID STIMULATION W/PACKER & CTU CEMENT SQUEEZES FOR WATER SHUTOFF I I/4/93 :' A CTU Acid Wash & Cement Resqueeze for Water Shutoff were performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/Hot Seawater & Crude, then RIH w/CT & reciprocated a presqueeze acid wash across the perforations (listed above). Pumped 50 bbls 15% HCI w/10% Xylene @ 2.2 bpm, followed by 50 bbls 13% HCI - 1.5 HF @ 2.2 bpm, followed by 100 bbls 1% NH4CI Water @ 2.2 bpm, followed by 45 bbls Seawater. Loaded the wellbore w/Crude & switched to pumping cement down the CT to squeeze the perforations (see above). Pumped 22 bbls Micro Matrix Cement, followed by 49 bbls Latex Acid Resistive Cement & attained 4000 psi maximum squeeze pressure (3200 psi equivalent at surface). Held 3200 psi for 1 hour & placed a total of 16 bbls of cement behind pipe. Contaminated cement w/biozan & jetted cement from wellbore down to 12379' MD. POOH w/CT. Rigged down. I I/5/93: RIH & tagged PBTD at 12380' MD. I 1/13/93: Reperforated: 12090 - 12098' MD (Z3) 12312 - 12314' MD (Z2) Ref. Log: BHCS 4/22/93. 12/10/93: Reperforated: 12249 - 12252' MD (Z2) Ref. Log: BHCS 4~22/93. Added Perforations: 12248 - 12249' MD (Z2) 12308 - 12312' MD (Z2) Ref. Log: BHCS 4/22/93. Returned well to production w/gaslift & obtained a valid production test. RECEIVED DEC 2 1 1995 Alaska 0il & Gas Cons. Commission Anchorage ARCO ,~lns~r_~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS DLL/gCS/~ DLL/MI~/AC/CN/GR CDN/CDR DLL/mLL/,~.C/aR 0~ DLL/MIJ,/AC/GR l~m 1 Job493196 ~ch Run I Job~5~9 Atlas Run I J~127 ~ch Run1 Job~59~.01 Atlas l~_m 1 Job~5915.01 Atlas Please sign and return _~he attached co~y, as receipt of data. c[lv o ' · AUG 3 1 199;} Have A Nice Day! /~, A{a/ska 0il & Gas Cons. Commission Sonya Wallace AP P R O V E D_~~ Anchorage ATO- 1529 Trans# 93087 CENTRAL FILES (CH) CHEVRON D&M BOB OCANAS (OH/GCT) EXXON MARATHON MOBIL # PI~-L~S PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO --This is a revised tape, please replace one previously issued. ARCO ~tlAskA, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 X2/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Aha Job #AKEI30010 Sperry Job#1209 BHI Ana Ana Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#AKEI30009 Sperry Job# 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Ana Ana Ana Job# 1159 Teleco Job# 1175 Teleco Job# 1167 Teleco Job#AKMM911128 Sperry Job#AKMM911231 Sperry Sperry Ana Job#AKMW30003 Sperry Job#AKMM921231 Spe try Job# 1168 Teleco Job#1172 Teleco Teleco Job# 1185-450 Teleco Job# 1185 Teleco Job# 1190 Teleco Job# 1195-450 Teleco Job#1205 BHI Please sign and return the attached copy as receipt of data. RECEIVED B _ Have A Nice Day. 4/e~. '~ ~ 1 - Sonya Wallace APPROVED__~~, ,~, ?00~' ATO- 1529 Trans# 93059 '. ~r~,~' '.~.~. ,~v '" CHEVRON # PB WELL FILES # CLINT CHAPMAN # BPX # EXXON # ST. OF AK. (2 COPIES) MOBIL # LUCILLE JOHNSTON ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ~- 7-17-93 Dual Burst TDTP R~!n 1, D o ' ~c q%~-18A 7-25-93 Pe~Record R~n 1, 5'd ~-~ch ~-36 7-15-93 USIT ~lor ~~ -36 7-20-93 Pe~ Record R~ 1, 5" n~o-~ h -36 7-24-93 Pe~ Record ~~ R~m 1, 5" Sch ~l~ ~-12 : 7-18-93 C~ ~-~ R~ 1, 5" Sch ~~ 4-16 7-19-93 ~ Brat ~P ~ ~~ 1, 5' Sch ~~4-40 7-22-93 ~ ~tect z~-~ R~ 1, 2"&5" Sch '~ ~ ~- 1 7-23-93 Pe~ Record ~-~ R~n 1, 5" Sch ~~~-29 7-22-93 ~od ~o~e l~-Io~ R~m 1, 5" .~ ,. Sch ~~-32 7-22-93 ~od ~o~e ~o~-tt~9 Rnn 1, 5" ~[*~,~ch 5 .~_~ch ~~ 1-27 7-18-93 ~ Brat ~ R~m 1," ~~~4-4 7-24-93 ~ Brat ~ R~ 1, ~~~ 5-3 7-14-93 ~ Brat T~ Rnn 1, ~ .... ~cn ~~~ 5-4 7-24-93 ~ Brat ~ R~ 1, ~,,~o~_ - ~~~ 5- ~3 7-24-~3 c~ R,m ~, 5"~~'~Sch ~-~5-~4 7-25-~3 C~ ~ox~~ ~,m ~, 5" ~h ~~6-~A 7-26-~3 ~uc~on ~g~m~,,~ ~, 2"~5" Sch ~~] 7-3 7-20-93 ~ucflon ~g R~ 1, 2"&5" Sch Plebe s~ ~d retm ~e at~ched copy ~ receipt of ~. ~ve A Nice ~y~ ~n~ W~ce APPROVED ATO- 1529 ~s~ 93~2 ,/ # CENTRAL FILES # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO The correct bottom logged interval for 4-16 is 11,507 feet. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WEL . COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of V~ell Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-19 3. Address B. APl Number I P. O. Box196612, Anchorage, Aiaska 99519-6612 ORI i~1, , ,. 5o-029-22340 4. Location of well at surface O I/]~.~.i., 9. Unit or Lease Nameprudhoe Bay Unit 906' NSL, 4381'WEL, SEC. 11, TION, R15E~~! At Top Producing Interval ! _ DA~.E ,~ i ~ ~. , 10. Well Number 2173' NSL, 2544' EWL, SEC. 12, TION, R15t ' ';i~i~ 11. Field and Pool At Total Depth ~ Ii i' 1 Prudhoe Bay Field/Prudhoe Bay Pool 2268' NSL, 2934' EWL, SEC. 12, TION, R1 · 5. Elevation in feet (indicate KB. DF, etc.) 16. Lease Designation and Serial No. KBE = 60.2' J ADL 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offsho re 116. No. of Completions 4/4/93 4/22/93 6/29/93J N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD', 19. Directional Survey ~)0. Depth where SSSV set 121. Thickness of Permafrost / 12569' MD/9187' TVD 12520' MD/9153' TVD YES [] NO [] 2245' feet MD I 1900' (Approx.) 22. Type Electric or Other Logs Run MSFL/DLL/BHCS/CNL/GR 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 31' 111' 30" 281 cuft Arcticset 13-3/8" 68# NT80 31' 3977' 16" 1517 sxCS 111/400 sx "G"/165 sx CS II 9-5/8" 47# NT80S 32' 11901' 12-1/4" 1210sx Class "G" 7" 29# 13CR80 11743' 12569' 8-1/2" 180 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 (MDI PACKER SET (MD) Gun Diameter MD3'3/8" 4 S~D 5-1/2"x4-1/2" 11741' 11678' 12064'- 12070' 8762'-8766' 12090'- 12098' 8781'-8786' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12249'- 12253' 8892'-8895' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12312'- 12314' 8935'8936' 12330'- 12334' 8947'-8950' 12382'- 12386' 8982'-8985' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7/25/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED ~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. RECEIV F Anchorago Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEP'rH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 12016' 8728' Shublik 12016' 8728' Top Sadlerochit 12016° 8728' Base Sadlerochit 12515' 9136' 81. LIST OF ATTAOHMENTS 32. I hereby certify lhat the foregoing is true and correct to the best of my knowledge Signed /~'~'~/~ Title Drill/no EnoineerSuoervisor 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- 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". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS3-36 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/03/93 12:01 SPUD: 04/04/93 11:30 RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 28E 04/01/93 (1) TD: 0 PB: 0 04/02/93 (2) TD: 0 PB: 0 ON THE ROAD TO 3-36 MW: 8.6 Seawater PREPARE TO MOVE & BLOW DN STEAM & H20. MOVE PITS OFF & SKID FLOOR. DISCONNECT & MOVE MOTOR COMPLEX. ON THE ROAD TO 3-36 LAY MATS FOR SUB. MW: 8.6 Seawater MOVE RIG TO DS 3. LEVEL PAD, NIPPLE UP DIVERTER & HYDRIL. & LAY MATS FOR SUBSTRUCTURE. 04/03/93 (3) TD: 0 PB: 0 04/04/93 ( 4) TD: 0 PB: 0 04/05/93 ( 5) TD: 1350' ( 0) 04/06/93 (6) TD: 3060' (1710) 04/08/93 (8) TD: 4000' ( 940) PU BHA MW: 8.6 Seawater NU DIVERTER. SPOT SUBSTRUCTURE OVER # 3-36. SPOT MOTORS COMPLEX. RAISE DERRICK & SKID FLOOR. SPOT MUD PITS COMPLEX & SET FUEL TANKS. STEAM AROUND. RIG UP FLOOR & TAKE ON H20. ACCEPTED RIG FOR OPERATION @ 2400 HRS. NIPPLE UP RISER & INSTALL FLOW LINE. STRAP & PU BHA. RD SUN DRLG WASHER MW: 8.8 KCl FUCTION TEST DIVERTER SYSTEM. PU KELLY & TAG ICE @ 81' RIG UP SUN DRILLING GRAVEL WASHER. UNPLUG ICE ON INJECTION LINE TO 3-35. INJECT 30 BBLS DIESEL. R/D SUN DRILLING GRAVEL WASHER. DRILLING @ 1350' MW: 8.9 VIS:300 RIG DOWN SUN DRILLING~RAVEL WASHER. RU VECO GUZZLER. SPUD IN, DRILLING FROM 86' TO 1350'. DRILLING @ 4853 MW: 9.0 VIS:300 DRILLING FROM 1350 TO 1992. CBU. POH, CHANGE BHA & RIH TO 1992. DRILLING FROM 1992 TO 2915. SHORT TRIP TO 1992. DRILLING FROM 2915 TO 3060. PU 12-1/4" BHA MW: 9.7 VIS: 52 FINISH RUNNING 13-3/8. MU MANDREL HANGER AND CEMENT HEAD. TAG LANDING SHOE @ 3977'MD. CIRC. AND CONDITION MUD FOR CEMENT JOB. RECIP CASING. RD LD LANDING JT. ND DIVERTER. PERFORM TOP JOB. RIH W/ 3/4 PIPE TO 60' BELOW HANGER. CIRC CLEAN. ATTEMPT TO MAKEUP 13 5/8 5M FMC UNIVERSAL WELLHEAD. DEFECTIVE LOCK RING. REPLACE LOCK RING. TST BOPE. INSTALL WEAR RING. PREP TO PICK UP 12-1/4" BHA. RECEIVED Anchorage WELL : DS3-36 OPERATION: RIG : NABORS 18E PAGE: 2 04/09/93 (9) TD: 5500' (1500) 04/10/93 (10) TD: 6750' (1250) 04/11/93 (11) TD: 7565' ( 815) 04/12/93 (12) TD: 8075' ( 510) 04/13/93 (13) TD: 9221' (1146) 04/14/93 (14) TD: 9725' ( 504) 04/15/93 (15) TD:10391' ( 666) 04/16/93 (16) TD:l1216' ( 825) DRILLING @ 5500' MW: 9.5 VIS: 40 MU 12-1/4" BHA. RIH AND TAG @ 3896'. TEST 13-3/8 CASING. DRILL PLUGS, FC AND CEMENT. REPAIR HOLE IN MUD LINE. DRILL CEMENT, FS AND 10' OF NEW HOLE TO 4010'. CIRC HOLE CLEAN. DRILL 4010 TO 5020. SHORT TRIP TO 13-3/8 CASING SHOE. DRILL 5020-5500'. DRILLING @ 6750 MW: 9.6 VIS: 41 DRILL 5500 TO 6035' SHORT TRIP 10 STANDS. TIH. NO EXCESS DRAG. DRILL 6035 - 6750. PREP TO TRIP FOR NEW BIT. DRILLING @ 7565 MW: 9.7 VIS: 42 DRILL 6750 - 6767' ROP DROPPING. CIRCULATE BOTTOMS UP. POOH. C/O BIT AND NB MOTOR STAB - UG. SERVICE MWD. TIH TO 13-3/8 CASING SHOE. SLIP AND CUT DRILL LINE. SERVICE DRAWORKS BRUSHES. TIH. REAM LAST 3 JTS TO BOTTOM - SAFETY. DRILL 6767 - 7565. DRILLING @ 8075' MW: 9.8 VIS: 41 DRILL 7565 - 7738' CIRCULATE BOTTOMS UP. POOH. C/O BIT AND MOTOR. SERVICE WEAR BUSHING. TIH. REAM 3 JTS. TO BOTTOM SAFETY. DRILL 7738 - 8075' CBU. MW: 9.8 VIS: 41 DRLG F/ 8075'-8751' CIRC. SHORT TRIP 12 STDS. DRLG F/ 8751'-9221'. DRLG. MW: 9.7 VIS: 41 CBU. POOH. RIH. WASH F/ 9125'-9221' DRLG F/ 9221'-9725'. DRLG. DRLG F/ 9725'-10269' 10269'-10391'. MW: 9.7 VIS: 45 SHORT TRIP 11 STDS. DRLG F/ DRLG. DRLG F/ 10391'-11216' MW: 9.8 VIS: 45 04/17/93 (17) TD:11265' ( 49) 04/18/93 (18) TD:l1705' ( 440) 04/19/93 (19) TD: 11906' ( 201) RIH. DRLG F/ 11216'-11265' BIT. MW: 9.7 VIS: 46 CBU. POOH. TEST BOPE. RIH W/ BHA, DRLG. MW:10.0 VIS: 42 RIH. REAM F/ 11135'-11265'. DRLG F/ 11265'-11658' SHORT TRIP 15 STDS. DRLG F/ 11658'-11705' RUN CSG. MW:10.1 VIS: 46 DRLG F/ 11705'-11906'. CIRC. SHORT TRIP 20 STDS. CIRC. POOH. L/D BHA. TEST BOPE. RIH W/ 9-5/8" CSG. AJaska Oil & r.~.~o~,,~, Gans. Anchorage WELL : DS3-36 OPERATION: RIG : NABORS 18E PAGE: 3 04/20/93 (20) TD:l1906' ( 0) 04/21/93 (21) TD:12079' ( 173) 04/22/93 (22) TD:12520' ( 441) 04/23/93 (23) TD:12569' ( 49) 04/24/93 (24) TD:12569' ( 0) 04/25/93 (25) TD:12569' ( 0) 04/26/93 (26) TD: 12569' ( 0) DRLG CMT. MW: 9.7 VIS: 41 RIH W/ 9-5/8" CSG. CIRC. PUMP 50 BBLS SPACER, 770 SX 'G' CMT, 440 SX 'G' CMT. NO BUMP PLUG. SET & TEST PACKOFF. TEST BOPE. RIH. WASH TO TOC. DRLG CMT TO 11819' POOH F/ BIT #9 MW: 9.1 VIS: 46 DRILLING F/ 11820' MD TO 11934' MD. CIRC BOTTOMS UP, CLEAN OUT PIT #6 FOR KCL/POLY MUD "DRILL IN FLUID ". DISPLACE LSND TO 9.1 KCL/POLY. DRILL F/ 11924' MD TO 12079' MD. CIRC BOTTOMS UP, BUILT 100 BBLS WORKING PIT VOLUME. POOH F/ BIT CHANGE. DRLG 8-1/2" PROD HOLE MW: 9.1 VIS: 44 RIH W/ BHA #8 W/ BIT #9. SLIP AND CUT DRLG LINE. RIH - TIGHT @11973. KELLY UP. REAM F/ 11973' MD TO 12079' MD. DRILL F/ 12079 MD TO 12520' MD. CONDITION 8-1/2" PROD. HOLE MW: 9.1 VIS: 46 DRLG F/ 12520' MD TO 12569' MD. CIRC BOTTOMS UP. SHORT TRIP 7 STANDS TO 9-5/8" SHOE. CIRCC 20 BBL HIGH VIS SWEEP. POOH FOR SWS. O..H. LOGGING. RIG UP SWS WIRELINE LOGGERS. PERFORM O.H. LOGGING SURVEY. RIG DOWN SWS O.H. LOGGERS. RIH TO 12569' MD. DROP TANDEM SINGLE SHOT. POOH TO RUN 7". POOH W/ 5" DP RUNNING TOOL MW: 9.2 VIS: 45 COMPLETE CIRC. POOH W/ BHA #8 - LD HEVI WEIGHT & 8-1/2" BHA. RIG UP NABOR CSG RUNNING CREW TO RUN 21 JTS 7" 29# 13CR/80 NSCC CSG. PICK UP 7" LINER/TIW LTP + HANGER. RIH W/ 7" CIRC LINER VOLUMNE. RIH W/ 7" LINER TO 12569. CIRC @ 8 BPMM AND RECIPROCATE 7" LINER. POOH 10 STANDS. POOH F/ 8-1/2 BIT TO DRESS OFF 7" TIE BACK EXT. TESTING BOPE MW: 9.3 VIS: 47 CONTINUE TO POOH W/ 7" LINER TOP PACKER RUNNING TOOL - LINER WIPER NOT ATTACHED TO RUNNING TOOL. P/U 8-1/2 BIT AND RIH. WASH AND REAMMM F/ 11482 TO 11733. TAGGED LINER TOP @ 11733 - NE CEMENT CONTACTED W/ 8-1/2 BHA. POOH F/ G" BIT. P/U 3-1/2 DP + 4-3/4" DC'S. CUT 104' DRILLING LINE. RIH TO 7" TIE BACK EXT - SET SLIPS ROTATE OFF INTO 7" LINER - TRIOP TO LANDING COLLAR - NO CEMENT NOTED - TAG LANDING COLLAR @ 12479. CIRC BOTTOMS UP. ATTEMPT TO TEST 7" 29# 13CR/80. POOH W/ 6" BHA. TEST BOPE. POOH W/ POLISH MILL MW: 9.4 VIS: 42 COMPLETE TEST OF BOPE. M/U HALLIBURTON 7" RTTS TOOL. RIH W/ 7" RTTS TOOL. POSITION 7" RTTS TOOL @ 11757. CIRCULATE BTTMS UP. POOH F/ POLISH MILL. M/U POLISH MILL - RIH. POLISH TIW TIE-BACK EXT. CIRC HIGH VIS SWEEP (20 BBLS BIOZAN). POOH F/ LINER TOP ISOLATION PACKER. RECEiVeD Anchor,..