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Home My WebLink About197-255 . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG . /);~,n,~,è~n i';,,!:,;,·,,;;; 1a. Well Status: DOil DGas D Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic ~ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/19/2006 197 -255 306-247 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 01/17/1998 50-029-22851-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 01/28/1998 PBU GNI-G2 4298' FSL, 681' FEL, SEC. 26, T11N, R15E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 1362' FSL, 353' FEL, SEC. 23, T11N, R15E, UM 51.2 Prudhoe Bay Field 1 Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2041' FSL, 303' FEL, SEC. 23, T11 N, R15E, UM 4164 + 4014 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 717300 y- 5956300 Zone- ASP4 7955 + 6979 Ft ADL 028323 TPI: x- 717558 y- 5958652 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 717588 y- 5959332 Zone- ASP4 None MD DYes ~No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: MWD, DIR, GR, SP, Caliper, RES, DEN, NEU, Sonic, RFT, USIT, CBT 22. CASING, LINER AND CEMENTING RECORD .,...' SETTING DEPTH MD SETTING DEPTH'TVD ~?~:i ./ 'COYY i/.. . .1 . '., "''š~1'' Wt.PERFT. GRÂDE Top BÖTTOM Top BOTTOM ;i; Å ,.'....; Y·/i. iY;i··,¡"¡;;. . 20" 94# H-40 Surface 80' Surface 80' 30" 260 sx Arctic Set (Aoorox.) 13-3/8" 54.5# L-55 1 L-80 30' 4137' 30' 3992' 16" 2451 sx Cold Set III 415 sx 'G' 9-5/8 47# L-80 27' 7938' 27' 6965' 12-1/4" 1540 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. i'ii'. ·I.JI3INGRÊ8~1?,; "·;i'.,.",. ", i)Y'i' ). ; './; Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 7", 29#, L-80 4150' - 4277' 4155',4181' MD TVD MD TVD 25. Aê,[),i;" "", Å;';"/Å ,Y .;4.;;',; ,', ','" "i'Y; ;i; yX /,.SX;; A ""..,~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ;'.;IC>, 6596' P&A with 62 Bbls Class 'G' 4164' Set CIBP 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection NIA Date ofT est Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL -BSL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). s.r:~:",iPS; if nono, state "nono", Non $¡¿~ { V "'n:;GD ; Form 1 12/2003 CONTINUED ON REVERSE SIDE G, 28. GEOLOGIC MARKER 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None", SV3 4066' 3935' None SV2 4274' 4101' SV1 4890' 4563' Ugnu 4 5668' 5160' Ugnu 1 6054' 5462' West Sak 1 6812' 6061' West Sak 2 7472' 6593' 30. List of Attachments: Pre Rig Summary report and a Well Schematic Diagram. 31. I hereby certify that the foregping is true and correct to the best of my knowledge. . 1 Signed Title Technical Assistant Date U ~ 1 ~ - Ú lo 197-255 306-247 Permit NO.1 A roval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 John Rose, 564-5271 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 TREE = CAMERON 6-3/8" WELLI;iEAD = FMC NSBB ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= . GNI-02 51' TES: KNOWN AS 4-62 IN PBAS; TIGHT SPOT NOT 4267'. IA CHEM INJ LINE. 1/4" SS OPEN ENDED CONTROL LINE STRAPPED TO OUTSIDE OF 7" TBG DOWN TO JOINT #50. 2669' 43 @ 4630' 6799' 6000'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" H TOPOF 13-3/8" CSG I -1 ES CEMENTER I -1CHEM CUTTBG (10/30/06) I -19-5/8" X 7" BKR SABL-3 PKR, ID = 6.062" I -15-11/16" BKRK-1 CIBPSET(10/29/06) I 113-3/8" CSG, 54.5#, K-55, ID = 12.35" I 4169' Minimum ID = 5.963" @ 4169' & 4252' MD - HES R NIPPLE 4172' -iT' PUP JOINT I 17" TBG, 29#, L-80, .0371 bpf, ID = 6.184' I 4183' 4181' -19-5/8" X 7 BKRSABL-3 PKR 4252' ÆRFORA TION SUMMARY REF LOG: SWS AfT 01/28/98 ANGLE AT TOP ÆRF: 35 @ 6898' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 6898 - 6918 C OS/21/06 4-1/2" 5 7230 - 7250 C 07/19/00 4-1/2" 5 7425 - 7435 C 03/13/98 4-1/2" 5 7435 - 7455 C 03/13/98 4277' -17" TBG TAIL WLEG I 4267' 1-1 ELMD TT LOGGED 02/28/98 PBTD I 7851' 19-5/8" CSG, 47#, L-80, ID = 8.681" I 7938' DA TE REV BY COMMENTS 03/13/98 ORIGINAL COM PLETION 07/16/04 JGMlKAK SET BKR IBP 07/06/05 NBJfTLH SET BKR IBPS 07/17/05 KSBfTLH PULL 3 IBPS 08/27/05 EZLfTLH LOWER IA MAASP OS/21/06 GJB/PJC ÆRFORATIONS DATE 10/30/06 11/05/06 11/06/06 REV BY COMMENTS JMF/PAG CIBP / TBG PUNCH / CHEM CUT SKBfTLH WAIVER SFTY NOTE DELETED DSMlTLH TREBWH CORRECTIONS PRUDHOE BAY UNfT WELL: GNI-02 ÆRMfT No: 1972550 API No: 50-029-22851-00 SEC 23, T11N, R15E, 303.05' FEL & 3237.22' FNL BP Exploration (Alaska) Digital Wellfi1e . . Page 1 of2 Well Events for SurfaceWell - GNI-02 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> GNI -> GNI-02 Date Range: 19/0ct/2006 to 15/Nov/2006 Data Source(s): DIMS, AWGRS Events Source Well Date DIMS GNI -02 11/15/2006 OlMS. GNI -02 11/14/2006 QIMS. GNI -02 11/13/2006 PIMS GNI -02 11/12/2006 PIMS GNI-02 11/11/2006 Â-WJiRS. GNI-02 11/10/2006 8W~RS GNI -02 11/10/2006 Description No summary information available in DIMS Pull XN plug w/SWS, L/D 7" tbg, M/U cleanout BHA, RIH, CBU, POH R/D SWS, ND, NU, C/O rams, Body test, M/U spear, Pull &L/D hanger & 2 jts tbg, M/U RTTS on tbg & Set @ 55', Test RTTS, R/U & test BOPE, Retrieve and LID RTTS Prep pad, Set mats, Spot rig & R/U, Pull XR plug w/SWS, Displace well to 9.8 brine, Set XN plug w/SWS, Test XN plug Move rig to GNI pad, Remove boosters, Wait on pad preparation T/I/O= 0/0/0. MIT- IA to 1000 psi. (PRE SIDETRACK) [PASSED on the first attempt] Held firm during the entire test. Pumped 1 bbl of 38* diesel to achieve test pressure. Well was 5/1 upon arrival. Final WHP= 0/0/0. WELL SHUT IN UPON ARRIVAL. RAN JUNK BASKET WITH 5.95" GUAGE RING TO 4100' MD. SET 5.935" WEATHERFORD ARROW-PAC PACKER ASSY W/ TAIL PIPE WITH MID ELEMENT AT 4073', 10' BELOW THE 7" CONNECTION BETWEEN JOINT 96 AND 97, USING CPST-AA. PRE-SET T/I/O = 0/0/0, POST SET T/I/O = 0/0/0. ***JOB COMPLETE*** DIMS GNI-02 11/10/2006 Skid rig floor, prepare rig for move, rig move from A-43 to GNI-02A Â-WGR5l. GNI-02 11/07/2006 T/I/O= 10/10/185. Temp= 51. WHP's post-bleed (pre-rig) call-in. Tubing pressure and lAP increased 10 psi. OAP increased 185 psi overnight. Bled lAP to slop trailer from 10 psi to 0 psi in 1 minute. During bleed tubing pressure tracked IA. Bled OAP from 185 psi to 0+ psi in 15 minutes. Monitored for 30 minutes. No change in tubing or lAP. OAP increased 120 psi. Final WHP's= 0/0/120. AWGRS GNI-02 11/07/2006 T/I/O =O/O/na Asked to re-test tubing hanger void. Tapped into test void and there was an unmeasurable amount of pressure on void. Pressured up to 5000 psi. Pressure was 4400 psi at 15 min and 4200 psi at 30 min. Initial test failed. Pressured up to 5000 psi a second time. Pressure was 4500 psi at 10 min. Pressure was 4700 psi at 15 min. and 4900 psi at 30 min. Tried to bleed test port off. Pressure wouldn't bleed off to safe level, so backed out high pressure bleeder tool and installed cap on test port. 8WGRS GNI-02 11/06/2006 T/I/O = 0/110/190. 51. No AL line. Bleed WHPs to 0 psi (pre- Rig Sidetrack). IA & OA fluid @ surface. Bleed IA & OAP to 0 psi (30 min). Monitor WHPs 30 min. No change in pressures, Final WHPs = 0/0/0. P.WGRS GNI-02 11/06/2006 T/IA/O (Pre-Rig Inspection) Flowline / Wellhead Measurements P.WGRS GNI-02 11/05/2006 T/I/0=135/135/205. Temp=SI. No A/L. Bleed WHPs pre-PPPOT(Rig ST). Both TBG & lAP increased 105 psi overnight. OAP increased 85 psi overnight. Bled IA from 135 psi to 0 in 5 mins. Bled OA from 205 psi to 0 in 15 mins. Kept an open bleed on both IA & OA while PPPOT was been down. Final WHP's 115/0/0. ,ll.WGRS GNI-02 11/05/2006 T/IA/OA = 51/150/100 (Pre-Rig Inspection) PPPOT-IC = Passed PPPOT-T = Failed Bled inner casing packoff to 0 psi., torqued lockdowns to 450 ft/lbs. Rigged up test equipment and pumped until clean fluids were achieved. Pressured up void to 3,800 psi. for 30 mins. = Passed. Bled tubing hanger void to 0 psi., torqued lockdowns to 550 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Tubing hanger void would only pressure up to 2,800 psi., could not get pressure to build. = Failed NOTE: Surface Casing (Mandral Fluted) Hanger out landed on load shoulder of Conductor Landing Ring. (May be "Jacking" out of ground. WIE informed. ) NOTE: Back pressure valve profile in tubing hanger is damaged, will not be able to set 6 3/8" type "J" Cameron plugs for workover. AWGRS GNI-02 11/04/2006 T/I/O= 30/750/250. Temp= 51. Bleed WHP's pre-PPPOT (Rig ST). IA FL @ surface. OA FL @ surface. Bled lAP to slop trailer from 750 psi to 0 psi in 10 minutes. During bleed tubing pressure dropped to 0 psi. Bled OAP from 250 psi to 0 psi in 5 minutes. Monitored for 30 minutes. Tubing pressure increased 25 psi. lAP increased 30 psi. OAP increased 120 psi. Final WHP's= 30/30/120. AW_~RS. GNI-02 11/04/2006 (CMIT Tx IA ) Travel Time to Milne Pt. AWGRS GNI-02 11/03/2006 T/I/0=450/500/250 ( CMIT Tx IA ) Bump up pressure with .3 bbls diesel. Intial http://digitalwellfi1e.bpweb.bp.comIW ellEvents/Home/Default.aspx 11/15/2006 Digital Wellfi1e . . Page 2 of2 ~ press.=960/1000/250. 15 min. press. = 900/930/250. 30 min press.=890/920/250. CMIT is a fail. / Retest CMIT Tx IA. Intial press.= 1010/1020/250. 15 min press.=920/980/250. 30 min press.=900/980/250. CMIT Tx IA is a pass. Retest CMIT Tx IA . Intial press = 2000/2000/400. 15 min press.= 1800/1810/380. 30 min press.=1760/1780/360. Test Failed on TBG side. Retest CMITTx IA. Initial press. = 2010/2000/400.= 15 min press.=1980/1990/400. 30 min press.=1950/1960/400. CMIT Tx IA is a pass.FWHP=360/400/180. 8W~RS GNI-02 11/03/2006 T/I/O=0/0/250 temp=s/i Circ-out, CMIT TxIA Pump 5 bbl meth spear followed by 366 bbls 9.3# brine down IA taking returns up tbg to open top. Pump 15 bbls diesel down tbg taking returns up IA to open top. U-tube tbg & IA. CMIT Tx lA-to 3500 psi- --Failed 4 times see mit sheets, FWHP's=0/0/400 Circ out well, CMIT TxIA to 3500 psi. Prepare for jobuload fluids, rig up, standby for vac truck & meth pup. ****Cont. job on next day WSR. **** (continued from 10-29-06) Assist e-line pressure up tbg to test plug (see mit data sheet) FWHP=0/20/250 CONTINUED FROM PREVIOUS DAY. WELL SHUT IN UPON ARRIVAL. TOOK SBHT SURVEY TO ENSURE PROPER TIMING FOR CHEMICAL CUT OPERATION. SET 5.687" BAKER K-l CEMENT RETAINER CIBP WITH MID ELEMENT AT 4164'. USED CPST-AA WITH SAFE ADAPTER. FIRED 18' , 2 STRAND STRING SHOT AT 4134' - 4152'. PUNCHED TUBING FROM 4106' - 4108' WITH 9 PJ 1606, HMX CHARGES. AVE EXIT HOLE = .25", MAX PENETRATION INTO OUTER PIPE = 0.05". CUT 7" TUBING AT 4150' WITH 5 3/4" PRS CHEMICAL CUTTER. USED TWO 2" X 72" CHEMICAL TUBES AND TANDEM 5.5" ANCHOR BODIES. ***job complete*** A.WGRS GNI-02 10/29/2006 T/I/0=0/0/250 Assist e-line MIT TBG (continued on 10/30/06) AWG,RS GNI-02 10/29/2006 WELL SHUT IN UPON ARRIVAL. TOOK SBHT SURVEY TO ENSURE PROPER TIMING FOR CHEMICAL CUT OPERATION. SET 5.687" BAKER K-l CEMENT RETAINER CIBP WITH MID ELEMENT AT 4164'. USED CPST-AA WITH SAFE ADAPTER. FIRED 18' , 2 STRAND STRING SHOT AT 4134' - 4152'. PUNCHED TUBING FROM 4106' - 4108' WITH 9 PJ 1606, HMX CHARGES. AVE EXIT HOLE = .25" ***JOB INCOMPLETE - CONTINUED ON 30-0CT-2006 AWGRS*** 8WGRS GNI-02 10/28/2006 T/I/0=0/0/270. Temp=SI. NO gas on pad. Bleed TBG & IA < 200 psi (e-line). TBGP & lAP at 0 psi on arrival. TBG FL 42'. AWGRS GNI-02 10/27/2006 ***WELL 5/1 ON ARRIVAL*** (pre_rwo) RUN 5.85" x 4' LONG CIBP DRIFTTHRU T.T. @ 4277' MD TO 6551' SLM. ***WELL LEFT 5/1*** 8WG,RS GNI-02 10/24/2006 ***WELL SHUT IN ON ARRIVAL *** (PRE RWO) NOT ABLE TO RIG UP / NO HANDRAILS ON WELLHOUSE ROOF ***WELL SHUT IN ON DEPARTURE*** AWG,ßS GNI-02 10/20/2006 CTU #6, P&A; ... Co nt' from WSR 10/19/06 ... Lay in 190 bbls 9.3 NaCI brine from 6200' to 3000'. Freeze protect well with 100 bbls 60/40 meth down to 2500'. Left 1300 psi trapped on well. *** Job Complete *** AWGRS GNI-02 10/19/2006 CTU #6, P&A; Standby for winds. MIRU. MU and RIH with 2.5" BDN. Tag at 7400' ctmd; adjust depth to 7374' elmd. PUH above perfs. Fluid pack well with 500 bbls 1 % KCL and establish injectivity down coil, 1400 psi at 1.5 bpm. Batch mix and lay in 62 bbls of 15.8 ppg cement from 7374' to 6595' elmd (estimate 4.0 bbls behind pipe). PUH to safety at 6000'. Hesitate 20 min and ramp pressure up to 1200 psi with 1.0 bbl; held solid. Estimated TOC is 6596' elmd. ... Job in Progress - Cont' on WSR 10/20/06 ... Well house roof does not have handrails or a cage on ladder. GNI- 01 and GNI-03 are not equipped with handrails or cages either. AWGRS GNI -02 11/02/2006 A WGBS GNI -02 10/30/2006 AWGRS GNI-02 10/30/2006 http://digitalwellfi1e.bpweb.bp.comIW ellEvents/Home/Default.aspx 11/15/2006 Doyon 14 BOP Test . l t:t 1 - 1--S 5 . Subject: Doyon 14 BOP Test From: "Rose, John G (FAIRWEATHER)" <John.G.Rose@bp.com> Date: Thu, 09 Nov 200610:58:32 -0900 To: Winton Aubert <winton ubert@ CC: "NSU, ADW Drlg <N <Greg .Hobbs@bp.com> in.state.ak.us> gRig14@bp. Winton, As the tubing hanger profile on the GNI-02 well is damaged to the point we cannot set our normal BPV and/or TWC, please note the attached document which details our plan for the NO tree and NU & test BOPE process which will allow us to begin the de-completion work on this well. If you have any questions or concerns, please advise. Thanks - JR «GNI-02A BOP Testing.doc» John G. Rose SP-Alaska Drílling Group Office 907/564-5271 Cell 907 i148-5223 Fax 907/564-4040 ~-_.-_._._- --_.__.__..._--------------_....__._-,_...._.~-~.._------"-'~ i:----------- --·-------------¡r-~-·------ -------------------------------·--1 i II Content-Description: GNI-02A BOP Testing.doc!, jGNI-02A BOP Testing.dodl Content-Type: application/msword ¡ ,; il Content-Encoding: base64 ,! l_=-=---=--===~~--==------==--=---==-- ------I_,__-==-------c------===--====------=====-=--==--=---===----~__==_=_=_~_ <"1'''>6 io..;;,.,¡^ :3~nb"\'JlJ~t[) ( c Irfl~' ,,"- "!.:' ".......'v\,; 1 ofl 11/9/2006 10:59 AM . . GNI-02A Barrier Issues f/Movina Ria on Well & ND Tree/NU BOPE (11/09/06) (Weatherford Arrow-Pac Packer/Tail Pipe Assembly w/XN Profile) As the BPV profile in tubing hanger on this well is damaged and we will not be able to set 6-3/8" type "J" Cameron plugs, please note the following plan as it relates to moving Doyon 14 onto this well and to proceed through the ND the tree and NU and test the BOP's process. 1. As additional pre-rig work for this well, set a Weatherford Arrow-Pac packer assembly w/Tail Pipe + XN profile on E-line through the tree in the 7" tubing just above the cut point at -4075' MD (-10' below the 7" connection between joints #96 and #97). With the plug in place, test from below to 1000 psi. a. WEG b. 4-1/2" XN Nipple (3.725" ID) w/XR Plug Installed (1-way check good f/6600 psi test f/below) C. -10' pup 4-1/2" d. Weatherford Arrow-Pac Packer (4" bore) (NOTE: This packer/tailpipe assembly will function as a standard BPV allowing 1-way circulation down the tubing string with a check-valve preventing flow back up the tubing. The actual length of the tailpipe assembly below the packer is not critical.) 2. Move Doyon 14 over the well, monitor well and check pressures. 3. RU Slick-Line and pull the XR Plug from the XN nipple to allow high rate circulation in both directions down the well. 4. Circulate out the freeze protect and 9.3 ppg brine and circulate the well to 9.8 ppg brine (hole volume = -300 bbls of 9.8 ppg brine - provides total kill-weight requirements for 4160' MD/4014' TVD). 5. Monitor well to confirm static/dead. 6. With Slick-line, install a Positive Pressure XN Plug (2-way check good f/5900 psi test f/above) in the XN profile in the packer/tailpipe assembly at 4085' MD and test from below to 1000 psi. (NOTE: This will convert the function of this packer/tailpipe assembly from a BPV to a TWC.) 7. ND tree. 8. NU BOP and test body to 2000 psi against the packer/tailpipe assembly. 9. Pull 7" tubing hanger and LD 2-4 joints of tubing. 10. Hang remainder of 7" tubing string on 9-5/8" storm packer and set at -100' MD (estimated buoyed weight of tubing = 1 03K Ibs) 11. Test BOP's to 4000 psi per the wellplan. 12. With Slick-line (2 runs), to pull the XN Plug from the XN profile. 13. Circulate well as required/monitor well. 14. Return to Well plan operations, i.e., continue to POOH w/tubing. 15. The joint of tubing with the Weatherford packer/tailpipe assembly can be returned to the Weatherford shop for retrieval of hardware. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 4 2006 REPORT OF SUNDRY WELL OPE~1IQlt,I~as Cons. Commission . f?f¿ 1/¡tJ¡j RECEIVED 1. Operations Performed: Anchora~ 0 Abandon 0 Repair WellO PIUR PerforationsD Stimulate 0 ther Alter Casing 0 Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate I&] Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 197-255 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceŒ 50-029-22851-00-00 7. KB Elevation (ft): 9. Well Name and Number: 51.20 GNI-02 8. Property Designation: 10. Field/Pool(s): ADL-028323 Prudhoe Bay Field I Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 7955 feet true vertical 6979.0 feet Plugs (measured) None Effective Depth measured 7851 feet Junk (measured) None true vertical 6896.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 49 20" 94# H-40 31 - 80 31.0 - 80.0 1490 470 SURFACE 3764 13-3/8" 72# L-80 30 . 3794 30.0 - 3709.0 4930 2670 SURFACE 343 13-3/8" 54.5# K-55 3794 - 4137 3709.0 - 3992.0 2730 1130 PRODUCTION 7910 9-5/8" 47# L-80 28 - 7938 27.0 - 6965.0 6870 4760 Perforation depth: "tAHNEI\ SED 2 0 2nnr 1(;). . '. .,./J . . i .¿ -. }",,\)-\..!t..~ Measured depth: 6898-6918,7230-7250,7425-7435,7435-7455 True vertical depth: 6131-6147,6399-6415,6555-6563,6563-6569 TubinR (size, Rrade, and measured depth): 7" 29# L-80 @ 25 - 4277 Packers & SSSV (type & measured depth): 9-5/8" Baker SABL-3 Packer @ 4181 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMSBFt SEP J 8 101)6 Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 --- - Subsequent to operation: 0 0 0 --- - 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒl Copies of Logs and Surveys run _ 16. Well Status after proposed work: Class II Cretaceous Disposal Well Daily Report of Well Operations_ ~ OilD GasD WAG 0 GINJD WINJD WDSPL[E 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. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr 306-136 Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~.~- .ß '/.,i f) ..... Phone 564-5174 Date 9/12/06 v -orm lU-4U4 KeVlsea 4/~UU4 L K :J 11\1 f\ L,. . . GNI-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/09/2006 ***WELL SHUT IN ON ARRIVAL*** TAG STICKY BTM @ 7374' ELM W/ 3.50" DRIFT. PERFS= 6,898' -7,455'. 476' OPEN PERFS, 81' COVERED. SAMPLE OF SANDY SCHMOO ***NOTIFY PAD OP WELL LEFT SHUT IN*** OS/24/2006 T/I/O=400/0/250 Injectivity test. (post perf) Pumped 25 bbls meoh, 200 bbls sea water, and 100 bbls meoh down tbg. Pumped at 4.7 bpm @ 2050 psi. Final WHP=650/0/250 OS/21/2006 PERF 4.5 HSD OMEGA POWERJET 6898-6918 5SPF OS/20/2006 ** WELL SHUT IN UPON ARRIVAL **** {pre ad-perf} DRIFTED W/ 5.00" CENT,SAMPLE BAILER ,TAGGED BTM @ 7373' SLM.