%,io WELL : DS3-36 OPERATION: RIG : NABORS 18E PAGE: 4 04/27/93 (27) TD:12569' ( 0) 04/28/93 (28) TD:12569 PB:12490 04/29/93 (29) TD:12569 PB:12490 POOH L/D 5" DP MW: 9.4 VIS: 0 RIH W/ BAKER "H" HYDRAULIC LINER TOP ISOLATION PACKER W/ TIW MOLYGLASS SEAL ASSEMBLY. RIH TO TOP OF TIE-BACK EXT @ 11733' MD. POOH L/D 5" HWT AND 6-1/4" DC'S. PU 3-1/2 MULE SHOE - RIH AND TAG TOP OF TIE BACK EXT. @ 12479' MD. DISPLACE MUD TO INHIBITED SEAWATER W/ 10 GAL/100 BBL CR-193 CORROSION INHIBITOR. TEST CASING. POOH - L/D 5" 3-1/2" DP. INSTALL CONTROL LINES TO SSSV MW: 8.8 POH LAYING DOWN 5" DP. SLIP & CUT DRILLING LINE. L/D 3 1/2 DP & 4 3/4 DC'S. CHANGE TOP PIPE RAMS TO 7" & TEST BONNET SEALS. RU & RUN 5 1/2 TBG. - PU SSSV & INSTALL CONTROL LINES. KC1 RELEASED RIG @ 0230 HRS. MW: 8.8 KC1 TEST CONTROL LINES. RUN 7" TBG & MU TBG HANGER, CONNECT & TEST CONTROL LINES. DISPLACED WELL W/ 140 BBLS DSL. LAND TBG & RILDS. U TUBE. DROP SETTING BALL & PRESS UP TBG. ND BOPE. NU ADPT FLANGE & XMAS TREE, TEST HANGER SEALS & CONTROL LINES. PULL TWO & INSTALL BPV, SECURE WELL. RELEASED RIG @ 0230 HRS. 04/29/93. SIGNATURE: (drilling superintendent) DATE: RECEIVED SRRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/3-36 500292234000 NORTH SLOPE COMPUTATZON DATE: 4/19/93 DATE OF SURVEY: 04/18/93 MWD SURVEY JOB NUMBER: AK-MW-30020 KELLY BUSHZNG ELEV. = 60.20 OPERATOR: ARCO ALASKA ZNC FT. TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DZRECTZON RECTANGULAR COORDZNATES DEGREES DG/IO0 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -60.20 196 196.00 135.80 439' 439.00 378.80 694 694.00 633,80 952 952.00 891.80 0 12 6 12 12 N .00 E .00 .OON .OOE S 87.60 E .10 .01S .34E N 8.50 E .09 .18N .80E S 79.00 W .10 .31N .39E S 69.20 E .15 .07N .37E .00 .33 .82 .44 .38 1207 1206.99 1146.79 1460 1459.99 1399.79 1714 1713.96 1653,76 1936 1935.92 1875,72 2092 2091.88 2031.68 12 N 50.80 W .15 .19N .44E 30 S 88.20 W .15 .43N 1.00W 6 N 46.70 E .59 2,07N .34W 6 N 22.40 E .21 5.50N 2.03E 30 N 39,80 E ,36 8.46N 3.90E ,47 -,91 ,04 2.99 5,37 2283 2282,62 2222.42 2379 2378,07 2317,87 2475 2472,75 2412.55 2570 2565.63 2505,43 2697 2688,57 2628.37 4 24 7 41 11 11 13 0 16 0 N 75,70 E 1,73 12,19N 12.61E N 75,60 E 3.44 14,70N 22,41E N 81,70 E 3,79 17,64N 37,87E N 83,80 E 1,95 20,13N 57,62E N 81,80 E 2,39 24,17N 89,15E 14,61 24,70 40,44 60,31 92,06 2824 2809,40 2749,20 2951 2927,47 2867.27 3079 3043,12 2982,92 3238 3182,44 3122,24 3397 3316,12 3255,92 19 47 23 23 27 17 30 17 35 12 N 80,80 E 3.00 30,11N 127,72E N 79,40 E 2,86 38,19N 173,76E N 79,40 E 3,05 48,27N 227.62E N 78,30 E 1,92 63,11N 302,75E N 77,60 E 3,09 81,10N 386.84E 131.06 177.80 232.60 309.18 395.13 3556 3441.98 3381.78 3715 3559.07 3498,87 3909 3692.10 3631.90 4085 3807,21 3747.01 4244 3910.58 3850.38 4O 45 48 49 49 5 N 78,80 E 3,12 100,90N 481,89E 0 N 78,80 E 3,08 121,77N 587,33E 24 N 79,10 E 1,76 148,82N 725,88E 54 N 80,30 E 1,.00 172,61N 856,85E 0 N 82,50 E 1,19 190,68N 976.28E 492,19 599,67 740,83 873,94 994,67 4403 4014,15 3953,95 4594 4134,98 4074,78 4786 4253,98 4193,78 4977 4370,77 4310,57 5166 4485,69 4425,49 49 42 51 47 51 35 53 0 52 5 N 81.10 E .80 207.90N 1095.67E N 80.20 E 1.16 231.94N 1241.58E N 82;40 E .91 254,73N 1390.49E N 80.80 E .99 276,82N 1539.97E N 79.20 E .82 302.86N 1687.71E 1115,20 1263,05 1413,63 1564,64 1714,66 5356 4600,95 4540,75 5547 4715,63 4655,43 5738 4831,24 4771,04 5929 4950,13 4889,93 6120 5070,58 5010,38 53 53 52 5O 51 12 0 30 30 17 N 81.10 E .98 328.68N 1836.50E N 78.80 E .97 355.32N 1986.87E N 80.40 E .72 382.77N 2136.39E N 79.70 E 1.09 408.58N 2283.60E N 78.70 E .58 436,36N 2429.19E 1865.66 2018.36 2170,38 2319.83 2468.04 RECEIVED Alaska Oil & Gas Cons. Anchorage S~-"'~RRY-SUN DRILLING SERVICES'"-'", ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/3-36 500292234000 NORTH SLOPE COMPUTATION DATE: 4/19/93 DATE OF SURVEY: 04/18/93 MWD SURVEY JOB NUMBER: AK-MW-30020 KELLY BUSHING ELEV. = 60.20 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS DIRECTION DEGREES DG/IO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 6247 5149.73 5089.53 6374 5228.44 5168.24 6565. 5351.45 5291.25 6661 5415.62 5355.42 6788 5500.76 5440.56 51 35 N 78.80 E ,24 51 47 N 78.70 E .17 48 0 N 79.20 E 2.00 48 5 N 78.80 E .33 47 42 N 79.50 E .52 455.74N 2526,60E 475.18N 2624,35E 503.20N 2767,71E 516.82N 2837,80E 534.56N 2930,34E 2567.36 2667.01 2813.08 2884.47 2978.70 6916 5586.58 5526.38 7104 5711.52 5651.32 7293 5836.26 5776.06 7450 5937.39 5877.19 7671 6076.02 6015.82 48 5 N 79.40 E .32 48 35 N 80.80 E .62 48 47 N 83.80 E 1.20 51 0 N 80.80 E 2.02 51 17 N 82.00 E .44 551.95N 3023.71E 576.09N 3162.08E 595.10N 3302.74E 611.24N 3421.71E 636.97N 3591.88E 3073.67 3214.13 3355.90 3475.83 3647.84 7828 6176.12 6115.92 7953 6257.13 6196.93 8111 6359.22 6299.02 8297 6478.53 6418.33 8360 6518.68 6458.48 49 30 N 78,10 E 2.23 49 42 N 77.10 E ,63 49 47 N 78.50 E ,68 50 24 N 77.10 E .66 50 24 N 78.50 E 1.71 657.81N 3711,00E 678.26N 3803.96E 703.74N 3921.82E 733.90N 4061.28E 744.15N 4108,72E 3768.76 3863.90 3984.42 4127,03 4175.55 8487 6599,12 6538.92 8645 6698.02 6637.82 8767 6773.63 6713.43 8926 6873.57 6813.37 9074 6967.91 6907.71 51 0 N 77.70 E .68 51 30 N 79.50 E .94 51 54 N 79.50 E .33 50 12 N 79.90 E 1.09 50 35 N 79.30 E .41 764.42N 4204.88E 788.77N 4325.66E 806.21N 4419.80E 828.33N 4541.44E 848.91N 4653.60E 4273.79 4396.98 4492.72 4616.36 4730,39 9251 7077.96 7017.76 9346 7135.33 7075,13 9441 7191.84 7131.64 9602 7287.71 7227.51 9755 7380.64 7320.44 52 30 N 78.70 E 1.11 53 12 N 78,80 E .74 53 47 N 79.20 E .72 53 5 N 80.60 E .82 52 5 N 79,40 E .90 875.37N 4789.65E 890.14N 4863.92E 904.71N 4938.88E 927,40N 5066.20E 948.49N 5185,89E 4868.98 4944.69 5021.06 5150.38 5271.91 9880 7457.60 7397,40 10005 7534.64 7474.44 10132 7612.83 7552.63 10288 7709,83 7649.63 10447 7810.54 7750.34 51 54 N 79.40 E .16 52 0 N 82.20 E 1.77 52 0 N 82..20 E .00 51 5 N 79.40 E 1.52 50 17 N 79.90 E .56 966.61N 5282.71E 982.34N 5379.85E 995.93N 5479.00E 1015.43N 5599.56E 1037.54N 5720.60E 5370.41 5468.79 5568.76 5690.87 5813.90 10574 7891.49 7831.29 10701 7971.67 7911.47 10828 8050.55 7990.35 10955 8128,30 8068..10 11081 8204.57 8144,37 5O 3O 51 12 52 0 52 30 53 0 N 79.40 E ,34 N 79,70 E .58 N 80.20 E .70 N 78,70 E 1.01 N 79.70 E .75 1055.12N 5816.86E 1072.98N 5913.71E 1090.35N 6011.71E 1108.74N 6110.42E 1127.53N 6208.93E 5911.76 6010.24 6109.77 6210.17 6310.46 ~T!RRY-SUN DRILLING SERVICES : ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/3-36 500292234000 NORTH SLOPE COMPUTATION DATE: 4/19/93 DATE OF SURVEY: 04/18/93 MWD SURVEY JOB NUMBER: AK-MW-30020 KELLY BUSHING ELEV. = 60.20 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 TOTAL RECTANGULAR COORDINATES VERT. NORTH/SOUTH EAST/WEST SECT. 11159 8251.51 8191.31 53 0 N 78.50 E 1.23 1139.31N 6270.10E 6372.75 11301 8338.63 8278.43 51 17 N 79.20 E 1.26 1161.00N 6380.09E 6484.85 11427' 8418.01 8357.81 50 35 N ?8.70 E .64 1179.75N 6476.13E 6582.70 11552 8498.44 8438.24 49 17 N ?7.60 E 1.24 1199.39N 6569.77E 6678.34 11677 8581.26 8521.06 47 42 N ?5.70 E 1.71 1220.98N 6660.84E 6771.82 11800 8664.75 8604.55 46 47 N 76.00 E .75 1243.06N 6748.42E 6861.95 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT : 6861.95 FEET AT NORTH 79 DEG. 33 MIN. EAST AT MD = 11800 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 79.56 DEG. S~I-'"iRRY-SUN DRZLLZNG SERVICES~". ANCHORAGE ALASKA PAGE 4 PRUDHOE BAY DRZLLZNG PBU/3-36 500292234000 NORTH SLOPE COMPUTATTON DATE: 4/19 /93 DATE OF SURVEY: 04/18/93 JOB NUMBER: AK-MW-30020 KELLY BUSHZNG ELEV, = 60,20 FT, OPERATOR: ARCO ALASKA ZNC ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNATES NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON O' ,00 -60,20 ,00 N ,00 E 1000 1000,00 939,80 ,01 N ,53 E 2000 1999,91 1939,71 6,64 N 2,50 E 3000 2972,18 2911,98 41,88 N 193,46 E 4000 3752,46 3692,26 161,65 N 792,76 E .00 ,00 .00 ,09 .09 27.82 27.73 247.54 219.72 5000 4384.61 4324.41 279.76 N 1558.10 E 6000 4995.29 4935.09 418.38 N 2337,50 E 7000 5642.68 5582.48 563,45 N 3085.16 E 8000 6287.53 6227,33 686.26 N 3838.91 E 9000 6920.94 6860.74 838.30 N 4597.42 E 615.39 367.85 1004.71 389.32 1357.32 352.61 1712.47 355.15 2079,06 366,59 10000 7531.56 7471.36 981.81 N 5375.94 E 11000 8155.70 8095.50 1115.73 N 6145.43 E 11800 8664.75 8604.55 1243,06 N 6748.42 E 2468,44 389,38 2844,30 375,86 3135,25 290,95 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON MZNZNUM CURVATURE METHOD, ~f~RY-SUN DRILL]"NG SERVICES'-'"', r ANCHORAGE ALASKA PAGE 5 PRUDHOE BAY DRILLING PBU/3-36 500292234000 NORTH SLOPE COMPUTATION DATE: 4/19/93 DATE OF SURVEY: 04/18/93 JOB NUMBER: AK-MW-S0020 KELLY BUSHING ELEV. = 60.20 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION O' .00 -60.20 60 60.20 .00 160 160.20 100.00 260 260.20 200.00 360 360.20 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .01 S .22 E .00 .00 .02 S .57 E .00 .00 .04 N .78 E .00 ,00 460 460.20 400.00 560 560.20 500.00 660 660.20 600.00 760 760.20 700.00 860 860.20 800,00 .21 N .80 E .00 .00 .39 N .83 E .00 .00 .33 N .51 E .00 .00 .27 N .17 E .00 .00 .18 N .07 E .00 .00 960 960.20 900.00 1060 1060.20 1000.00 1160 1160.20 1100.00 1260 1260.20 1200.00 1360 1360.20 1300.00 .06 N .40 E .00 .00 .07 S .72 E .01 .00 .09 N .57 E .01 .00 ,31 N .30 E .01 .00 ,46 N ,13 W .01 .00 1460 1460.20 1400.00 1560 1560.20 1500.00 1660 1660.20 1600.00 1760 1760,20 1700.00 1860 1860.20 1800.00 .43 N 1.00 W .01 .00 .41 N 1.88 W .02 .00 .36 N 1.09 ~ ,03 ,02 .68 N .31 E .05 ,02 .16 N 1.47 E ,07 .02 1960 1960.20 1900.00 2060 2060.20 2000.00 2160 2160.20 2100.00 2260 2260.20 2200.00 2360 2360.20 2300.00 5.93 N 2.20 E .08 .02 7.82 N 3.37 E .11 .03 9.82 N 5.76 E .16 .05 11.76 N 11.01 E .32 .16 14.12 N 20.17 E ,78 .46 2462 2460.20 2400.00 2564 2560.20 2500.00 2667 2660.20 2600.00 2771 2760.20 2700.00 2878 2860.20 2800.00 17.28 N 35.47 E 2.01 1.23 20.00 N 56.38 E 4.23 2.21 23.07 N 81,30 E 7,34 3.11 27.45 N 111,00 E 11.76 4.42 33.27 N 146.53 E 18.06 6.30 2986 2960.20 2900.00 3098 3060,20 3000.00 3212 3160.20 3100.00 3329 3260.20 3200.00 3451 3360.20 3300.00 40.87 N 188.07 E 26.63 8,57 49.91 N 236.35 E 38.06 11.43 60.53 N 290,16 E 52.12 14.06 73,04 N 349.79 E 69.23 17.12 87.86 N 418.22 E 91.33 22.10 ~o¢'"'"~'iRRY-SUN DRILLING SERVICES."-'"'- . ANCHORAGE ALASKA PAGE 6 PRUDHOE BAY PBU/3-36 500292234000 NORTH SLOPE COMPUTATION DRILLING DATE: 4/19/93 DATE OF SURVEY: 04/18/93 JOB NUMBER: AK-MW-30020 KELLY BUSHING ELEV. = 60.20 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3579. 3460,20 3400,00 3716 3560,20 3500,00 3861 3660,20 3600,00 4012 3760,20 3700,00 4167 3860,20 3800,00 103,92 N 497,14 E 122,00 N 588,45 E 142,10 N 691,12 E 163,20 N 801,82 E 183,03 N 918,77 E 119.76 28,42 156,41 36.65 201,14 44,74 251,82 50,67 306,96 55,15 4319 3960,20 3900,00 4474 4060,20 4000,00 4634 4160,20 4100,00 4796 4260,20 4200,00 4959 4360,20 4300,00 198,14 N 1032,88 E 216,30 N 1149,31 E 237,39 N 1273,16 E 255,77 N 1398,28 E 274,58 N 1526,12 E 359,44 52.48 414,00 54,56 474,58 60,59 535,82 61,24 599,24 63,42 5124 4460,20 4400,00 5287 4560,20 4500,00 5454 4660,20 4600,00 5621 4760,20 4700,00 5785 4860,20 4800,00 296,73 N 1655,55 E 320,25 N 1782,68 E 341,12 N 1914,67 E 366,81 N 2044,88 E 389,06 N 2173,60 E 664,30 65,07 727,76 63.46 794,68 66,91 860,85 66,18 925,37 64,51 5944 4960,20 4900,00 6103 5060,20 5000,00 6263 5160,20 5100,00 6424 5260,20 5200.00 6578 5360,20 5300,00 410,77 N 2295,62 E 433,82 N 2416,48 E 458,31 N 2539,56 E 482,90 N 2663,21 E 505,02 N 2777,26 E 984,64 59,27 1043,19 58,56 1103,66 60,46 1164,58 60,92 1217,88 53,31 6727 5460,20 5400,00 6876 5560,20 5500,00 7026 5660,20 5600,00 7177 5760,20 5700,00 7329 5860,20 5800,00 526,41 N 2886,49 E 546,54 N 2994,81 E 566,79 N 3104,62 E 584,92 N 3216,59 E 598,27 N 3330,17 E 1267.51 49,63 1316,30 48.79 1366,20 49,90 '1417,42 51,21 1469,35 51,93 7486 5960,20 5900,00 7645 6060,20 6000,00 7803 6160,20 6100,00 7957 6260,20 6200.00 8112 6360,20 6300,00 615,74 N 3449,52 E 634,22 N 3572,33 E 654,06 N 3692,64 E 679.06 N 3807,49 E 703,97 N 3922,96 E 1526,04 56,70 1585,50 59,45 1643,22 57.72 1697,55 54,33 1752,32 54.78 8268 6460,20 6400,00 8425 6560,20 6500.,00 8584 6660,20 6600,00 8745 6760,20 6700,00 8905 6860,20 6800,00 728,95 N 4039,69 E 754,22 N 4157,96 E 780,10 N 4278,91 E 803,09 N 4402,96 E 825,51 N 4525,64 E 1808,05 55,73 1864,99 56.94 1924,05 59,07 1985,03 60,98 2044,91 59,87 S~'~RY-SUN DRILLING SERVICES''-'', ANCHORAGE ALASKA PAGE 7 PRUDHOE BAY DRILLING PBU/3-36 500292234000 NORTH SLOPE COMPUTATION DATE: 4/19/93 DATE OF SURVEY: 04/18/93 JOB NUMBER: AK-MW-30020 KELLY BUSHING ELEV. = 60.20 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9061- 6960.20 6900.00 847,17 N 4644.38 E 2101.65 56.74 9221 7060.20 7000.00 870.83 N 4766.96 E 2161.63 59.98 9387 7160.20 7100.00 896,59 N 4896.57 E 2227.35 65.73 9556 7260.20 7200.00 921.41 N 5030.04 E 2295.97 68.62 9721 7360,20 7300.00 943.66 N 5160.08 E 2361.53 65.55 9884 7460.20 7400.00 967.22 N 5285.97 E 2424.02 62.49 0046 7560.20 7500.00 986.78 N 5412.26 E 2486.32 62.30 0208 7660.20 7600.00 1004.31 N 5538.93 E 2548.66 62.34 0368 7760.20 7700.00 1026.86 N 5660.81 E 2607.92 59.27 0524 7860.20 7800.00 1048.14 N 5779.55 E 2664.61 56.69 0682 7960.20 7900.00 1070.43 N 5899.67 E 2722.50 57.89 0843 8060.20 8000,00 1092.45 N 6023.88 E 2783.47 60.97 1007 8160.20 8100,00 1116.88 N 6151.19 E 2847.20 63,73 1173 8260.20 8200,00 1141.61 N 6281.40 E 2913.24 66.03 1335 8360.20 8300.00 1166.04 N 6406.54 E 2975.29 62,06 1493 8460.20 8400.00 1189.86 N 6526.23 E 3033.08 57.78 1645 8560.20 8500.00 1215.26 N 6638.41 E 3085.51 52.43 1800 8664.75 8604.55 1243.06 N 6748.42 E 3135.25 49.74 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SUB - S URFA CE DIRECTIONAL SURVEY F~ UIDANCE ONTINUOUS ~ OOL .qlaska Oii& :,-.~4, ,.,o,:.~, Anchorage Company Well Name Field/Location ARCO ALASKA, INC. n D.S. 3-36 (906' FSL, 4381' F'EL, SEC 11, TION, R15E) PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 93313 Logged By: WEST Date 16-JUL-93 Computed By: DEES * SCHLUMBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. D.S. 3-36 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' 16-JULY-1993 ENGINEER' T. WEST METHODS OF COMPUTATION TOOL LOCATION' MINIMU~ CURVATURE INTERPOLATION- LINEAR VERTICAL SECTION- HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 79 DEG $3 MIN EAST ArCO ALASKA, INC. D.S. 3 - 36 PRUDHOE BaY NORTH SLOPE, ALASKA COMPUTATION DATE- 30-JUL-93 PAGE DATE OF SURVEY' 16-JULY-1993 KELLY BUSHING ELEVATION' 60.20 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 0 N 0 0 E 0 2 S 73 54 E 0 0 S 33 29 E 0 3 S 62 25 E 80 0 3 S 72 16 E 8O 0 2 S 59 45 E 80 0 0 S 22 16 E 80 0 2 S 23 50 W 80 0 6 S 33 26 W 80 0 4 S 18 45 W 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 9OO O0 -60 20 39 80 139 80 239 80 339 439 539 639 739 839 0 6 S 4 i W 0 5 S 40 57 W 0 8 S 66 36 W 0 26 N8'! I W 0 27 N 73 8 W 0 8 N 49 21 W 0 3O N 2O 38 E 1 2 N 43 36 E I 17 N 43 49 E I 23 N 33 18 E 1000 O0 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 O0 1100 O0 1200 O0 1300 O0 1400 O0 1499 O0 1599 O0 1699 O0 1799 O0 1899 939.80 O0 1039.80 O0 1139.80 O0 1239.80 O0 1339.80 99 1439.79 99 1539.79 98 1639.78 96 1739.76 93 1839.73 2000 O0 1999 91 1939 71 2100 2200 2300 2400 2500 26OO 2700 2800 29OO 88 2039 81 2139 54 2239 73 2338 98 2436 50 2534 13 2630 35 2726 92 2819 I 2O N 4O 28 E 68 1 30 N 44 39 E 61 3 0 N 65 44 E 34 5 31 N 76 56 E 53 9 10 N 79 21E 78 11 56 N 83 28 E 30 13 32 N 83 55 E 93 16 28 N 82 13 E 15 19 15 N 81 2 E 72 22 5 N 80 11E O0 2099 O0 2199 O0 2299 O0 2398 O0 2496 O0 2594 O0 2691 00. 2786 O0 2879 N 79 30 E N 79 47 E N 79 33 E N 79 4 E N 78 44 E n 79 0 E N 79 8 E n 79 23 E N 79 55 E N 8O 37 E 3000 O0 2971 50 2911.30 25 2 O0 3O6O O0 3148 O0 3234 O0 3316 O0 3396 O0 3472 O0 3545 O0 3615 O0 3682 89 3000.69 28 1 55 3088.35 29 38 23 3174.03 32 34 90 3256.70 35 43 61 3336.41 38 49 92 3412.72 41 34 54 3485.44 44 55 14 3554.94 47 7 O1 3621.81 48 45 ENGINEER' T. WEST 3100 3200 3300 3400 3500 3600 3700 3800 3900 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG ~IN O. O0 O. 03 O. O4 0,. 05 0 15 0 19 0 2O '0 19 0 13 0 02 O, O0 0 10 0 O0 0 11 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 N 0 O0 S 0 O0 S 004 S 0 08 S 0 09 S 0 lOS 0 13 S 022 S 0 34S 000 E 003 E 0 04 E 0 06 E 0 17 E 021E 022E 022E 0 17 E O08E 000 N 0 0 E O3 S 89 11E O4 S 86 9 E 07 S 58 42 E 19 S 66 11E 23 S 66 42 E 24 S 65 23 E 25 S 58 38 E 27 S 37 30 E 35 S 13 6 E 0 O0 -0 09 -0 21 -0 74 -1 47 -1 87 -1 80 -0 84 0 84 2 58 0 O0 0 O0 0 16 0 02 0 O0 0 08 0 70 0 48 0 23 0 O0 0505 064S 0 71 S 0 73 S 0 53 S 0 36 S 0 07 N 1 17 N 2 60 N 4 48 N 0 09 E O02E 00BW 0 62 W 1 40W 1 84W 1 85W 1 06W 0 39 E 1 82 E 0 50 S 10 10 E 64 S 1 38 E 72 S 6 44 W 96 S 4O 26 W 49 S 69 14 W 87 S 78 52 W 85 N 87 42 W 58 N 42 6 W 63 N 8 35 E 84 N 22 7 E 4 28 6 16 9 49 16 61 29 47 69 95 125 161 15 71 78 45 94 17 0 O0 0 77 2 O6 3 23 3 98 1 72 1 76 2 7O 3 39 3 71 6 38 N 8 16 N 10 19 N 12 21N 14 87 N 17 55 N 19 91N 22 96 N 27 33 321E 4 7 14 26 45 67 92 45 N 123 15 N 157 8O E 82 E 69 E 96 E 33 E 32 E 86 E 7.14 N 26 40 E 9.46 N 30 29 E 12.84 N 37 30 E 19 10 N 50 16 E 30 79 N 61 7 E 48 61 N 68 50 E 70 21 N 73 32 E 95 66 N 76 7 E 03 E 126 05 N 77 25 E 80 E 161 24 N 78 8 E 201 30 246 10 294 22 345 75 401 97 462 33 526 93 595 55 667 43 741 78 2.90 1 52 2 45 3 56 2 51 3 58 2 78 1 98 2 85 1 26 40 34 N 197 29 E 201 37 N 78 27 E 48 56 66 77 89 101 114 127 139 42 N 241 99 N 288 58 N 339 42 N 394 09 N 453 34 N 517 16 N 584 10 N 655 65 N 728 34 E 246 70 E 294 34 E 345 51E 4O2 73 E 462 17 E 527 59 E 595 3O E 667 58 E 741 15 N 78 39 E 27 N 78 5O E 8O N 78 54 E O3 N 78 54 E 4O N 78 53 E O0 N 78 55 E 63 N 78 57 E 51 N 79 I E 84 N 79 9 E COMPUTATION DATE- 30-JUL-g3 PAGE 2 ARCO ALASKA, INC. D.S. 3 -36 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 16-JULY-1993 KELLY BUSHING ELEVATION' 60.20 FT ENGINEER' T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET Of MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIkaJTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3747 22 3687 02 49 49 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3811 O0 3876 O0 3942 O0 4007 O0 4071 O0 4134 O0 4196 O0 4258 O0 4320 69 3751 83 3816 30 3882 50 3947 96 4011 53 4074 56 4136 61 4198 56 4260 49 49 39 63 49 7 10 49 10 30 49 32 76 50 28 33 51 45 36 51 30 41 51 50 36 51 54 N 80 57 E 817.58 N 81 43 E 894.00 N 83 2 E 969 8O n 83 29 E 1045 25 N 82 16 E 1120 96 N 81 35 E 1197 36 N 80 57 E 1275 35 N 82 I E 13~3 76 N 83 5 E 1432 O9 N 82 35 E 1510 45 0 83 0 99 0 75 0 26 0 78 2 55 0 37 I 25 I O2 3 O0 151 76 N 803 42 E 817 63 N 79 18 E 163 173 182 191 2O2 214 226 236 40 N 878 45 N 954 22 N 1029 51N 1104 17 N 1180 29 N 1257 O3 N 1334 12 N 1412 245.42 N 1490 96 E 894 17 E 969 24 E 1045 49 E 1120 20 E 1197 26 E 1275 81E 1353 58 E 1432 52 E 1510 O2 N 79 28 E 81 N 79 42 E 25 N 79 58 E 97 N 8O 10 E 39 N 80 17 E 39 N 80 20 E 81 N 80 23 E 18 N 80 31E 59 N 80 39 E 5000 O0 4381 36 4321.16 53 5 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4441 O0 45O2 O0 4563 O0 4623 O0 4681 O0 4741 O0 48O2 O0 4863 O0 4925 69 4381.49 52 24 75 4442.55 52 31 56 4503.36 52 48 11 4562.91 54 5 88 4621.68 53 28 94 4681.74 52 49 59 4742.39 52 33 51 4803.31 52 22 81 4865.61 50 34 N 81 16 E 1589 8O N 80 8 E 1669 N 79 45 E 1748 N 80 39 E 1828 N 8O 58 E 1908 N 79 47 E 1989 N 80 20 E 2069 N 80 47 E 2148 N 81 11E 2228 N 79 57 E 2306 54 73 11 44 33 29 79 O7 28 0 44 2 44 0 78 1 22 0 99 1 69 1 O1 0 33 0 84 0 82 256 91 N 1569 07 E 1589.97 N 80 42 E 269 283 297 3O9 323 337 35O 362 375 53 N 1647 68 N 1725 16 N 1803 92 N 1883 22 N 1963 27 N 2041 27 N 2120 64 N 2198 43 N 2275 82 E 1669.72 N 80 43 E 73 E 1748.89 N 80 40 E 97 E 1828.28 N 80 39 E 28 E 1908.61 N 80 39 E 08 E 1989.51 N 80 39 E 79 E 2069.46 N 80 37 E 23 E 2148.97 N 80 37 E 56 E 2228.26 N 80 38 E 72 E 2306.48 N 80 38 E 6000 O0 4989 45 4929 25 50 32 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5052 64 4992 O0 5114 87 5054 O0 5177 14 5116 OO 5239 33 5179 O0 5302 12 5241 O0 5368 42 5308 O0 5435.46 5375 O0 5502.76 5442 O0 5569.91 5509 44 51 11 67 51 39 94 51 17 13 51 50 92 49 34 22 47 56 26 47 52 56 47 41 71 48 3 N 8O 5 E 2383.42 N 78 52 E 2460 92 N 78 19 E 2539 18 N 78 29 E 2617 40 N 78 18 E 2695 68 N 78 33 E 2773 N 79 9 E 2848 N 79 29 E 2922 N 79 57 E 2996 N 8O 32 E 3070 47 31 51 48 57 0 64 1 44 0 16 0 38 0 67 4 75 1 07 0 55 0 37 0 84 388 76 N 2351 69 E 2383.61 N 80 37 E 402 418 434 449 465 48O 493 506 519 84 N 2427 40 N 2504 63 E 2539 13 N 2581 28 E 2617 86 N 2657 98 E 2695 55 N 2734 20 E 2773 02 N 2807 64 E 2848 73 N 2880.57 E 2922 95 N 2953.35 E 2996 54 N 3026.37 E 3070 91E 2461 10 N 80 35 E 33 N 8O 31E 53 N 80 27 E 78 N 80 24 E 56 N 8O 2O E 38 N 80 18 E 58 N 80 16 E 54 N 80 16 E 64 N 80 16 E 7000.00 5636 49 5576.29 48 25 7100.00 5702 7200.00 5768 7300 O0 5834 7400 O0 5899 7500 O0 5962 7600 O0 6025 7700 O0 6087 7800 O0 6150 7900 O0 6214 62 5642.42 48 47 57 5708.37 48 34 66 5774.46 48 54 70 5839.50 50 6 78 5902.58 51 28 24 5965.04 51 26 54 6027.34 51 20 59 6090.39 50 14 96 6154.76 49 59 N 81 14 E 3145.18 N 82 5 E 3220.15 N 82 49 E 3295.24 N 83 44 E 3370.16 N 82 51 E 3445.95 N 81 6 E 3523.49 N 80 35 E 3601.58 N 80 31 E 3679.79 N 77 51 E 3757.40 N 76 57 E 3833.83 0.73 0.74 0.64 0 83 3 O9 0 35 0 79 0 65 3 35 0 59 531 37 N 3100 04 E 3145.25 N 80 16 E 542 552 56O 569 580 592 605 619 636 25 N 3174 13 N 3248 88 N 3323 31N 3398 57 N 3475 82 N 3552 75 N 3629 82 N 37O6 26 E 3220.24 N 80 18 E 77 E 3295.36 N 80 21 E 31 E 3370.31 N 80 25 E 79 E 3446.14 N 80 29 E 55 E 3523.71 N 80 31 E 69 E 3601.81 N 80 32 E 83 E 3680.03 N 80 32 E 15 E 3757.62 N 80 30 E 91 N 3780.74 E 3834.02 N 80 26 E COMPUTATION DATE' 30-JUL-93 PAGE 3 ARCO ALASKA, INC. D.S. 3 - 36 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 16-JULY-1993 KELLY BUSHING ELEVATION' 60.20 FT ENGINEER' T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR'rl~RE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLrrH FEET DEG/IO0 FEET FEET FEET DEG 8000 O0 6279 25 6219 05 50 2 8100 8200 83O0 8400 850O 8600 8700 8800 8900 O0 6343 O0 6407 O0 6470 O0 6533 O0 6596 O0 6658 O0 6720 O0 6781 O0 6842 38 6283 29 6347 74 6410 94 6473 62 6536 73 6598 25 6660 38 6721 49 6782 18 50 8 09 50 28 54 50 42 74 51 10 42 51 15 53 51 55 05 52 6 18 52 30 29 51 11 N 77 13 E 3910 34 N 77 13 E 3986 99 N 77 16 E 4063 82 N 77 5 E 4141 02 N 76 54 E 4218 42 N 76 48 E 4296 23 N 77 6 E 4374 50 N 77 41 E 4453 26 N 77 33 E 4532 34 N 78 11E 4611.43 0 63 0 19 0 O9 0 58 0 71 0 71 0 74 1 07 0 33 3 74 654 O1 N 3855 41 E 3910 49 N 80 22 E 67O 687 7O5 722 740 758 775 792 8O8 99 N 3930 97 N 4005 13 N 4080 63 N 4156 34 N 4231 15 N 4308 27 N 4385 24 N 4462 96 N 4539 24 E 3987 10 N 80 19 E 25 E 4063 91 N 80 15 E 61E 4141 09 N 80 12 E 11 E 4218 47 N 80 8 E 99 E 4296 26 N 80 5 E 31 E 4374 51 N 80 1 E 27 E 4453.27 N 79 58 E 56 E 4532.34 N 79 56 E 92 E 4611.43 N 79 54 E 9000 O0 6906 05 6845 85 50 28 9100 9200 9300 9400 9500 9600 9700 980O 9900 O0 6969 O0 7031 O0 7091 O0 7151 O0 7210 O0 7269 O0 7328 O0 7389 O0 7450 24 6909 13 6970 73 7031 14 7090 O0 7149 20 7209 96 7288 51 7329 36 7390 04 51 7 93 52 20 53 53 9 94 53 48 8O 54 5 O0 53 15 76 53 9 31 52 42 16 52 6 N 78 19 E 4688 61 N 78 28 E 4766 09 N 79 0 E 4844 61 N 79 16 E 4924 15 N 79 16 E 5004 N 79 16 E 5085 N 79 57 E 5166 N 80 12 E 5246 N 8O 20 E 5325 N 8O 27 E 5405 59 42 O1 19 77 12 0 40 1 30 1 20 0 85 0 37 0 74 0 26 1 58 0 78 0 34 824 58 N 4615 53 E 4688.61 N 79 52 E 84O 855 87O 885 900 915 929 942 955 30 N 4691 64 N 4768 56 N 4846 54 N 4925 64 N 5005 22 N 5084 03 N 5163 50 N 5241 73 N 5319 43 E 4766 09 N 79 S1 E 45 E 4844 59 E 4924 62 E 5004 04 E 5085 30 E 5166 28 E 5246 72 E 5325 96 E 5405 61 N 79 50 E 15 N 79 49 E 59 N 79 48 E 43 N 79 48 E O1 N 79 48 E 19 N 79 48 E 78 N 79 48 E 12 N 79 49 E 10000 OO 7511 TO 7451.50 52 19 10100 10200 10300 10400 10500 10600 10700 lO800 10900 O0 7572 O0 7633 O0 7695 O0 7757 O0 7821 O0 7884 O0 7946 O0 8008 O0 -8069 87 7512.67 52 24 80 7573.60 52 36 39 7635 19 51 24 88 7697 68 50 58 18 7760 98 50 41 26 7824 06 51 11 69 7886 49 51 38 34 7948 14 52 11 31 8009 11 52 38 N 80 45 E 5484 09 N 80 50 E 5563 N 8O 44 E 5642 N 80 17 E 5721 N 8O 9 E 5799 N 79 57 E 5876 N 79 57 E 5954 N 79 47 E 6032 N 79 42 E 6111 N 79 36 E 6190 19 48 25 31 73 32 44 18 44 0 18 0 85 0 66 0 57 1 61 0 54 1 28 0 76 0 49 0 69 968 60 N 5397 88 E 5484 10 N 79 50 E 981 993 1006 1020 1033 1047 1060 1074 1089 28 N 5475 92 N 5554 86 N 5631 08 N 5708 47 N 5785 05 N 5861 82 N 5938 79 N 6015 03 N 6093 97 E 5563 20 N 79 50 E 25 E 5642 48 N 79 51 E 95 E 5721 25 N 79 52 E 89 E 5799 31 N 79 52 E 15 E 5876 73 N 79 52 E ' 54 E 5954.32 N 79 52 E 44 E 6032.44 N 79 52 E 93 E 6111.18 N 79 52 E 89 E 6190.44 N 79 52 E 11000 O0 8129.71 8069 51 53 11 11100 O0 8189.68 8129 11200 O0 8250.08 8189 11300 O0 8311.87 8251 11400 O0 8375.13 8314 11500 O0 8438.74 8378 11600 O0 8503.81 8443 11700 O0 8570.55 8510 11800 O0 8638.54 8578.34 46 57 11900.00 8707.53 8647.33 45 47 48 53 11 88 52 21 67 51 11 93 50 36 54 50 1 61 48 42 35 47 26 N 79 24 E 6270 14 N 79 21E 6350 N 79 28 E 6429 N 79 24 E 6508 N 79 0 E 6585 N 78 1E 6663 N 77 3 E 6738 N 76 30 E 6813 N 75 36 E 6886 N 75 5 E 6958 16 85 47 92 05 92 27 44 58 2 17 0 43 0 90 0 99 0 86 1 67 1 05 2 96 1.44 1.75 1103 61 N 6172 25 E 6270 14 N 79 52 E 1118 1133 1147 1161 1177 1193 1210 1228 1246 37 N 6250 06 N 6329 44 N 6406 89 N 6482 20 N 6558 64 N 6632 71N 6704 37 N 6776 88 N 6846 9O E 635O 23 E 6429 53 E 65O8 62 E 6585 24 E 6663 37 E 6738 85 E 6813 02 E 6886 O0 E 6958 16 N 79 51E 85 N 79 51E 47 N 79 51E 92 N 79 50 E 06 N 79 49 E 92 N 79 48 E 28 N 79 46 E 46 N 79 43 E 63 N 79 41E COMPUTATION DATE: 30-JUL-93 PAGE 4 ARCO ALASKA, INC. D.S. 3 - 36 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 16-JULY-1993 KELLY BUSHING ELEVATION: 60.20 FT ENGTNEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 12000 O0 8778 17 8717 97 44 20 12100 O0 8849 78 8789 58 44 39 12200 O0 8920 22 8860 02 45 55 12300 O0 8988 91 8928 71 47 15 12400 O0 9056 42 8996 22 47 39 12500 O0 9123 78 9063 58 47 39 12569 O0 9170 26 9110 06 47 39 N 76 1E 7029 14 N 76 27 E 7098 82 N 76 16 E 7169 66 n 76 14 E 7242 19 N 76 16 E 7315 80 N 76 16 E 7389 56 N 76 16 E 7440 45 1 .61 0.71 1 .53 1.40 O. O0 O. O0 O. O0 1264 62 N 6914.51 E 7029 21 N 79 38 E 1281 03 N 6982.36 E 7098 90 N 79 36 E 1297 78 N 7051.33 E 7169 77 N 79 34 E 131S 04 N 7121.93 E 7242 32 N 79 32 E 1332 57 N 7193.57 E 7315 96 N 79 30 E 1350 11 N 7265.37 E 7389 75 N 79 28 E 1362 22 N 7314.90 E 7440 66 N 79 27 E COMPUTATION DATE: 30-JUL-93 PAGE 5 ARCO ALASKA, INC. D.S. 3 - 36 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 16-JULY-1993 KELLY BUSHING ELEVATION: 60.20 ET ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGLE_AR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZI~LFFH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 1000 O0 1999 O0 2971 O0 3747 O0 4381 O0 4989 O0 5636 O0 6279 O0 6906 -60 20 O0 939 91 1939 50 2911 22 3687 36 4321 45 4929 49 5576 25 6219 05 6845 0 0 80 0 6 71 1 20 3O 25 2 02 49 49 16 53 5 25 50 32 29 48 25 05 5O 2 85 50 28 N 0 0 E 0.00 S 4 1W 0.00 N 40 28 E 4.28 N 79 30 E 201.30 N 80 57 E 817.58 N 81 16 E 1589.80 N 80 5 E 2~83.42 N 81 14 E 3145.18 N 77 13 E 3910.34 N 78 19 E 4688.61 0 O0 0 O0 0 O0 2 90 0 83 0 44 0 64 0 73 0 63 0 4O 0 O0 N 0 6 4O 151 256 388 531 654 824 0 O0 E 50 S 0 38 N 3 34 N 197 76 N 803 91N 1569 76 N 2351 37 N 3100 O1 n 3855 58 N 4615 0 O0 N 0 0 E 09 E 0 21E 7 29 E 201 42 E 817 07 E 1589 69 E 2383 04 E 3145 41E 3910 53 E 4688 50 S 10 10 E 14 N 26 40 E 37 N 78 27 E 63 N 79 18 E 97 N 80 42 E 61 N 80 37 E 25 N 80 16 E 49 N 80 22 E 61 N 79 52 E 10000.00 7511.70 7451.50 52 19 11000.00 8129.71 8069.51 53 12000.00 8778.17 8717.97 44 20 12569.00 ~ 9170.26 9110.06 47 39 N 80 45 E 5484.09 N 79 24 E 6270.14 N 76 1 E 7029.14 N 76 16 E 7440.45 0.18 2.17 1.61 0. O0 968.60 N 5397.88 E 5484.10 N 79 50 E 1103.61N 6172.25 E 6270.14 N 79 52 E 1264.62 N 6914.51 E 7029.21 N 79 38 E 1362.22 N 7314.90 E 7440.66 N 79 27 E COMPUTATION DATE' 30-JUL-93 PAGE 6 ARCO ALASKA, TNC. D.S. 3 - 36 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY- 16-JULY-1993 KELLY BUSHING ELEVATION. 