{ M/T BAILER} { - 82' FILL ABOVE BTM PERF @ 7455'MD.} **** WELL LEFT SHUT IN**** 05/17/2006 TII/O=340NAC/220. Replace N2 cap in IA. IA FL near surface. Pressured up the control line to 1000 psi. Control line held pressure for 1 hour with no decrease. IA stayed on VAC. Final WHP's=340N AC/220 FLUIDS PUMPED BBLS 3 PT Surface Equipment 125 60/40 Methanol Water 200 Sea Water 328 TOTAL Page 1 , TREE = WELLHEAD = ACTUA TOR = · KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = MCEVOY MCEVOY 51' 2669' 43 @ 4630' 6799' 6000' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I 1 TOP OF 13-3/8" CSG I 113-3/8" CSG, 54.5#, K-55, 10 = 12.35" I Minimum ID = 5.963" @ 416 4252' MD - HES R NIPPLE 17" TBG, 29#, L-80, .0371 bpf, 10 = 6.184' ÆRFORA TION SUMMARY REF LOG: SWSArr01/28/98 ANGLE AT TOP ÆRF: 35 @ 6898' Note: Refer to Production DB for historical p SIZE SPF INTERV AL Opn/Sqz 4-1/2" 5 6898 - 6918 0 4-1/2" 5 7230 - 7250 0 4-1/2" 5 7425 - 7435 0 4-1/2" 5 7435 - 7455 0 19-5/8" CSG, 47#, L-80, 10 = 8.681" DA TE REV BY COMMENTS 03/13/98 ORIGINAL COMPLETION 07/16/04 JGM'KAK SET BKR IBP 07/06/05 NBJ/TLH SET BKR IBPS 07117105 KSB/TLH PULL 3 IBPS 08127105 EZUTLH LOWER IA MAASP OS/21/06 GJB/PJC ÆRFORATIONS GNI-02 SAFETY NOTES: KNOWN AS 4-62 IN PBAS; TIGHT SPOT NOTED@ 4267'. IA CH8\IIINJ LINE. 1/4" SS OPEN ENDED CONTROL LINE STRAPPED TO OUTSIDE OF 7" TBG DOWN O. OPERATING PRESSURE, MAX lAP = 1000 P = 1000 PSI (08/25/05 NOTICE TO TO JOINT #5 ·...LOWERED PSI, MAX OA CHANGE)'" - 3794' I 3794' I 4137' ~( ~ I 4148' J 8: ....... 4155' 1- ~ I I . I 4169' J 9'& I 4172' I 8: ~ 4181' I- I 4183' I ""-" I . . 4252' . - I 427T I I 4267' I erf data DATE 05/21/06 07/19/00 03/13/98 03/13/98 7851' I I 7938' I -1 ES C8v1ENTER I - 9-5/8" X 7" BKR SABL-3 A<R, ID = 6.062" I - 7" HES R NIP, 10 = 5.963" I -17" PUP JOINT I - 9-5/8" X 7 BKR SABL-3 A<R -i 7" HES R NIP, ID = 5.963" I -17" TBG TAIL WLEG I - ELMO TT LOGGED 02/28/98 PBTD I DATE REV BY COMMENTS PRUDHOE BA Y UNrr WELL: GNI-02 ÆRMrr No: '"1972550 API No: 50-029-22851-00 SEC 23, T11 N, R15E, 303.05' FEL & 3237.22' FNL BP Exploration (Alaska) (fù ;;;-?l r· Wß\ '1? r? ",.. . II !^\ .:1 ¡ ¡ """.." U:.. .. .!.' '.. \ i.'. ,.1 ~ r. t::v '" LflJ W ~ e f'mf? :·':IJ:¡L, II ~ fUr ~ i r \.'::!.) u e ,!T\ ,f A, ljJ\ D1 ff.n " u FRANK H. MURKOWSKI, GOVERNOR AI/ASHA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU GNI-02 Sundry Number: 306-247 Dear Mr. Wesley: 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, æ;~ Cathy P. Foerster Commissioner "? ^...ft- DATED thisØ,L day of July, 2006 Encl. . '" --- ¡ '-1'"1 - 05~") At. .11" nil Rt Gas ons. 1, Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate TITi~e Exte~orage 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: Wc, A- 5, Permit To Drill Number BP Exploration (Alaska) Inc, ~velopment ~xPloratOry 197 -255 r' 3, Address: D Stratigraphic Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22851-00-00 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 GNI-02 /' Spacing Exception Required? DYes 181 No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028323 51.2 Prudhoe Bay Field / Prudhoe Bay Pool 12.>: . r/> i/ ..:.>; ·'A't:I·':· ... ,..., .... .: ...·;r;....·.·'r./:·.:·,i .>. < Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7955 6979 7851 ./ 6896 None None Casinn Lenath Size MD r TVD Burst Collacse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 4107' 13-3/8" 4137' 3992' 2730 1130 Intermediate Production 7911' 9-518" 7938' 6965' 6870 4760 Liner Perforation Depth MD ~·I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 6898' - 7455' 6131' - 6579' 7",29# L-80 4277' Packers and SSSV Type: 9-5/8" x 7" Baker 'SABL-3' packer; packers and SSSV MD (ft): 4181' r' 9-5/8" x 7" Baker 'SABL-3' packer 4155' 13. Attachments: 14. Well Class after proposed work: vJ6!r- 181 Description Summary of Proposal D BOP Sketch D Exploratory ~evelopment Œ(Service D Detailed Operations Program 15. Estimated Date for AU9US~006 16. Well Status after proposed work: CommencinQ Operations: DOil DGas D Plugged 181 Abandoned 17. Verbal Approval: D~j/ DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564-5271 Printed Name Q9ve Wesley Title Senior Drilling Engineer Signature Á~/W !'/.L: ¿) ~ Date ?j3/cÇ:, Prepared By Name/Number. Phone 564-5153 Terrie Hubble, 564-4628 , , v Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:·'2{J (0 -,..;;4 7 ¡ÿ( Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: T.v; t- ISo P f- ro 4000 f~' /tffl 1-'0</ tJ {:oVIA.A- 10 - 40/ rt-ð ~Y\.I d Cot' ~ !Jz tv tÅ-6~ ~tl c:¡¿r - oz.Æ . Subsequent Form Required: lO - 407. Approved BV:r:;!/{l / ~--1 i APPROVED BY Date (~ 2IJ - 0" COMMISSIONER THE COMMISSION Form 1 0-403 Revised Ø"6/2006 Submit In Duplicate ~ V'I"'"11 CP;¡7--tð·-Oro /f¿ 7ß1/~ tJ\f STATE OF ALASKA '. ~ ALA. Oil AND GAS CONSERVATION COM.SION W , \ APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 \t.J (, A- 1/ 'L,e U-O 0 (, RECE\VED JUL 1 9 2006 C commission OR\G\NAl RBDMS BFl JUL 2 12006 ... e e Obp GL~. To: Winton Aubert - AOGCC Date: July 13, 2006 From: John Rose - BPXA GPB Rotary Drilling Subject: GNI-02A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of the GNI-02 Class 2 Ungu injector well. {hiS injector well is currently shut-in due to poor injectivity response and will be sidetracked later this year to a new Ungu injection target. GNI-02 was drilled and completed in 1998 with 13-3/8" surface casing to 4137' MD (SV-3). The 9-5/8" long string was run through the West Sak to 7938' MD and cemented to just below the surface casing shoe. During this cement job, an ES cementer was used to ensure the surface casing shoe/OA remained open. 7" tubing was run to 4277' MD to include a 1/4" open ended control line which was strapped to the tubing to 2000 ft to allow N2 to be placed /displaced from the inner annulus. The well was perforated 7425 - 7455' MD, later 7230-7250' MD and recently 6898-6918' MD. GNI-2 is part of the 3 injection well package which support the Grind & Inject operations on DS#4. Disposal on this well began in 1998. To P&A this well, the plan will be to place a balanced cement plug (15.8 ppg Class G cement) from the current TD back to 100' above the top ,,-/ perforation at 6898' MD (estimated TOC -6798' MD). - The current sidetrack plan for this well, is to make a whipstock exit of the parent GNI-02 wellbore in the existing 13-3/8" casing at the deepest depth possible below 2760' MD based upon the ability to cut and pull the existing 9-5/8" casing (to determine the actual cut point, a USIT log will be run in the 9-5/8" casing after Doyon 14 moves ,/ onto the well and pulls the existing 7" tubing from the planned cut point at 4150' MD). After a successful whipstock departure from the 13-3/8" casing, a 12-1/4" hole will be drilled to the final well TD at -8526' MD (top of the West Sak formation) where a new 9-5/8" casing string well be run from surface to TD and then cemented back to just below the sidetrack window in the 13-3/8" casing (the 9-5/8" X 13-3/8" annulus will be left "open" to allow some monitoring of down-hole injection activities). A new 7" injection string will then be run into the well for the final completion. The well will then be E-line perforated after the rig moves off the well. The GNI-02A sidetrack is currently scheduled for Doyon 14 beginning the second week of September, 2006. The pre-rig work for this sidetrack will be priority scheduled once Sundry approval has been obtained, Estimated Pre-Rig Start: Estimated Spud Date: 08/15/06 09/1 5/06 John Rose GPB Rotary Drilling Engineer Ph: 564-5271 CC: Well file Terrie Hubble / Sondra Stewman GNI-02 Application for Sundry e e GNI-02A Operations Summarv (07/13/06) Current Condition:. ./ The 3/06 tubing caliper log indicated 45% cross-sectional wall loss in tubing joints #1 & #11 (tubing collapse rating 0- / rated to 1845 psi). ./ M/T-IA to 1530 psi passed on 4/22/06. ./ Wellhead pressure test to 4000 psi passed on 7/13/05. ~ì ./ MIT-OA failed on 4/17/04 (LLR = 3.8 gpm at 2000 psi). (Note'!J1iho d fail as un-cemented annulus.) ./ Pore pressure estimate = -3130 psi @7432' MD, 6560' TVD = .2 pg. ./ The current cement bond log indicates cement stringers abov " e ES cementer at 4841' MD, therefore, a new US/T log must be run to confirm our 9-5/8" cut point. Pre-Ria Work: 1. Bleed OA & IA to 0 psi. PPPOT-T & IC. Function all LOS. 2. RU slickline and drift tubing to include a TO tag in preparation for the planned service coil P&A cement work. 3. Using service coil, P&A existing perfs by the displacement method using a balanced cement plug (see details below): A. RIH ~/ ~~e coil and confirm current TO (some attempt to clean-out "fill" may be pe.. rf. ormed if deemed necessary). B. Lay -42 ~I balanced cement plug (15.8 ppg Class G cement) f/PBTD to 100' above top perf (42 bbls equals the volu ßf9-5/8" casing f/7851, MD to 6798' MD). (NOTE: Last TO tag at 737~' [) on 5/20/06.) C. Allow cement to reach 1000 psi compressive strength and test cement plug to. ... 5 6si and record. 4. RIH and tag TOC w/E-line (record depth of tag). 5. Set permanent CIBP in 7" tubing just below upper packer at -4160' MD. 6. Jet cut tubing at -4150' MD (mid-9' pup above BOT packer at 4155' MD). 7. Fluid pack well with seawater by circulating the well through the tubing cut. 8. Bleed casing and annulus pressures to zero. 9. Freeze protect well to 2000' w/diesel. 10. Set a BPV and test to 1000 psi from tubing annulus. 11. Secure the well and level the pad as necessary. . '-. ~ ~ ~ ~ (:) ......... Ria Operations: 1. MI/ RU 2. Circulate out diesel freeze protection and displace the well to seawater. Install TWC. 3. Nipple down tree. Nipple up and test BOPE to 4,000 psi. Pull TWC. / 4. R/U. Pull 7" tubing from jet cut at 4150' MD. (Note: 14" SS open ended control line strapped to outside of 7" down to joint #50.) 5. MU 8-1/2" clean-out assembly and clean-out the 9-5/8" casing down to the top of the tubing stub at -4150' MD. 6. RU E-line and run USIT log to determine the cut point for the 9-5/8" casing. (NOTE: The original 9-5/8" cement bond / log on this well was run from TO back to 3900' MD indicates cement bond back to the log top at 3900', therefore, the cut point will most likely be above that point.) 7. RIH with 9-5/8" casing cutter and cut casing at the point as determined by the USIT log in Step #6. (NOTE: The bond log on the 13-3/8" indicates good 15.8 ppg G-slurry bond to -3150' MD with generally good bond (12.2 ppg Coldset III) back up to -1850' MD which is also the approximate base Permafrost.) 8. RU and pull the 9-5/8" casing from the cut point. 9. If the cut point on the casing is determined to be too high (above 2700' SS), remove additional 9-5/8" casing by either / washing-over the casing andtøfñ.~rrilling-Up the casing as required to establish a "minimum" depth KOP in the 13-3/8"/ casing from the SV6 shale at ~700' SS. 10. With an sufficient amount of 9- casing removed from the well, RIH w/13-3/8" clean-out assembly to include a 13-3/8" casing scraper to top of 9-5/8" stub in preparation to set EZSV for the planned 13-3/8" whipstock. 11. RIH with drillpipe and set 13-3/8" EZSV retainer just above 9-5/8" casing stub (max hole angle to 13-3/8" shoe = 35 degrees). 12. Pressure test 13-3/8" casing to 2000 psi for 30 minutes and chart. 13. P/U and RIH with 12-1/4" Baker bottom-trip anchor whip stock assembly. Orient whip-stock as desired and set on bridge plug. Shear off of whip-stock. 14. Displace the well to 9.3 ppg LSND. Mill the window and 20' new formation. Perform FIT to 11.1 ppg. 15. RIH w/12-1/4" DIR/GR/Res (real time) - Neu/Den/Sonic (recorded mode) drilling assembly and drill to planned TO at 8577' MD. 16. Circulate and condition the hole prior to POOH to run open-hole logs and run 9·5/8" casing. 17. Run open-hole log(s) (MDT) as required (may be drill-pipe conveyed based upon hole angle/conditions). 18. Make conditioning trip if necessary prior to running the 9-5/8" casing. 19. Run 9-5/8", 47#, L-80, BTC-M casing from surface to the final well TO (an ES cementer positioned in the 9-5/8" casing to be -10' below the window in the 13-3/8" casing. 20. Cement the 9-5/8" casing from TO to the base of the window in the 13-3/8" casing with 15.8 ppg class G cement bumping the plug on the cement job with mud. / N"\ ~ ~ V' 1t GNI-02 Application for Sundry e e 21. With the plug on the cement job bumped, continue to pressure up the casing to open the ES cementer (-3300 psi opening pressure required / will have a baffle adapter in the casing string above the float collar to allow the required opening pressure) and circulate the 9-5/8" x 13-3/8" annulus clear of excess cement with mud (this annulus will be left open to allow monitoring of injection activities). Close the ES cementer by pumping down the closing plug w/1300 psi over displacement pressure. 22. RIH and drill out the ES cementer and clean out the 9-5/8" casing to TO. 23. With the well cleaned out to TO, displace the well to clean 9.3 ppg NaCI brine (see MI procedure for mud to brine displacement). POOH. 24. Run cement bond logs as required. 25. R/U and run 7", 29#, L-80, BTC-M completion tubing with open-ended 3/8" SS control line to 1000'. (NOTE: Injection packer to be set -4959' MD/4565' TVD (-3370' above top perf) and will require waiver from AOGCC.) 26. Land the tubing & RILDS. 27. Set a TWC and test to 1000 psi. 28. Nipple down the BOPE. Nipple up the tree (new/re-furbished) and test to 5,000 psi. Pull TWC w/lubricator. 29. While taking returns up the annulus, pump -126 bbls diesel down the tubing to freeze protect the well to 2000' on both sides of the tubing followed by -38 bbls of inhibited seawater treated with enough inhibitor to treat -75 bbls of seawater which is the volume of the annulus from the base of the diesel at 2000' to the top of the injection packer at 4959' MD). (NOTE: 126 bbls of diesel plus the 38 bbls of inhibited seawater represent a volume less than the tubing volume from surface to the WLEG at 4999' MD.) With the combined 164 bbls of diesel and inhibited seawater in the tubing, shut down and U-tube the well through the tree to get the inhibited brine and 2000' of diesel to the annular side. 30. Drop ball & rod and set packer and individually test the tubing and annulus to 4000psi for 30 minutes and record each test. 31. Install BPV 32. Secure the well/ rig down and move off. Post-RiCl Work 1. RU slick-line and pull ball & rod to allow freeze protection of the tubing string. 2. Run tie-in logs and e-line perforate well. 3. Install well house and instrumentation. Well Coordinates: Surface Location: Proposed BHL: x = 717,300/ Y = 5,956,300 X = 715,800/ Y = 5,959,800 Z = 6660' TVDss Time and Cost: P10 Pmean/AFE P90 14.9 days 18.4 days 23.4 days $2,940,300 $3,630,000 Tangible ($1 ,097k), Intangible ($2,533k) $4,610,100 TiminCl: Estimated Pre-rig operations start date: Estimated Rig operations / spud date: 1 0/06 09/10/06 10/10/06 GNI-02 Application for Sundry TREE = WELLHEAD = ACTUA TOR = KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MD = Datum lVD = MCEVOY MCEVOY 51' 2669' 43 @ 4630' 6799' 6000' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" -i 1 TOP OF 13-3/8" CSG I 113-3/8" CSG, 54.5#, K-55, ID = 12.35" I Minimum ID = 5.963" @ 4169' & 4252' MD - HES R NIPPLE 17" TBG, 29#, L-80, .0371 bpf, ID = 6.184' I e GNI-02 4183' ÆRFORA TION SUMMARY REF LOG: SWS ArT 01/28/98 ANGLEATTOPÆRF: 35@6898' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 4-1/2" 5 6898 - 6918 0 OS/21/06 4-1/2" 5 7230 - 7250 0 07/19/00 4-1/2" 5 7425 - 7435 0 03/13/98 4-1/2" 5 7435 - 7455 0 03/13/98 1 PBTD I 7851' 19-5/8" CSG, 47#, L-80, ID = 8.681" I 7938' DA TE RBI BY COMMENTS 03/13/98 ORIGINAL COMPLETION 07/16/04 JGMlKAK SET BKR IBP 07/06/05 NBJITLH SET BKR IBPS 07/17/05 KSBITLH PULL 31BPS 08/27/05 EZLITLH LOWER IA MAASP OS/21/06 GJB/PJC ÆRFORATIONS DA TE REV BY COMMENTS SAF TES: KNOWN AS 4-62 IN PBAS; TIGHT SPOT NOTED 4267'. IA CHEM INJ LINE. 1/4" SS OPEN ENDED CONTROL LINE STRAPPED TO OUTSIDE OF 7" TBG DOWN TO JOINT #50. -LOWERED OPERATING PRESSURE, MAX lAP = 1000 PSI, MAX OAP = 1000 PSI (08/25/05 NOTICE TO CHANGE)- 1/4" SS Control Line Strapped to Top 50 Joints of 7" Tubing 4148' 4155' -19-5/8" X 7" BKR SABL-3 PKR, ID = 6.062" I 4169' -17" HES R NIP, ID = 5.963" I 4172' -i7" PUP JOINT I 4181' -l9-5I8" X7 BKRSABL-3 A<R 4252' 4277' -17" TBG TAIL WLEG I 4267' -i ELMD TT LOGGED 02/28/98 Last TO tag at 7373' SLM - 5/20/06 Last Injectivity Test = 4.7 BPM @2050 PSi w/Seawater PRUDHOE BAY UNrT WELL: GNI-02 ÆRMrT No: "1972550 API No: 50-029-22851-00 SEC 23, T11 N, R15E, 303.05' FEL & 3237.22' FNL BP Exploration (Alaska) TREE = McEvoy 7-1/16" WH = FMC 13-5/8" 5K ACTUA TOR = KB. ELEV = 9F. ELEV = KOP= Max Angle - Datum MD = DatumlVD= e e 51' GNI-02A Proposed 2669' 43 @ 4630' 6799' 6000' SS NOTE: The exact location of the window in the 13-3/8" casing will be determined by how much 9-5/8" casing can be successfully removed from the well. However, the cur- rent plan is to keep the 22' windpw below the upper grav- els which top at 2760' MD. / 3/8" SS Control Line Strapped to Top 1000' of 7" Tubing Open Annulus (13-318" x 9-5/8") 9-5/8" CSG, 47#, L-80, BTC-M - 8577' MD -13-3/8" CSG, 72#, L-80, ID=12.347" to 3794' MD -13-3/8" Whipstock - xxxx' MD EZSV - xxxx' MD / Top of 9-5/8" Stub - xxxx' MD 13-3/8" CSG, 54.5#, K-55, ID=12.35" to 4137' MD 4148' -IES CEMENTER I 4155' -9-5/8"X 7" BKRSABL-3PKR, ID = 6.062" I 4169' :17" HES R NIP, ID = 5.963" I 7" TBG, 29#, L-80, BTC-M - 4999' MD 17" TBG, 29#, L-80, .0371 bpI, ID = 6.184' 1-1 4183' HES R-Nipple (5.963" 10) - 4979' MD / IPBTD I -i 9-5/8" X 7 BKR SA BL-3 PKR -17" HES R NIP, ID = 5.963" I ÆRFORA TION SUMMARY REF LOG: SWSAfT01/28/98 ANGLEATTOPÆRF: 35 @ 6898' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 6898 - 6918 S -8/06 4-1/2" 5 7230 - 7250 S -8106 4-1/2" 5 7425 - 7435 S -8/06 4-1/2" 5 7435 - 7455 S -8/06 4277' -17" TBG TAIL WLEG I I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 7938' DA TE REV BY COMMENTS 03/13/98 ORIGINAL COMPLETION 07/16/04 JGMlKAK SET BKR IBP 07106/05 NBJITLH SET BKR IBPS 07/17105 KSBITLH PULL 3 IBPS 08/27105 EZLITLH LOWER IA MAASP 05/21/06 GJB/PJC ÆRFORATIONS DA TE REV BY COMMENTS PRUDHOE BA Y UNfT WELL: GNI-02 ÆRMfT No: "1972550 API No: 50-029-22851-01 SEC 23, T11N, R15E, 303.05' FEL & 3237.22' FNL BP Exploration (Alaska) PBD GNI-02 Change of Approved Sundry p_am , ~ -r- l-t;S e Subject: PBU GNI-02 Change of Approved Sundry Program From: "Bill, Michael L (Natchiq)" <MichaeI.BiII@bp.com> Date: Mon, 15 May 2006 13:38:58 -0800 To: winton_aubert@admin.state.ak.us CC: "Engel, Harry R" <Harry.Engel@bp.com>, "Vestal, Sharmaine V (SAIC)" <Sharmaine.Vestal@bp.com>, "Deckert, Steven L" <Steven.Deckert@bp.com> Winton, BP received approval of an Application for Sundry Approval for re-perforating a portion of the existing perforations in well PBU Grind & Inject disposal wells GNI-02 on 4/11/06 (see enclosed Sundry Number 306-136). We have since made several unsuccessful fill cleanout attempts to gain access to this interval to re-perforate the well. «GNI-2 Sundry ApprovaLtif» As a result of these unsuccessful attempts, we now wish to perforate new disposal intervals higher in the well, but within the approved disposal strata referenced in Area Injection Order 4E, Rule 2: "... Class II slurry injection from Grind and Inject processes may be disposed into strata defined as those which correlate with and are common to the strata found in the ARCO Sag River State No.1 well between the measured depths of 4270-6750 feet." We request to Change the Approved Program to perforate the following intervals to achieve sufficient injectivity for slurry disposal: Measured Depth ft True Vertical Depth ft 6818 - 6838 6898 - 6918 6066-6082 6131-6147 I will be out of town from 5/16 through 5/30. Please copy any correspondence and refer questions to Harry Engel at 564-4194 during that period. Mike Bill GPB Wells Group 907-564-4692 office 907-564-5510 fax ---- .