60.20 FT ENGINEER- T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG ~IN 0 O0 60 20 160 20 260 20 360 20 460 20 560 20 660 20 760 20 860 20 0 O0 60 20 160 20 260 20 36O 2O 460 20 560 20 660 20 760 20 860 20 -60.20 0 0 0.00 0 0 100.00 0 0 200 O0 0 2 300 O0 0 4 400 O0 0 1 500 O0 0 1 600 O0 0 1 700 O0 0 4 800.00 0 5 n 0 0 E N 0 0 E S 44 26 E S 10 13 E S 68 41 E S 68 4 E S 35 57 E S 11 6 W S 32 55 W S35 9W 0 O0 0 O0 0 04 0 04 0 12 0 18 0 20 0 20 0 16 0 O5 0 O0 000 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 18 0 O0 0 O0 N 0 O0 N 0 O0 S 0 02S 0 06 S 0 09 S 0 10 S 0 12S 0 17 S 0 30S 000E 000 E 0 04 E 0 05 E 0 13 E 0 20E 022E 0 22 E 0 20 E 0 10 E 0 O0 N 0 0 E O0 N 0 0 E 04 S 86 33 E 05 S 69 1E 15 S 65 8 E 22 S 66 51E 24 S 65 44 E 25 S 61 56 E 26 S 49 39 E 31 S 18 57 E 960 20 1060 1160 1260 1360 1460 1560 1660 1760 1860 96O 20 20 1060 20 1160 20 1260 20 1360 21 1460 21 1560 21 1660 23 1760 25 1860 900 O0 20 1000 O0 20 1100 O0 20 1200 O0 2O 1300 20 1400 20 1500 20 1600 20 1700 20 1800 0 7 0 5 0 4 0 22 O0 0 29 O0 0 12 O0 0 17 O0 0 51 O0 1 11 O0 ! 23 S 10 27 E S 35 32 W S50 8W S 89 19 W N74 2W N 66 35 W N 2 5 W N 37 10 E N 46 2O E N 35 9 E 0 O1 -0 05 -0 15 -0 47 -1 18 -1 79 -1 91 -1 35 0 14 1 91 0 O0 0 O0 0 O0 0 29 0 O0 0 34 0 58 0 76 0 O1 0 11 042S 0 59 S 0 68S 0 75S 0 62S 0 41 S 0 19 S 0 68 N 200N 3 69 N 0 08 E 0 06 E 0 03W 0 34 W 1 09W 1 75W 1 90W 1 49 W 0 22 W 1 28 E 0 43 S 11 14 E 59 S 5 29 E 68 S 2 3O W 83 S 24 22 W 25 S 6O 17 W 79 S 76 42 W 91 S 84 2O W 63 N 65 33 W O1 N 6 11W 90 N 19 12 E 1960 28 1960 20 1900.00 2060 2160 2260 2361 2462 2564 2667 2772 2878 1 2O 31 2060 35 2160 51 2260 05 2360 46 246O 75 2560 84 2660 38. 2760 77 2860 20 2000.00 1 21 20 2100.00 2 11 20 22O0 O0 4 18 20 230O O0 7 32 20 2400 O0 11 7 20 2500 O0 13 1 20 2600 O0 15 29 20 2700 O0 18 20 20 2800 O0 21 23 N 36 29 E N42 6 E N 56 46 E N75 4 E N 77 33 E N 82 14 E N84 1 E N 82 56 E N 81 18 E N 80 30 E 3 58 5 38 7 80 13 26 23 49 4O 21 61 69 86 63 117 05 153 31 0 54 0 oo 1 72 2 66 4 51 2 46 1 21 3 47 3 31 2 99 5.66 N 7.45 N 9.34 N 11 41 N 13 74 N 16 63 N 19 05 N 21 82 N 26 31 2 62E 4 6 11 21 37 59 84 08 N 114 83 N 150 13 E 26 E 44 E 41 E 88 E 26 E 10 E 6.24 N 24 5O E 8.52 N 29 2 E 11.24 N 33 49 E 15.16 N 45 4 E 25.44 N 57 19 E 41.37 N 66 18 E' 62.25 N 72 11E 86.89 N 75 27 E 24 E 117.18 N 77 8 E 05 E 153.39 N 78 1 E 2987 52. 2960 20 2900 O0 24 40 3O99 3213 3331 3453 3583 3720 3867 4020 4174 22 306O 20 3000 42 3160 20 3100 O0 3260 20 3200 80 .3360 20 3300 07 3460 20 3400 67 3560 20 3500 06 3660.20 3600 13 3760.20 3700 57 3860.20 3800 O0 28 0 O0 29 58 O0 33 39 O0 37 10 O0 41 8 O0 45 19 O0 48 19 O0 49 58 O0 49 11 N 79 31 E N 79 47 E N 79 27 E N 78 56 E N 78 52 E N 79 7 E N 79 29 E N 80 24 E N 80 59 E N 82 46 E 196 02 245 73 300 88 362 68 433 89 515 76 610 21 717 10 832 97 950 59 2 62 1 56 2 79 3 46 3 32 2 42 1 gl 1 49 0 57 0 97 39.38 N 192 09 E 196 08 N 78 25 E 48.35 N 240 58.20 N 295 69.81N 355 83 64 N 425 99 24 N 5O6 116 85 N 599 135 58 N 7O4 154 18 N 818 171 07 N 935 98 E 245 25 E 300 95 E 362 82 E 433 20 E 515 O0 E 610 23 E 717 62 E 833 08 E 950 79 N 78 39 E 93 N 78 51E 74 N 78 54 E 96 N 78 53 E 84 N 78 55 E 29 N 78 58 E 16 N 79 6 E O1 N 79 20 E 60 N 79 38 E Arco ALASKA, INC. D.S. 3 - 36 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE- 30-JUL-93 PAGE 7 DATE OF SURVEY- 16-JULY-1993 KELLY BUSHING ELEVATION- 60.20 FT ENGINEER' T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4327 38 3960 20 3900.00 49 13 4481 4641 4802 4964 5130 5294 5463 5630 5794 62 4060 46 4160 58 4260 89 4360 28 4460 45 4560 36 4660 19 4760 59 4860 20 4000.00 50 10 20 4100.00 51 43 20 4200.00 51 50 20 4300.00 52 47 20 4400.00 52 13 20 4500.00 52 45 20 4600.00 54 1 20 4700.00 52 45 20 4800.00 52 26 N 83 19 E 1065 94 N 81 48 E 1183 N 81 14 E 1307 N 83 7 E 1434 N 81 22 E 1561 N 79 38 E 1693 N 80 37 E 1823 N 80 27 E 1959 N 80 33 E 2093 N 81 12 E 2223 24 90 11 79 51 70 79 33 79 .83 .82 .84 .04 .43 · 03 .17 .40 .06 .61 184 61 N1049 83 E 1065 94 N 80 2 E 200 219 236 252 273 296 318 341 361 15 N 1166 33 N 1289 37 N 1414 68 N 1541 73 N 1671 43 N 1799 13 N 1933 27 N 2065 98 N 2194 22 E 1183 27 N 80 16 E 42 E 1307 94 N 80 21 E 59 E 1434 20 N 80 31 E 38 E 1561 95 N 80 41E 41E 1693 68 N 80 42 E 61 E 1823 86 N 80 39 E 98 E 1959 97 N 80 40 E 50 E 2093.50 N 80 37 E 33 E 2223.98 N 80 38 e 5954 05 4960.20 490000 50 25 6112 6272 6433 6587 6736 6885 7035 7187 7338 07 5060.20 5000.00 51 18 89 5160.20 5100.00 51 23 71 5260.20 5200.00 51 38 70 5360.20 5300.00 48 81 5460.20 5400.00 47 42 50 5560.20 5500.00 47 58 78 5660.20 5600.00 48 33 34 5760.20 5700.00 48 37 99 5860.20 5800.00 49 15 N 80 5 E 2347 97 N 78 44 E 247O N 78 28 E 2596 N 78 18 E 2722 N 79 5 E 2839 N 79 37 E 2949 N 8O 26 E 3059 N 81 32 E 3171 N 82 44 E 3285 N 83 53 E 3399 32 24 13 17 77 8O 96 76 54 0 ,49 1 32 0 59 1 27 0 89 0 68 0 73 0 71 0 65 1 26 382 68 N 2316 78 E 2348.17 N 80 37 E 404 429 455 478 498 517 535 55O 564 66 N 2437 89 N 256O 23 N 2683 29 N 2798 68 N 2907 75 N 3015 38 N 3126 93 N 3239 05 N 3352 14 E 2470 50 N 80 34 E 54 E 2596 90 E 2722 67 E 2839 38 E 2949 75 E 3059 53 E 3172 35 E 3285 59 E 3399 37 N 80 28 E 24 N 8O 22 E 25 N 80 18 E 83 N 80 16 E 87 N 8O 15 E 04 N 80 17 E 87 n 80 21E 71 N 80 27 E 7495 86 5960 20 5900 O0 51 26 7656 7814 7970 8126 8283 8441 8602 8765 8928 15 6060 98 6160 37 6260 25 6360 36 6460 90 6560 38 6660 26 6760 05 6860 20 6000 O0 51 31 20 6100 O0 50 3 20 6200 O0 49 57 20 6300 O0 50 11 2Q 6400 O0 50 44 20 6500.00 51 12 20 6600.00 51 56 20 6700.00 52 22 20 6800.00 50 30 N 81 6 E 3520 26 N 80 27 E 3645 N 77 25 E 3768 N 77 10 E 3887 N 77 14 E 4007 N 77 7 E 4128 N 76 53 E 4251 N 77 7 E 4376 N 77 35 E 45O4 N 78 20 E 4633 51 88 67 12 16 03 37 82 18 0 48 0 32 2 26 0 20 0 21 0 67 0 54 0 75 0 61 1 31 580 07 N 3472.36 E 3520 48 N 80 31 E 600 09 N 3596.01E 3645 622 30 N 3717.37 E 3769 648 98 N 3833 28 E 3887 675 44 N 3949 89 E 4007 702 26 N 4068 06 E 4128 730.03 N 4187 91 E 4251 758.57 N 4310 14 E 4376 786.31 N 4435 67 E 4504 813.39 N 4561 22 E 4633 74 N 80 32 E lO N 80 30 E 82 N 8O 23 E 23 N 80 18 E 23 N 8O 12 E' 06 N 80 7 E 38 N 8O I E 82 N 79 57 E 18 N 79 53 E 9085 62 6960 20 6900.00 51 1 9247 9415 9584 9751 9916 10079 10243 10403 10561 76 7060 20 7000.00 52 40 35 7160 20 7100.00 53 51 93 7260 20 7200.00 53 20 72 7360 20 7300.00 52 36 02 7460 20 7400.00 52 6 27 7560 20 7500.00 52 16 24 7660.20 7600.00 52 6 67 7760.20 7700.00 50 56 74 7860.20 7800.00 50 55 N 78 24 E 4754 9O N 79 13 E 4882 N 79 15 E 5016 N 79 52 E 5153 N 80 16 E 5287 N 80 30 E 5417 N 80 47 E 5546 N 80 37 E 5676 N 80 8 E 5802 N 79 55 E 5924 5O 98 92 4O 76 78 72 16 58 1 O7 0 56 0 43 0 88 0 28 0 45 0 93 2 13 1 46 0 34 838.05 N 4680 47 E 4754 90 N 79 51 E 862 8O N 4805 887 913 936 957 978 999 1020 1041 84 N 4937 09 N 5072 02 N 5203 82 N 5332 66 N 5459 47 N 5588 57 N 5711 84 N 5832 67 E 4882 80 E 5016 39 E 5153 90 E 5287 42 E 5417 76 E 5546 04 E 5676 70 E 5802 25 E 5924 50 N 79 49 E 98 N 79 48 E 92 N 79 48 E 41 N 79 48 E 76 N 79 49 E 78 N 79 50 E 72 N 79 52 E 16 N 79 52 E 58 N 79 52 E ARCO ALASKA, INC. D.S. 3 - 36 PRUDHOE BaY NORTH SLOPE, ALASKA COMPUTATION DATE: 30-JUL-93 PAGE 8 DATE OF SURVEY: 16-JULY-1993 KELLY BUSHING ELEVATION: 60.20 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 10721 80 7960 20 7900.00 51 48 10884 11050 11216 11376 11533 11684 11831 11974 12114 99 8060 84 8160 56 8260 50 8360 26 8460 67 8560 63 8660 79 8760 67 8860 20 8000.00 52 34 20 8100.00 53 4 20 8200.00 52 12 20 8300.00 50 32 20 8400.00 49 38 20 8500.00 47 35 20 8600.00 46 35 20 8700.00 44 42 20 8800.00 44 46 12257.89 8960.20 8900.00 46 45 12405.61 9060.20 9000.00 47 39 12554.06 9160.20 9100.00 47 39 12569.00 9170.26 9110.06 47 39 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN N 79 48 E 6049 55 N 79 39 E 6178 N 79 21E 6310 N 79 28 E 6442 N 79 10 E 6567 N 77 39 E 6688 N 76 34 E 6801 N 75 13 E 6909 N 75 42 E 7011 N 76 25 E 7109 51 82 96 77 45 98 41 51 12 N 76 16 E 7211.45 N 76 16 E 7319.94 N 76 16 E 7429.43 N 76 16 E 7440.45 0 76 0 44 1 34 0 99 0 85 1 24 2 96 1 51 1 73 0 9O 1.41 0. O0 0. O0 O. O0 1063.86 N 5955 28 E 6049 55 N 79 52 E 1086.88 N 6082 1111.10 N 6212 1135.46 N 6342 1158.45 N 6464 1182.56 N 6583 1208.08 N 6693 1234.17 N 6798 1260.30 N 6897 1283.45 N 6992 17 E 6178 24 E 6310 12 E 6442 80 E 6567 08 E 6688 85 E 6801 33 E 6909 37 E 7011 40 E 7109 51 N 79 52 E 82 N 79 52 E 96 N 79 51E 77 N 79 5O E 45 N 79 49 E 99 N 79 46 E 44 N 79 43 E 56 N 79 39 E 21 N 79 36 E 1307.72 N 7092.00 E 7211.57 N 79 33 E 1333.55 N 7197.60 E 7320.10 N 79 30 E 1359.60 N 7304.18 E 7429.64 N 79 27 E 1362.22 N 7314.90 E 7440.66 N 79 27 E COMPUTATION DATE' 30-JUL-93 PAGE 9 ARCO ALASKA, INC. D.S. 3 - 36 PRUDHOE BaY NORTH SLOPE, ALASKA MARKER 7" LINER TOP GCT LAST READING 7" LINER BOTTOM TD DATE OF SURVEY' 16-JULY-1993 KELLY BUSHING ELEVATION' 60.20 FT ENGINEER' T. WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 906' FSL & 4381' FEL, SEC11 TION R15E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 11730.00 8590.84 8530.64 12342.30 9017.55 8957.35 12569.00 9170.26 9110.06 12569.00 9170,26 9110.06 1215.91 N 6726.32 E 1322.44 N 7152.15 E 1362.22 N 7314.90 E 1362.22 N 7314.90 E ARCO ALASKA, INC. D.S. 3 - 36 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER 7" LINER TOP 7" LINER BOTTOM ID COMPUTATION DATE: 30-JUL-93 PAGE 10 DATE OF SURVEY: 16-JULY-1993 KELLY BUSHING ELEVATION: 60.20 FT ENGINEER: T. WEST ************ STRATIGRAPHIC SUMMARY ****~*~*~ SURFACE LOCATION = 906' FSL & 4381' FEL, SECll TION R15E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11730.00 8590.84 8530.64 1215.91N 6726.32 E 12569.00 9170.26 9110.06 1362.22 N 7314.90 E 12569.00 9170.26 9110.06 1362.22 N 7314.90 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12569. O0 9170.26 9110.06 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7440.68 N 79 27 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD PRUDHOE BAY WELL D.S. 3 - 36 COUNTRY USA RUN ONE DATE LOGGED 16 - JUL - 93 DEPTH UNIT FEET REFERENCE 93313 All interpretations are oplntons based on Inferences from electrical or other msasurement~ and wa cannot, and do not guarantee the accuracy or correctness of any Interpretations. and we shall not. except in the case of ~ oss or wlffull negligence on our part. be liable or responsible for any loss. costs, damages or expenses Incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees, These Interpretations are also subject to our General Terms and Conditions as set out In our current price Schedule. k'ELL: D.S. 3-36 ' ~ (906' FSL, 4381' FEL, SEC 11, TION, R15E) HORIZONTAL PROdECTION NORTH 8000 REF ~33"13 6000 4000 2000 -2000 -4000 -6000 SOUTH -8000 -4000 -2000 0 2000 SCALE = I / 2000 IN/FT 4000 6000 8000 10000 12000 WEST EAST il/ELL- D.S. 3-36 (906' FSL, 4381' FIlL, SEC 1~, TION, R15E) VERTICAL'PROdECT]ON 260.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 !:~;;.;.*! .... !..!-..!...~ ...... F..?.!...! :::: ....... :::: :::: :,::: ::::,:::: :::: :::: :::: :::: :::: !i!! !!!i .... !**!'*T*! !"'!~! !'!*! ii!"! '~i[~ ;~'!! !~!!* !!~i!~! ~! ilii :::: :::: :::: :::: ::;: :::: :::: :::: :::: !!~-, i-!.!..-i ...... !...i...i-i ..... i-i.-?i .*!..-i..-!...! ..... !.-!*-*i--! ...... !*-.ifi .... 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'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"!' 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I ;..; 80.00 PROJECTION ON VERTICAL PLANE 260.00 80.00 SCALED tN VERTICAL DEPTHS HOI::IIZ SCALE - 1 / 2000 IN/PT ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS · 1_1B~ 1~'°~6_20.93 1-16 ~'~;,~ 6-25-93 1-22 iv ~.l 6-29-93 1-30 ~;~'~ ~ 6 29 93 3-30 ~~ 6-23-93 3-31 ~-0~6-23-93 3-33 ~'¥-1/o 6-29-93 3-36 ~-l~ 6-28-93 4-37 ~/~7 6-20-93 4-40 ~ I~ {~6-20-93 5-3A ~t 6-18-93 5-26 ~ ~-~ 6-25-93 6-4 ?~- ~ z~-6-26-93 6-13 ~ -3~ 6-25-93 9-50 ~-~ 6-26-93 12-26e~ 6-22-93- 13-1~~ 6-27-93 13-14 ~-~ 6-28-93 13-20 ~ -~? 6-19-93 16-12 ~l~ 6-21-93 17-20 ~-~6-26-93 '~.~L%AGI-6~ ~ ~.o~ 4-25-93 AGI-8 ~ ~ - ~ ~ 6-19-93' *** AGI-10 ~$~ 6-18-93 *** AGI-10~3 6-18-93 Prod Profile Run 1, 5" Sch Perf Record Run 1, 5" Sch Production Log Run 1, 5" Sch Leak Detect R~m 1, 5" Sch Perf Record R-~ 1, 5" Sch Leak Detect R.n 1, 2"&5" Sch Bridge Plug Setting Run 1, 5" Sch Completion Record Run 1, 5" Sch Perf Record Run 1, 5" Sch Dual ~urst TDTP ~orax) Run 1, 5" Sch Completion Record Run 1, 5" Sch SBT/GR/CCL R~m 1, 5" Atlas TDTP (Borax) R-n 1, 5" Sch Production Log R-n 1.5" Sch Perf Record R.n 1, 5" Sch Production LOg Run 1, 1"&5" Sch ~Production LOg R-n 1, 2"&5" Sch CNL Run 1, 5" Sch Leak Detect Run 1, 2" Sch Leak Detect Run 1, 2" Sch Plug Depth Record Run 1, 5" $ch Prod Profile R.n 1, 1"&5" Sch Production LOg Run 1, 5" Sch ;;~..AcousticCBT Run 1, 5" Atlas Perf Record Run 1, 5" Sch GR/CCL Run 1, 5" Sch Perf Record R.n 1, 5" Sch Please sign and return the attached .c~p~ as receipt of data. Have A Nice Day~/~ ' / Sonya Wallace ATO-1529 APPROVED_~~ff_ Trans# 93074 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA The correct name for this log is 1-1B. Tb~s is a revised log, please discard previous copy received. The correct APl# for AGI-10 is 50-029-22353-00. t £CEIVEo # 'JUL 3 0 1993 # CLINT CHAPMAN ## EXXONMosIL ~aska 011 & ~as Cons. Com~i~lo. An*hor~o ARCO Alasks. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: ~__~_~~1-14 14-22A 8-9A LS-16A 6-9-93 5-6-93 Static Pressure Run 1, 5" 5-8-93 Prod Profile Run 1, 5" 5-10-93 Production Run 1, 5" 5-11-93 CBT/New TBG/Jewelry Run 1, 5" 5-10-93 Leak Detect/Spin/Temp/Press Run 1, 2' & 5" 5-4-93 USIT (Cement & Corrosion) (Color) Run 1. 5" 5-3-93 InJ Proflle/Spin/Temp/Press Run 1, 5" 5-2-93 InJ Profile/PITS Run 1, 5" 4-24-93 Leak Detect/Spin/Temp/Press Run 2, 5" 5-7-93 D-_~! Burst/TDT-P (Borax) Run 1. 5" 5-6-93 Vertilog Run 1. 5" 5-8-93 GR/Collar Run 1. 5" 5-6-93 Perf Record Run 1, 5" 5-7-93 GR/CCL l~__m 1, 5" 5-10-93 CNL Run 1, 5" 5-11-93 Leak Detect Run 1, 2' & 5" 5-7-93 Peri' Record Run 1, 5" 5-9-93 TDT-P (Borax) Run 1, ii" 5-3-93 Leak Detect/Spin/T_~mp/Press Run 1, 5" 5-3-93 Perf Record Run 1, 5" 5-4-93 Production Run 1, 5" 5-5-93 CCL/PerfRecord Run 1, 5" 5-8-93 sHr/G~~ l~_m 1, 5" Run 1, 5" Run 1. 5" l~m 1. 2' & 5" a 7~~I4 5-?-93 GR/C(I, (Color) ~~_~.AGI-5 5-1~93 GR/~ (~l~) ~~I4 $1~93 GR/~ (~l~) q~/~ ~EI4 ~93 ~/G~~ ~e~e s~ ~d retm ~e at~ched copy ~ receipt of ~ RECEIVED BY_~~~~ Have A Nice Day! Sonya Wallace ~ ~''~'~ APPROVED AT0-1529 ~d. ~_ C/~.~S~ 9306~ ..... ~ C~~ON "~ ?~. PB ~~ ~ CLOT C~~ '"~. ~ BPX ~ E~ON ~ MOB~ # STATE OF ALAS~ Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Sch Sch Sch Atlas MEMORANDUM ALASKA OIL AND GAS CONSERVATION COMMISSION STATE OF ALASKA to: David Johnsto~ date: Commissione~..~" file: thru: Blair E Wondzell ~~ subject: Petr Insp Supervisor from: ~'~n Spaulding Petr Inspector May 7, 1993 041693,doc BOP Test - Nabors 28E Prudhoe Bay Unit ARCO Well 3-36 PTD ~93~t9' Friday, April 16, 1993: I witnessed a BOP test on Nabors Rig 28E, Arco PBU well 3-36. I recieved short notice on this test as the bit had run out. The rig was quite clean and the location was well layed out with good access. Summary: I witnessed the BOP test on Nabors 28E, Arco PBU well 3-36; test time 3.5 hours, zero failures. attachments STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg.: ~' Workover: Drlg Contractor: /[//,~'~'o P- 5 Operator: ,z~-~d.. ~ Well Name:... ~,~,U. ..~ - ,~/~ Casing Size: / $ 5/~ Set (~ Test: Initial~ Weekly DATE: Rig No. 03.8 ~ PTD # c~ ~ _ ! ~ Rig Ph.# Rep. ~~ ~ ~A~ Rep. ~~~- ~ Feet Location: Sec. /~ T. /~ R. Other Test Well Sign V ¢ .5 Drl. Rig ~oo,~ P/F Alarm ,, MISC. INSPECTIONS: Location Gen.: .,~ o ~ Housekeeping: ~ (Gen) Reserve Pit ~4 BOP STACK: Qua. Ann. Preventer Pipe Rams Blind Rams / Chk/Ln Valves ! HCR Valves Kill Line Valves I' Check Valve Test Pressure MUD SYSTEM: Light Tdp Tank ~ ~, , Pit Level Indicators ../ , Flow Indicator ~ Gas Detectors ~ FLOOR SAFETY VALVES: Quan. Pressure P/F UpperKelly [ J~/.3~e {;;;, J LowerKelly / !~/~-~o~ ! ? Ball Type / 1,70°/5oo ~ ! R Inside BOP / 0! P, CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure / 200 psi Attained After Closure minutes_2 System Pressure Attained / minutes ...~, Blind Switch Covers: Master: Nitgn. BU's: ' ~ ~'. , ~2../~ ~ Psig. Number-of FailUres '-~' 'T~t 'Time"' '""~ '"~HO'~irS """~'u~'b~: ofvai~es'~ie'd'"~'~ .... '~'e'p'~ii:'~: 'R~i~i~'~'r~'t"(~ i~';;ii'~i .... Equipment shall be made within ~ days. Notify the Inspector on duty and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax NO: 275-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector 'STATE WIT~'SS REQUIRED? YESv//' NO 24 HOUR NOTICE GIVEN YES NO ,, Waived By: ~ W~tnessed By: ~.~ FI-021 L.XLT Rev. 1/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO EN~IP_.~~E FINALS 3-18A 3- SA 3- SA I4 1-6 4-25-93 8STVD Run 1, r'&2- 4-25-93 DLL/MLL/GR/SP/Cal · Run 1, 2"&5" 4-25-93 BHCA/GR Run 1, 2'&5' 4-25-93 CNL/GR/CCL Run 1, 4-25-93 Z-DEN/CNL/GR/Cal Run 1, 2'&5" 4-25-93 BH Profile Run 1, 4-25-93 Dielectric/GR Run 1, 4-25-93 Spectmlog Run 1, 4-22-93 DLL/MSFL Color Run 1, 2'&~' 4-22-93 BHCS/GR Color Run 1, :~'&~' 4-22-93 CNL/GR Color Run 1, 2'&~' 4-25-93 DLL ~/!~.T-/SP/GR Run 1, 2'&l~' 4-25-93 BHCA/GR Run 1, ~'&t~' 4-25-93 BH Profile Run 1, 4-25-93 AcouStic CBT Run 1, .. .... Please sign and return the attached copy as receipt of data. R E CE IV ED B ¥__.~~~,~__~ Have A Nice Day! RECEIVED Sonya Wallace ATO-1529 0 1993 APPROVED__~_~ Trans# 93057 Naska 011 & Gas Cons. Commission Anchorage # CENTRAL FILES # CHEVRON #D&M # CLINT CHAPMAN # EXXON # MOBIL Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas 8ch 8ch Atlas Atlas Atlas Atlas # PHILLIPS # PB WELL FILES R&D # BPX # STATE OF ALASKA CONSERVATION CO~IMISSION ALASKA OIL AND GAS ~ 300, PORCUPINE DRIVE ' ~ ^.c.o.^eE,^L^S~ .,O.E: TELECOPY: (9~ 2~-7542 February 5, 1993 Michael Zanghi, Drlg Engr Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 3-36 ARCO Alaska, Inc. Permit No. 93-19 Sur. Loc. 906'NSL, 4381'WEL, Section 11, T10N, R15E, UM Btmnhole Loc. 2223'NSL, 2283'WEL, Section 12, T10N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~nston ~ - -'"' Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc. Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. {~ p,inled on recycled paper b y C. I STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION COMMi'SSION PERMIT TO DRILL 2O AAC 25. OO5 a. Type of work Drill [] Redrill Re-Entry [] DeepenI-II Service [-I Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE =65' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28327 ¢. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 AAC 25.o25) 906' NSL, 4381' WEL, SEC. 11, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2122' NSL, 2904' WEL, SEC 12, TION, R15E DS 3-36 U-630610 At total depth 9. Approximate spud date Amount 2223' NSL, 2283' WEL, SEC. 12, TION, R15E 2/15/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line . . ADL 28332-2223'Tee[ DS3-11-50'@ 2900' feet 2560 12884' MD/9191' TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 22.oofeet Maximum hole angle 54.2' o Maximum surface 2800psig At total depth (TVD) 8800'/3600pstg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5~ H-40 Weld 80' 31' 31' 111' 111' 11yds Arcticset 16" 13-3/8" 68# K55/L.80 BTC 3771' 31' 31' 3802' 3760' 2894 cu ft CS 111/460 cu ft "G" 12-1/4" 9-5/8" 47# L-80 NSCC 12080' 31' 31' 12111' 8744' 1249 cu ft "G"/502 cu fl "G" 8-1/2" 7" 26# 13CR80 NSCC 923' 11961' 8657' 12884' 9191' 250 cu ft Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth (~tornUdC3cUtro;~' R E C E IV ~ D Surface Intermediate ,~ ~:. ~ ~,,,,~ Production ,, ~'i~ Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l"~ Drilling fluid pro, ram [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby cartify that the folegoing is true and correct to the best of my knowledge Si~lned~'=~ /~~ TitleDriliin~TEn~tineerSupervisor ~ ,_/x Commission Use Only Permit Number IAPI number IApproval date See cover letter ,c~_/~ [50-~?'- z...z,$ ~ [ ~---~'-'.-__~ .~ for other requirements Conditions of approval Samples required [] Yes ,[~ No Mud log requir.ed [] Y~s .~ No Hydrogen sulfide measures I-I Yes ~_ No Directional survey requ~recl ,~ Yes [] No Required working pressure for BOPE [] 2M; CI3M; 1~5M; F'I10M; 1'-115M"; Other: Origina~ S~gnod By by order of Approved by David Yr. johnston Commissioner ,ne commission Date~/_~-"'/. Form 10-401 Rev. 12-1-85 Submit in triplicate PROPOSED DRILLING AND COMPLETION PROGRAM DS 3-36 Procedure , MIRU drilling rig. N/U diverter and function test same. Drill 16" hole.to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5,000 psi. , PU 12_-1/4" BHA and RIH. Test casing to 2_,500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. 4. Drill intermediate hole to intermediate casing point. 5~ MU and run 9-5/8 casing string and cement as per well plan. Bump cementing plug with mud. o So RIH and drill 8-1/2" hole through reservoir to TD. RU and run e-line logs. MU 7" liner on 5" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from wellbore. POOH. 9. MU casing scraper & clean out 7" liner. 10. Run 7" x 5-1/Z", 13Cr tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and tubing annulus to 3500 psi. 11. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: , Maximum'Anticipated '~?~-:~.. Surface PreSsure: "~ '"-: Planned Completion Fluid: Notes: 3600 psi @ 8800' TVD SS 2800 psi 8.6 ppg filtered sea water ,. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. ~" b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). .c. Based on previous logs on DS 3, no potential productive zones are anticipated above the Sadlerochit target d. No potential hazardous levels of H2S are anticipated in this well. WELLNAME' DS 3-36 SURFACE LOCATION TARGET LOCATION TD LOCATION 906' FSL 4381' FEL Sll T10N R15E 2122' FSL 2904' FEL S12 T10N R15E 2223' FSL 2283' FEL S12 T10N R15E ESTIMATED START DATE: ESTIMATED DAYS TO COMPLETE: 15 FEB 93 22 days (18 drilling & 4 to complete) CONTRACTOR' NABORS ALASKA DRILLING RIG #18E MAX ANGLE: KOP: BUILD RATE: SECTION COURSE: KB ELEVATION: 54.7° 2700' MD/TVD 2.5°/100, N79.88E 65' ITEM TVD (BKB) MD (BKB), MIlD WI' (PPG) 20" Conductor 13 3.8" shoe (@T5 marker) k15 k12 kl0 k5 Top of 7" Liner Hanger Top of Sadlerochit 9-5/8" shoe Target Top Oil Water Contact HOT.~ , . , Original Oil Water Contact Total depth (7" liner shoe) LOGGING PROGRAM · 8O' 111' 8.5 3760' 3802' 9.5 4924' 5500' 9.0 7027' 9139' 9.7 7567' 10074' 9.7 8168' 11114' 9.7 8657' 11961' 9.7 8744' _+35' 12111' 9.7 8744' _+35' 12111' 9.7 8744 _+35' 12111' 9.0 9034' _+15' 12613' 9.0 9054' _+15' 12648' 9.0 9104' _+15' 12734' 9.0 9191' _+30' 12884' 9.0 -9.7 - 10.0 - 10.0 - 10.0 - 10.0 - 10.0 - 10.0 - 9.5 -9.5 - 9.5 - 9.5 -9.5 '" OPEN HOLE: 12-1/4" HOLE' none 8-1/2" HOLE: GR/DIL/SDN/CNT CASED HOLE A GCT gyro will be run after rig release. ANNULAR INJECTION Waste fluids associated with the drilling process will be injected down the DS 3- 35 casing annulus and/or injected at the central CC-2A injection facility. Call ARCO WIRELINE for testing nearby wells and to check for open annulus. FREEZE PROTECTION The 5-1/2" X 7" tubing along with the 5-1/2" X 7" annulus will be freeze protected by evacuating the fluids via gas lifting or diesel thru the top GLM at 3000' TVD. Dry crude needs to be injected down the 13-3/8" x 9-5/8" annulus for freeze protection. DS 3-36 MUD PROGRAM The mud program for this well shall follow the new Mud Policy. The following are mud parameters identified for the surface and intermediate hole sections in DS 3-36. MUD SPECIFICATIONS- SURFACE HOLE Mud Weight Funnel Viscosity YP 10 sec Gel 10 min Gel pH APl Fluid loss Hardness Surface:, Casing ppg 8.5- 9.5 8.5- 9.0 sec/qt ~300 < 1 oo Ibs/100ft2 40 - 60 20 - 40 lbs/100ft2 30 - 60 15 - 20 Ibs/100ft2 60 - 80 20 - 30 - 9-10 9-10 mi/30 min 15-25 15-25 mg/I < 200 <200 MUD SPECIFICATIONS:-, INTERMEDIATE/PRODUCTION HOL. E Surface casing shoe to Top 'K' shale (,,,6000- 7000'): Mud Weight ppg 9.5 - 10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/100ft2 5 - 10 10 min Gel Ibs/100ft2 .r 10- 20 APl Fluid Loss mi/30 min <15 pH -- 9.5 - 10.0 Hardness mg/I < 200 Top 'K' shale to Section TD. Mud Weight ppg 9.5 - 10.5 Yield Point "Ibs/100ft2 10 - 20 10 sec Gel lbs/100ft2 5 - 10 10 rain Gel lbs/100ft2 15 - 25 APl Fluid loss mi/30 rain 6.0 - 8.0 pH -- 9.5 - 10.0 Hardness mg/Itr < 200 For more detailed information refer to the Prudhoe Bay Drilling Mud Policy that resides in DRILLING VOLUME #1 (file server) under the MUD POLICY folder. DS 3-36 Cement Calculations 13-3/8" CASING Measured Depth: Basis: Total Cement Vol: Lead Slurry Vol: Tail Slurry Vol: 3802' 2 X Annular volume 3354 (cu ft) 2894 (cuft) 1508 Sx Cold Set II! @ 1.92 Cu ft/Sk 460 (cuft) 400 Sx Class G cement @ 1.15 Cu ft/Sk Top job if no returns to surface: 250 sxs Cold Set II @ 0.96 cf/sx 9-5/8" CASING Measured Depth: Basis: 7" LIN Total Cement Vol: Lead Slurry Vol: Tail Slurry Vol: ER Measured Depth: Basis: Total Cement Vol: 12111' Tail: 1000' MD above shoe w/50% excess Lead: from 1000' MD above to 300' MD above top of Ugnu 1751 (cu ft) 1249 (cu ft) 520 Sx Class G @ 2.40 Cu ft/Sk 502 (cuft) 440 Sx Class G @ 1.14 Cu ft/Sk 12884' 8 1/2" X 7" annulus volume w/30 % excess + 7" casing capacity below landing collar + 150' of liner lap + 200' of cement on top of 7" liner in the 9 5/8" casing. 250 (cuft) 212 Sx Class G @ 1.18 Cuft/Sk Casing Design CASING SIZE BURST COLLAPSE TENSION TOP BTM LENGTH (PSI) (PSI) (LBF) (BKB) (BKB) (FT) 13 3/8" 5020 2260 1069000 31 3802 3771 9-5/8" 6870 4750 1086000 31 12111 12080 7" 7240 5410 604000 11961 12884 923 Set 13 3/8" surface casing shoe at top of T5 formation, set 9 5/8" production casing shoe at top of Sadlerochit, and set 7" production liner shoe at 150'MD below OOWC. DS 3-36 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1 950 L-80 5020 2260 PBYS (#) TJYS (#) 1069000 1300000 1556000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) Si PRESSURE 1 4 3760 2737 Burst S.F. 1.26 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3760 1857 Collapse S.F. 1.22 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (Ff') Mud Wt. (ppg) String Wt. (#) 68 3802 9.5 221038 Tension S.F. PBYS TJYS 4.84 5;88 DS 3-36 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1 086000 I 161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SFFP 3420 Burst S.F. 2.01 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) ... (psi/ft) 10,2 8744 0.1 . . Collapse S.F. 1.2 6 .. Collapse press 3763 Tension Calculation Based on full string weight in mud Casg Wt. (#irt)., ,MD (FT)..