__._-----------~-~_..~..._, " Content-Description: GNI-2 Sundry Approval.tifii GNI-2 Sundry Approval.ti(' Content-Type: image/tiff ii , ¡' , Content-Encoding: base64 II _ ____________m_____ __m______________ _______._______--==--~~ ------------.------------ - 1 of 1 5/15/2006 1 :41 PM Ir?. j... rm , ::::;¡ ! ¡ 'I I"'"'" ¡ ~ ~u; (, ..' r" ,,- H 3;1 H ~ ~~J e AI.~4iHA OIL AND GAS CONSERVATION COMMISSION Michael Bill Staff Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-661 0."1". h..~,~ìi'~¡0;i ; ~\;¡¡4'':'" .~- FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, GNI-02 Sundry Number: 306-136 ~ \0(\' '}J Dear Mr. Bill: 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 thisJL day of April, 2006 Encl. STrg o~'l~::KA ~rl 1/ /l)Ob RËCEit#~~·lj~)O(P A~~~~~~~G~~~~S~~~~~N¡~~~~~~L~1~IJt~ APR 11 / <- .. 20 MC 25.280 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): I 7851 6896.12 I None Size MD / TVD Burst Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Michael Bill Title Staff Engineer Signature .-.'.., ~ ,. :;..._ Phone 564-4692 Date COMMISSION USE ONLY 1. Type of Request: Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Suspend 0 Repair well D Pull Tubing D 51.2 KB 8. Property Designation: ADL-028323 11. Total Depth MD (ft): 7955 rTotal Depth TVD (ft): 6978.98 Length Casing Conductor Surface Production 80 4107 7911 20" 94# H-40 13-3/8" 72# L -80 9·5/8" 47# L-80 Perforation Depth MD (ft): 7230 - 7250 / 7425 - 7435 7435 - 7455 Packers and SSSV Type: Perforation Depth TVD (ft): 6398.9 - 6414.96 6555.28 - 6563.28 6563.28 - 6579.31 7" Baker SABL-3 Packer 7" Baker SABL-3 Packer 12. Attachments: Descriptive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: ç;:)o06 '<- Date: Perforate U Alas.f(ai~tI~ l:ias t,;ons.ott:\ør!tlliI. swn Stimulate D Time Extension DAnchoraga Re-Perf /' Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory 0 197-2550/ Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic 0 6. API Number: 50-029-22851-00-00 / Service ~ / 9. Well Name and Number: GNI-02 f""" 30 30 27 110 3992 6965 IJUnk (measured): I None Collapse 520 2670 4760 110 30 4137 30 7938 27 1530 5380 6870 Tubing Size: 7" 29# Tubing Grade: L-80 Tubing MD (ft): 25 - 4277 ./ Packers and SSSV MD (ft): 4155 4181 / 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Service ~ Abandoned 0 WDSPL ~ r Prepared by Sharmaine Vestal 564-4424 Michael Bill ". 4/10/2006 Conditions of approval: Notify Commission so that a representative may witness ISUndryNUmber:~ ",. t ~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test D Location Clearance 0 Other: Subsequent Form Required: ~) ~Ir / ~ Æ Approved by: ( / ~ / t1M V -./ , Form 10-403 Revised 712005 0 RIG I N A L RBDMS 8Fl APR 1 1 2006 COMMISSIONER APPROVED BY THE COMMISSION Date: 1- /Í .., b b Submit in Duplicate TREE WELLHEAD '" ACTUA TOR KB. ELEV '" BF KOP'" e GNI-02 MCEVOY MCEV OY 51' 13-3/8" CSG, 72#, L-80. ID'" 12,347" TOP OF 13-3/8" CSG Minimum 10 = 4252' MD - H 4183' SUMfv1ARY REF I_OG SWS AIT 01/28/98 A NGLE A T TOP PERF Note: Refer to Production DB SIZ SPF INTERV AL 4-1/ 7230-7250 '/2" 7435-7455 0 / DA TE REV BY COMMENTS 08/27/05 EZLlTLH LOWER Li\ fv1AASP IPBTD I 7938' DA TE REV 03/13/98 08/14/01 09/21/01 07/16/04 07/06/05 07/17105 SAFET OTES: KNOWN AS 4-62 IN PBAS; TIGHT SPOT NOTED @ 4267'. IA CHEM INJ LINE. 1/4" SS OPEN ENDED CONTROL LINE STRAPPED TO OUTSIDE OF 7" TBG DOWN TO JOINT #50. ***LOWERED OPERATING PRESSURE, MAX lAP = 1000 PSI, MAX OAP = 1000 PSI (08/25/05 NOTICE TO CHANGE)*** 4155' 4169' 4172' H T' PUP JOINT I 4181' 4252' PRUDHOE SA Y UNIT WELL: GNI-02 PERMIT No: 1972550 API No: 50-029-22851-00 SEC 23, T11 N. R15E, 303.05' FEL 3237,22' FNL BP Exploration (Alaska) ... Purpose: Perforations: Tubing: Packer: Min 10: PBTD: Last Tag: Last FCD: Max. Deviation: Fluid in well: Fluid in IA: Tie in Log: Latest H2S value: Current status: e e GNI-02 April 1 0, 2006 Re-perf, Perf Breakdown Cost Code: PBGNIWELL Restore disposal injection. / 7230-7250' MD (07/19/00); 7425-7455' MD (03/13/98) (ref: Schlumberger Array Induction Imager 01/28/98) 7" Tail @ 4277' MD Top 7" X 9 5/8" Baker SABL @ 4155' MD (Drlg) (10 = 6.00") Top R Nipple @ 4169' 5.963" 10, Btm R Nipple @ 4252' 5.963" 10 7851' MD (Drlg 02/01/98) 7458' MD SLM 03/20/06 CT FCD to 7454' MD 04/09/06 with 3.0" nozzle 43° @ 4630' MD; 36° at perfs Seawater, freeze protected with methanol Nitrogen blanket, Diesel to 2200', Seawater to packer Baseline Temperature Log - GR-CCL Jewelry Log 02/28/98 None taken. Expected level = 0 ppm based on seawater slurry , Active slurry injector. Timing: Target to complete by 04/17/06 Grind & Inject Plant: John Dumont/Jim Luhrs, 659-8419 G&I Engineer: Mike Bill, 564-4692 (w), billml@bp.com, 333-5395 (h) 1. Slickline Drift & Tag to ensure access to lower perforated interval 2. Re-perforate interval 7425 - 7445' MD / 3. Rig up to pump truck to pump methanol-water and seawater. 4. Pump at least 20 barrels methanol-water to ensure the well will take fluid. /' 5. Pump 200 barrels seawater at least 5 bpm. Max pressure 3500 psi. Record rate and pressure every 5 minutes. 6. Freeze protect well with 100 barrels methanol-water. ~/ G&I cycles between the three GNI wells, switching to the next well aft~lecting 20,000 cubic yards (8-10 days injection in each well). This work is requested before Apri~Vo allow the well to resume its normal injection cycle. Scheduling for this work should be confirmed Witn the G&I plant operator at 659-8419, pager 659-5100,2815. 2 MEMORANDUM State of Alaska TO: ~ ~ ~::"m.., 'Ç? "1'1 1\\ '1?A DLt Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve DATE: Wednesday, April 21, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC G&I-02 PRUDHOE BAY UNIT G&I-02 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv.::JBe- 4 z?; 04 Comm API Well Number: 50-029-22851-00-00 Insp No: mitCS040417140714 Inspection Date: 4/17/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: G&I-02 Type Inj. N TVD 4155 IA 0 1590 1540 1540 P.T. 1972550 TypeTest SPT Test psi 1038.75 OA 270 330 360 360 Interval Other (describe in notes) P/F 'P Tubing 350 360 360 360 Notes: Pretest pressures found stable. Well on 2 Year test cycle. Wednesday, April 21, 2004 Page 1 of 1 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 10/31/03 NO. 3017 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD H-19B _~ c[ ~ ~ ~ MEM PPROF & IPROF LOG 09129103 1 H-27A E~L'-~"~ '~ ~ MEM PPROF & IPROF LOG 10/01107 1 D.S. 1-10 1'"~-~'-'O~ PSP LDL 10125103 1 ;D.S. 15-23 }~ I - I ~ RST G~VEL PACK LOG 07/10/03 .s. LDL P1-17 f ~' ,~ '~;%'[ PROD PROFILE W/DEFT/GHOST 10/26/03 1 ~NI-02 ' ~' TE~P PROFILE/SBHPSURVEY 10/08/03 1 D.S. 6-16 j~~%~ LDL 10/12/07 1 P1-18A ~-~~ PROD PROFILE ~/DEFT 10/1~/07 1 D.S. ~-28A ~1 ~ I~ ~D~ 10/14/03 1 D.S. 12-20 ~-I~ LDL .', 10/21/03 1 2-32/SH-03 'L~,,O- [ ~, LDL 10~2~/07 1 Z.39 ~- ~ 10~6310~ RST-SlG~A 09/22/03 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. '" Anchorage, Alaska 99508 !?'~'.!~; i ....... ~';~ ,~.-'- ~i~ ~ ~.~ ;T. '~.=~' Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A-I-FN: Beth Received by:~~ .,,V~-,~ ,.[. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU' Tom Maunder Petroleum Engineer FROM' Leu Grimaldi Petroleum Inspector TO: Cammy O. Taylor C_C< DATE' Chair SUBJECT' Mechanical Integrity Tests Grind & Inject pad ~I~-D'~'> GNI-02 Prudhoe Bay Unit Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial t5 Min. 30 Min. We.,I tiN,'02"' Type ,~j. ls~ Not~'I'T.v.D. I' 4~Sg'lTubing ! 1t40 '1 1140' I' 1:1~O'''j'' ! v' P.T.D.I 197'255Typ~testIP '1:l-est PS~I ~500 ICasingI '~ ,, '1' 1640,. I ~6~5"! !60s !P/F' I' P~' ' Notes' Ground mud slurry, Observed Pretest for 20 mins. Post test dropped annulus to 640, observed for 20 mins "OK Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I arrived to find the DHD crew rigged up and ready to test this well. The annulus was presured up to 1640 psi and lost 35 psi over the next thirty minutes (Non-Linear).Atthough these pressure met the 500 psi minimum Tubing/Casing differential, we had time while we rigged up to test the next well. I had the crew drop the annulus pressure to 640 psi which I observed unchanged for twenty minutes. I observed the pressure up of the casing on GNI-01 but had to leave to check on the H-21 incident. I left the paperwork for GNI-01 with Mike Eagling and allowed for him to finish that test. M.I.T.'s performed: ~_ Attachments: None Number of Failures: None Total Time during tests: 3 hours cc: Anders/Yeaqer MIT report form 5/12/00 L.G. MIT GNI-02 4-17-02 LG.xls ~SG^NNED JUN g & ?_002 5/23/02 bp Memorandum To: G. McBdde/J. Smart GPB Well Ops Team Leaders From: Mike Bill Disposal & Regulatory Compliance Engineer Date: March 23, 2001 PECT: F58GR! Cap_Sust_ FCO_Tag TD_Re- Perf Est. Cost: $40,000 Subject: .G,.,NI-02 CT FCO; SL D.r. jff& ,Ta;;: Repe,rf 1. C 2. S 3. E CT Fill Cleanout to expose lower perfs - reverse circulate, motor if necessary Slickline drift/tag of well GNI-02. (Note: solids may still be on bottom of pipe.) Re-perforate lower interval (7435-7455 ff MD). Request 4-1/2 gun, 5tB charge, 5 SPF. Background: While injecting slurry on 03~06~01 into well GNI-02, the G&I plant was shut down due to a pipeline leak. Solids settled across the perforations. A CT FCO attempt was made to expose the perfs and re-initiate injection (03/14 & 15). While CT reached as deep as 7500 ft, they were unable to reverse deeper than 7362' CTM. A motor may be required. Solids are probably still packed in and above the perforations. If injection cannot be restored during a FCO, a re-perf of the lower interval will be required. The last time the well was plugged, it began to flow during a FCO while reversing. While there are two sets of perforations, it is likely only the lower set of perfs takes fluid. Justification/Priority/Timing: G&I cycles injection between the 3 GNI wells, switching to the next well after injecting 25,000 cubic yards (+/- 2 weeks injection in each well). The latest slurry cycle began in GNI-3 on 3/18/01. We need to begin using well GNI-2 by April 15 if possible, to reduce dependence on the other two wells. Well: Perforations: Tubing: Packer: Min ID: PBTD: Last Tag: Max. Deviation: Fluid in IA: Tie-In Log: Last Downhole Op: Latest H2S value: Current status: GNI-02 7230-7250', 7425-7455' MD (ref: Schlumberger Array Induction imager 1/28198) 7" Tail @ 4277' MD Top 7"X 9 5/8' Baker SABL-3 @ 4155' MD (Drlg) Top "R' Nipple @ 4169' MD (Drlg), ID=5.963' Bottom "R" Nipple @ 4252' MD (Drlg), ID=5.963" 5.15" drift stopped @ 4267' MD, 4.75" drift passed to 4400'MD 7851' MD (Drig 02101198) 7362' MD on 03/15/01, CTM 43° @ 4630' MD; 36° at perfs N2 blanket, Diesel to 2000 ft, Seawater to packer Static Temperature/Jewelry Tie-in Log 2/28198 CT FCO 03/15/01 None taken. Expected level = 0 ppm based on seawater slurry Shut-In slurry injector- freeze protected For questions or comments please call Mike Bill at 564-5789(w) or 333-5395(h) or 240-8033 (cell). Well File Mike Bill Willv Friar Schlm er r Typical 4 1116" BOPE Set-Up and attachment for Service Coil Units BOP Oo, o0op~ wP) Blind/Shear Rams Blind/Shear Rams Slip Rams Pipe Rams Pumpi~ Sub ('lO, O00psi WP) Two Gate Valves Wellhead Swab Valve Win~ Valve Master Valve Subject: BP service Coil Tubing BOP Sketch Date: Tue, :3 Apr 2001 20:22:10 +0100 From: "Rauf, Paul C" <RaufPC@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Gantt, Lamar L" <GanttLL@BP.com> Tom, Here is the latest / revised BOP sketch for our CT service units. Sorry for the confusion. <<Newest Service CT BOP,pdf>> pcr Paul C. Rauf Technical Assistant, BPXA Drilling & Wells Office: (907) 564-5799, Cell: 240-8041, cube 889B Email: raufpc@bp, com i Name: Newest Service CT BOP.pdfi ~Newest Service CT BOP.pdf~ Type: Acrobat (application/pdf) i Encoding: base64 1 of 1 4/3/01 12:41 PM STATE OF ALASKA --~ .... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 51 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 981' FNL, 681' FEL, Sec. 26, T11 N, R15E, UM (asp's 717298, 5956300) GNI-02 At top of productive interval 9. Permit number / approval number 4380' FNL, 410' FEL, Sec. 23, T1 1N, R15E, UM (asp's 717514, 5958187) 197-255 At effective depth 10. APl number 50-029-22851 At total depth 11. Field / Pool 3237' FNL, 303' FEL, Sec. 23, T11 N, R15E, UM (asp's 717586, 5959332) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 7955 feet Plugs (measured) Tagged PBTD @ 7358' on 2/01/2001. true vertical 6979 feet Effective depth: measured 7358 feet Junk (measured) true vertical 6502 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 260 Sx AS 80' 80' Surface 4086' 13-3/8" 2451 sx cs III & 415 sx Class G 4137' 3992' Production 343' 9-5/8" 154o sx Class G 7938' 6965' Perforation depth: measured 7230' - 7250'; 7425' - 7455'. ~,(~ %_=_. -.r~_.¢ .~ ~ %~' ~'~' true vertical 6399' - 6415'; 6555' - 6579'. '~' Tubing (size, grade, and measured depth 7", 29#, L-8O Tbg @ 4183' MD. Alask8 0ii & Gas Cor, s. Commission Anchora9e Packers & SSSV (type & measured depth) 9-5/8 X 7 BAKER SABL-3 PACKER @ 4181' MD; 9-5/8" X 7" BAKER SABL-3 PACKER @ 4181' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: February 13, 2001 16. If proposal was verbally approved Oil__ Gas__ Suspended Name of approver Date approved Service Disposal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Bill @ 564-5789. Signed ~~'~ Title: Disposal & Regulatory Compliance Engineer Date Mike Bill Prepared by Paul Rauf @ 564-5799. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Appro_val n.c. Plug integrity __ BOP Test ~ Location clearance[ - Mechanical Integrity Test__ Subsequent form required lO- Approved by order of the Commission D Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp Memorandum To: AOGCC Date: February 07, 2001 From: Mike Bill Disposal & Regulatory Compliance Engineer Cap_Sust_ Tag TD_Re-Perf Subject: GNI-02 SL Drift & Ta.q; Reperf 1. S 2. E Slickline drift/tag of well GNI-02. (Note: solids may be on bottom of pipe.) Re-perforate upper interval (7230-7250 ft MD). Request 4-1/2 gun, 51B charge, 5 SPF. Background: While injecting slurry on 11/19/00 into well GNI-02, the G&I plant shut down. An attempt to resume injection into the well after 1 hour was unsuccessful due to solids settling across the perforations. Two CT FCO attempts have been made to clean out the well and re-initiate injection (12/22/00 and 01/30/01). Sufficient injectivity was not re-established after the latest FCO probably due to solids packed in the perforations (0.6 bpm at 2900 psi). The upper set of perforations was added 7/19/00, but the lower set of perfs continued to take all of the injection. We would like to initiate injection into the upper perforations at this time. J ustification/P rio rity/Ti ming: G&I cycles injection between the three GNI wells, switching to the next well after injecting 25,000 cubic yards (about 2 weeks for each well in the cycle). The latest cycle began in GNI-3 on 2/1/01. We need to begin using well GNI-2 as soon as possible, by March 1, to reduce dependence on the other two wells. Well: Perforations: Tubing: Packer: Min ID: PBTD: Last Tag: Max. Deviation: Fluid in IA: Tie-In Log: Last Downhole Op: Latest H2S value: Current status: GNI-02 7230-7250', 7425-7455' MD (ref: Schlumberger Array Induction Imager 1/28/98) 7" Tail @ 4277' MD Top 7"X 9 5/8" Baker SABL-3 @ 4155' MD (Drlg) Top "R" Nipple @ 4169' MD (Drlg), ID=5.963" Bottom "R" Nipple @ 4252' MD (Drlg), ID=5.963" 5.15" drift stopped @ 4267' MD, 4.75" drift passed to 4400'MD 7851' MD (Drlg 02/01/98) 7490' MD on 01/30/01, CTM 43.0 @ 4630' MD; 36.0 at perfs N2 blanket, Diesel to 2000 ft, Seawater to packer Static Temperature/Jewelry Tie-in Log 2/28/98 CT FCO 01/30/01 None taken. Expected level = 0 ppm based on seawater slurry Shut-In slurry injector - freeze protected to 2500 ft. fEB0 Alaska Oil & Gas Cons. Cornmission Anchorage For questions or comments please call Mike Bill at 564-5789(w) or 333-5395(h) or 240-8033 (cell). 6 5 4 2 I · i iii~ I . I COILED TUBING UNIT BOP EOU 1 PMENT 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 51:H:)OPSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS $. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 ..... ~,-. C-"ommis$ion ] Anchorage i~ HIREL ]NE BOP EOUIP,FIEN? __ 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANC; ~. 501:)0 PSI WIRELINE RAMS (VARIABLE $12E) 3. 5000 PSI 4 1/6" L UBRICAIOR 4. 5000 PSI 4 1/6" fLOW TUBE PACK-orr ARCO ALASKA, INC. Tubing Liner Casing 4148' E-S Cementer PKR 4169' MIN ID = 5.963' (7"HES R Nipple) NIP OTHER PKR NIP TTL Perf Perf A Prudhoe Bay GNI-0; GNI-02 : , : :: :i :i APl: 500292285100 Well Type: DISP Angle @ TS: deg @ SSSV Type: Orig Compltn: 3/13/98 Angle @ TD: 37 deg @ 7955 Annular Fluid: 6.8 Diesel/8.5 Last W/O: 2/12/98 Rev Reason: Tag Seawater Reference Log: SWS AlT Ref Log Date: 1/28/98 Last Update: 1/21/99 Last Tag: 7475 TD: 7955 ftKB Last Tag Date: 2/11/99 Max Hole 43 deg @ 4630 Angle: Depth AnnotatiOns ' , ,, :, ': :,]:], Depth Comment 4148 4148' E-S Cementer 4169 4169' MIN ID = 5.963' (7"HES R Nipple) GeneralNOtes: :: ;: , : ::: :;:: ;::: ::::::: Date Note KNOWN AS 4-62 in PBAS; Tight spot noted 02/06198 @ 4267' IA CHEM IN J-LINE: 1/4" SS open ended control line strapped to outside of 7" tbg down to joint #50. TTL ELM @ 4267: ELM Tubing Tail - 2/28/98 SWS GRICCL Other (plugs, equiP, etC.). JEWELRY : : : :: ::;;:: :: :: :::: Depth TVD Type Description ID 4155 4007 PKR 9-5/8" x 7" Baker SABL-3 Packer 6.062 4169 4018 NIP 7" HES R Nipple 5.963 4172 4020 OTHER 7"Pup Joint 6.184 4181 4028 PKR 9-5/8 x 7 Baker SABL-3 Packer 6.000 4252 4084 NIP 7" HES R Nipple 5.963 4277 4103 TTL 7" Tubing Tail W/L Re-entry Guide 6.125 Casing Strings, Ail: : :: : ,::] ::] ::::: ::: Size Weight Grade Top Btm Feet Description 13.380 72.00 L-80 0 3794 3794 Casing 13.380 54.50 K-55 3794 4137 343 Casing 9.630 47.00 L~80 0 7938 7938 Liner Tubing Strings - All : :: ::: : :: : : : Size Weight Grade Top Btm Feet Description 7.000 29.00 L-80 0 4183 4183 Tubing Perforations sUmmary: i ;i : : i Interval 'FVD Zone StatusFeetsPF Date Type cOmment 7425- 7455 6555- 6579 O 30 5 3/13/98 IPERF FEB 0 ? 200! Alaska Oii& Gas Cons. Commission Anchorage Subject: FW: GNI-02 FCO, Tag, Reperf Request Date: Sat, 24 Mar 2001 01:09:21 -0000 From-"Rauf, Paul C" <RaufPC@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Bill, Michael L" <BilIML@BP.com> Tom, Per our phone conversation this afternoon, could you reactivate the sundry application for GNI-02 for reperforation. Thanks pcr .... Original Message .... From: Bill, Michael L Sent: Friday, March 23, 2001 3:04 PM To: Rauf, Paul C Subject: FW: GNI-02 FCO, Tag, Reperf Request Paul, You get to say "i told you so!!" on this one. Below is the request I just sent to the slope to clean out GNI.02 once again. We finally got it back on line in eady March after several fill cleanout attempts and it plugged again when we shut down for the G&I pipeline leak. This request includes a re-perf request in case we can't get it back with the FCO. Please submit a sundry application for the re-perf. It should be identical to the last one you submitted on this well and then cancelled at my request. Thanks, Mike Bill, BPXA Drilling & Wells Office 907-564-5789; Fax 907-564-5510, Cell 907-240-8033 biliml @ bp.corn -----Original Message .... From: Bill, Michael L Sent: Friday, March 23, 2001 1:23 PM To: G ANC We//work Program; GPB, Wells Tech Aide Cc: Friar, William L; Barrel, Paul; Schmoyer, Al; Friar, William L; Rossberg, R Steven; EOA, Waste G&I Plant; EOA, Waste Mgmt Project Mgr; GPB, WL & Completion Supervisor Subject: GN/-02 FCO, Tag, Reperf Request Enclosed is a request for a reverse CT fill cleanout (may require motor), a slickline tag and, if injection is not restored, reperforation of a portion of the lower perforated interval in slurry disposal well GNt-02. Details are included in the request. <<GNI-2 FCO, Tag, Reperf 03-23-01.doc>> Mike Bill, BPXA Drilling & Wells Office 907-564-5789; Fax 907.564-5510, Cell 907-240-8033 billml @ bp.corn I of 2 3/28/Ol 2:03 PM STATE OF ALASKA A~A~KA OIL AND GAS CONSERVATION COMMISSION 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 elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 51 feet 3. Address Explorato~__ 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 981' FNL, 681' FEL, Sec. 26, T11 N, R15E, UM (asp's 717298, 5956300) GNI-02i At top of productive interval 9. Permit number / approval number 4380' FNL, 410' FEL, Sec. 23, T1 1 N, R15E, UM (asp's 717514, 5958187) 197-255/approval # 300-167 signed 6/27/2000 At effective depth 10. APl number 50-029-22851 At total depth 11. Field / Pool 3237' FNL, 303' FEL, Sec. 23, T1 1N, R15E, UM (asp's 717586, 5959332) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 7955 feet Plugs (measured) PBTD tagged (7/18/2000) @ 7469' MD. true vertical 6979 feet Effective depth: measured 7469 feet Junk(measured)ORIGINAL true vertical 6591 feet Casing Length Size Cemented Measured Depth True vertical Depth · Conductor 80' 20" 260 Sx AS 80' 80' Surface 4086' 13-3/8" 2451 Sx CS III & 415 sx Class G 4137' 3992' Production 343' 9-5/8" 154o Sx Class G 7938' 6965' Perforation depth: measured 7230' - 7250'; 7425' - 7455'. JUL 2 8 true vertical 6399' - 6415'; 6555' - 6579'. ~aska 0i4 ® "*~" ~¢'~--'~ ~:' ..... Tubing (size, grade, and measured depth) 7". 29#, L-80 Tbg @ 4183' MD. Packers & SSSV (type & measured depth) 9-5/8" X 7" BAKER SABL-3 PACKER @ 4155' MD; 9-5/8 X 7 BAKER SABL-3 PACKER @ 4181' 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 Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 27141 1428 Subsequent to operation (Shut in) - 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,¢;~- ~ Title: Disposal / Rog Compliance Engineer Date Mike Bi// Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE .... GNI-02i '~--~ DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 4/21/2000: 7/17/2000: 7/18/2000: 7/18/2000: MITIA to 1500 psi - passed. RIH & performed FCO f/7455' to 7535' MD. RIH & tagged PBTD @ 7469' MD. MIRU ELU. PT'd BOP / Riser to 3000 psi. RIH w/perf guns & shot 20' of Add Perforations @: 7230' - 7250' MD (Ugnu Zone ) Reference log: AlT 1/28/1998. Used 4-1/2" carriers & all shots @ 5 SPF, random orientation, 72° phasing, & balanced pressure. POOH w/perf guns. ASF. RD. GNI-02 will be brought back online in August of 2000. This work completes approval number 300-167 dated by AOGCC on 6/27/2000. Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Alter o'~g _ Change approved pto;~rcnm __ Abondon _ Suspend _ Op~icrSoc. t klhuk:~v,,-n _ t~epCar well _ 1Mugging _ Iime extension _ Pull tubing_ Varicmce _ Pecforgte _X R~nter m.~!cended welt __ Stimutate __ OLhez _ Name of Operator: ARCO Alaska, Inc. Address: P.O. Box 100360 Anchorage, AK 99510~D360 Lock,on o! we]] at surface: 4298' NSL, ~81' WEL, Sec 26, T/IN, R15E, UM At top of productive interv~: 000' NSL, 410' WEL, Sec 23, TllN, R15E, UM At effective depth: At total depth: 2040' NSL, 300' WEL, Sec 23, TllN, R15E, UM 5. Type of Welh Develccxnent _ Strala~cE~c _ 6, Dcu%~ of elc~va'don (DF or KB feet): 51.2' RKB 7. Unit or Property: Pmdhoe Bay Unit 8. We]] numker: 9. ~rmit nun~ber: 97-255 10. API number: 50-029-22851 l I. Field/Pooh Prudhoe Bay Oil Pool 12. Present well oondi~fon summary Tot~ Depth: measured true vertical 7955 feet 6979 feet Effective Depth: measured 7851 feet true vertic~ 6896 feet Plugs (measured) Conductor 80' 20" 260 SX Arcticset 80' Su~aoe 4107' 13-3/8" 2451 SX Cold Set III 4137' & 415 Sx Class G Production 7911' 9-5/8" 1540 Sx Class G 7938' ~edoration Depth measured 7425 - 7455' true vert/cal 6555 - 6579' Tree verti¢~ ~ 80' 3992' 6965' , !i 2 3 2uvu Tubing (s~ze, grade, and measured depth) 7", 29#, L-80, Tubing @ 25'-4181'MD; 7", 29#, L-80, Tubing @ 4183'-4277' MD. Packers and SSSV (type and measured depm) 9-5/8 X 7" Baker SABL-3 Packer @ 4155' MD; 9-5/8 x 7" Baker SABL-3 Packer @ 4181' ME. 13, Attachments Description summgry of proposal _X Detailed opercrtions program _ BOP sketch _X 14. Estimated date for commencing opera,on June, 2000 16. I~ proposol was verbally approved Nome of aprxover Date approved 15. statusof well ¢lossiftco~on Oil_ Service Dk%pos~ Well_ 17. Ihereb, y c~rDy th~t ?e torgoing is true and correct to the best of my knowledge. (~0Es,rjoN5 ; M~k¢ B;ll, Signed '"~"~'~~;~-,. - ,~-)F' '~[" ~.~-~/~"/' "'"¢-' '~ Title: Engineering Supervisor~-v ~., ~.f,, J FOR COMM~$ION USE ONLY CondRions of approval: Nolif~ Comission so represenlitive may wilness Plug fntegrety _ BOP test_ Locx:r~on cle~ranoe _ Mech~mic~ integreW test_ Subsequent form required 10- ~¢~ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED b'~ r') T~vlor ~e. amoun! · D~rte - S~MIT IN TRIPLICAT~ GNI-02 Intended Procedure Add Perforations Perforations are to be added in the well to distribute slurry waste injection into other intervals, which should reduce disposal zone operating pressure and the effects on other wellbores in the area. 1. Add Perforations higher in the well at 7230 - 7250' MD @ 5 spf. 2. Return the well to Grind & Inject Slurry injection. June 23, 2000 5 4 2 COILED 1UBIN~ UNIT BOP EI)IJ 1 PI, I. EN~' 1. ~K)OC)PS1 ?" WELLHEAD CONN£CTOR FLANGE 2. ~)00 PSI4 1/16" PIPE RAMS 3. ~ PSI4 1/6" HYDRAULIC SLIPS 4. 5000 PSI4 1/6" SHEAR RAU$ 5. 5000 PS14 1/6" BLIND RAkI$ 6. 5000 PSI4 1/16" STUFFING BOX r :zr_;:>' HIRELINE BOP EOUIPHENT 1. 5000 PSI ?" WELLHEAD CX)NN[CIOR Ir*LAN(:; 2. ~,000 PS1 WIR[LIN£ RAU$ (VARIABLE SIZE;) 3. 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PS1 '4 1/6." FLOW TUBE PACK-OFF .. Well complianc Report File on Left side of folder 197-255-0 PRUDH~BAY UNIT G&I-02 50- 029-22851-00 ARCo MD 07955 -- TVD 06979 "- G6mpletionDate: 3713/98 Completed Status: WDSPL Current: T Name _r . D 8480 L 8554 L BHCS L BHP L CMT ADVISOR. L MCFL L MCFL L PEX-3DD/CN L PEX-AIT L PEX-CN L PRES TEM SR. VY PRES TEM SR.VY L PRES/TEM L PR.ES/TEM L REAL TIME-MD L REAL TIME-TVD L SSTVD L STATTEM SRVY L STEP RATE TEST L TEM SRVY L TEMP/PRES USIT/CMT R SRVY RPT Interval Sent Received T/C/D SCHLUM GR OH 6/29/98 6/29/98 . ~" SCHLUM BHCS/AIT/CNT/SDN OH 6/26/98 6/24/98 ~ 4120-7891 OH 6/29/98 7/2/98 k, FINAL 4120-7925 OH 6/29/98 7/2/98 ~'"' _,BL(C) 50-3800 CH 5 2/4/98 2/4/98 ~~AL 4120-7925 OH 6/29/98 7/2/98 . N L 4120-7925 OH 7/29/98 7/2/98 ,. L 4120-7925 OH 7/29/98 7/2/98 t~n 4120-7935 OH 7/29/98 7/2/98 [F~L 4120-7912 OH 6/29/98 7/2/98 LF~AL 7432-7436 CH 12/18/98 1/5/99 LFIlqAL 3450-7424 CH 5 1/29/99 2/2U99 ~I'NAL 150-7815 ~IN~A L 7200-7820 ~AL ~050-7900 tY4qq A L ~0/50-7900 ~N~L 4120-7935 f_A;I~)~L 100-7432 10/3/99 FINAL 7700 /F~AL 50-7432 4/25/99 ~INAL 100-7440 1 /.~Lu M 0-7955. CH 3/4/98 3/5/98 CH 5 4/23/98 4/30/98 OH 6/26/98 6/24/98 OH 6/26/98 6/24/98 OH 7/29/98 7/2/98 CH 5 10/12/99 10/27/99 CH 5 6/15/98 6/24/98 CH 5 6/9/99 6/16/99 CH 5 7/1/98 7/2/98 CH 5 2/4/98 2/4/98 OH 4/16/98 4/17/98 Tuesday, April 0410'~~ Page 1 of 2 Was the well cored? yes .~,.~-~' Comments: Are Dry Ditch Samples Required? yes ~_- d Receive ~ ye ~ Analysis Description Receiv~d~?.L~~ no ~ Tuesday, April 04, 2000 Page 2 of 2 Scblumberger NO. 12854 10/12/99 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD GNI #2 L~., c.. STATIC TEMPERATURE LOG 991003 I 1 D.S. 11-28 LEAK DETECTION LOG 990927 I 1 D.S. 14-25 L~t C_ INJECTION PROFILE 990929 I 1 D.S. 7-34 99352 EST .~ d~ ~1~ (p 990828 1 I 1 D.S. 15-30 99376 MEMORY GR/CCL -~' c~72(~ 990901 1 , , , q · '~ - I09.- .,,, (], 'j',,' 2 7 i999 SIGNE DATE: AI~ 0il & Gas Cons. Commission ~ ~ Anc~0rage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 6/9/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 12637 Compan~ Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Sepia CDR GNI 2 ~(/C,~ TEMP SURVEY 990425 1 1 D.S. 3-23 PROD PROFILE W/DEFT & GHOST 990427 1 1 D.S. 3-25A PROD PROFILE W/DEFT 990426 1 1 D,S, 4-18 PROD PROFILE W/DEFT 990408 1 ] D.S, 4-32 PROD PROFILE W/DEFT 990422 1 1 D.S. 4-48 PROD PROFILE W/DEFT 990409 1 ] D.S. 5-12A INJECTION PROFILE 990504 ] ] D.S. 1 t-ll PROD PROFILE W/DEFT 990505 1 ] . D.S, 12-4A PROD PROFILE W/DEFT 990430 ] D.S. ,12-12 PROD PROFILE W/DEFT & GHOST 990428 1 1 D.S. ,12-28 ~ BP GR/CCL 990502 ] ] D.S. ,14-27 L.~! C_. INJECTION PROFILE 990405 1 ] D.S.. 17-08 q/- INJECTION PROFILE 990405 1 1 D.S. 18-24A GR/CCL 990505 ] ] DATE: ,~a {,}ii ~ ~a~ C;o~'~;~, Please sign and return one copy of this transmiflal to Sherrie at the above address or fax to (907) 562-6521. Thank you. 1/29/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'I'N: Sherrie NO. 12286 Compan~ Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 4-01 ~:~ (~ I'k) 99036 CNTG 981113 1 1 1 D.S. 11-07ST L4. t (__. INJECTION 'PROFILE 990123 1 1 ~.~. 1~-3o PROOUCT~O~ ~,oo ~o~ 1 1 GNI~2 ~% ~ P~SS a T~P PROFILE 990125 1 1 , 'EB DATE: SIGN ~a,~8, 0il & G3s C0~'~S. ~nhar;ma Please sign and return one copy of this transmiMal to Sherrie at the above address or fox to (907) 562-6SZI~"T.~ you 12/18/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'I'N: Sherrie NO. 12178 Compan~ Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BI. Sepia Disk Tape GNI #2 PRESS & TEMP SURVEY 981102 1 1 L2-11 DEPTH DETERMINATION LOG 981202 1 1 D.S. 6-10A CBL/SLIM-CMT 981114 1 1 D.S. 7-8 PRODUCTION PROFILE 981127 1 1 D.S. 7-34 GR/CCL 981122 1 1 D.S. 7-34 GR/CCL 981124 1 1 D.S. 12-11 PRODUCTION PROFILE 981102 1 1 D.S. 12-27 c,~c_ INJECTION PROFILE 981117 1 1 D.S. 12-30 PRODUCTION PROFILE/GLS 981121 1 1 D.S. 12-30 DIG.ENTRY&FLUID IMAGER 981121 1 1 D.S. 16-24 INJECTION PROFILE 981105 1 1 D.S. 17-01 PROD.PROFILE W/DEFT 981202 1 1 D.S. 17-06 u~.~ ~_ INJECTION PROFILE 981103 1 1 Please sign and return on py of this transmittal to Sherrie at the above address or fax to (907) 562-652~'~:~fi~'iYo~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I-I'N: Sherrie NO. 11312 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/1/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape G N I #1 TEMPERATURE LOG W/PRESSURE 980606 I 1 GNI #2 TEMPERATURE/PRESSURE LOG 980512 I 1 G NI #3 PRESSURE TEMPERATURE LOG 980606 I 1 D.S. 2-25 PRODUCTION PROFILE LOG 980511 I 1 D.S. 3-22 PRODUCTION LOG 980531 I 1 D.S. 3-24A GR/CCL LOG 980529 I 1 D.S. 3-31 STATIC PRESSURE SURVEY 980514 I 1 D.S. 9-44 PRODUCTION PROFILE LOG 980511 I 1 D.S. 11-2 INJECTION PROFILE LOG 98051 3 I 1 D.S. 11-05A PRODUCTION PROFILE 980527 1 1 D.S. 11-6 PRODUCTION PROFILE 980522 1 1 D.S. 11-24A PRODUCTION LOG & GAS LIFT SURVEY 980531 I 1 D.S. 12-33 i¢1. I C.~ INJECTION PROFILE 980528 I 1 D.S. 14-36 ~ I ~ INJECTION PROFILE LOG __ 980604 I 1 ~).S. 17-19A STATIC PRESSURE SURVEY 98051 4 I 1 D.S. 17-19A PRESSURE & TEMPERATURE SURVEY 980601 1 I o~. o¢ SIGNED DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. 6/29/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11302 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape IGNI #1 98285 !PEX-AIT/BCS/CNT/SDN 980128 1 .. GNI #2 98285 PEX-AIT 980128 I 1 GNI #2 98285 PEX-MCFL 980128 1 1 GNI#2 98285 'PEX-CNL 980128 I 1 GNI #2 98285 PEX-3 DET.DENSlTY CNL 980128 I I __ GNI #2 98285 BHC SONIC 980128 I 1 GNI #2 98285 BOREHOLE PROFILE 980128 I 1 'GNI #2 98285 SSTVD 980128 1 1 GNI #2 98285 RFT 980128 I 1 -- -- -- DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11299 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 6/26/98 Field: Prudhoe Bay (Open Hole) FLPY Well Job # Log Description Date BL RF Sepia DISK G"I #2 ,'j~*<)Q~"~ 98286 MWDGh 980128 1 GNI #2 98286 REAL TIME MODE MD 980128 I 1 GNI#2 98286 REAL TIME MODE TVD 980128 I 1 -- -- -- , , -- ..... SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. Intern~,tJonal Airport Road Anchorage, AK 99518-1199 ATTN: SherrJe NO. 11255 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 6/15/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D.S. 15-4~L~ 98206 TUi'P 971226 I I 1 ~ #1 ~ RATE ~ 980423 I 1 ~ #2 STEP RATE TEST 980417 I 1 (;[~TX #3 CI~ 980510 I 1 D.S. 2-23 PRQ[X.~-~IC~PROF~ 980506 I 1 D.S. 6-16 ~~~~W/P~ 980501 I 1 D.S. 7-33 ~I~~~ 980418 I 1 D.S. 11-16 ~1 ~I~~R 980~26 1 1 -- D.S. 15-09A ~~I~~R 980509 1 1 D.S. 18-11 ~~I~~~ 980501 1 ......... -- _ SIGNED: ~~~~'~ DATE: i ii. ~. i, Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. FROM: A-^O May 1,1998 FAX NO. : ARCO Alaska. Inc. Post Office B,J ..... )2~6~ Anchorage Alaska 99510-0360 Telephone 907 275 ~. 21 ?7 David W. Hanson Staff Permit Coordinator Prudhoe Bay/GPMA (ATO-1968)' 907-263-4745 907-264-4334 (fax) 907 265 6216 05-01-98 02:38P P.02 Ms. Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, AK 99501-3192 RE' Grind & Inject Facility Status Eastern Operating Area, Prudhoe Bay Unit Dear Ms. Mahan: The following information is an update on the completion status of the three Grind & Inject (G&I) injection wells and the slurry operations at the plant: Well GNI-1 Required by AIO 4B? Date Well GNI-2 Date Surface Casing Cement Quality Log Injection Casing Cement Quality Log Initial Perforation Perf Breakdown/Step Rate Test Y 1/5/98 1/22/98 Y 1/14/98 2/1/98 N 1/12/98 1/13/98 N 1/13/98 1/14/98 Begin Seawater Injection 4/6/98 4/6/98 Baseline Temperature Survey Baseline Pressure Failoff Test Baseline Step Rate Test SI Temperature Log MIT Witnessed Y 2/28/98 2/28/98 Y 4/17/98 4/20/98 Y 4/23/98 4/17/98 N 4/23/98 4/17/98 Y 4/23/98 4/23/98 Begin Slurry Injection 4/25/98 $11198 Well GNI-3 is currently drilling; surface casing was run on April 29. When this well has been completed, a similar status update will be sent to you. FROM: PRCO EH~ PAX NO : QO? 265 6216 05-01-Q8 02:39P Wendy Mahan Page 2 May 1,1998 P .03 Slurry injection in well GNI-1 began on April 25. As of today (May 1), 129.979 bbls of slurry (6,204 cubic yards of solids) has been injected. Slurry injection is planned to begin in well GNI-2 this evening. Both the seawater and the slurry injection have proceeded as planned. Please note, beginning on May 10, Flow Station 2 (FS-2) will shutdown for three days. Because the seawater for G&I comes from FS-2, the G&I plant will also be shutdown during this time period. If you have any questions, please call Mike Bill (263-4354) or me. cerely, ~, David W. Hanson ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfleldComp,3.ny GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 111019 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 4/23/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D.S. 1-135~'qq.~ 98192 CNTG 971224 1 I 1 D.S. 4-41-~ l[c/fl~ 98190 TDTP 971220 I I 1 D.S. 5-1B d~-~O~ 98180 TDTP 971225 I I 1 GNI #1 PRESS/TEMP LOG 98031 3 I 1 GNI #2 PRESS/TEMP LOG 98031 4 I 1 D.S. 1-02 PRODUCTION PROFILE 9 8032 8 I 1 D.S. 6-16 PRODUCTION PROFILE 980328 I 1 D.S. 9-06 PRODUCTION PROFILE W/DEFT 980329 I 1 D.S. 16-14A CEMENT BOND LOG 980409 I 1 ,,, SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [--I Oil [] Gas [] Suspended []Abandoned [] Service Class II Cretaceous Disposal Well 2. Name of Operator 7.9P¢_~ ARCO Alaska Inc. 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22851 4. Location of well at surface ~ "::::i"..':'-' :::-. ~ .] .11~~~~ ~ 9. Unit or Lease Name 4298' NSL, 681' WEL, SEC. 26, T11N, R15E, UM ; ' ~ ::..::: '. Prudhoe Bay Unit At top of productive interval '-~/'~-~'~" i ~i10' well Number 900' NSL, 410' WEL, SEC. 23, T11N, R15E, UM ~ ............ !~:~ GNI-02 At total depth ! ~,'~i~'~i;-'i~ -,~-'~- ....... i 11. Field and Pool 2040' NSL, 306' WEL, SEC. 23, T11N, R15E, UM ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE -- 51.2'I ADL 028323 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.t15. Water depth, if offshore 116. No. of Completions 1/17/98 1/28/98 3/13/98 N/A MSLI One 17. Total Depth (MD+TVD)7955 6979 FT1118' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set t21' Thickness °f Permafr°st7851 6896 FT, []Yes I~No None MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, SP, Caliper, RES, DEN, NEU, Sonic, RFT, USlT, CBT 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 80' 30" 260 sx Arctic Set (Approx.) 