-~. ' ' Mud Wt. : ::!,. 4 7 ·...' .."... .'~ 12111 ,-. ' String Wt. (#) 480576 DS 3-36 Casing Design PRODUCTION LINER 7", 26#, 13Cr, NSCC Casing GRADE BURST 13Cr 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid SITP Fluid wt (ppg) back up (ppg) Burst Pressure 3420 9.7 9.5 3512 Burst S.F. 2,06 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 10.2 9191 0.1 3956 Collapse S.F. 1.37 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 923 Mud Wt. String Wt. (#) 10.0 20334 Tension S.F. PBYS TJYS 29.70 32.80 JAN-26-1995 l~:O~ PRUDHOE .... DRILLING _ DS 3-36 (Pi) VERTICAL SECTION VIEW i ii i i i -- -~ · i i II . I iii Sec[ion et.: 79.88 Drawn ' 0~/25/93 Marker IOentif icat~un ~O BKB SE~TN INCLN A) KG ~ 0 0 0.00 e) KOP BUILD 2.50/~00 2700 2700 0 C) END OF 2.50 BUILD 46~8 ~57i B6B 54.70 D~ TARGET 12i~l 874J 686~ 54.70 E) TD t~884 919i 749J 54,70 ' Ill [ I I ] I I ; I I I I I I Ill o 6O0 ! 1200 ~.800 2400 3000 :3500 Sect Jori D~D8~ture 4200 4800 5400 6000 6600 7200 7800 ¢r¢¢t L¢,d ¢~r¢¢t~o~] ~]]~¢ PRUDHOE BAY DRI LING BS 3-36 (Pi) PLAN VTEN ~:L. OSURE ' 7494 feet at Azimuth 79.88 :)ECL [NATION.' 30.15 E '3CALE ' ! ~nch = 1000 feet i 3FtM, IN - 0',/25/93 ., Marker ldent i i i cat i lin MO N/S E/~f A} KB 0 0 fl 0 E B) KDP ItUII_D 2.§0/100 2700 0 ~ 0 E C} E~ OF 2.50 8g[t~ 4888 t70 N g53 E D) I~GEf 12~1~ i206 N 6756 E E) ID ~2884 ~317 N 7377 E 3 J i 500 0 500 · (- MESf' EA§l -> ;' I~1 4,'1n2 D'~TI1F~ 111.40 5.51 I'~ !) 1000 1500 2O00 25O0 :t000 II Ill . Illlll, i 3500 4000 4500 5000 5500 6000 6500 7000 75O0 8000 13500 DRILL SiTE ?RU 3HOF.. BAY NA3ORS i 8E ; / / ; ; / ; / ; / / /- ; / / ; / / / / : / JAN-26-1995 13:16 FROM~.~RbHI LHNU UiN UKiLLlmU lU GREAT LAND DIRECTIONAL DRILLING, Corporate Office 1111 East 80th Avenue A=nchorape, A~ 99518 (907) 349-4511 Fax 349-2487 INC. DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING well ......... : DS 3-36 (Pi) ~ipld ........ : PRUDHOE B.~Y DRILL SITE 3 Computation..: MINIMUM CLTRVATURE Units ........ : FEET Prepared ..... : 01/26/93 Section a~...: 79.88 KB elevation.: 64.00 fk LEGAL DESCRIPTIO~ Surface ...... : 906 FSL 4381 FEL Sll TION R15E ~4~ Taz~et ....... : 2112 FSL 2904 FEL $12 T10~ R15E UM B~L .......... : 2223 FSL 2283 FEL S12 T10N R15E UM X ASP ZONE 4 Y 714172.19 5936971.20 720890.13 5938371.78 721507.73 5938500.85 PROPOSED WELL PROFILE STATION MEAS INCLN VRRT-DEPTHS IDENTIFICATION DEPT~ ~GLE B¥~ SUB-$ 0 0.00 0 -64 500 0.00 500 436 600 0.00 600 536 700 0.00 700 800 0.00 800 736 SECT DIST DIRECTION ~ZIMUTH REL-COORDINATE$ FROM-WELLHEAD 0 0.00 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 ~ 0 KOD BUILD 2.50/100 900 0.00 900 836 !000 0.00 1000 936 !100 0.00 1100 1036 1200 0.00 1200 !136 1300 0.00 1300 1236 1400 0.00 1400 1336 1500 0.00 1500 1436 1600 0.00 1600 1536 1700 0.00 1700 1636 1800 0.00 1800 1736 1900 0.00 1900 1836 2000 0.00 2000 1936 2100 0.00 2100 2036 2200 0.00 2200 21~6 2700 0.00 2700 2636 2800 2.50 2800 2736 2900 5.00 2900 2836 3000 7.50 2999 2935 3100 10.00 2098 3034 3200 12.50 3196 2132 3300 15.00 3293 3229 3400 ~7.50 ~$89 3325 3500 20.00 3484 3420 3600 2-2.50 3S77 3513 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79,88 0 ~ 0 0 79.88 0 N 0 2 9 2O 35 54 78 ~06 17% 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 I4 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 0 79.88 0 N 0 79.88 79.88 79.88 79.88 79.88 79.8~ 79.88 DT./ lO0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ~0,.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ON 2 E 2.5 2 N 9 E 2.5 3 N 19 E 2.5 6 N 34 E 2.5 10 N 53 E 2.5 77 104 136 172 14 19 24 31 N 2.5 2.5 2.5 2.5 TOTAL P. 03 JAN-26-1~'~J iJ~iJ DS 3-86 STATION IDEN~i~IFICkTION T5 END OF 2.50 BUILD K15 UGI~U SA/~DS K12 K10 K5 LCU TARGET TOP SADLEROCHIT ZON~ 4A ZONE 3 ZO1QE 2C ZONE 2R CURRE~ OWC ZONE 2A HOT ZONE 1 ORIGINAL OWC BASE IViS~-A/< S-Z~TD TD LISBURI~E oi/16/93 ~ge 2 PROPOSED WELL PROFILE MEAS INCLN DEPTH ~GLE VERT-DEPTHS SECT BK~ SDB-S DIST DIRECTION REL-COORDINATE$ DL/ AZIIVK3TH FROM-WELLHF_~ 100 3700 2~.00 3669 3605 215 3800 27.50 3758 3694 259 3802 27.55 ~760 3696 260 3900 30.00 3846 3782 307 4000 32.50 3931 3867 359 79.88 38 N 211 79.88 46 ~ 255 E 2.5 79.88 46 N 256 E 2.5 79.88 54 N 302 E 2.5 79.88 63 N 353 E 2.5 4100 35.00 4015 3951 414 4200 37.50 4095 4031 474 4300 40.00 4!73 4109 536 4400 42.50 424~ 4184 602 4500 45.00 4321 4257 671 4600 47.50 4390 4326 743 4700 50.00 4456 4392 819 4800 52.50 4518 4454 897 4888 54.70 4571 4507 968 5500 ~4.70 4924 4860 1467 79.88 73 N 408 E Q.5 79.88 83 N 466 ~ 2.5 79.88 94 N 528 E 2.5 79.88 106 ~ 593 E 2.5 79.88 118 N 661 E 2.5 79.88 13! N 732 ~ 2.5 79.88 144 ~ 806 E 79.88 1~8 N 883 ~ 2.5 79.88 170 N 953 E 2.5 79.88 258 N 1444 ~ 0.0 7423 54.70 6035 5971 3036 9139 54.70 7027 6963 4437 10074 54.70 7567 7503 5200 11114 54.70 8168 8!04 6049 !~1i! 54.70 8744 8680 6863 12111 54.70 8744 8680 6863 12111 54.70 8744 8680 6863 12111 54.70 8744 8680 6863 12260 54.70 88~0 ~7~6 6984 12331 54.70 8871 8807 7042 79.88 534 N 2989.E 0.0 79.88 780 N 4368 E 0.0 79.88 914 N 5119 E 0.0 79.88 1063 N 5955 ~ 0.0 79.88 1206 N 6756 E 0.0 79.88 1206 N 6756 E 0.0 79.88 1206 N 6756 E 0.0 79.88 1206 N 6756 E 0.0 ?9.88 122B ~ 6875 E 0.0 79.88 1138 N 6932 E 0.0 12423 54.70 8924 8860 7117 12613 54.70 9034 8970 7272 12613 54.70 9034 8970 7272 1264~ 54.70 ~054 8990 7301 126B2 54.90 9074 9010 7329 12734 54.70 9104 9040 7371 12783 54.70 9132 9068 7411 12884 54.70 9191 9127 7494 9327 ~263 79.88 1251 N 7006 E 79.88 1278 N 7159 ~ 0.0 79.88 1278 N 7159 E 0.0 79.88 1283 N 7187 ~ 0.0 79.88 1288 ~ 7215 E 0.0 79.88 1296 N 7256 E 0.0 79.88 1303 N 7295 E 0.0 79.88 1317 N 7377 E 0.0 Great Land Directional Drilling, Collision Avoidance Analysis Inc. Client.: Field..: Pad .... : Well...: PRUDHOE BAY DRILLING NSLOPE Drill Site 3 DS0336P Method..: Date .... : WellHd X: WellHd Y: Normal Plane 01/26/93 714172.19 5936971.20 Comment: DS 3-36 2700 KOP Wells with minimum separation greater than 200 ft not reported. All depths are relative to the planned well. Existing Well DS031!G DS03!2G DS0313G DS031~G DS0326G Band Closest Point .... 100' ........ 25' ..... Occurs at Warning-Band Serious-Band Depths Enter Leave Enter Leave BKD MD MD MD MD MD 50 2900 2901 56 1975 1975 59 1350 1350 180 0 0 146 3802 3850 2666 3105 0 2344 0 2422 NABORS 18 E 13 5/8" 5,000 psi Stack 1.50 · I" 4.75 4.73 t 3.98 3.66 I I-' 1.49 2.37 2.21 0.55 .: GROUND LEVEL RKB 1 ! ,, J HYDRIL [ I PIPE RAM BLIND RAM KR TQ RF RIG FI t"")C')R 11.41 15.66 17.93 MUD CROSS J PIPE RAM J MUD CROSS ~ J TBG SPOOL I J ~ASEFLG/// 22.96 26.45 28.25 30.25 SUF..,',zC,_ rtOLE DIVERTER SYSTEM ...... ' Two lines venting 90 deg. apart in direclions that ensure safe down wind venting, and ex- tending to a point at least 100' Irom any source o! ignition. .~.10' Full Opening Valves 35' or as required Dresser Sleeve 1. All pipe connections 150¢. ANSI Flanges or welded connections and secured lo prevent movemenL 2. Manual 10' full opening valves mechanically ~nnected to ensure that one valve is tail-sale open at all lim~s. 10' Diverter line All tums are 90 deg. and targeled. 10' FulI opening ball valve w/Hydraulic Actuator MEM 1/3/'90 Hub T~ A~Jy ~ TO SrAm~ I00 ~L. i~Lt, IHE TAll g icc) TRIP TANK ..~AN D ,,/ I~0 88/.- v',".Cuuri -) - Choke Manifold - Poor Boy Degasser · - Brandt Vacuum.-Type Degasser '- Brandt Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge HUD OlSTRII~,JTION o~rc /' /' (; / / 1 - RecOrding drilling fluid pit *level indicator with both visual and audio warning devices at driller's console 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp Agitators DS3-36t4T.XLS State: Well: Field: State Permit Rudhoe Engineer.' ¥./ork Sheet: Date: Cement Vo~/me Calcu/8lion,~ 1/25/$3 Casing Type Casing Size -Inches Casing Length - Feet Hole Diameter -Inches Cement- Sacks 111 Cement-Yield111 Cement-Cubic ft' 111 Cement- Cubic it 111 Cement- Sacks 112 Cement-YieldII2 Cement- Cubic It 112 Cement-Cubic ft 112 Cement- Sacks 113 Cement- Yield 113 Cement- Cubic It 113 Cement- Cubic t~t 113 Cement- Cubic It / Vol Cement- Fill Factor Cor',:iuctor 20.000 80.000 30.000 0.000 0.000 O. O00 297.000 0.000 0.000 0.000 0.000 297.000 1.361 Surface 13.375 3,771.000 16.000 0.000 0.000 0.000 2,894.000 0.000 0.000 0.000 460.000 0.000 0.000 0.000 0.000 3,354.000 2.115 Liner 7.000 923.000 8.500 0.000 0.000 250.000 0.000 0.000 0.000 O. OOO 250.000 2.136 Casing Type Casing Size -Inches Casing Depth- Feet Hole Dbmete~-Inches Cement- Sacks 11i Cement- Yield 111 Cement- Cubic it 111 Cement-Cubic ft 111 Cement- Sacks 112 Cement- Yield 112 Cement- Cubic ft 112 Cement- Cubic It 112 Cement- Sacks 113 Cement- Yield 113 Cement- Cubic ft 1:I3 Cement-Cubic tt 113 Cement- Cubic tt /VoI Cement-interval ft Top of Cement- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 0.00 11DIV/O! ~DIV/O! Intermediate 112 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! IIDIV/O! Produe~ 12,111.000 12250 0.00 0.00 0.00 1,249.00 0.00 0.00 0.00 502.00 0.00 0.00 0.00 0.00 1,751.00 5,785.98 ' 6,325.0 Measured Depth CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee ,~' (2) Loc [2 thru 8] . . 7- 2~-- g~ [lO & 13] [14 thru 22] [23 thru 28] (5) BOPE Company /~¢ 4_¢ 1. Is 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 & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nLrnber appropriate .......................................... 13. Does well have a unique name & nLrnber ................................ 14. Is conductor string provided ......................................... 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ Lease S Well YES NO , , REMARKS A 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all knov~ productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension, and burst. 20. Is well to be kicked off from an existing wellbore ................... 21. Is old wellbore abandonment procedure included on 10-403 ............. 22. Is adequate wellbore separation proposed ............................. 23. Is a diverter System required ........................................ 24. Is drilling fluid program schematic & list of equipment adequate ..... 25. Are necessary diagrams & descriptions of diverter & BOPE attached .... 26. Does BOPE have sufficient pressure rating -- test to ~-~oo~ psig ..... 27. Does choke manifold comply w/API RP-53 (May 84) ...................... 28. Is presence of H2S gas probable ...................................... (6) Other ,,'¢~'~. r'/~~~3~]' [29 th (7) Contact ~ ~ ~- ' _ [32] - (8) Addl ~.~.¢:~./~ ~-2~-~ geology' engineering: DWJ MTM ~ RAD']) RP.~, BEW JDH-~F-f~ LG rev 12/92 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone nLrnber of contact to supply weekly progress data ...... 33. Additional requirements ..................... . ........................ INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional UM y' hIERIDIAN: SM remarks' WELL TYPE: Exp,~.~¢,,~'-~V In j,,, - Red ri l 1 Rev 0 ~'Z u~-! Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER ....... SCHLUMBERGER --* RECEIVED AUG ;~ 1 1995 Alaska Oil & Gas Cons. Commission Anchorage COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 3-36 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22340-00 REFERENCE NO : 93196 ~£S Tape Verification ListSng Schlumberger' AlaSka Computing Center 7'JUN-1993 10'22 **** REEL HEADER **** ' ED DATE · 7 ORIGIN : FLIC REEL NAME : 93196 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.,PRUDHOE BAY,D.S. 3-36,50-029-22340-00 **** TAPE HEADER SERVICE NAME · EDIT DATE · 93/06/ 7 ORIGIN : FLIC TAPE NAME : 93196 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.,PRUDHOE BAY,D.S. 3-36,50-029-22340-00 TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 3-36 500292234000 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 7-JUN-93 RUN 1 RUN 2 RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 93196 SARB~R COOK/REEM 11 1 0N 15E 906 4381 61.90 60.40 32.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 8.500 9.625 11901.0 PAGE: ~£S TaDe Verification ListSng Schlumberger'Alaska Computing Center 3RD STRING PRODUCTION STRING REMARKS: 7-JUN-1993 10:22 FIELD ENGINEER'S REMARKS: TOOL STRING CENTRALIZED WITH 1.2" TEFLON STANDOFFS. A 2' RUBBER HOLE FINDER WAS ALSO USED. DUE TO THE USE OF TEFLON STANDOFFS ON THE SONIC TOOL THE LOGGING SPEED WAS 1000-1200 F/H, WHICH IS MUCH SLOWER THAN USUAL TO ELIMINATE ROAD NOISE. THE FIRST LOGGING PASS HAD AN UNACCEPTABLE LEVEL OF TENSION PULLS ON IT. TO IMPROVE LOG QUALITY THE SECOND PASS WAS MADE WITH THE CALIPER CLOSED. THIS IMPROVED THE TOOL STICKING, BUT THERE WILL BE NO CALIPER OR MSFL DATA BECAUSE OF THIS. THE CNL USED THE MSFL CALIPER FOR HOLE CORRECTION ON THE REPEAT PASS, AND BIT SIZE ON THE MAIN PASS. THE CALIPER WAS CLOSED 2 TIMES ON THE REPEAT PASS TO GET THRU TIGHT SPOTS. DURING CLOSING ALL MSFL AND DLL DATA IS INVALID. **** FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION · 001A0~ DATE '93~6 7 MAX REC SIZE · 10 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES All tool strings; DeDth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12497.0 BCS 12523.0 DLL 12548.0 CNTH 12503.