13-3/8" 54.5# / 72# L-55 / L-80 30' 4137' 16" 2451 sx Cold Set III, 415 sx Class 'G' ~~~ ~ ~":-E~:' 9-5/8" 47# L-80 27' 7938' 12-1/4" 1540 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RE~ Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 7", 29#, L-80 25' - 4181' 4155' MD TVD MD TVD 7", 29#, L-80 4183' - 4277' 4181' 7425' - 7455' 6555' - 6579' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 132 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ~ ; ~% April 6, 1998] Class II Cretaceous Disposal Well Date of Test Hours Tested :PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I 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. *This well is taking about 9-1/2 Bbls/Min at 1450 psi Form 10-407 Rev. 07-01-80 Submit In Duplicate 29.' Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. SV3 4066' 3935' SV2 4274' 4101' SV1 4890' 4563' Ugnu 4 5668' 5160' Ugnu 1 6054' 5462' West Sak 2 7472' 6593' West Sak 1 6812' 6061' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 132. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~ .,__ '¢q. ~ Title Engineering Supervisor Date "t/I ,/ff ~ GNI #2 97-256 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23-' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator ARCO Date 21:08, 11 Feb 98 Page 1 Formation Integrity Test Report The analysis is from - 12:00, 23 Jan 98 - to - 12:00, 23 Jan 98 Programs in Result Table: GNI#2 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(ecfuivalent mud weight) Depth MDR Hole Size MDR GNI-02 Event 12:00, 23 Jan 98 12:00, 23 Jan 98 0 hr 0 min Obtained required level of integrity 13.6 5156.0 12-1/4 Facility Date/Time 16 Jan 98 17 Jan 98 18 Jan 98 19 Jan 98 20 Jan 98 PB Surfcote Progress Report Well GNI-02 Rig Nabors 18E Page Date Duration Activity 06:00-12:00 12:00-12:30 12:30-00:00 00:00-05:00 05:00-06:00 06:00-10:30 10:30-11:00 11:00-11:30 11:30-12:00 12:00-12:30 12:30-14:00 14:00-14:15 14:15-22:00 22:00-22:15 22:15-00:00 00:00-00:30 00:30-01:00 01:00-01:15 01:15-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-09:30 09:30-12:00 12:00-12:30 12:30-21:00 21:00-21:15 21:15-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-01:45 O1:45-06:00 06:00-12:00 12:00-12:30 12:30-14:45 14:45-15:15 15:15-15:30 15:30-16:00 16:00-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-21:00 21:00-22:00 22:00-22:15 22:15-23:00 23:00-00:00 6 hr 1/2 hr 11-1/2 hr 5 hr lhr 4-1/2 hr 1/2hr 1/2 hr 1/2hr 1/2 hr 1-1/2 hr 1/4 hr 7-3/4 hr 1/4 hr 1-3/4 hr 1/2 hr 1/2 hr 1/4 hr 4-3/4 hr 2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 8-1/2 hr 1/4 hr 2-3/4 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 4-1/4 hr 6hr 1/2 hr 2-1/4 hr 1/2 hr 1/4 hr 1/2 hr 8 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 1 hr 1-1/2 hr 1 hr 1 hr 1 hr 3 hr 1 hr 1/4 hr 3/4 hr 1 hr Rig moved 50.00 % Held safety meeting Rig moved 100.00 % Installed Divertor Made up BHA no. 1 Made up BHA no. 1 (cont...) Held safety meeting Held drill (Accumulator) Circulated at 80.0 ft Held safety meeting Drilled to 200.0 ft Held drill (Kick while drilling) Drilled to 600.0 ft Held drill (Kick (well kill)) Drilled to 649.0 ft Held safety meeting Drilled to 700.0 ft Held drill (Kick while drilling) Drilled to 1020.0 ft Drilled to 1115.0 ft (cont...) Circulated at 1115.0 ft Pulled out of hole to 200.0 ft R.I.H. to 1115.0 ft Drilled to 1239.0 ft Held safety meeting Drilled to 1953.0 ft Held drill (Kick while drilling) Drilled to 1953.0 ft Held safety meeting Pulled out of hole to 1110.0 ft R.I.H. to 1953.0 ft Held drill (Kick while tripping) Drilled to 2381.0 ft Drilled to 2381.0 ft (cont...) Held safety meeting Drilled to 3008.0 ft Pulled out of hole to 1900.0 ft Held drill (Kick while tripping) R.I.H. to 3008.0 ft Drilled to 3533.0 ft Held safety meeting Drilled to 3850.0 ft Drilled to 4063.0 ft (cont...) Held safety meeting Drilled to 4147.0 ft Circulated at 4147.0 ft Pumped out of hole to 670.0 ft Singled in drill pipe to 1321.0 ft R.I.H. to 4147.0 ft Circulated at 4147.0 ft Pulled out of hole to 2000.0 ft Held drill (Kick while tripping) Pulled out of hole to 670.0 ft Pulled BHA 1 11 February 98 Facility Date/Time 21 Jan 98 22 Jan 98 23 Jan 98 24 Jan 98 25 Jan 98 PB Surfcote Progress Report Well GNI-02 Rig Nabors 18E Duration Activity 00:00-00:30 00:30-01:30 01:30-03:00 03:00-06:00 06:00-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-14:30 14:30-18:30 18:30-18:45 18:45-18:52 18:52-18:58 18:58-21:15 21:15-21:22 21:22-00:00 00:00-00:30 00:30-02:30 02:30-06:00 06:00-06:30 06:30-09:30 09:30-12:00 12:00-12:30 12:30-13:30 13:30-16:00 16:00-16:30 16:30-18:30 18:30-21:30 21:30-00:00 00:00-00:30 00:30-02:30 02:30-04:00 04:00-06:00 06:00-06:45 06:45-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-04:00 04:00-05:15 05:15-05:45 05:45-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-03:30 03:30-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-08:30 1/2 hr 1 hr 1-1/2 hr 3 hr 6 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 4 hr 1/4 hr 0hr 0 hr 2-1/4 hr 0 hr 2-1/2 hr 1/2 hr 2 hr 3-1/2 hr 1/2 hr 3 hr 2-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 2 hr 3 hr 2-1/2 hr 1/2 hr 2 hr 1-1/2 hr 2 hr 3/4 hr 2-1/4 hr 1-1/2 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3-1/2 hr 1-1/4 hr 1/2 hr 1/4 hr 6 hr 1/2 hr 11-1/2 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 1-1/2 hr Held safety meeting Pulled BHA Installed Casing handling equipment Ran Casing to 1200.0 ft (13-3/8in OD) Ran Casing to 4137.0 ft (13-3/8in OD) Held safety meeting Installed Casing hanger Ran Drillpipe in stands to 4093.0 ft Functioned Float collar Circulated at 4137.0 ft Held safety meeting Pumped Gel spacers - volume 85.000 bbl Tested High pressure lines Mixed and pumped slurry - 950.000 bbl Displaced slurry - 71.500 bbl Circulated at 4090.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Removed Divertor Installed Casing head Installed BOP stack Wait on cement Held safety meeting Rigged up Block line Tested BOP stack Installed Wear bushing Conducted electric cable operations Conducted electric cable operations Made up BHA no. 2 Held safety meeting R.I.H. to 4091.0 ft Circulated at 4091.0 ft Tested Casing - Via annulus and string Tested Casing - Via annulus and string Drilled installed equipment - Float collar Circulated at 4157.0 ft Performed formation integrity test Held safety meeting Drilled to 4887.0 ft Held safety meeting Drilled to 5156.0 ft Pulled out of hole to 4150.0 ft R.I.H. to 5156.0 ft Drilled to 5156.0 ft Drilled to 5433.0 ft Held safety meeting Drilled to 5986.0 ft Held safety meeting Drilled to 6173.0 ft Circulated at 6173.0 ft Cleared Kelly/top drive hose Pulled out of hole to 3100.0 ft Pulled out of hole to 675.0 ft Pulled BHA Page Date 2 11 February 98 Progress Report Facility PB Surfcote Well GNI-02 Rig Nabors 18E Page 3 Date 11 February 98 Date/Time 08:30-10:00 10:00-11:00 11:00-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-19:15 19:15-19:45 19:45-00:00 26 Jan 98 00:00-00:30 00:30-01:30 01:30-04:30 04:30-05:00 05:00-06:00 06:00-12:00 12:00-12:30 12:30-21:00 21:00-00:00 27 Jan 98 00:00-00:30 00:30-06:00 06:00-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-00:00 28 Jan 98 00:00-00:30 00:30-01:00 01:00-02:00 02:00-02:30 02:30-03:00 03:00-05:00 05:00-06:00 06:00-07:45 07:45-08:30 08:30-14:00 14:00-21:00 21:00-00:00 29 Jan 98 00:00-00:30 00:30-01:30 01:30-03:30 03:30-06:00 06:00-07:00 07:00-09:30 09:30-10:30 10:30-10:45 10:45-12:00 12:00-12:30 12:30-17:00 17:00-18:00 18:00-23:30 23:30-00:00 30 Jan 98 00:00-00:30 00:30-02:45 Duration 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 4-1/4 hr 1/2 hr 4-1/4 hr 1/2 hr 1 hr 3 hr 1/2 hr 1 hr 6 hr 1/2 hr 8-1/2 hr 3 hr 1/2 hr 5-1/2 hr 3 hr 2 hr 1 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2hr 1/2 hr 2 hr 1 hr 1-3/4 hr 3/4 hr 5-1/2 hr 7 hr 3 hr 1/2 hr 1 hr 2 hr 2-1/2 hr 1 hr 2-1/2 hr 1 hr 1/4 hr 1-1/4 hr 1/2 hr 4-1/2 hr 1 hr 5-1/2 hr 1/2 hr 1/2 hr 2-1/4 hr Activity Made up BHA no. 3 Functioned downhole tools at 674.0 ft Held safety meeting Held drill (Kick while tripping) Held safety meeting Held drill (Kick while tripping) R.I.H. to 6173.0 ft Drilled to 6392.0 ft Investigated pressure change Pulled out of hole to 220.0 ft Held safety meeting Pulled BHA R.I.H. to 6293.0 ft Functioned downhole tools at 6392.0 ft Drilled to 6392.0 ft Drilled to 6705.0 ft Held safety meeting Drilled to 7149.0 ft Drilled to 7154.0 ft Held safety meeting Drilled to 7390.0 ft Drilled to 7490.0 ft Drilled to 7508.0 ft Drilled to 7515.0 ft Held safety meeting Drilled to 7924.0 ft Held safety meeting Drilled to 7955.0 ft Circulated at 7955.0 ft Pulled out of hole to 6300.0 ft R.I.H. to 7955.0 ft Circulated at 7955.0 ft Pulled out of hole to 5000.0 ft Pulled out of hole to 218.0 ft Pulled BHA Conducted electric cable operations Conducted electric cable operations R.I.H. to 6500.0 ft Held safety meeting R.I.H. to 7955.0 ft Circulated at 7955.0 ft Pulled out of hole to 220.0 ft Pulled BHA Installed BOP stack Installed Casing handling equipment Held safety meeting Ran Casing to 450.0 ft (9-5/8in OD) Held safety meeting Ran Casing to 4130.0 ft (9-5/8in OD) Circulated at 4130.0 ft Ran Casing to 7900.0 ft (9-5/8in OD) Installed Casing hanger Held safety meeting Circulated at 7938.0 ft Facility Date/Time 31 Jan 98 01 Feb 98 02 Feb 98 Progress Report PB Surfcote Well GNI-02 Page 4 Rig Nabors 18E Date 11 February 98 02:45-02:50 02:50-03:04 03:04-03:15 03:15-04:50 04:50-05:50 05:50-06:00 06:00-06:45 06:45-08:30 08:30-10:00 10:00-12:00 12:00-12:30 12:30-13:30 13:30-16:30 16:30-17:00 17:00-19:30 19:30-20:30 20:30-22:30 22:30-23:00 23:00-23:15 23:15-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-03:00 03:00-04:30 04:30-06:00 06:00-08:30 08:30-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-14:15 14:15-16:00 16:00-17:30 17:30-19:30 19:30-20:00 20:00-00:00 00:00-00:30 00:30-03:30 03:30-03:45 03:45-04:15 04:15-04:30 04:30-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-16:00 16:00-18:00 18:00-22:00 22:00-00:00 00:00-00:30 00:30-01:45 01:45-02:45 Duration 0 hr 0 hr 0 hr 1-1/2 hr 1 hr 0 hr 3/4 hr 1-3/4 hr 1-1/2 hr 2hr 1/2 hr 1 hr 3 hr 1/2 hr 2-1/2 hr 1 hr 2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/4 hr 1-3/4 hr 1-1/2 hr 2 hr 1/2 hr 4 hr 1/2 hr 3hr 1/4 hr 1/2 hr 1/4 hr 1-1/2 hr 5 hr 1 hr 1/2 hr 1/2 hr 3 hr 2hr 4 hr 2 hr 1/2 hr 1-1/4 hr 1 hr Activity Pumped Fresh water spacers - volume 10.000 bbl Tested High pressure lines Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 315.000 bbl Displaced slurry - 568.600 bbl Held 1800.0 psi pressure on 0.500 bbl squeezed cement Functioned Other sub-surface equipment Circulated at 4148.0 ft Rigged down Casing handling equipment Installed Casing hanger & seal assembly running tool Held safety meeting Installed Well control Tested Well control Serviced Drillfloor / Derrick Made up BHA no. 5 R.I.H. to 4112.0 ft Circulated at 4148.0 ft Functioned downhole tools at 4148.0 ft Tested Casing - Via string Drilled installed equipment - DV collar Circulated at 4148.0 ft Held safety meeting Tested Casing - Via string Drilled installed equipment - DV collar R.I.H. to 7735.0 ft Drilled cement to 7851.0 ft Circulated at 7851.0 ft Tested Casing - Via string Pulled out of hole to 7000.0 ft Held safety meeting Pulled out of hole to 4000.0 ft Held drill (Kick while tripping) Held drill (Kick (well kill)) Pulled out of hole to 760.0 ft Pulled BHA Removed Drillstring handling equipment Conducted electric cable operations Held safety meeting Conducted electric cable operations Rigged down sub-surface equipment - Completion equipment Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 800.0 ft (7in OD) Ran Tubing to 4277.0 ft (7in OD) Installed Casing hanger Held safety meeting Ran Tubing to 4277.0 ft (7in OD) Removed BOP stack Rigged up Wellhead primary components Circulated at 4277.0 ft Functioned Setting tools Held safety meeting Tested Casing Tested Tubing Facility Date/Time 03 Feb 98 04 Feb 98 05 Feb 98 Progress Report PB Surfcote Well GNI-02 Page 5 Rig Nabors 18E Date 11 February 98 02:45-04:00 04:00-05:15 05:15-06:00 06:00-07:00 07:00-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-17:30 17:30-18:00 18:00-20:00 20:00-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-04:15 04:15-05:15 05:15-06:00 06:00-07:00 07:00-08:30 08:30-08:45 08:45-11:00 11:00-12:00 12:00-12:30 12:30-14:15 14:15-14:30 14:30-15:30 15:30-17:30 17:30-18:30 18:30-20:30 20:30-22:30 22:30-00:00 00:00-00:30 00:30-02:30 02:30-03:30 03:30-06:00 06:00-07:30 07:30-08:00 08:00-10:00 10:00-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-15:00 15:00-16:00 16:00-16:30 16:30-18:30 18:30-20:00 20:00-22:00 22:00-00:00 00:00-00:30 00:30-02:00 Duration 1-1/4 hr 1-1/4 hr 3/4 hr 1 hr 5 hr 1/2 hr 1-1/2 hr 1/2 hr 3 hr 1/2 hr 2 hr 2 hr 1 hr 1 hr 1/2 hr 1/2 hr 1 hr 2-1/4 hr 1 hr 3/4 hr 1 hr 1-1/2 hr 1/4 hr 2-1/4 hr 1 hr 1/2 hr 1-3/4 hr 1/4 hr 1 hr 2 hr 1 hr 2 hr 2 hr 1-1/2 hr 1/2 hr 2 hr 1 hr 2-1/2 hr 1-1/2 hr 1/2 hr 2 hr 2 hr 1/2 hr 1/2 hr 1 hr 1 hr 1 hr 1/2 hr 2 hr 1-1/2 hr 2 hr 2 hr 1/2 hr 1-1/2 hr Activity Tested Tubing Tested Casing Rigged up BOP stack Removed Wellhead primary components Rigged up BOP stack Held safety meeting Tested BOP stack Removed Well control Ran Drillpipe to 2400.0 ft (3-1/2in OD) Circulated at 2400.0 ft Ran Drillpipe to 4150.0 ft (3-1/2in OD) Circulated at 4150.0 ft Tested Tubular strings - Via string Tested Tubing - Via annulus Held safety meeting Cleared Chicksan lines Pulled Drillpipe in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Pulled out of hole to 100.0 ft Conducted slickline operations on Slickline equipment - Retrival run Installed Tubing handling equipment Held safety meeting Worked stuck pipe at 4180.0 ft Rigged down sub-surface equipment - Completion tools Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Conducted electric cable operations Conducted electric cable operations Circulated at 4152.0 ft Worked stuck pipe at 4180.0 ft Laid down 30.0 ft of Tubing Laid down 120.0 ft of Tubing Held safety meeting Laid down 890.0 ft of Tubing Conducted electric cable operations Laid down 1350.0 ft of Tubing Laid down 4185.0 ft of Tubing Rigged down Casing handling equipment Rig waited · Materials Made up BHA no. 5 Held safety meeting R.I.H. to 1000.0 ft Serviced Block line R.I.H. to 4160.0 ft Circulated at 4160.0 ft Fished at 4160.0 ft Pulled out of hole to 30.0 ft Laid down fish Ran Drillpipe in stands to 4200.0 ft Laid down 2000.0 ft of 3-1/2in OD drill pipe Held safety meeting Laid down 2000.0 ft of 3-1/2in OD drill pipe Facility Date/Time 06 Feb 98 07 Feb 98 Progress Report PB Surfcote Well GNI-02 Page 6 Rig Nabors 18E Date 11 February 98 02:00-04:30 04:30-05:00 05:00-06:00 06:00-12:00 12:00-12:30 12:30-14:00 14:00-20:30 20:30-00:00 00:00-00:30 00:30-03:00 03:00-05:15 05:15-05:30 05:30-06:00 06:00-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-15:00 15:00-19:00 19:00-22:30 22:30-00:00 00:00-00:30 00:30-03:00 03:00-05:00 05:00-06:00 06:00-09:00 Duration 2-1/2 hr 1/2 hr 1 hr 6 hr 1/2 hr 1-1/2 hr 6-1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 2-1/4 hr 1/4 hr 1/2 hr 3 hr 2 hr 1 hr 1/2 hr 2-1/2 hr 4 hr 3-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2 hr 1 hr 3 hr Activity Rigged up Top ram Rigged up Casing handling equipment Ran Tubing to 7in (100.0 ft OD) Ran Tubing to 4183.0 ft (7in OD) (cont...) Held safety meeting Space out tubulars Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Setting run Held safety meeting Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Pulled out of hole to 0.0 ft Installed Hanger plug Rigged down BOP stack Rigged up Xmas tree Removed Hanger plug Held safety meeting Removed Hanger plug Removed Xmas tree Installed Xmas tree Freeze protect well - 130.000 bbl of Inhibited brine Held safety meeting Freeze protect well - 132.000 bbl of Diesel Tested Permanent packer Installed Hanger plug Rigged down Fluid system GNI-02 INITIAL PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/4/98: RIH w/dummy gun & tagged TD at 7800' MD. 3/13/98: MIRU & NU BOPS on well. as follows: PT equipment, then RIH w/perforating guns & shot initial perforation interval Perforated: 7425 - 7455' MD (Cret) Used a 4-1/2" hollow carrier & shot the perf interval at 5 spf at 60 degree phasing. Shot upper 10' of interval at balanced pressure, and the lower 20' of interval at underbalanced pressure. POOH w/gun. ASF. RD. 3/14/98: Pumped 304 bbls Seawater @ 1 - 5 bpm to perform an Injectivity Test. Had a final injectivity of 1500 psi at 5 bpm w/304 bbls Seawater away. Followed Injectivity Test w/Temperature Log, which indicated channels up & down from perfs. RD. Placed the well on initial injection & obtained a valid injection rate. Anadrill Client: ARCO Field: Prudhoe Bay Well Name: APl number: Job Number: Rig: County: State: GNI #2 50-029-72851 40002038 NABORS 18E NSB AK Survey Calculations Calc method for positic Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum MSL Depth reference Drill Floor, 49.7 GL above Permanent 20.9 KB above Permanent 51.2 DF above Permanent 49.7 Vertical section origin - Latidude (+N/S-): Departure (+E/W-): Azim from rotary table to target: +70,2832600 -148.241389 8.50 degrees Schlumberger ANADRILL Survey Report SURVEY REPORT Spud Date: 17-Jan-98 Last survey date: 27-Jan-98 Total accepted surveys: 84 MD of first survey: 218 FT MD of last survey: 7894 FT Geomagnetic data Magnetic Model: BGGM 1996 Version Magnetic Date: 31-Dec-97 Magnetic field strength: 1147.7 HCNT Magnetic dec (+E/W-): 28.6 degrees Magnetic Dip: 80.78 degrees MWD Survey Reference Criteda Reference G: 1002.68 mGal Reference H: 1147.09 HCNT Reference Dip: 80.76 degrees Tolerance G: 4 mGal Tolerance H: 6 HCNT Tolerance Dip: 0.3 degrees Correction Magnetic dec (+E/W-): 28.514 degrees Grid convergence (+E/W-): 0 degrees Total az corr (+E/W-): 28.514 degrees I Seq Measured Incl Azimuth Course TVD Vertical # Depth angle angle length depth section (fi) (deg) (deg) (ft) (fi) (ft) Displacement Total at Azm DLS +N/S- +E/W- displacement (deg/ (fi) (fi) (ft) (deg) lOOf) Srvy tool type Tool quality 1 0.00 0.00 0.0 0.00 0.00 0.00 2 159,11 0.26 25.2 159.1 159.10 0,35 3 250,13 0.20 65.7 91.0 250.10 0.63 4 343,59 0.21 97.5 93.5 343.60 0.72 5 436,12 0.10 112.8 92.5 436.10 0.70 6 521.30 0.26 18.7 7 616,33 0.28 50.8 8 709,27 0.60 44.2 9 803,59 0.65 60.0 10 901,43 0.4 55.3 11 991,16 0.72 59.4 12 1085.66 0.65 72,3 13 1177.00 0.36 58.0 14 1269,24 0.53 78.5 15 1362.41 0.74 53.1 16 1457.64 0.69 59.9 17 1550.59 0.60 49.9 18 1643.31 0.61 49.8 19 1737.01 0.67 57.6 20 1829.83 0.43 43.3 21 1923.62 0.80 48.5 22 2016.17 1.36 21.6 23 2109.67 3.16 13,7 24 2200.16 4.70 10.2 25 2296.71 5.87 10.0 85.2 95.0 93.0 94.3 97.8 89.8 94.5 91.3 92.2 93.2 95.2 93.0 92.7 93.7 92.8 93.8 92.6 93.5 90.5 96.5 521.30 616.30 709.29 803.59 901.38 0.00 0.00 0.00 0.03 0.00 TIP - 0.33 0.15 0.36 25.20 0.16 MWD 6-axis 0.58 0.39 0.70 33.72 0.19 MWD 6-axis 0.62 0.70 0.94 48.51 0.12 MWD 6-ax~s 0.57 0.95 1.11 58.96 0.13 MWD_M - 0.88 0.72 1.08 1.30 56.10 0.33 MWD 1.26 1.08 1.33 1.71 50.98 0.16 MWD 1.82 1.57 1.84 2.42 49.60 0.35 MWD 2.56 2.19 2.65 3.44 50.44 0.19 MWD_M 3.14 2.66 3.41 4.33 52.04 0.26 MWD_M 6-axis 6-a)ds 6-axis - . 