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 11890.0 11890.0 11890.0 11890.0 EQUIVALENT UNSHIFTED DEPTH- $ MERGED DATA SOURCE ~£S TaDe Verification ListSng Schlumberger'Alaska Computing Center 7-JUN-1993 10:22 PBU TOOL CODE RUN NO. PASS NO. MERGE TOP MERGE BASE $ REMARKS: COMPUTING CENTER REMARKS: THE CALIPER AND MSFL THAT APPEAR IN THIS FILE ARE FROM THE REPEAT PASS. (SEE FIELD ENGINEER'S REMARKS ON TAPE HEADER). NO DEPTH CORRECTIONS WERE NEEDED. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS ( HEX ) DEPT FT 599471 00 000 00 0 1 1 1 4 68 LLM DLL OHMM 599471 00 000 00 0 1 1 1 4 68 LLD DLL OHMM 599471 00 000 00 0 1 1 1 4 68 CALS DLL IN 599471 00 000 00 0 1 1 1 4 68 SP DLL MV 599471 00 000 00 0 1 1 1 4 68 MTEM DLL DEGF 599471 00 000 00 0 1 1 1 4 68 MRES DLL OHMM 599471 00 000 00 0 1 1 1 4 68 MSFL DLL OHMM 599471 00 000 00 0 1 1 1 4 68 NPHI CNTH PU-S 599471 00 000 00 0 1 1 1 4 68 CRAT CNTH 599471 00 000 00 0 1 1 1 4 68 NRAT CNTH 599471 00 000 00 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 diS TaDe Verification ListSng Schlumberger'Alasfka Computing Center 7-JUN-1993 10:22 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS ( HEX ) NCNT CNTH CPS 599471 00 000 00 0 1 1 1 4 68 FCNT CNTH CPS 599471 00 000 00 0 1 1 1 4 68 CNTC CNTH CPS 599471 00 000 00 0 1 1 1 4 68 CFTC CNTH CPS 599471 00 000 00 0 1 1 1 4 68 DT BCS US/F 599471 00 000 00 0 1 1 1 4 68 GR BCS GAPI 599471 00 000 00 0 1 1 1 4 68 TENS BCS LB 599471 00 000 00 0 1 1 1 4 68 TEND BCS LB 599471 00 000 00 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA DEPT. 12560.000 LLM.DLL -999.250 LLD.DLL -999.250 SP.DLL -999.250 MTEM.DLL 167.646 MRES.DLL 0.062 NPHI.CNTH -999.250 CRAT.CNTH -999.250 NRAT.CNTH -999.250 FCNT.CNTH -999.250 CNTC.CNTH -999.250 CFTC.CNTH -999.250 GR.BCS -999.250 TENS.BCS 3815.000 TEND.BCS 417.137 DEPT. 12500.000 LLM.DLL 14.572 LLD.DLL 14.390 SP.DLL -20.000 MTEM.DLL 167.646 MRES.DLL 0.062 NPHI.CNTH 28.660 CRAT.CNTH 2.650 NRAT.CNTH 2.806 FCNT.CNTH 877.506 CNTC.CNTH 2283.673 CFTC.CNTH 880.921 GR.BCS -999.250 TENS.BCS 5115.000 TEND.BCS 963.137 DEPT. 12400.000 LLM.DLL 7.945 LLD.DLL 8.701 SP.DLL -2.250 MTEM.DLL 168.355 MRES.DLL 0.062 NPHI.CNTH 26.274 CRAT.CNTH 2.491 NRAT.CNTH 2.791 FCNT.CNTH 734.424 CNTC.CNTH 2155.142 CFTC.CNTH 792.992 GR.BCS 107.007 TENS.BCS 5025.000 TEND.BCS 853.443 DEPT. 12300.000 LLM.DLL 12.102 LLD.DLL 12.158 SP.DLL 3.438 MTEM.DLL 169.292 MRES.DLL 0.062 NPHI.CNTH 23.538 CRAT.CNTH 2.308 NRAT.CNTH 2.373 FCNT.CNTH 1069.089 CNTC.CNTH 2456.219 CFTC.CNTH 1111.518 GR.BCS 81.898 TENS.BCS 5135.000 TEND.BCS 919.128 DEPT. 1 2200. 000 LLM.DLL 2. 345 LLD.DLL 3.01 3 SP.DLL -1.250 MTEM.DLL 168.720 MRES.DLL 0.066 NPHI. CNTH 29 . 009 CRAT. CNTH 2. 673 NRAT. CNTH 2. 773 FCNT.CNTH 939.61 7 CNTC.CNTH 2660. 291 CFTC.CNTH 990. 194 GR. BCS 33.515 TENS.BCS 5170.000 TEND. BCS 926.023 DEPT. 12100.000 LLM.DLL 14.129 LLD. DLL 16.797 SP. DLL 9 . 250 MTEM.DLL 1 67. 805 MRES.DLL 0. 066 NPHI . CNTH 20. 344 CRAT. CNTH 2. 095 NRAT. CNTH 2.1 86 FCNT. CNTH 1 621 . 822 CNTC.CNTH 3393.1 71 CFTC. CNTH 1 646. 384 GR.BCS 28.700 TENS.BCS 5175.000 TEND. BCS 1045.112 CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS -999.250 -999.250 -999.250 -999.250 7.504 156.084 2317.503 71.983 7.523 5.361 2111.741 76.550 8.462 12.998 2598.407 73.350 7.720 1.543 2780.940 99.850 8.279 5.174 3556.752 82.900 diS TaDe Verification Listing Schlumberger°Alas'ka Computing Center DEPT. 12000.000 LLM.DLL SP.DLL 1.125 MTEM.DLL NPHI.CNTH 50.846 CRAT.CNTH FCNT.CNTH 345.007 CNTC.CNTH GR.BCS 164.922 TENS.BCS DEPT. 11900.000 LLM.DLL SP.DLL 0.375 MTEM.DLL NPHI.CNTH 44.099 CRAT.CNTH FCNT.CNTH 396.440 CNTC.CNTH GR.BCS 199.261 TENS.BCS DEPT. 11890.000 LLM.DLL SP.DLL 1.625 MTEM.DLL NPHI.CNTH 50.724 CRAT.CNTH FCNT.CNTH 335.253 CNTC.CNTH GR.BCS 166.149 TENS.BCS END OF DATA 7-JUN-1993 10:22 6.286 LLD.DLL 165.967 MRES.DLL 3.917 NRAT.CNTH 1407.481 CFTC.CNTH 5080.000 TEND.BCS 6.021 LLD.DLL 162.846 MRES.DLL 3.548 NRAT.CNTH 1363.484 CFTC.CNTH 4785.000 TEND.BCS 0.111 LLD.DLL 163.065 MRES.DLL 3.910 NRAT.CNTH 1332.307 CFTC.CNTH 4830.000 TEND.BCS 6.384 0.067 4.214 371 .254 966.094 7.440 0.068 3.635 403.597 892.683 0.244 0.068 4.082 347.155 910.538 CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS CALS.DLL MSFL.DLL NCNT.CNTH DT.BCS PAGE: 7.784 0.857 1 481. 940 101 .450 8.136 0.419 1365.045 91.600 9.312 0.191 1413.809 108.300 **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION · 001. A0~ DATE · 93/06 MAX REC SIZE · 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC DATE ' 93~ MAX REC SIZE · 10 4 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 diS TaDe Verification ListSng Schlumberger'Alas'ka Computing Center 7-JUN-1993 10:22 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH BHC DLL CNL GR $ LOG HEADER DATA DATE LOGGED: 12523.0 12548.0 12503.0 12497.0 SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLE~ (~T)' TD LOGGER(FT): TOP LOG INTERVAL (FTl' BOTTOM LOG INTERVAL%~T)' LOGGING SPEED (FPHR)' TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 11890.0 11890.0 11890.0 11890.0 22-APR-93 5C0-423 1300 2005 12569.0 12562.0 11890.0 12522.0 1200.0 22-APR-93 22-APR-93 TOOL NUMBER AMS TCC GR CNL BHC BHC DLL DLL DLL $ AUXILLIARY MEASURMENTS TELEMETRY CARTRIDGE GAMM RAY CARTRIDGE COMPENSATED NEUTRON BOREHOLE SONIC CART. BOREHOLE SONIC SONDE DUAL LATEROLOG CART. DUAL LATEROLOG SONDE DUAL LATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN~: DRILLERS CASING DEPTH.(F?)' LOGGERS CASING DEPTH (FT)' BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (La/g)' MUD VISCOSITY (S)' MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF RESISTIVITY (OHMM) AT TEMPERATURE MUD AT MEASURED TEMPERATURE (MT MUD AT BOTTOM HOLE TEMPERATURE MUD FILTRATE AT (MT) MUD FILTRATE AT (BHT)' MUD CAKE AT (MT) ; MUD CAKE AT(BHT)' DEGF ): : BHT ): AMS-AA 724 TCC-B SGC-SA 503 CNC-HA 398 SLC-UA 278 BLS-WA 2004 DLC-D 724 DLS-F 724 SRE-F 1729 8.50O 11901 .0 11890.0 KCL POLYMER 9.10 44.00 8.90 6.20 168.0 0.169 70.0 0.141 70.0 0.217 70.0 PAGE: ~IS TaDe Verification Listing Schlumberger~Ala~ka Computing Center 7-JUN-1993 10:22 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: TOOL STRING CENTRALIZED WITH 1.2" TEFLON STANDOFFS. A 2' RUBBER HOLE FINDER WAS ALSO USED. DUE TO THE USE OF TEFLON STANDOFFS ON THE SONIC TOOL THE LOGGING SPEED WAS 1000-1200 F/H. WHICH IS MUCH SLOWER THAN USUAL TO ELIMINATE ROAD NOISE. THE FIRST LOGGING PASS HAD AN UNACCEPTABLE LEVEL OF TENSION PULLS ON IT. TO IMPROVE LOG QUALITY THE SECOND PASS WAS MADE WITH THE CALIPER CLOSED. THIS IMPROVED THE TOOL STICKING, BUT THERE WILL BE NO CALIPER OR MSFL DATA BECAUSE OF THIS. THE CNL USED THE MSFL CALIPER FOR HOLE CORRECTION ON THE REPEAT PASS, AND BIT SIZE ON THE MAIN PASS. THE CALIPER WAS CLOSED 2 TIMES ON THE REPEAT PASS TO GET THRU TIGHT SPOTS. DURING CLOSING ALL MSFL AND DLL DATA IS INVALID. #~ $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 164 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ~IS TaDe Verification Listing Schlumberger'Alafka Computing Center SET TYPE - CHAN ** 7-JUN-1993 10:22 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS ( HEX ) DEPT FT 599471 00 000 00 0 2 1 1 4 68 LLS DIL OHMM 599471 00 000 00 0 2 1 1 4 68 LLD DIL OHMM 599471 00 000 00 0 2 1 1 4 68 CALS DIL IN 599471 00 000 00 0 2 1 1 4 68 CALl DIL IN 599471 00 000 00 0 2 1 1 4 68 SP DIL MV 599471 00 000 00 0 2 1 1 4 68 GR DIL GAPI 599471 00 000 00 0 2 I 1 4 68 TENS DIL LB 599471 00 000 00 0 2 1 1 4 68 MTEM DIL DEGF 599471 00 000 00 0 2 1 1 4 68 MRES DIL OHMM 599471 00 000 00 0 2 I 1 4 68 HTEN DIL LB 599471 00 000 00 0 2 1 1 4 68 MSFL DIL OHMM 599471 00 000 00 0 2 1 1 4 68 SMIN DIL OHMM 599471 00 000 00 0 2 1 1 4 68 SMNO DIL OHMM 599471 00 000 00 0 2 1 1 4 68 NPHI CNL PU 599471 00 000 00 0 2 1 1 4 68 RTNR CNL 599471 00 000 00 0 2 1 1 4 68 TNPH CNL PU 599471 00 000 00 0 2 1 1 4 68 TNRA CNL 599471 00 000 00 0 2 1 1 4 68 NPOR CNL PU 599471 00 000 00 0 2 1 1 4 68 RCNT CNL CPS 599471 00 000 00 0 2 1 1 4 68 RCFT CNL CPS 599471 00 000 00 0 2 1 1 4 68 CNTC CNL CPS 599471 00 000 00 0 2 1 1 4 68 CFTC CNL CPS 599471 00 000 00 0 2 1 1 4 68 GR CNL GAPI 599471 00 000 00 0 2 1 1 4 68 CALS CNL IN 599471 00 000 00 0 2 1 1 4 68 TENS CNL LB 599471 00 000 00 0 2 1 1 4 68 MRES CNL OHMM 599471 00 000 00 0 2 1 1 4 68 MTEM CNL DEGF 599471 00 000 00 0 2 1 1 4 68 HTEN CNL LB 599471 00 000 00 0 2 1 1 4 68 DT BHC US/F 599471 00 000 00 0 2 1 1 4 68 TT1 BHC US 599471 00 000 00 0 2 1 1 4 68 TT2 BHC US 599471 00 000 00 0 2 1 1 4 68 TT3 BHC US 599471 00 000 00 0 2 1 1 4 68 TT4 BHC US 599471 00 000 00 0 2 1 1 4 68 SP BHC MV 599471 00 000 00 0 2 1 1 4 68 GR BHC GAPI 599471 00 000 00 0 2 1 1 4 68 CALl BHC IN 599471 00 000 00 0 2 1 1 4 68 TENS BHC LB 599471 00 000 00 0 2 1 1 4 68 MTEM BHC DEGF 599471 00 000 00 0 2 1 1 4 68 MRES BHC OHMM 599471 00 000 00 0 2 1 1 4 68 HTEN BHC LB 599471 00 000 00 0 2 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12581.500 LLS.DIL 7.616 LLD.DIL CAL1.DIL 4.446 SP.DIL -20.000 GR.DIL MTEM.DIL 167.646 MRES.DIL 0.062 HTEN.DIL SMIN.DIL 0.836 SMNO.DIL 1.143 NPHI.CNL 7.127 CALS.DIL 52.652 TENS.DIL -233.225 MSFL.DIL 26.489 RTNR.CNL 4.729 1710.000 0.303 2.625 biS TaDe Verification Listing Schlumberger'AlaSka Computing Center TNPH.CNL 26.651 TNRA.CNL RCFT.CNL 978.809 CNTC.CNL CALS.CNL 4.729 TENS.CNL HTEN.CNL -233.225 DT.BHC TT3.BHC 503.200 TT4.BHC CAL1.BHC 4.446 TENS.BHC HTEN.BHC -233.225 DEPT. 12500.000 LLS.DIL CAL1.DIL 4.443 SP.DIL MTEM.DIL 167.646 MRES.DIL SMIN.DIL 0.843 SMNO.DIL TNPH.CNL 28.511 TNRA.CNL RCFT.CNL 877.506 CNTC.CNL CALS.CNL 4.682 TENS.CNL HTEN.CNL 963.137 DT.BHC TT3.BHC 470.800 TT4.BHC CAL1.BHC 4.443 TENS.BHC HTEN.BHC 963.136 DEPT. 12400.000 LLS.DIL CAL1.DIL 4.406 SP.DIL MTEM.DIL 168.355 MRES.DIL SMIN.DIL 0.849 SMNO.DIL TNPH.CNL 30.437 TNRA.CNL RCFT.CNL 734.424 CNTC.CNL CALS.CNL 4.678 TENS.CNL HTEN.CNL 853.443 DT.BHC TT3.BHC 503.200 TT4.BHC CAL1.BHC 4.406 TENS.BHC HTEN.BHC 853.443 DEPT. 12300.000 LLS.DIL CAL1.DIL 4.386 SP.DIL MTEM.DIL 169.292 MRES.DIL SMIN.DIL 0.832 SMNO.DIL TNPH.CNL 22.720 TNRA.CNL RCFT.CNL 1069.089 CNTC.CNL CALS.CNL 4.633 TENS.CNL HTEN.CNL 919.128 DT.BHC TT3.BHC 484.800 TT4.BHC CAL1.BHC 4.386 TENS.BHC HTEN.BHC 919.128 DEPT. 12200.000 LLS.DIL CAL1.DIL 4.383 SP.DIL MTEM.DIL 168.720 MRES.DIL SMIN.DIL 0.853 SMNO.DIL TNPH.CNL 29.958 TNRA.CNL RCFT.CNL 939.617 CNTC.CNL CALS.CNL 4.630 TENS.CNL HTEN.CNL 926.023 DT.BHC TT3.BHC 630.000 TT4.BHC CAL1.BHC 4.383 TENS.BHC HTEN.BHC 926.023 7-JUN-1993 10:22 2. 505 NPOR.CNL 251 2. 059 CFTC.CNL 1 71 0. 000 MRES.CNL 71.900 TT1 .BHC 362. 400 SP.BHC 1 71 0. 000 MTEM.BHC 1 4. 572 LLD. DIL -20. 000 GR.DIL 0. 062 HTEN.DIL 1 . 01 0 NPHI.CNL 2. 650 NPOR.CNL 2283. 673 CFTC.CNL 511 5. 000 MRES.CNL 71 .983 TT1 .BHC 331 . 200 SP.BHC 5115. 000 MTEM.BHC 7.945 LLD.DIL -2.250 GR.DIL 0.062 HTEN.DIL 0.850 NPHI.CNL 2.491 NPOR.CNL 2155.142 CFTC.CNL 5025.000 MRES.CNL 76.550 TT1.BHC 348.400 SP.BHC 5025.000 MTEM.BHC 12.102 LLD.DIL 3.438 GR.DIL 0.062 HTEN.DIL 1.123 NPHI.CNL 2.308 NPOR.CNL 2456.21 9 CFTC.CNL 51 35 . 000 MRES.CNL 73. 350 TT1 .BHC 333.600 SP.BHC 5135.000 MTEM.BHC 2.345 LLD.DIL -1.250 GR.DIL 0.066 HTEN.DIL 0.946 NPHI.CNL 2.673 NPOR.CNL 2660.291 CFTC.CNL 5170.000 MRES.CNL 99.850 TT1.BHC 422.000 SP.BHC 5170.000 MTEM.BHC 26.651 1016.860 0.062 503.200 -20.000 167.646 14.390 59.068 963.136 28.660 29.272 880.921 0.062 501.000 -20.000 167.646 8.701 107.007 853.443 26.274 32.609 792.992 0.062 504.400 -2.250 168.355 12.158 81 .898 919.128 23.538 22.060 1111.518 0.062 503.200 3.438 169.292 3.013 33.515 926.023 29.009 29.619 990.194 0.066 628.600 -1.250 168.720 RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC PAGE: 2602.424 52.652 167.646 356.400 52.652 0.062 4.682 5115.000 0.225 2.806 2317.503 59.068 167.646 336.400 59.068 0.062 4.678 5025.000 0.159 2.791 2111 .741 107.007 168.355 350.800 107.007 0.062 4.633 5135.000 0.292 2.373 2598.407 81.898 169.292 346.200 81.898 0.062 4.630 5170.000 0.194 2.773 2780.940 33.515 168.720 435.600 33.515 0.066 LIS TaDe Verification ListSng Schlumberger'Alaska Computing Center 7-JUN-1993 10:22 PAGE: 10 DEPT. 12100.000 LLS.DIL CAL1.DIL 4.384 SP.DIL MTEM.DIL 167.805 MRES.DIL SMIN.DIL 0.857 SMNO.DIL TNPH.CNL 20.501 TNRA.CNL RCFT.CNL 1621.822 CNTC.CNL CALS.CNL 4.631 TENS.CNL HTEN.CNL 1045.112 DT.BHC TT3.BHC 539.600 TT4.BHC CAL1.BHC 4.384 TENS.BHC HTEN.BHC 1045.112 DEPT. 12000.000 LLS.DIL CAL1.DIL 4.384 SP.DIL MTEM.DIL 165.967 MRES.DIL SMIN.DIL 0.878 SMNO.DIL TNPH.CNL 47.487 TNRA.CNL RCFT.CNL 345.007 CNTC.CNL CALS.CNL 4.631 TENS.CNL HTEN.CNL 966.094 DT.BHC TT3.BHC 645.600 TT4.BHC CAL1.BHC 4.384 TENS.BHC HTEN.BHC 966.094 DEPT. 11900.000 LLS.DIL CAL1.DIL 4.384 SP.DIL MTEM.DIL 162.846 MRES.DIL SMIN.DIL 0.903 SMNO.DIL TNPH.CNL 40.810 TNRA.CNL RCFT.CNL 396.440 CNTC.CNL CALS.CNL 4.626 TENS.CNL HTEN.CNL 892.683 DT.BHC TT3.BHC 596.000 TT4.BHC CAL1.BHC 4.384 TENS.BHC HTEN.BHC 892.683 DEPT. 11800.000 LLS.DIL CAL1.DIL 4.385 SP.DIL MTEM.DIL 161.189 MRES.DIL SMIN.DIL 1.071 SMNO.DIL TNPH.CNL 43.710 TNRA.CNL RCFT.CNL 313.987 CNTC.CNL CALS.CNL 4.624 TENS.CNL HTEN.CNL 900.431 DT.BHC TT3.BHC 407.600 TT4.BHC CAL1.BHC 4.385 TENS.BHC HTEN.BHC 900.431 DEPT. 11700.000 LLS.DIL CAL1.DIL 4.378 SP.DIL MTEM.DIL 159.958 MRES.DIL SMIN.DIL 1.079 SMNO.DIL TNPH.CNL 51.352 TNRA.CNL RCFT.CNL 279.006 CNTC.CNL 14.129 LLD.DIL 9.250 GR.DIL 0.066 HTEN.DIL 0.957 NPHI.CNL 2.095 NPOR.CNL 3393.171 CFTC.CNL 5175.000 MRES.CNL 82.900 TT1.BHC 363.400 SP.BHC 5175.000 MTEM.BHC 6.286 LLD.DIL 1.125 GR.DIL 0.067 HTEN.DIL 0.842 NPHI.CNL 3.917 NPOR.CNL 1407.481 CFTC.CNL 5080.000 MRES.CNL 101.450 TT1.BHC 453.200 SP.BHC 5080.000 MTEM.BHC 6.021 LLD.DIL 0.375 GR.DIL 0.068 HTEN.DIL 0.852 