991.18 3.71 3.13 4.15 5.20 53.03 0.36 MWD 6-axis 1085.67 4.32 3.59 5.18 6.30 55.24 0.18 MWD 6-axis 1176.97 4.73 3.90 5.91 7.08 56.56 0.34 MWD 6-axis 1269.17 5.07 4.14 6.58 7.77 57.81 0.25 MWD 6-axis 1362.36 5.64 4.59 7.48 8.77 5&48 0.37 MWD 6-axis 1457.55 6.44 5.24 8.47 9.98 58.23 0.10 MWD 6-axis 1550.55 7.15 5.84 9.32 11.00 57.95 0.15 MWD 6-axis 1643.24 7,89 6.47 10,07 11.97 57.29 0.01 MVVD 5-axis 1736.94 8,62 7.09 10.92 13.01 57.01 0,11 MVVD 5-axis 1829.73 9,26 7.63 11.61 13.89 56.70 0.30 MWD 6-axis 1923.53 10.05 8.32 12.34 14.89 56.02 0.40 MWD 5-axis 2016.11 11.62 9.77 13.23 16.45 53.56 0.80 MWD 6-axis 2109.53 15.27 13.31 14.25 19.50 46.97 1.95 MWD 5-axis 2199.82 21.48 19.38 15.50 24.81 38.66 1.72 MWD 5-axis 2295.91 30.34 .28.13 1~06 3~90 31.23 1.21 MWD 5-axis Page 1 ORIGINAL Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth # Depth angle angle . (fi) (deg) (deg) 26 2389.22 6.26 11.8 27 2482.75 7.04 11.1 28 2575.39 8.35 7.2 29 2668.74 9.91 6.4 30 2761.98 11.53 7.9 TVD Displacement Total at Azm DLS Srvy Tool displacement (deg/ tool quality (it) (deg) 100f) type type 31 2853.03 13.47 7.8 32 2944.89 15.54 7.3 33 3035.85 17.90 7.4 34 3132.42 19.89 8.3 35 3223.84 21.50 8.9 36 3316.95 23.98 10.2 37 3409.30 24.76 10.1 38 3501.81 26.12 9.9 39 3597.57 27.34 10.8 40 3692.80 28.89 11.0 41 3783.67 31.25 11.5 42 3878.11 32.43 10.7 43 3969.67 34.77 8,3 44 4063.08 35.78 8.5 45 4163.89 36.45 7.9 46 4257.68 38.64 7.7 47 4350.73 41.32 7.5 48 4444.05 42.18 7.7 49 4537.00 42.89 9.5 50 4629.73 43.29 9.0 51 4721.81 40.56 5.8 52 4816.44 39.71 6.2 53 4910.90 40.00 7.3 54 5003.58 41.30 5,9 55 5093.39 39.71 6.9 56 5188.54 38.73 5.5 57 5279.53 37.92 6.1 58 5371.14 38.71 5.1 59 5464.20 40.02 5.8 60 5556.89 41.14 6.0 61 5648.48 41.95 6.6 62 5740.90 40.83 8.0 63 5833.60 38.48 7.8 64 5920.31 36.74 8.2 65 6018.14 35.90 5.9 66 6112.62 36.59 7,0 67 6206.74 37.36 6.6 68 6298.95 37.54 6.7 69 6396.37 38 5.6 70 6490.47 38.42 6.5 71 6584.13 38.58 7.6 72 6676.77 39.31 8.1 73 6771.06 37.71 6.0 74 6864.01 35.35 5.1 75 6956.80 35.28 3.8 76 7049.46 38.33 5.9 77 7139.23 38.49 5.9 78 7233.17 38.61 4.9 79 7328.27 36.69 4.1 Course length (ft) 92.5 93.6 92.6 93.3 93.3 91.0 91.9 91.0 96.5 91.4 93.1 92.4 92.5 95.8 95.2 90.9 94.4 91.6 93.4 100.8 93.8 93.0 93.3 93.0 92.7 92.1 94.6 94.5 92.7 89.8 95.1 91.0 91.6 93.1 92.7 91.6 92.4 92.7 86.7 97.8 94.5 94.1 92.2 97.5 94.1 93.6 92.7 94.3 92.9 92.8 92.7 89.7 94.0 95.1 depth (fi) 2387.89 2480.86 2572.62 2664.74 2756.41 Ve~ical section (fi) +N/S- (ft) 40.10 37.72 18.91 42.20 26.62 0.47 MWD 6-axis 50.93 48.35 21.00 52.73 23.54 0.84 MVVD_M - 63.32 60.59 22.99 64.80 20.78 1,52 MVVD 6-axis 78.12 75.29 24.74 79.25 18.19 1,68 MWD 6-axis 95.47 92,50 _26_91 96.34 16.22 1 ~76 MVVD 6-axis 2845.25 115.16 112.01 29.60 115.86 14.80 2.13 MWD 6-axis 2934.21 138.17 134.83 32.62 138.72 13.60 2.26 MWD 6-axis 3021.36 164.35 160.79 35.97 164.77 12.61 2.59 MWD 6-axis 3112.65 195.59 191.75 40.25 1 95.93 11.85 2.08 MWD 6-axis 3198.15 227.89 223.68 45.09 228.18 11.40 1.78 MWD 6-axis 263.87 301.98 341.70 364.76 429,58 475.07 524.82 575.49 629.43 688.84 3284.01 3368.18 3451.71 3537.27 3621423 3699.89 3780.09 3856.38 3932.63 4014.06 259.16 296.69 335.82 378.21 422.26 466.93 515.79 565.78 619.14 677.95 51.00 57.80 64.69 72.44 80.93 89.82 99.40 107.73 115.61 124.08 264.15 11.15 2.72 MWD 6-axis 302.27 11.02 0.85 MWD 6-axis 342.00 10.90 1.47 MVVD 6-axis 385.08 10.84 1.34 MWD 6-axis 429.95 10.85 1.63 MWD 6-axis 475.49 10.89 2.61 MWD 6-axis 525.29 10.91 1.33 MWD 6-axis 575.95 10,78 2.94 MWD 6-axis 629.64 10.58 1.09 MWD 6-axis 689.21 10.37 0.75 MWD 6-axis 4088.43 745.99 734.57 131.84 746.31 10.17 2.34 MWD 6-axis 4159.68 805.73 793.80 139.74 800.00 9.98 2.89 MWD 6-axis 4229.29 867.85 855.38 147.96 868.00 9.81 0.93 MVVD 6-axis 4297.82 930.72 917.54 157.36 930.93 9.73 1.51 MWD 6-axis 4365.52 994.04 980.04 167.54 994.26 9.70 0457 MWD 6-axis 1055.54 1116.46 1177.04 1237.44 1295.73 1355.81 1412.17 1468.89 1527.85 1588.09 1648.80 1709.87 1769.02 1821.93 1879.63 1935.66 1992.23 2048.27 2107.94 2166.09 4434.04 4506.37 4578.87 4649.16 4717.44 4791.11 4862.50 4934.38 5006.35 5076.76 5145.31 5214.63 5268.00 5354.68 5433.48 5509.70 5584.87 5858.07 5735.14 5809.08 1041.04 1101.68 1161.87 1221.90 1279.86 1339.64 1395.78 1452.30 1511.08 1571.06 1631.44 1692.04 1750.63 1803.02 1860.50 1916.02 1972.22 2027.90 2007.27 2145.15 2202.98 2250.70 2318.96 2373.99 2427.47 2481.50 2534.46 2590.19 2646.78 5882.33 5954.43 6028.22 6102.86 6178.59 6253.77 6325.96 6401.48 6477.77 175.51 I 55.73 9.57 3.76 MWD 6-axis 181.88 I 116.59 9.37 0.94 MWD 6-axis 189.01 I 177.14 9.24 0.84 MWD 6-axis 195.94 1 237.51 9.11 1.64 MWD 6-axis 202.44 I 295.77 8.99 1.91 MWD 6-axis 208.94 1 214.64 1 220.18 1 225.79 1 231.99 I 238.68 1 246.41 1 254.54 1 261.90 1 269.02 1 355.83 8.86 1.39 MWD 6-axis 412.19 8.74 0.98 MWD 6-axis 468.89 8.62 1.10 MWD 6-axis 527.85 8.50 1.49 MWD 6-axis 588.09 8.40 1.22 MWD 6-axis 646.80 8.32 0.99 MWD 6-axis 709.68 8.29 1.57 MWD 6-axis 769.04 8.27 2.54 MWD 6-axis 821.94 8.26 2.03 MWD 5-axis 879.85 8.23 1.64 MWD 6-axis 275.30 1 935.69 8.18 1.00 MWD 6-axis 282.00 I 992.27 8.14 0.86 MWD 6-axis 288.50 2 48.32 8.10 0.21 MWD 6-axis 294.89 2 108.00 8.04 0.84 MWD_M - 301.03 2 166.17 7.99 0,74 MWD 6-axis 2224.33 2282.50 2341.28 2396.51 2450.01 2504.13 2557.32 2613.21 2669.84 308.18 2 316.14 2 323.36 2 328.72 2 332.89 2 337.48 2 342.96 2 348.22 2 352.68 2 224.43 7.96 0.75 MWD 6-axis 282.70 7.96 0.86 MWD 6-axis 341.40 7.94 2.19 MWD 6-axis 396.64 7.88 2.60 MVVD 6-axis 450.19 7.81 0,81 MWD 6-axis 504.35 7.74 1.74 MWD 6-axis 557.56 7.71 O. 18 MWD 6-axis 613.49 7.68 0.65 MWD 6-axis 670.18 7.59 0.51 MWD 6-axis Page 2 Schlumberger ANADRILL Survey Report I Seq Measured Incl Azimuth Course 'I'VD Vertical Displacement Total at Azm DLS Srvy Tool # Depth angle angle length depth section +N/S- +E/W- displacement (deg/ (fi) (deg) (deg) (fi) (ft) (fi) (fi) (fi) (fi) (deg) 10Of) type type 80 7425.11 36.77 4.8 96.8 6555.36 2727.59 2704.50 357.17 2 727.98 7.52 0.44 MVVD 6-axis tool quality 81 7518.27 36.67 4.3 82 7613.16 36.72 3.0 83 7708.39 36.99 4.0 84 7801.68 37.09 2.4 85 7894,74 37.19 2.1 93.2 6630.06 2783.18 2760.05 361.59 2 783.63 7.46 94.9 6706.16 2839.68 2816.64 365.20 2 840.21 7.39 95.2 6782.33 2896.56 2873.63 368.69 2 897.18 7.31 93.3 6856.81 2952.52 2929.74 371.82 2 953.24 7.23 93.0 6930.94 3008.33 2985.85 374.03 3 9.18 7.14 0.34 MWD 6-axis 0.82 MWD 6-axis 0.69 MWD 6-axis 1.04 MWD 6-axis 0,22 MWD 6-axis 86 7955.00 37.19 2.1 60.3 6978.98 3044.56 3022.27 375.36 3 45.49 7.08 0.00 Projected - Page 3 Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Date: Well Name: Company: API Number: Location: Field: Rig: January 28, 1998 GNI #2 ARCO 50-029-72851 North Slope, Alaska Pmdhoe Bay Nabors 18-E Anadrill Personnel Field Crew: Cell Manager: Steve Barney Andrew Hettinger Field Support: Alaska District Manager: Martin Varco Field Service Manager: Craig Brown SERVICES PROVIDED Service Directional Survey Service (DSS) Gamma Ray (GR) Service Dates 17 Jan 98 - 27 Jan 98 23 Jan 98 - 27 Jan 98 Depthlnterval 110-7955FT 4050-7955FT OPERATING STATISTICS Total MWD Pump Hours: Total MWD Below Rotary Hours: Total MWD Footage: Total MWD Runs: 146.0 173.0 7845 4 Total LWD Pump Hours: Total LWD Below Rotary Hours: Total LWD Footage GR: Total LWD Runs: GR: JOB PERFORMANCE 86.0 126.7 3905 3 DIRECTIONAL Anadrill's PowerPulse tool was nm for the entire Well. Surveys (DSS) were provided from surface. Toolfaces were provided with a 7 second update rote. Continuous inclination and azimuth were also provided. Kick offwas executed in the 16 inch hole from 2000 ft. A maximum angle of 43 degrees was achieved. The maximum DLS was 3.76. Signal quality was good during slides and while offbottom surveying. Thus, the value of the directional service was good due to the high efficiency. A total of 84 surveys were provided. FORMATION EVALUATION Real time GR was mn for the 12.25 inch hole section. The hole was logged behind casing from 4050 ft to 4137 ft where the 13 3/8 inch casing had been set. Signal quality was bad while on bottom rotating, This caused noisy data and occasional loss of sync. All attempts were made to minimize the noise, but without success. It is thought that the noise was the result of stabilizer torque. SHOCK Downhole shocks were monitored in order to minimize fatigue on the tool and BI-I~ Shocks were frequent on this well because of the drilling conditions. LESSONS LEARNED It was noticed during drilling that the frequency spectrum in the 16 I-Iz range was relatively quiet. If a similar condition is expected in the future it may be effective to run the MWD tool on this carrier frequency in order to minimize signal interference. Anadrill appreciated the oppommity to provide ARCO with MWD and LWD services on GNI #2. Sincerely, Craig Brown Field Service Manager Steve Barney MWD Engineer GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11884 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 3/4/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape (a~T/ #1 PRESSURE T~4PERA~Y/RE GR/CCL JEWELRY LOG 980228 I 1 ~ #2 PRESSURE T~4PERATURE GR/CCL JEISELRY LOG 980228 I 1 D.S. 07-37 IPRESS/T~4P LOG 980219 I 1 D.S. 9-2 PRODUCTI0~ LOG FBS/CFM/PRESS/T~vIP/GRAD 980227 I 1 D.S. 11-36 PRODUCTI0~ LOG FBS/CFM/PI~F_.SS/T~/GRAD 980226 I 1 D.S. 02-06A ~gO 97568 RS~-~OR~X LO~ ~oROCSSSSD 971~12 I 1 ~ I __ -- SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. TONY KNOWLE$, GOVERNOFi ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Janua~'7.1998 Dan Stoltz Senior Drilling Engineer ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99501-0360 ae~ Pmdhoe Bay Unit GNI//2 ARCO Alaska. Inc. Permit No. 97-255 Sur. Loc 4298'NSL. 68 I'WEL. Sec. 26, T1 IN. Ri5E. UM Btmhole Loc. 2033'NSL. 228'WEL. Sec. 23. T11N. R15E. UM Dear Mr. Stoltz: Enclosed is thc approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A step-rate test and a temperature baseline log are required prior to disposal. The blowout prex'ention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission max, witness the tests. Notice max- be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffEnclosure cc: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. .... STATE OF ALASKA ALAS'r,,~-~ OIL AND GAS CONSERVATION c~OMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil l [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 15. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 50.6' Prudhoe Bay Field / Prudhoe 3. Address !6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028323 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4298' NSL, 681' WEL, SEC. 26, T11 N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 1508' NSL, 306' WEL, SEC. 23, T11 N, R15E, UM GNI #2 Attotal depth 9. Approximate spud date Amount $200,000.00 2033' NSL, 228' WEL, SEC. 23, T11N, R15E, UM 01/08/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028324, 2033'I No Close Approach 2560 7942' MD / 6986' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 2000' Maximum Hole Angle 37-15° Maximum surface 2650 psig, At total depth (TVD) 7000' / 3350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 16" 13-3/8" 72# L-80 BTC 4147' Surface Surface 4147' 3961' ~2465 sx CS, 610 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 BTC-Mod 7942' Surface Surface 7942' 6986' !1595 sx 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 MD TVD Structural Conductor Surface Intermediate :irn°edructiOn R E C E J~/E D ORIGINAL PeRoration depth: measured ~0il & Gas Cons. Com~ Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: David Nakamura, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 Signed Dan Stoltz ,,~~// ~~"~'~ ~,. ~,~'~.~,..~ ~t¢ ~ ''~ ~' Title Senior Drilling Engineer Date /__.3 Commission Use Only J r.~, ~_~z_ ~,:'? I Appr°va'Date I Permit Number ~ APl Numbe~.~_ ~JC~ See cover letter ¢:,~- __~ ~,j(" 50- O -- J for other requirements Conditions of Approval: Samples Required []Yes J~ No Mud Log Required DYes ]~ No Hydrogen Sulfide Measures []Yes ~]No Directional Survey Required ,]~Yes [] No Required Working Pressure for BOPE __ •2M; ~]3M; •5M; D10M; ~15M Other: 3 _,.~_ ~p,~ _ Original si¢rqed By by order of //~ h~(~ Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Subr~j ,Triplicate STATE OF ALASKA .~:. ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work l~ Drill [-IRedrill Ilb. Typeofwell I--IExploratory [-I Stratigraphic Test [-I Development Oil [] Re-Entr~ [] DeepenI []Service [] Development Gas I-ISingle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 50.6' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028323 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAO 25.025) 4298' NSL, 681' WEL, SEC. 26, T11 N, R15E, UM Prudhoe Ba~, Unit At top of productive interval 8. Well Number Number U-630610 1508' NSL, 306' WEL, SEC. 23, T11 N, R1 hE, UM GNI #2 At total depth 9. Approximate spud date Amount $200,000.00 2033' NSL, 228' WEL, SEC. 23, T11N, R15E, UM 01/08/98 12. Distance to nearest property line] 13. Distance to nearest well 14. N umber of acres in property 15. Proposed depth (MD and 'I'VD) ADL 028324, 2033'I No Close Approach 2560 7942' MD / 6986' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 2000' Maximum Hole Angle 37.15° Maximum surface 2650 psig, At total depth ('I'VD) 7000' / 3350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 16" 13-3/8" 72# L-80 BTC 4147' Surface Surface 4147' 3961' 2465 sx CS, 610 sx Class 'G' 12-1/4" 9-5/8" 47# 1_-80 BTC-Mod 7942' Surface Surface 7942' 6986' 1595 sx 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 fe6t Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production 1,iner Perforation depth: measured true vertical ~,nch0rage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: David Nakamura, 564-5480 Prepared By Name/Number: Terrie Hubb/e, 564-4628 21.1 hereby certify that tJ;f/e~fCegoing i~e/)~n~ correct to the best of my knowledge "¢'¢~ ,Z.,z~, ff'l Signed Dan Sto~tz ~'~/~'J / '~"~-'/-~.~-,/'¢~ Title Senior Drilling Engineer Date /~_,/~ ~- v - I ! '/' ' ' · Z3 Commission Use Only ] I Ap, prqval Date See cover letter Permit Number APl Number ~.~ .... ,~.,~_. ,?~.~".~ 50- ,'-) ~'~- ~ -- - ~ ~'~..~ / U q) ~ for other requirements L Conditions of Approval: Samples Required []Yes I~No Mud Log RequiredI' []Yes ~No Hydrogen Sulfide Measures []Yes ~]No Di_re~ctional Survey Required ~]Yes [] No Required Working Pressure for BOPE 1--12M; ~;],,3M; []hM; I-]10M; E]15M Other: .. j.,,[],~.~.t(r,~...~.~~ I~'~ ¢~". by order of Approved By [!2.',';': ~,;~. d01]nst0n Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit l plicate I Well Name: I GNI #2 (Surfcote Pad Middle) I Type of Well: Injection Well Summary I lnject°r I Surface Location: Target Location: BHL: 4298' FSL 1508' FSL 2033' FSL 681'FEL, S26 T11N R15E UM 306' FEL, S23 T11N R15E UM 228' FEL S23 T11N R15E UM I AFE Number: 14J0365 I Estimated Start Date: I 1/8/98 17942' ~VD: I Rig: I Nabors 18E I Operating days to complete:1 18 16986' I I KB Elev. 15o.6o' I Well Design: I Big Bore Injector Objective:: Three new Class II Cretaceous disposal wells are planned in support of EOA Reserve Pit Close Out Grind and Inject operations. These wells will be located at the east end of the Surfcote Pad, between DS-4 and L-4. These disposal wells will be in highly erosive service, accepting mud and cuttings slurries. No chrome alloys are required and H2S fluids injection is unlikely. Bond logs are required in each well. .Formation Markers Formation Tops Base Permafrost MD 1851' TVD 1851' SV5 3533' 3461' SV3 4134' 3951' SV2 4373' 4141' SV1 4906' 4566' UG4 5565' 5091' U (31 6744' 6031' WS2 7384' 6541' WS1 7647' 6751' CM3 7942' 6986' TD 7942' 6986' Casing/Tubing Program Hole Size Tubular Wt/Ft Grade -Conn - Length- Top Btm O.D. MD/TVD MD/TVD 30" 20" 94# H-40 Weld 80' Surface 110'/110' 16" I ~3-3/8" I 72# I L-80 I BmC I 4147' I Su~ace 14147¥3961' 12-1/4" I 9-5/8" I 47# I L-80 I BTC-MOD I 7942' I Surface 17942'/6986' NA I 7" 29# L-80 BTC-MOD 4385' Surface 4385'/4151' Page 1 Open Hole Logs: 16" Hole: Logging Program MWD Directional 12-1/4" Hole: MWD Directional/GR; E-Line GR/SPICalipedResistivity/Density/Neutron, Sonic, RFT Cased Hole Logs: 16" Hole: GR/USIT 12-1/4" Hole: GR/USIT/CBT Directional I KOP: 12000' I Maximum Hole Angle: Rig Move Close Approaches: Drilling Close Approaches: 37'15° None None Cement Calculations Lead Cement Tail Cement Casing/Liner Sk ! Wt / Yield Sk I Wt I Yield Comments Cold Set Lead to surface (350% excess through 13-3/8" 2465 / 12.2 / 1.92 610 / 15.8 / 1.15 permafrost, 100% excess to top tail); Class G Tail (750' MD with 100% excess; Pump time=4+ hr.; TOC = Surface Class G Tail (50% excess to surface casing shoe); Pump 9-5/8" N/A 1595 / 15.8 / 1.14time=4+ hr.; TOC = Surface Casing Shoe Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Mud Program Surface Section: Spud Mud I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss Initial 9.6 ± 300 35-50 25-45 50-80 9-10 15-20 Final 9.6 - 9.8 300 20-40 15-30 30-50 9-10 15-20 Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning. Intermediate Section: LSND J Density, ppg I FunnelVis, sec[ LSRYP Gels J pH 9.4 - 10.0 40 - 60 8 - 13 15-25 / 20-35 9 - 10 Hazards/Concerns Potential high torque could require lubricant use. Be alert for lost circulation, differential sticking due to higher MW. HPHT FL, cc <1o Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. · Maximum anticipated BHP: 3350 psi @ 7000' TVDss (9.2 ppg EMW) · Maximum surface pressure: 2650 psi @ 7000' TVDss (based on BHP and a full column of gas from TD @ 0.10 psi/fi) Page 2 Operations Summary Drillin_q Ri_q Procedure 1. Pre-rig: Set and cement 80' of 20" conductor. Install cellar ring. 2. MIRU Nabors 18E. NU and function test diverter. 3. Drill 16" hole to _.4147' MD (_+3961' TVD) per directional plan. Hold diverter drill while 'drilling surface hole. . Run and cement 13-3/8", 72 #/ft, L-80 casing to TD. Will cement 13-3/8" casing with two stage job (ES Cementer set at +_2051' MD - 200' MD below the Base of Permafrost). Ensure that cement reaches surface. Si Test 13-3/8" casing to 3,000 psi for 30 minutes. Run GR/USIT (cement evaluation log) in 13-3/8" casing. Drill shoe joint and 20' of new formation. Perform and record LOT. 6. Drill 12-1/4" hole directionally to _+7942' MD (6986' TVD). 7. Log well with GR/SPICalipedResist/Density/Neutron, Dipole Sonic and RFT. . Run and cement 9-5/8" casing to TD. TOC to 13-3/8" casing shoe. RU and establish injection down 9-5/8" x 13-3/8" annulus. 9. Test 9-5/8" casing to 4000 psi for 30 minutes. 10. Log 9-5/8" with GR/USIT/CBT (cement evaluation log). 11. Run 7" L-80 completion with packer at_+4370' MD. Have AOGCC representative witness annulus test. 12. Freeze protect well, set packer. 13. Set BPV, ND BOPE. 14. NU and test tree. 15. RDMO. 16. Post rig' Perforate 9-5/8" casing. Page 3 xz/zz/1uu! 21:51 907-344-2160 ANADRILL DPC PAGE 04 ,: SHARED SERVICES DRILLING i-- <x,>o-- , ..... 1' GNI#2 (P4)Mid Slot l VERTICAL SECTION VIEW 400 ...... Section ~t: 8.50 j . TVD Scale.' 1 inch = 800 feet coo .... Dep Scale.' I inch -- 800 feet Drawn .... ' ~;~ Dec ~997 . t200- ' ................ ~nadrJ ] ] Schlumberger I i600 ........ Marker Identification MD ~8 SECTN INCLNi i Al KB 0 0 0 0.00~ - ~ 81 KOP/CUR~E 2.00/tO0 ~000 2000 0 o,0o[ ' ~~ ~m~ C) END 2.00/t00 ~flVE ~8 3730 58t 37.151 2000-- 8 .... O] 13-3/8" CS6 PT ql> 4147 3~t 756 El TAR~T ~wwl~ww~ww~w 7064 6286 8518 37,151 Fl TO 9~/8' C56 Pffll> 7942 6986 3048 37. [NADR:LL A~-DPC .I acc- - A P i~ i{~ ~ r, u m ~oo ~ F(~R PI:RMITTIb G ...... ~ ~._~t ~,oo~- ~ .. ~-~,, ~,PLAN _~. ~ . 4000 -~- ~r ..... .......... 4400- - 48oo,~ 5aoo - ! .....~ n~oo _,., . I BO00 '- - ~F ........ ' ................ ~ target [ladiuS 2( 0 feet ) 6400 ~ ...... ~,~ ~ 6800~ ~,- ~r n ~. ~-- ................... ,-- / F 7200 -- ~ ....... 0 ~00 800 i200 ~600 2000 2400 2800 3200 3BO0 4000 4~00 4800 Section Departure I 907-344-2160 SHARED i ANADRILL DPC PAGE 05 "'SERVI'CES DRILLING Maoker Idenl:J fication HO N/S A! KB 0 0 N 8] KOP/CURVE 2.00/~00 2.000 0 N ri} 13-3/8' CSG PT <l I> 4147 748 N E) TARGET ~,x~,,~.~x 70§4 24~0 N F) TO 9-5/B" CSG PT<II> 7942 ~015 N OE tt2 E -GNI#2 (P4)Mid Si,or PLAN. VIEW CLOSURE · 3048 feet at Azimuth DECLINATION.' +28.517 SCALE · ~ inch ~ 500 feet DRAWN ' 22 Dec 1997 AnadrJ l] Schlumbergem 8.5( i i LAN -~, ...L , . , I ............ I [ .... ~750 t500 I250 tO00 750 500 250 0 250 §00 750 ~000 ~250 1500 i750 <- WEST' EAST -> I Anadrill Schlumberger Alaska DistriCt 111I Eash 80th Avenue Anchor&ge, AK 99518 (907) 349-45[~ Fax 344-2Z60 DIP~CTIONAL WELL PLAN for SHARED ~e[1 ......... : GNI~2 (P4) Mid SloC Field ........ : Prudhoe Bay, SurfcoCe Pad CompuCation..: Minimum Curvature units ........ : FEET Surface Lat..: 70.28325990 N Surface Lon~.: 148.24133627 W LeDa[ Description Surface ...... : 6298 FSL 68[ FEL S26 T11N R15S UM Tar~et ....... : 1508 FSL 306 FEL S23 TllN R15E UM BKL .......... : 2033 FSL 228 FEL S9~ TllN R15E UM LOCATIONS - AL4~SKA Zone: 4 X-Coord Y-Coord 717299.94 5956300.20 7[7600.00 5955600.00 7~7663.2~ 5959326.62 STATION ~,[EASURED INCL~ DIReCTiON ID~NTIFICAT~ON DEl>TH AN~LE AZI~ ~ 0,00 O.OO 0.00 BASE PB~OST ~B50.60 O.OO 0.00 KOP/~RVE 2.00/L00 2000.00 0.00 O.O0 2L00.O0 2.00 2200.00 4.00 8.50 2300.00 6.00 8.50 2400.00 B.O0 8.50 2500.00 10.0O 8.S0 2600.00 ~.aa a.5o 2700.00 14.00 8.50 2BOO,OD 16.00 8,50 2900.00 18.00 B.50 · j'-'[L',,r, vi:i ,ti'5,' :..;fiLL"-' j.J/&.L '.d;$,6 i';.4 PROPOSED WEL~ PROFILE VE~TICAL-DEPTRB SXCTIO~ TVD SUB-SEA DE~ART 0.00 -50.~0 0.00 [B50.~O 1800.Off. 0.00 2000.00 ~D49.40 0o00 2D99.98 2049.38 1.75 2[99.84 2149.24 6.98 2299.4~ 2248.65 15.69 2398.70 2348.10 29.B8 2497.47 2466.87 43.52 .2595.62 2545.~2 62.60 2693.06 2642.46 8S.~O 2759.6{ 2739.06 110.98 2865.27 2834.67 140.2L Prepared ..... : 22 Dec 299~ Vert seeC az.: B.50 KB elevation.: 50.60 f~ Mag~e~£~ Dcln: +28.$~? (E} ~cale Factor.: 0.99995364 Convergence..: +[.6~55~{24 , , ANADRILL APPROVED AKA-DPC FOR PERMITTING COORDINATES-FR(X~ A/~SKA zone 4 TOOb DL/ WELLHEAD X Y FACE 100 mmmf ~ sma msmm msm~ mmmmmm m 15.52 N 2.32 E 719301.8[ 5956315.78 43.04 N 6.43 E 717305.13 59563%3.41 63.91 N 9.25 H 717~0~ ~3B.67 N 20.73 ~ 71731~.65 5956439.4~ 3> Z Hid SLot STATION IDeNTIfICATION 9rs ~m~ mmmmmm MEASURED [NCLN OEFI~4 3000.00 20.00 3L00.00 22.00 3200.00 3300.00 26.00 3400.00 28.00 3700.00 30.00 3532.68 30.65 3600.00 32.00 3700.00 34.00 3fiO0.O0 36.00 EFD 2.00/100 CURVE 3857.66 35.15 SV3 4134.21 37.15 13-3/8" CS~ PT <Il> 41~6.75 37.~5 SV2 4372.60 37.15 SV[ 4905,83 37.[~ t~34 5566.53 37.LS UG1 6743.92 37.L5 TARGET *~*'****~**#* 7063.86 WS2 7383.80 37.L$ WS1 7640.28 7942.12 37,15 TD 9-5/8" CSG g~¢fl> 7942,12 37,15 PRO~DSED WELL AZIMUTH TVD SUB-SEA 8.50 2979.82 2929,22 8.50 3073.L? 3022.55 S.50 3165.2L 3114.6[ 8.50 3255.84 3205.24 $.50 3344.94 3294.34 9ECTXON D~PART 172.79 20~ .60 247.6? 259.93 335.33 8.50 3432.39 3381.79 383.8~ 8.50 3460.60 3~1~.00 ~00.3L ~.50 3$LB.1L 3~67.51 ¢35.3L B.50 3602.97 3551,37 ' &fi9,77 8.50 3683.88 3633.28 547.13 8.50 3730.18 3679.58 8.50 3950.60 3900.00 fi.SO 3960.60 3910.00 fi.SO ~140.60 4090.00 8.50 4565.~0 4SLS.OO 581.48 748.51 ?56.08 B92.~8 1224.52 8.50 5090.60 5040.00 1612.3~ fi.50 6030.68 $950.00 2324.63 8.S0 6285.60 6235.00 25[~.86 8.50 6540.60 6490.00 27[~.0~ 8.50 6?50.60 6700.00 2870.22 22 Dec 1997 Pa7e 2 COORD/RAT~S-FROM ALASKA Zone 4 TOOL WELLHEAD X Y FACE 170-.87 N 25.54 E 7L7320.53 5956471.73 ~ 206.31 N 30.83 H 719324.80 5956507-31 ~ 244.95 N 36.61 ~ 717329.&6 5956546.10 HS 286.75 N 42.86 ~ 7L~334,~9 5956~88.85 HS 331.65 N 49.57 ~ 719339.90 5956643.13 }IS 2.ao 2.00 2.00 2.00 2.00 379.59 N 56.73 ~ 7L9347.68 5956681.26 ~IS 2.00 395.91 N 59.17 ~ 7L?3&7.65 5956697.6~ ]..IS 2.00 43D.53 N 64.35 B 717351.82 5956732.39 ~ 2.00 484.39 N 72.~0 ~ 7~7358.3L S9567&6.~6 E~ 2.00 541.12 N $0.fi7 R 71736~.~4 5956843.~0 ~ 2.00 575.L0 K 85.95 R ~17369.24 5956877.51 HS 2.00 740.28 N 110.64 E 717389.L4 5957043.3~ HS 0.00 747.78 N 11L.76 E 717390.04 5957050.fi6 ~S 0.00 882,67 ~ 131.92 8 ?17406.30 S959186,28 BS 0.00 I201.18 H 179.52 E 71744~.68 5957506.0~ H~ 0.00 1594.63 N 238.33 E ?17492.09 5957900.98 HS 0.00 2299.10 N 3~3.62 S 717576.97 5958608.~6 E~ 0.00 2490.20 R 3~2.ifi B 917600.00 5958800.00 KS O.OO 2681.31 N 400.74 E 717623.03 5958991.84 ~ 0.00 283fi.69 ~ 42&.26 E 7~764~.99 5959L49.83 ~ 0.00 450.58 E 217663.2! 5959326.62 0.00 450.58 E 7Z7663.2L 5959326.62 0.00 8.50 6985.60 6935.00 3048.29 30L4.80- N 8.50 6985.60 6935.00 3048.29 3014.80 N Z ~0 (A.uadriLl (c) 97 GNIP2 3.2b.5 2:36 PM P} ANADRILL AY, A-DPC APPROVED FOR PERMITTING ONLY .......................... ~:.-..-.-~.:.~ .... ~..._-_- - : --..,~ ..... J TREE: FMC 20", 94#, H-40 13-3/8", 72#, L-80 9-5/8", 47 #, L-80 @ 7942' MD GNI #2 Proposed Completion Design K.B. ELEV = 50.4' 7" L-80 7"x 9-5/8" Packer 'XN' nipple, WLEG Cretaceous GNI Perforations DATE REVISED BY COMMENTS PRUDHOE BAY UNIT WELL: GNI #2 12/23/97 D. Nakamura Grind and Inject #2 APl NO 50-029-22XXX SEC 26; T11 N; R15E BP Exploration (Alaska) DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 11897 CK 111897N 100. O0 100. O0 PYMT COMMENTS' accompanu permit, to dritl app 1 ication HANDLING INST' s/h terrie hubble, x4628 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBEO ABOVE. i~liY_,lB I .., ,---~- FIELD & POOL WELL PERMIT CHECKLIST COMPANY INIT CLASS ADMINISTRATION ENGINEERING DATE GEOLOGY D~TE/ ,,'~¢ ,~ ,,.,,~ WELL NAME ~ ~'~ :,~ ~ / GEOL AREA ;~ ~ PROG, RAM: exp [] dev [] redrll [] serv-"~wellbore seg F_: ann. disposal para req ~'?~/~-'3 UNIT# /,~ ~'._~<~ ON/OFF SHORE 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Permit lee attached ....................... Lease nu m ber appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling, unil bounda~ o,.er.e,,s .......... Su~cient acreage available in drilling unit ............ If devialed, is wellbore plat included ............. Operator only affected pady ................... Operator has approprime bond in force ............. Permit can be issued without conse~ation order ....... Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided Su~ace casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & sud csg CMT vol adequate to tie-in long string to sud csg ........ C MT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... A~equate tankage or reseme pit ................. If a to-drill, has a ~ 0-403 for abandonment been approued. A0equate wellbore separation proposed ............. If 0Weber required, does it meet regulations .......... Drillm~ fluid pro,ram schematic & equip list adequate BO~Es, do theg meet m~ulation .... ............ BO¢fi press ratin~ appropriate; tom lo Choke manifol0 complies w/A~l ~P-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of ~2S ~as probable ............ ' 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. N 34. Contact name/phone for weekly,progress repqrts ...... / Y N lexploratory omyj GEOLOGY: ENGINEERING' ,c.,OMMISSIC~. RP .~/,,, .... JD BEH~ RNC~ DWJ._.¢:~ Comments/Instructions: co HOW/lit - A \FC)RM,~\,H,4, h.~I r¢,v f,q'q 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 ****************************** . ............................ . ............................ COMPANY NAME : ARCO AI_~SKA, INC. WELL NAME : GNI #2 FIELD NAI~E : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292285100 REFERENCE NO : 98285 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/19 ORIGIN : FLIC REEL NAME : 98285 CONTINUATION # '. PREVIOUS REEL : COFk4ENT : ARCO ALASKA INC, GNI #2, PRUDHOE BAY, API #50-029-22851-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/06/19 ORIGIN · FLIC TAPE NAME : 98285 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : ARCO ALASKA INC, GNI #2, PRUDHOE BAY, API #50-029-22851-00 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NAIV~ : API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL : FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING GNI #2 500292285100 ARCO Alaska, Inc. SCHLUMBERGER WELL SERVICES 19-JUN-98 RUN1 98285 E. Bartz W. Stafford RUN 2 RUN 3 .......... 26 liN 1SE 4298 681 51.20 49.70 20.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 12. 250 13.375 4137.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 3RD STRING PRODUCTION STRING REMARKS: THIS FILE CONTAINS THE LDWG FORMATTED PEX, AIT, AND BCS OPEN HOLE DATA AQUIRED ON ARCO ALASKA'S GN1 #2 WELL. THE BCS GAMF~A RAY IS THE PRIMARY DEPTH CONTROL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-OI~BER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUFk~ARY LDWG TOOL CODE .............. BCS AIT CNT SDN $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (M~ASURED DEPTH) START DEPTH STOP DEPTH ..................... 7905.0 4120.0 7934.0 4126.0 7912.0 4120.0 7922.0 4120.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: THIS FILE CONTAINS THE EDITED OPEN HOLE BCS, AIT, CNT, AND SDN CURVES. THE DATA HAS BEEN DECIMATED AND CLIPPED OF INVALID COUNTS AT FIRST READING AND AT CASING. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... BCS AIT CNT SDN RUN NO. PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 116 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 8 12 68 13 66 0 14 65 ?T 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFI~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI O0 000 O0 0 1 1 1 4 68 0000000000 SP BCS MV O0 000 O0 0 1 1 1 4 68 0000000000 TENS BCS LB O0 000 O0 0 1 1 1 4 68 0000000000 TEND BCS LB O0 000 O0 0 i 1 1 4 68 0000000000 MRES BCS OH~IM O0 000 O0 0 1 1 I 4 68 0000000000 MTE~BCS DEGF O0 000 O0 0 1 1 1 4 68 0000000000 DEV BCS DEG O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OP~4~ O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN OHI4~ O0 000 O0 0 1 1 1 4 68 0000000000 f4NOR SDN OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT O~ O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 4 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) AF20 AIT OHFk4 O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT OHIO4 O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT OH~E4 O0 000 O0 0 1 1 1 4 68 0000000000 AF90 AIT OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. TEND. BCS CNTC. CNT CRA T . CNT CALl. SDN MSFL. SDN AF20.AIT DT. BCS DEPT. TEND. BCS CNTC. CNT CRA T . CNT CALl. SDN MSFL. SDN AF20.AIT DT. BCS 7942.000 GR.BCS 1174.123 f4RES.BCS -999.250 CFTC. CNT -999.250 NRAT. CNT -999.250 DRHO.SDN -999.250 MINV. SDN -999.250 AF30.AIT -999.250 4120.000 GR.BCS 1099.093 F~ES.BCS 1522.019 CFTC. CNT 3.981 NRAT. CNT 12.968 DRHO. SDN 1.247 MINV. SDN -999.250 AF30.AIT -999.250 -999 250 SP.BCS -999 250 MTE~.BCS -999 250 FCNT. CNT -999 250 NPHI. CNT -999 250 PEF. SDN -999 250 FiNOR.SDN -999 250 AF60.AIT 40.553 SP.BCS 1.817 MTEM. BCS 414.851 FCNT. CNT 3.990 NPHI.CNT 1.429 PEF. SDN 3.066 FiNOR.SDN -999.250 AF60.AIT -36.063 TENS.BCS -999.250 DEV. BCS -999.250 NCNT. CNT -999.250 CPHI. CNT -999.250 RHOB.SDN -999.250 AFiO.AIT -999.250 AF90.AIT 6.938 TENS. B C S 87. 791 DEV. BCS 344. 651 NCNT. CNT 47. 634 CPHI. CNT 2.826 RHOB. SDN 2. 371 AFIO .AIT -999. 250 AF90 .AIT 5443 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 3038.000 35.997 1406.657 42.319 2.931 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUF~ARY LDWG TOOL CODE .............. BCS CNT $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 4120.0 4012.0 4120.0 4012.0 BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... BCS CNT REMARKS: THIS FILE CONTAINS THE EDITED CASED HOLE BCS AND CNT DATA. THE CURVES HAVE BEEN DECIMATED AND CLIPPED AT CASING AND AT LAST READING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: TYPE REPR CODE VALUE .............................. 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 TENS BCS LB O0 000 00 0 2 1 1 4 68 0000000000 HTEN BCS LB O0 000 O0 0 2 1 1 4 68 0000000000 MTEMBCS DEGF O0 000 O0 0 2 1 1 4 68 0000000000 GRCH BCS GAPI O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 RCFT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 RCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 4120.000 TENS.BCS 3038.000 HTEN. BCS 1099.093 MTEM. BCS GRCH. BCS 40.553 CNTC. CNT 1522.019 CFTC. CNT 414.851 RCFT. CNT RCNT. CNT 1406.657 CRAT. CNT 3.981 NRAT. CNT 3.990 NPHI. CNT CPHI.CNT 42.319 DEPT. 4012.000 TENS.BCS 2943.000 HTEN. BCS 1065.539 MTEM. BCS GRCH.BCS 47.107 CNTC. CNT 1220.711 CFTC. CNT 285.551 RCFT. CNT RCNT. CNT 1220.767 CRAT. CNT 4.412 NRAT. CNT 4.908 NPHI. CNT CPHI.CNT 54.370 87. 791 344. 651 47. 634 88.079 279.524 55.834 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMFL%RY FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN 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 tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH BHC 7956.0 4120.0 AIT 7956.0 4120.0 PEX 7956.0 4120.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 28-JAN-98 8C0-609 300 28-JAN-98 1048 28-JAN-98 7955.0 7945.0 4120.0 7912.0 TOOL NI]M~ER LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: GR CNL SDN AIT BHC $ GAM~A RAY COMPENSATED NEUTRON SONIC DENSITY ARRAY INDUCTION BOEHOLE COMP SONIC HGR HCNT HRGD 842 AIT-H DSLT-TCC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12.250 4137.0 4120.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) : 48.0 MUD PH: 8.9 FLUID LOSS (C3): 6.3 MAXIMUM RECORDED TEMPERATURE (DEGF) : 160.0 RESISTIVITY (OHIO,) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.260 MUD AT BOTTOM HOLE TE~qPERATURE (BHT) : MUD FILTRATE AT (MT): 2.1 O0 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 760 MUD CAKE AT (BHT) : 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.5 REMARKS: Two 1.5" standoffs run on Induction tool. Four 1.5" standoffs run on BHC Sonic. Bowspring run on Neutron. Sandstone matrix; ~4DEN = 2.65 g/cc used for all porosity c No stretch added to wireline depth as per client request. Rig: Nabors 18E THIS FILE CONTAINS THE MAIN PASS RAW OPEN HOLE DATA AQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUF~ NUFi~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 TENS PEX LB 00 000 00 0 3 1 1 4 68 0000000000 HTEN PEX LB O0 000 O0 0 3 1 1 4 68 0000000000 FIRES PEX OHFk~ O0 000 O0 0 3 1 1 4 68 0000000000 MTEMPEX DEGF O0 000 O0 0 3 1 1 4 68 0000000000 DEVI PEX DEG O0 000 O0 0 3 1 1 4 68 0000000000 GR BHC GAPI O0 000 O0 0 3 1 1 4 68 0000000000 SP PEX MV O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS O0 000 O0 0 3 1 1 4 68 0000000000 RCNT PEX CPS O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 10 DEPT. 7956.000 TENS.PEX 3277.000 HTEN. PEX MTEM. PEX 110.133 DEVI.PEX -999.250 GR.BHC NPOR.PEX 31.560 NPHI.PEX 39.335 TNPH. PEX RTNR.PEX 3.170 CNTC.PEX 2550.080 CFTC. PEX RCFT. PEX 802.273 DT.BHC 91.348 DEPT. 4120.000 TENS.PEX 3038.000 HTEN. PEX MTE~.PEX 87.791 DEVI.PEX 35.997 GR.BHC NPOR.PEX 45.284 NPHI.PEX 47.634 TNPH. PEX RTNR.PEX 3.990 CNTC. PEX 1522.019 CFTC. PEX RCFT. PEX 344.651 DT. BHC 189.795 355.024 MRES.PEX 46.251 SP.PEX 31.959 TNRA.PEX 856.191 RCNT. PEX 1099.093 MRES.PEX 40.553 SP.PEX 42.319 TNRA.PEX 414.851 RCNT. PEX 1.450 -33.563 3.007 2529.176 1.817 6.938 3.981 1406.657 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NACRE : EDIT .004 SERVICE : FLIC VERSION : O01COi DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLEMAIN 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 tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH BHC 7956.0 AIT 7956.0 STOP DEPTH 4120.0 4120.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 11 PEX LOG HEADER DATA 7956.0 4120.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNL COMPENSATED NEUTRON SDN SONIC DENSITY AIT ARRAY INDUCTION BHC BOEHOLE COMP SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHb94) AT TEMPERATURE (DEGF) : MUD AT MEASURED TE~IPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) .' NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-JAN-98 8C0-609 300 28-JAN-98 1048 28-JAN-98 7955.0 7945.0 4120.0 7912.0 TOOL STANDOFF (IN): TOOL NUMBER ........... HGR HCNT HRGD 842 AIT-H DSLT-TCC REMARKS: 12.250 4137.0 4120.0 LSND 9.60 48.O 8.9 6.3 160.0 2. 260 66.0 2.100 66.0 1. 760 66.0 Two 1.5" standoffs run on Induction tool. Four 1.5" standoffs run on BHC Sonic. Bowspring run on Neutron. 1.5 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE 12 Sandstone matrix; ~4DEN = 2.65 g/cc used for all porosity c No stretch added to wireline depth as per client request. Rig: Nabors 18E THIS FILE CONTAINS THE MAIN PASS RAW OPEN HOLE DATA AQUIRED AT 0.25' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 AFiO AIT Okff4M O0 000 O0 0 4 1 1 4 68 0000000000 AF20 AIT OH~M O0 000 O0 0 4 1 1 4 68 0000000000 AF30 AIT OH~4~ O0 000 O0 0 4 1 1 4 68 0000000000 AF60 AIT OHPiM O0 000 O0 0 4 1 1 4 68 0000000000 AF90 AIT Otff4M O0 000 O0 0 4 1 1 4 68 0000000000 AIBD AIT IN O0 000 O0 0 4 1 1 4 68 0000000000 AFRT AIT OHMM O0 000 O0 0 4 1 1 4 68 0000000000 * * DA TA * * LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 13 DEPT. 7956.000 AFiO.AIT AF60.AIT 3.900 AFgO.AIT 3.112 AF20.AIT 4.017 AIBD.AIT 3.363 AF30.AIT 4.071 AFRT.AIT 3.547 3.968 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE · 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUFmfARY FILE HEADER FILE NUMBER 5 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 tool strings per run. 1 1 1 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH BHC 7956.0 4120.0 AIT 7956.0 4120.0 PEX 7956.0 4120.