NPHI.CNL 3.548 NPOR.CNL 1363.484 CFTC.CNL 4785.000 MRES.CNL 91.600 TT1.BHC 427.800 SP.BHC 4785.000 MTEM.BHC 0.155 LLD.DIL 5.375 GR.DIL 0.068 HTEN.DIL 0.671 NPHI.CNL 3.649 NPOR.CNL 1269.278 CFTC.CNL 4615.000 MRES.CNL 55.700 TT1.BHC 294.400 SP.BHC 4615.000 MTEM.BHC 0.151 LLD.DIL -1.063 GR.DIL 0.068 HTEN.DIL 0.670 NPHI.CNL 4.159 NPOR.CNL 1215.208 CFTCoCNL 16.797 28.700 1045.112 20.344 20.151 1646.384 0.066 539.800 9.250 167.805 6.384 164.922 966.094 50.846 46.648 371.254 0.067 643.200 1.125 165.967 7.440 199.261 892.683 44.099 42.427 403.597 0.068 614.000 0.375 162.846 5.965 165.320 900.431 45.941 46.008 356.660 0.068 410.400 5.375 161.189 1.003 105.058 906.891 55.276 50.151 301.850 CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL 4.631 5175.000 0.197 2.186 3556.752 28.700 167.805 366.200 28.700 0.066 4.631 5080.000 0.152 4.214 1481 .940 164.922 165.967 445.000 164.922 0.067 4.626 4785.000 0.151 3.635 1365.045 199.261 162.846 432.800 199.261 0.068 4.624 4615.000 0.095 3.739 1255.843 165.320 161.189 300.400 165.320 0.068 4.622 4475.000 0.095 4.611 1286.812 105.058 LIS Tape Verification ListSng Schlumberger'AlaMka Computing Center CALS.CNL 4.622 TENS.CNL HTEN.CNL 906.891 DT.BHC TT3.BHC 409.200 TT4.BHC CAL1.BHC 4.378 TENS.BHC HTEN.BHC 906.891 DEPT. 11680.500 LLS.DIL CAL1.DIL 4.377 SP.DIL MTEM.DIL 159.644 MRES.DIL SMIN.DIL -999.250 SMNO.DIL TNPH.CNL 49.276 TNRA.CNL RCFT.CNL 334.403 CNTC.CNL CALS.CNL 4.622 TENS.CNL HTEN.CNL 881.574 DT.BHC TT3.BHC -999.250 TT4.BHC CAL1.BHC 4.377 TENS.BHC HTEN.BHC 881.574 END OF DATA 7-JUN-1993 10:22 4475.000 MRES.CNL 64.100 TT1.BHC 337.200 SP.BHC 4475.000 MTEM.BHC 0.148 LLD.DIL 0.063 GR.DIL 0.069 HTEN.DIL -999.250 NPHI.CNL 4.108 NPOR.CNL 1207.024 CFTC.CNL 4545.000 MRES.CNL 53.100 TT1.BHC -999.250 SP.BHC 4545.000 MTEM.BHC 0.068 409.600 -1.063 159.958 0.952 81.579 881.574 54.339 44.956 329.862 0.069 -999.250 0.063 159.644 MTEM.CNL TT2.BHC GR.BHC MRES.BHC CALS.DIL TENS.DIL MSFL.DIL RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL TT2.BHC GR.BHC MRES.BHC PAGE: 11 159.958 296.000 105.058 0.068 4.622 4545.000 -999.250 4.190 1207.210 81.579 159.644 -999.250 81.579 0.069 **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION · 001A0~ DATE '93~6 7 MAX REC SIZE ' 10 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · 001A07 DATE ' 93~06/ MAX REC SIZE - 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY tool string, and run in separate files. LIS TaDe Verification ListSng Schlumberger'Alaska Computing Center 7-JUN-1993 10:22 VENDOR TOOL CODE START DEPTH STOP DEPTH DLL 12548.0 CNL 12503.0 GR 12497.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (~T)' TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL(FT)- LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 11890.0 11890.0 11890.0 22-APR-93 5C0-423 1300 22-APR-93 2005 22-APR-93 12569.0 12562.0 11890.0 12522.0 1200.0 TOOL NUMBER AMS TCC GR CNL BHC BHC DLL DLL DLL $ AUXILLIARY MEASURMENTS TELEMETRY CARTRIDGE GAMM RAY CARTRIDGE COMPENSATED NEUTRON BOREHOLE SONIC CART. BOREHOLE SONIC SONDE DUAL LATEROLOG CART. DUAL LATEROLOG SONDE DUAL LATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN~: DRILLERS CASING DEPTHs(F?)' LOGGERS CASING DEPTH (FT)' BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/Q)' MUD VISCOSITY (S)' MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF RESISTIVITY (OHMM) AT TEMPERATURE MUD AT MEASURED TEMPERATURE (MT BOT O MUD FILTRATE AT()BHT ' MUD CAKE AT (MT): MUD CAKE AT()BHT ' i~EGF) ' . ~HT)' NEUTRON TOOL TOOL TYPE MATRIX: (EPITHERMAL OR THERMAL): AMS-AA 724 TCC-B SGC-SA 503 CNC-HA 398 SLC-UA 278 SLS-WA 2004 DLC-D 724 DLS-F 724 SRE-F 1729 8.500 11901.0 11890.0 ICL POLYMER 9.10 44.00 8.90 6.20 168.0 0.169 70.0 0.141 70.0 0.217 70.0 THERMAL SANDSTONE PAGE: 12 LIS TaDe Verification Listing Schlumberger A±aSka Computing Center 7-JUN-1993 10:22 MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: TOOL STRING CENTRALIZED WITH 1.2" TEFLON STANDOFFS. A 2' RUBBER HOLE FINDER WAS ALSO USED. DUE TO THE USE OF TEFLON STANDQFFS ON THE SONIC TOOL THE LOGGING SPEED WAS 1000-1200 F/H. WHICH IS MUCH SLOWER THAN USUAL TO ELIMINATE ROAD NOISE. THE FIRST LOGGING PASS HAD AN UNACCEPTABLE LEVEL OF TENSION PULLS ON IT. TO IMPROVE LOG QUALITY THE SECOND PASS WAS MADE WITH THE CALIPER CLOSED. THIS IMPROVED THE TOOL STICKING, BUT THERE WILL BE NO CALIPER OR MSFL DATA BECAUSE OF THIS. THE CNL USED THE MSFL CALIPER FOR HOLE CORRECTION ON THE REPEAT PASS, AND BIT SIZE ON THE MAIN PASS. THE CALIPER WAS CLOSED 2 TIMES ON THE REPEAT PASS TO GET THRU TIGHT SPOTS. DURING CLOSING ALL MSFL AND DLL DATA IS INVALID. # $ LIS FORMAT DATA PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 164 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS TaDe Verification Listing Schlumberger~Ala~ka Computing Center SET TYPE - CHAN ** 7-JUN-1993 10:22 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS ( HEX ) DEPT FT 599471 00 000 00 0 3 I 1 4 68 LLS DLR OHMM 599471 00 000 00 0 3 I 1 4 68 LLD DLR OHMM 599471 00 000 00 0 3 I 1 4 68 CALS DLR IN 599471 00 000 00 0 3 1 I 4 68 CALl DLR IN 599471 00 000 00 0 3 I 1 4 68 SP DLR MV 599471 00 000 00 0 3 1 1 4 68 GR DLR GAPI 599471 00 000 00 0 3 1 1 4 68 TENS DLR LB 599471 00 000 00 0 3 I 1 4 68 MTEM DLR DEGF 599471 00 000 00 0 3 1 1 4 68 MRES DLR OHMM 599471 00 000 00 0 3 I 1 4 68 HTEN DLR LB 599471 00 000 00 0 3 I 1 4 68 MSFL DLR OHMM 599471 00 000 00 0 3 1 1 4 68 SMIN DLR OHMM 599471 00 000 00 0 3 I 1 4 68 SMNO DLR OHMM 599471 00 000 00 0 3 1 1 4 68 NPHI CNR PU 599471 00 000 00 0 3 1 1 4 68 RTNR CNR 599471 00 000 00 0 3 I 1 4 68 TNPH CNR PU 599471 00 000 00 0 3 1 1 4 68 TNRA CNR 599471 00 000 00 0 3 I 1 4 68 NPOR CNR PU 599471 00 000 00 0 3 1 1 4 68 RCNT CNR CPS 599471 00 000 00 0 3 1 1 4 68 RCFT CNR CPS 599471 00 000 00 0 3 1 1 4 68 CNTC CNR CPS 599471 00 000 00 0 3 1 1 4 68 CFTC CNR CPS 599471 00 000 00 0 3 1 1 4 68 GR CNR GAPI 599471 00 000 00 0 3 1 1 4 68 CALS CNR IN 599471 00 000 00 0 3 I 1 4 68 TENS CNR LB 599471 00 000 00 0 3 1 1 4 68 MRES CNR OHMM 599471 00 000 00 0 3 I 1 4 68 MTEM CNR DEGF 599471 00 000 00 0 3 1 1 4 68 HTEN CNR LB 599471 00 000 00 0 3 I 1 4 68 DT BHR US/F 599471 00 000 00 0 3 1 1 4 68 TT1 BHR US 599471 00 000 00 0 3 1 1 4 68 TT2 BHR US 599471 00 000 00 0 3 1 1 4 68 TT3 BHR US 599471 00 000 00 0 3 1 1 4 68 TT4 BHR US 599471 00 000 00 0 3 1 1 4 68 SP BHR MV 599471 00 000 00 0 3 1 1 4 68 GR BHR GAPI 599471 00 000 00 0 3 1 1 4 68 CALl BHR IN 599471 00 000 00 0 3 1 1 4 68 TENS BHR LB 599471 00 000 00 0 3 1 1 4 68 MTEM BHR DEGF 599471 00 000 00 0 3 1 1 4 68 MRES BHR OHMM 599471 00 000 00 0 3 1 1 4 68 HTEN BHR LB 599471 00 000 00 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA DEPT. 12580.000 LLS.DLR 7.542 LLD.DLR 6.842 CAL1.DLR 5.982 SP.DLR -20.000 GR.DLR 52.652 MTEM.DLR 164.911 MRES.DLR 0.062 HTEN.DLR -136.243 SMIN.DLR 1.147 SMNO.DLR 2.020 NPHI.CNR 34.330 CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR 6.231 2280.000 0.809 3.000 LIS TaDe Verification Listing Schlumberger~Ala~ka Computing Center TNPH.CNR 32.032 TNRA.CNR RCFT.CNR 732.386 CNTC.CNR CALS.CNR 6.231 TENS.CNR HTEN.CNR -136.243 DT.BHR TT3.BHR 494.400 TT4.BHR CAL1.BHR 5.982 TENS.BHR HTEN.BHR -136.243 DEPT. 12500.000 LLS.DLR CAL1.DLR 8.016 SP.DLR MTEM.DLR 165.065 MRES.DLR SMIN.DLR 17.363 SMNO.DLR TNPH.CNR 27.184 TNRA.CNR RCFT.CNR 841.215 CNTC.CNR CALS.CNR 7.504 TENS.CNR HTEN.CNR 910.263 DT.BHR TT3.BHR 473.400 TT4.BHR CAL1.BHR 8.016 TENS.BHR HTEN.BHR 910.263 DEPT. 12400.000 LLS.DLR CAL1.DLR 7.929 SP.DLR MTEM.DLR 165.840 MRES.DLR SMIN.DLR 2.396 SMNO.DLR TNPH.CNR 29.196 TNRA.CNR RCFT.CNR 821.456 CNTC.CNR CALS.CNR 7.523 TENS.CNR HTEN.CNR 903.335 DT.BHR TT3.BHR 503.800 TT4.BHR CAL1.BHR 7.929 TENS.BHR HTEN.BHR 903.335 DEPT. 12300.000 LLS.DLR CAL1.DLR 8.109 SP.DLR MTEM.DLR 166.388 MRES.DLR SMIN.DLR 31.659 SMNO.DLR TNPH.CNR 25.797 TNRA.CNR RCFT.CNR 1176.218 CNTC.CNR CALS.CNR 8.462 TENS.CNR HTEN.CNR 1014.285 DT.BHR TT3.BHR 492.400 TT4.BHR CAL1.BHR 8.109 TENS.BHR HTEN.BHR 1014.285 DEPT. 12200.000 LLS.DLR CAL1.DLR 7.218 SP.DLR MTEM.DLR 166.233 MRES.DLR SMIN.DLR 4.610 SMNO.DLR TNPH.CNR 29.715 TNRA.CNR RCFT.CNR 883.463 CNTC.CNR CALS.CNR 7.720 TENS.CNR HTEN.CNR 943.128 DT.BHR TT3.BHR 623.000 TT4.BHR CAL1.BHR 7.218 TENS.BHR HTEN.BHR 943.128 7-JUN-1993 10:22 2.863 NPOR.CNR 2146.330 CFTC.CNR 2280.000 MRES.CNR 71.100 TT1.BHR 354.000 SP.BHR 2280.000 MTEM.BHR 12.594 LLD.DLR -20.000 GR.DLR 0.063 HTEN.DLR 38.993 NPHI.CNR 2.557 NPOR.CNR 2208.277 CFTC.CNR 5475.000 MRES.CNR 74.000 TT1.BHR 332.400 SP.BHR 5475.000 MTEM.BHR 8.009 LLD.DLR -7.125 GR.DLR 0.063 HTEN.DLR 5.320 NPHI.CNR 2.703 NPORoCNR 2327.250 CFTC.CNR 5270.000 MRES.CNR 75.950 TT1.BHR 349.800 SP.BHR 5270.000 MTEM.BHR 13.127 LLD.DLR -18.125 GR.DLR 0.063 HTEN.DLR 28.141 NPHI.CNR 2.358 NPOR.CNR 2946.893 CFTC.CNR 5500.000 MRES.CNR 73.767 TT1.BHR 340.400 SP.BHR 5500.000 MTEM.BHR 2.281 LLD.DLR -13.313 GR.DLR 0.064 HTEN.DLR 5.983 NPHI.CNR 2.719 NPOR.CNR 2511.653 CFTC.CNR 5345.000 MRES.CNR 101.050 TT1.BHR 429.800 SP.BHR 5345.000 MTEM.BHR 32.032 760.858 0.062 499.200 -20.000 164.911 12.302 55.736 910.263 28.409 27.382 881.396 0.063 493.400 -20.000 165.065 8.883 106.840 903.335 30.580 29.106 882.531 0.063 507.000 -7.125 165.840 13.375 87.756 1014.285 24.325 25.590 1220.690 0.063 503.200 -18.125 166.388 2.923 29.859 943.128 30.634 29.847 940.391 0.064 620.000 -13.313 166.233 RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR PAGE: 1 5 2223.540 52.652 164.911 355.200 52.652 0.062 7.504 5475.000 156.084 2.566 2275.030 55.736 165.065 343.467 55.736 0.063 7.523 5270.000 5.361 2.775 2416.792 106.840 165.840 348.600 106.840 0.063 8.462 5500.000 12.998 2.556 3071.448 87.756 166.388 355.200 87.756 0.063 7.720 5345.000 1.543 2.769 2592.885 29.859 166.233 427.200 29.859 0.064 LIS TaDe Verification Listing Schlumberger'Alafka Computing Center 7-JUN-1993 10:22 PAGE: 16 DEPT. 12100.000 LLS.DLR CAL1.DLR 7.330 SP.DLR MTEM.DLR 164.746 MRES.DLR SMIN.DLR 14.782 SMNO.DLR TNPH.CNR 20.325 TNRA.CNR RCFT.CNR 1481.081 CNTC.CNR CALS.CNR 8.279 TENS.CNR HTEN.CNR 987.694 DT.BHR TT3.BHR 537.200 TT4.BHR CAL1.BHR 7.330 TENS.BHR HTEN.BHR 987.693 DEPT. 12000.000 LLS.DLR CAL1.DLR 9.870 SP.DLR MTEM.DLR 163.570 MRES.DLR SMIN.DLR 2.291 SMNO.DLR TNPH.CNR 47.820 TNRA.CNR RCFT.CNR 334.848 CNTC.CNR CALS.CNR 7.784 TENS.CNR HTEN.CNR 1061.161 DT.BHR TT3.BHR 652.800 TT4.BHR CAL1.BHR 9.870 TENS.BHR HTEN.BHR 1061.161 DEPT. 11900.000 LLS.DLR CAL1.DLR 10.585 SP.DLR MTEM.DLR 160.374 MRES.DLR SMIN.DLR 1.872 SMNO.DLR TNPH.CNR 45.569 TNRA.CNR RCFT.CNR 395.937 CNTC.CNR CALS.CNR 8.136 TENS.CNR HTEN.CNR 964.728 DT.BHR TT3.BHR 601.600 TT4.BHR CAL1.BHR 10.585 TENS.BHR HTEN.BHR 964.728 DEPT. 11800.000 LLS.DLR CAL1.DLR 8.402 SP.DLR MTEM.DLR 158.999 MRES.DLR SMIN.DLR 0.781 SMNO.DLR TNPH.CNR 52.236 TNRA.CNR RCFT.CNR 329.079 CNTC.CNR CALS.CNR 7.924 TENS.CNR HTEN.CNR 929.139 DT.BHR TT3.BHR 405.467 TT4.BHR CAL1.BHR 8.402 TENS.BHR HTEN.BHR 929.139 DEPT. 11779.500 LLS.DLR CAL1.DLR -999.250 SP.DLR MTEM.DLR -999.250 MRES.DLR SMIN.DLR -999.250 SMNO.DLR TNPH.CNR -999.250 TNRA.CNR RCFT.CNR -999.250 CNTC.CNR 13.615 LLD.DLR -11.750 GR.DLR 0.065 HTEN.DLR 15.737 NPHI.CNR 2.095 NPOR.CNR 3140.016 CFTC.CNR 5460.000 MRES.CNR 85.300 TT1.BHR 364.600 SP.BHR 5460.000 MTEM.BHR 6.291 LLD.DLR -18.688 GR.DLR 0.068 HTEN.DLR 3.283 NPHI.CNR 3.891 NPOR.CNR 1381.429 CFTC.CNR 5105.000 MRES.CNR 101.700 TT1.BHR 465.600 SP.BHR 5105.000 MTEM.BHR 5.923 LLD.DLR -15.188 GR.DLR 0.067 HTEN.DLR 2.140 NPHI.CNR 3.747 NPOR.CNR 1559.688 CFTC.CNR 5040.000 MRES.CNR 98.300 TT1.BHR 426.200 SP.BHR 5040.000 MTEM.BHR 0.146 LLD.DLR -6.063 GR.DLR 0.066 HTEN.DLR 0.594 NPHI.CNR 3.784 NPOR.CNR 1250.173 CFTC.CNR 4720.000 MRES.CNR 56.000 TT1.BHR 260.200 SP.BHR 4720.000 MTEM.BHR -999.250 LLD.DLR -999.250 GR.DLR -999.250 HTEN.DLR -999.250 NPHI.CNR -999.250 NPOR.CNR -999.250 CFTC.CNR 16.005 26.961 987.693 20.609 20.838 1532.411 0.065 543.000 -11.750 164.746 6.456 168.891 1061 .161 51 .450 49.423 362.437 0.068 664.400 -18.688 163.570 7.383 202.864 964.728 48.290 44.884 424.580 0.067 605.600 -15.188 160.374 44.175 109.520 929.139 57.600 52.102 334.223 0.066 444.000 -6.063 158.999 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR MTEM.CNR TT2.BHR GR.BHR MRES.BHR CALS.DLR TENS.DLR MSFL.DLR RTNR.CNR RCNT.CNR GR.CNR 8.279 5460.000 5.174 2.197 3197.879 26.961 164.746 366.800 26.961 0.065 7.784 5105.000 0.857 3.929 1388.537 168.891 163.570 460.400 168.891 0.068 8.136 5040.000 0.419 3.808 1637.942 202.864 160.374 423.200 202.864 0.067 7.924 4720.000 0.094 3.952 1310.911 109.520 158.999 300.400 109.520 0.066 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification ListSng Schlumberger~AlaDka Computing Center 7-JUN-1993 10:22 PAGE: 17 CALS.CNR -999.250 TENS.CNR -999.250 MRES.CNR HTEN.CNR -999.250 DT.BHR -999.250 TT1.BHR TT3.BHR -999.250 TT4.BHR -999.250 SP.BHR CAL1.BHR -999.250 TENS.BHR -999.250 MTEM.BHR HTEN.BHR -999.250 -999.250 MTEM.CNR -999.250 TT2.BHR -999.250 GR.BHR -999.250 MRES.BHR -999.250 -999.250 -999.250 -999.250 END OF DATA **** FILE TRAILER FILE NAME : EDIT .003 SERVICE : FLIC DATE ' 93/ 7 MAX REC SIZE · 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME · EDIT DATE ' 93/06/ 7 ORIGIN : FLIC TAPE NAME : 93196 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · ARCO ALASKA INC.,PRUDHOE BAY,D.S. 3-36,50-029-22340-00 **** REEL TRAILER SERVICE NAME · EDIT DATE · 93/06/ 7 ORIGIN : FLIC REEL NAME : 93196 CONTINUATION # : PREVIOUS REEL : COMMENT ' ARCO ALASKA INC.,PRUDHOE BAY,D.S. 3-36,50-029-22340-00