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: 28-JAN-98 8C0-609 300 28-JAN-98 1048 28-JAN-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-i998 12:31 PAGE: 14 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNL COMPENSATED NEUTRON SDN SONIC DENSITY AIT ARRAY INDUCTION BHC BOEHOLE COMP SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 7955.0 7945.0 4120.0 7912.0 TOOL NUM~ER ........... HGR HCNT HRGD 842 AIT-H DSLT-TCC 12.250 4137.0 4120.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) : 48.0 MUD PH: 8.9 FLUID LOSS (C3): 6.3 MAXIMUM RECORDED TEMPERATURE (DEGF) : 160.0 RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT FiEASURED TEMPERATURE (MT): 2.260 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 2.100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT) '. 1. 760 MUD CAKE AT (BHT) : 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN) '. 1.5 REMARKS: Two 1.5" standoffs run on Induction tool. Four 1.5" standoffs run on BHC Sonic. Bowspring run on Neutron. Sandstone matrix; 14DEN = 2.65 g/cc used for all porosity c No stretch added to wireline depth as per client request. Rig: Nabors 1SE THIS FILE CONTAINS THE MAIN PASS RAW OPEN HOLE DATA AQUIRED AT 0.1667' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUAIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 TT1 PEX US O0 000 O0 0 5 1 1 4 68 0000000000 TT2 PEX US O0 000 O0 0 $ 1 1 4 68 0000000000 TT3 PEX US O0 000 O0 0 5 1 1 4 68 0000000000 TT4 PEX US O0 000 O0 0 5 1 1 4 68 0000000000 RXOZ PEX Oh?4~ O0 000 O0 0 5 1 1 4 68 0000000000 RX08 PEX OH~q O0 000 O0 0 5 1 1 4 68 0000000000 HCNT PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 HCFT PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 HGR PEX GAPI O0 000 O0 0 5 1 1 4 68 0000000000 RHFT PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 RHNT PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 DPHZ PEX PU O0 000 O0 0 5 1 1 4 68 0000000000 HTNP PEX PU O0 000 O0 0 5 1 1 4 68 0000000000 HNPO PEX PU O0 000 O0 0 5 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 PEFZ PEX O0 000 O0 0 5 1 1 4 68 0000000000 HDRA PEX G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 HMIN PEX OH~4M O0 000 O0 0 5 1 1 4 68 0000000000 H~NO PEX OH~4 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 16 ** DATA ** DEPT. 7956.000 TT1.PEX TT4.PEX 388.516 RXOZ.PEX HCFT. PEX 856.191 HGR.PEX DPHZ.PEX 60721.211 HTNP. PEX PEFZ.PEX -999.250 PiDRA.PEX 613. 828 TT2. PEX 2. 724 RX08. PEX 46. 251 RHFT. PEX 31 . 959 HNPO. PEX -999. 250 HMIN. PEX 430. 469 TT3. PEX 2. 794 HCNT. PEX 802.273 R3{NT. PEX 31. 560 RHOZ. PEX 2. 564 HPiNO . PEX 570.547 2550.080 2529.176 -999.250 2.289 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUF~N~Y FILE HEADER FILE NUMBER 6 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 tool strings per run. 1 1 1 0.0833 VENDOR TOOL CODE START DEPTH ........................... BHC 7956.0 AIT 7956.0 PEX 7956.0 $ LOG HEADER DATA STOP DEPTH .......... 4120.0 4120.0 4120.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 17 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 28-JAN-98 8C0-609 300 28-JAN-98 1048 28-JAN-98 7955.0 7945.0 4120.0 7912.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNL COMPENSATED NEUTRON SDN SONIC DENSITY AIT ARRAY INDUCTION BHC BOEHOLE COMP SONIC $ TOOL NUMBER ........... HGR HCNT HRGD 842 AIT-H DSLT-TCC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12.250 4137.0 4120.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) : 48.0 MUD PH: 8.9 FLUID LOSS (C3): 6.3 MAXIMUM RECORDED T~'~4PERATURE (DEGF) : 160.0 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 2. 260 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 2.100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 760 MUD CAKE AT (BHT) : 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 Two 1.5" standoffs run on Induction tool. Four 1.5" standoffs run on BHC Sonic. Bowspring run on Neutron. Sandstone matrix; MDEN = 2.65 g/cc used for all porosity c No stretch added to wireline depth as per client request. Rig: Nabors 18E THIS FILE CONTAINS THE MAIN PASS RAW OPEN HOLE DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 18 AQUIRED AT O. 0833 ' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 O. 083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NT]M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NI]b~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 6 1 1 4 68 0000000000 HCAL PEX IN O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 7956. 000 HCAL. PEX 4. 071 ** END OF DATA ** LIS Tape verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 19 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH BHC 7962.0 AIT 7962.0 PEX 7962.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 7627.0 7627.0 7627.0 28-JAN-98 8C0-609 300 28-JAN-98 1048 28-JAN-98 7955.0 7945.0 4120.0 7912.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNL COMPENSATED NEUTRON TOOL NUM~ER ........... HGR HCNT .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 2O SDN SONIC DENSITY AIT ARRAY INDUCTION BHC BOEHOLE COMP SONIC $ HRGD 842 AIT-H DSLT-TCC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12.250 4137.0 4120.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) : 48.0 MUD PH: 8.9 FLUID LOSS (C3): 6.3 MAXIMUM RECORDED TEMPERATURE (DEGF) : 160.0 RESISTIVITY (OHF~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 260 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (FIT): 2. 100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 760 MUD CAKE AT (BHT) : 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) .' THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: Two 1.5" standoffs run on Induction tool. Four 1.5" standoffs run on BHC Sonic. Bowspring run on Neutron. Sandstone matrix; FIDEN = 2.65 g/cc used for all porosity c No stretch added to wireline depth as per client request. Rig: Nabors 18E THIS FILE CONTAINS THE RAW REPEAT OPEN HOLE DATA AQUIRED AT O. 5 ' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX) ....................................................................................... DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 GR PEX GAPI O0 000 O0 0 7 1 i 4 68 0000000000 SP PEX MV O0 000 O0 0 7 1 1 4 68 0000000000 DT PEX US/F O0 000 O0 0 7 1 1 4 68 0000000000 TENS PEX LB O0 000 O0 0 7 1 1 4 68 0000000000 HTENPEX LB O0 000 O0 0 7 1 1 4 68 0000000000 MRES PEX OH~4 O0 000 O0 0 7 1 1 4 68 0000000000 MTEMPEX DEGF O0 000 O0 0 7 1 1 4 68 0000000000 DEVI PEX DEG O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PEX CPS O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PEX CPS O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PEX CPS O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PEX CPS O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PEX O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PEX O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PEX PU O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PEX PU O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PEX PU O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-I998 12:31 PAGE: 22 DEPT. 7962. 000 GR. PEX TENS. PEX 2432. 000 HTEN. PEX DEVI.PEX -999.250 CNTC. PEX RCNT. PEX 2357. 949 TNRA. PEX NPHI. PEX 40. 515 NPOR. PEX DEPT. 7627. 000 GR. PEX TENS. PEX 5006. 000 HTEN. PEX DEVI . PEX 36.619 CNTC. PEX RCNT. PEX 2202. 416 TNRA. PEX NPHI. PEX 27.785 NPOR. PEX 77. 085 SP. PEX 34.122 MRES. PEX 2375. 671 CFTC. PEX 3. 392 RTNR. P~ 37. 353 72. 574 SP. PEX 1095. 001 FIRES. PEX 2314. 528 CFTC. PEX 2. 833 RTNR. PEX 28.326 -34. 250 DT. PEX 1. 464 MTE~. PEX 707. 612 RCFT. PEX 3.577 TNPH. PEX -58.688 DT. PEX 1.464 MTE~.PEX 791.050 RCFT. PEX 2.990 TNPH. PEX 88.887 108.874 667.418 37.834 95. 225 109. 096 719. 702 30. 016 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: O . 2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH BHC 7962.0 AIT 7962.0 PEX 7962.0 $ STOP DEPTH .......... 7627.0 7627.0 7627.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 23 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 28-JAN-98 8C0-609 300 28-JAN-98 1048 28-JAN-98 7955.0 7945.0 4120.0 7912.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNL COMPENSATED NEUTRON SDN SONIC DENSITY AIT ARRAY INDUCTION BHC BOEHOLE COMP SONIC $ TOOL NUMBER HGR HCNT HRGD 842 AIT-H DSLT- TCC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12.250 4137.0 4120.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) : 48.0 MUD PH: 8.9 FLUID LOSS (C3): 6.3 MAXIMUM RECORDED TEMPERATURE (DEGF) : 160.0 RESISTIVITY (OHI4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 260 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 2.100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 760 MUD CAKE AT (BHT): 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: Two 1.5" standoffs run on Induction tool. Four 1.5" standoffs run on BHC Sonic. Bowspring run on Neutron. Sandstone matrix; MDEN = 2.65 g/cc used for all porosity c No stretch added to wireline depth as per client request. LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 24 Rig: Nabors 18E THIS FILE CONTAINS THE RAWREPEAT OPEN HOLE DATA AQUIRED AT O. 25 ' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AU3FI~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 8 1 1 4 68 0000000000 AFiO AIT 0H~94 O0 000 O0 0 8 1 1 4 68 0000000000 AF20 AIT OH~4~ O0 000 O0 0 8 1 1 4 68 0000000000 AF30 AIT 0H~94 O0 000 O0 0 8 1 1 4 68 0000000000 AF60 AIT 0H~94 O0 000 O0 0 8 1 1 4 68 0000000000 AF90 AIT OH~4~ O0 000 O0 0 8 I 1 4 68 0000000000 AIBD AIT IN O0 000 O0 0 8 1 1 4 68 0000000000 AFRT AIT 0~4 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 25 DEPT. 7962. 000 AFIO.AIT AF60. AIT 3.916 AF90. AIT 3.330 AF20.AIT 3. 981 AIBD.AIT 3.407 AF30.AIT 8.986 AFRT. AIT 3.577 3.981 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREFiENT : FILE SUF~fARY FILE HEADER FILE NUMBER 9 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... BHC 7962.0 7627.0 AIT 7962.0 7627.0 PEX 7962.0 7627.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGBR (FT) : TOP LOG INTERVAL (FT) : 28-JAN-98 8C0-609 300 28-JAN-98 1048 28-JAN-98 7955.0 7945.0 4120.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center ig-JUN-1998 12:~1 PAGE: 26 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAI4MA RAY CArL COMPENSATED NEUTRON SDN SONIC DENSITY AIT ARRAY INDUCTION BHC BOEHOLE COMP SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 7912.0 TOOL NUMBER ........... HGR HCNT HRGD 842 AIT-H DSLT-TCC 12.250 4137.0 4120.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) : 48.0 MUD PH: 8.9 FLUID LOSS (C3): 6.3 MAXIMUM RECORDED TEMPERATURE (DEGF) : 160.0 RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 260 MUD AT BOTTOM HOLE TE~4PERATURE (BHT) : MUD FILTRATE AT (MT): 2. 100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1. 760 MUD CAKE AT (BHT) : 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: Two 1.5" standoffs run on Induction tool. Four 1.5" standoffs run on BHC Sonic. Bowspring run on Neutron. Sandstone matrix; NDEN = 2.65 g/cc used for all porosity c No stretch added to wireline depth as per client request. Rig: Nabors 18E THIS FILE CONTAINS THE RAW REPEAT OPEN HOLE DATA AQUIRED AT 0.1667' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-JUN-1998 12:31 PAGE: 27 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 $ 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUFiB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 9 1 1 4 68 0000000000 DEPT FT RX08 PEX O~ O0 000 O0 0 9 1 1 4 68 0000000000 HCNT PEX CPS O0 000 O0 0 9 1 1 4 68 0000000000 HCFT PEX CPS O0 000 O0 0 9 1 1 4 68 0000000000 HGR PEX GAPI O0 000 O0 0 9 1 1 4 68 0000000000 RHFT PEX CPS O0 000 O0 0 9 1 1 4 68 0000000000 RHNT PEX CPS O0 000 O0 0 9 1 1 4 68 0000000000 TT1 PEX US O0 000 O0 0 9 1 1 4 68 0000000000 TT2 PEX US O0 000 O0 0 9 1 1 4 68 0000000000 TT3 PEX US O0 000 O0 0 9 1 1 4 68 0000000000 TT4 PEX US O0 000 O0 0 9 1 1 4 68 0000000000 DPHZ PEX PU O0 000 O0 0 9 1 1 4 68 0000000000 HTNP PEX PU O0 000 O0 0 9 1 1 4 68 0000000000 HNPO PEX PU O0 000 O0 0 9 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 9 1 1 4 68 0000000000 PEFZ PEX O0 000 O0 0 9 1 1 4 68 0000000000 HDRA PEX G/C3 O0 000 O0 0 9 1 1 4 68 0000000000 RXOZ PEX OH~4 O0 000 O0 0 9 1 1 4 68 0000000000 H~IN PEX OH~4 O0 000 O0 0 9 1 1 4 68 0000000000 HFiNO PEX OH~4~ O0 000 O0 0 9 1 1 4 68 0000000000 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAiWiE : GNI #2 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API~ER : 50-029-22851-00 REFERENCE NO : 98286 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/22 ORIGIN : FLIC REEL NAME : 98286 CONTINUATION # : PREVIOUS REEL COf4FiENT : ARCO ALASKA INC., PRUDHOE BAY GNI 2, API #50-029-22851-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/06/22 ORIGIN : FLIC TAPE NAME : 98286 CONTINUATION # : 1 PREVIOUS TAPE CO~ : ARCO ALASKA INC., PRUDHOE BAY GNI 2, API #50-029-22851-00 TAPE HEADER PRUDHOE BAY MWD LOGS WELL NA~4E : OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING GNI #2 500292285100 ARCO Alaska, INC. SCHLUMBERGER WELL SERVICES 22-JUN-98 BIT RUN 1 ......... 98286 BARNEY STAFFORD BIT RUN 2 BIT RUN 3 .................. 26 liN 1SE 51.20 49.70 20.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 16.000 20.000 110.0 12.250 13.375 4139.0 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 3RD STRING PRODUCTION STRING REMARKS: DATA FROM THE MWD GR LOGGED 22-JAN TO 28-JAN-98. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 1 EDITEDMERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INC~: 0.5000 FILE SUM~IARY LDWG TOOL CODE .............. $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH ..................... 4000.0 7890.0 BASELINE DEPTH .............. 88888.0 7897 5 7894 5 7879 0 7875 0 7863 5 7853 0 7846.0 7840 0 7832 0 7794 0 7739 0 7718 0 7703 5 7688 0 7667.0 7588.5 7569.0 7560.0 7550.5 7543.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD ....... 88877.0 7886.5 7883.0 7869.0 7865.5 7853.5 7847.0 7838.0 7831.5 7822.5 7785.0 7729.5 7707.0 7691.0 7676.5 7656.0 7579.5 7559.0 7550.5 7540.0 7534.0 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 7518.0 7508.5 7486.0 7463.0 7428.5 7403.5 7401.0 73 92.5 7390.5 7353.0 7339.5 73 02.0 72 81.0 7250.0 7200.5 7186.0 7171.5 7165.0 7163.0 7156.0 7152.0 7136.0 7092.0 7027.5 6996.5 6989.5 6893.5 6885.0 6875.0 6718.0 6704.0 6701.0 6689.0 6661.0 6624.5 6611.0 6546.0 653 8.5 6523.5 6509.0 6486.5 6472.0 6417.0 6392.0 63 62.5 6309.5 6296.5 6288 5 62 71 5 6259 5 6250 5 6223 0 6211 5 6204 0 6197 0 7507.0 7498.5 7475.5 7454.5 7418.5 7394.5 7393.0 7384.0 73 81.0 7345.0 7330.0 7293.5 7272.0 7241.5 7191.5 7176.5 7164.0 7157.0 7154.0 7147.5 7144.0 7127.0 7081.5 7016.0 6986.5 6977.0 6881.5 6872.5 6863.0 6705.5 6690.5 6688.5 6677.0 6649.5 6610.5 6598.5 6533.5 6525.0 6512.0 6496.5 64 75.0 6459.0 6402.5 6378.0 6347.5 6293.5 6283.5 6276.0 6259.5 6244.0 6237.0 6210.0 6199.0 6190.5 6184.0 22-JUN-1998 15:55 PAGE: LIS ~ape Verification Listing Schlumberger Alaska Computing Center 6172.0 6158.5 6166.5 6153 . 5 6125.5 6113.0 6103.5 6093.0 6095.5 6083.5 6052.0 6041 . 0 6026.0 6014.5 5987.5 5975.5 5891.5 5880.0 5861.0 5848.5 5838.0 5826.5 5827.5 5815.5 5765.0 5754.0 5761.5 5749.5 5752.0 574 O. 5 5723.0 5712.0 5709.5 5698.0 5675.5 5664.5 5666.0 5655.5 5641.5 5632.0 5622.0 5611 · 5 5615.5 5603.5 5572.5 5561.0 5561 · 0 5548.5 5547.5 5536.0 5539.5 5527.5 5534.0 5523.5 5517.0 5504.0 5492.5 5480.0 5446.0 5433.0 5438.0 5425.5 5424.5 5412.5 5344.5 5333.0 5298.0 5286.0 5293.0 5280.5 5279.5 5267.5 5270.5 5260.0 5235.5 5223 · 5 5204.0 5191.0 5184.0 5171 · 5 5048.5 5035.5 5041.0 5028.5 5013.0 5000.0 5010.0 4996.5 5006.5 4992.0 4990.5 4976.5 4951.0 4937.5 4935.0 4922.5 4916.5 4903.5 4854.5 4842.0 4837.5 4823.0 4821.5 4806.5 4791.5 4777.5 4750.0 4735.5 4738.5 4724.5 22-JUN-1998 15:55 PAGE: LIS ~ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 PAGE: 4724.0 4638.5 4616.5 4608.5 4575.5 4562.5 4554.5 4508.0 4456.5 4446.0 4424.5 4395.0 4372.0 4329.0 4324.5 4285.0 4264.0 4256. 4247 4242 4219 4205 4148 4143 100 MERGED DATA SOURCE LDWG TOOL CODE $ REM_ARKS: 4710.5 4625.5 4603.0 4596.0 4562.0 4551.0 4542.0 4495.0 4443.0 4433.5 4411.5 4381.5 4359.0 4316.5 4310.5 4270.0 4250.5 4240.5 4230.5 4223.5 4201.0 4187.0 4127.5 4123.5 80.0 BIT RUN NO. MERGE TOP MERGE BASE THIS IS THE EDITEDDATA FROM THE REAL TIME MWDGR THAT WAS LOGGED 22-JAN TO 28-JAN 1998. THE LOG HAS BEEN DEPTH SHIFTED TO THE OH BHC GR LOGGED 29-JAN-98. THE DATA WAS INTERPOLATED ATAKICS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 PAGE: 6 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 51 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 PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT 4000203 O0 000 O0 0 1 1 1 4 68 0000000000 GRRWMWD AAPI 4000203 O0 000 O0 0 1 1 1 4 68 0000000000 GRIN MWD AAPI 4000203 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000203 O0 000 O0 0 1 1 1 4 68 0000000000 GR BHC GAPI 4000203 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. GR.BHC 7905.000 GRRW. MWD -999.250 GRIN. MWD -999.250 ROP.MWD -999.250 67.959 DEPT. GR.BHC 7000.000 GRRW. MWD -999.250 GRIN.MWD 83.723 43.844 ROP.MWD 38.370 DEPT. GR. BHC 6000.000 GRRW. MWD -999.250 GRIN. MWD 72.789 71.025 ROP.MWD 53.813 DEPT. 5000.000 GRRW.MWD 62.970 GRIN. MWD 62.970 ROP.MWD 119.050 GR.BHC 64.949 DEPT. 4000.500 GRRW. MWD -999.250 GRIN.MWD -999.250 ROP.MWD -999.250 GR.BHC -999.250 ** END OF DATA ** LIS ~ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 4020.0 7901.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (f~MORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GA~A RAY $ 28-JAN-98 IDEAL 4.2B REAL-TIME 7955.0 4050.0 7955.0 8O 35.8 38.0 TOOL NUMBER ........... MWD GR LIS ~ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 16.000 110.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 9.80 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: THE RAW DATA WAS INTERPOLATED AT AK ICS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 4000203 GR MWD AAPI 4000203 GR INT AAPI 4000203 ROP5 MWD F/HR 4000203 ROP5 INT F/HR 4000203 VDEPMWD FT 4000203 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7901.000 GR.MWD 59.350 ROP5.INT 67.940 VDEP.MWD 6935.960 DEPT. 7000.000 GR.MWD 92.650 ROP5.INT 113.360 VDEP.MWD 6213.750 DEPT. 6000.000 GR.MWD -999.250 ROP5.INT 36.980 VDEP.MWD 5418.830 DEPT. 5000.000 GR.MWD -999.250 ROPS.INT 146.680 VDEP.MWD 4646.450 DEPT. 4020.500 GR.MWD -999.250 ROPS.INT -999.250 VDEP.MWD 3897.970 GR.INT 59.350 ROP5.MWD GR. INT 92.650 ROP5. MWD GR.INT 73.500 ROPS.MWD 67.940 113.360 36.980 GR. INT 62. 970 ROPS.MWD 146. 680 GR.INT -999.250 ROPS.MWD -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : Lis ~-ape Verification Listing Schlumberger Alaska Computing Center 22-JUN-1998 15:55 PAGE: 10 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/06/22 ORIGIN · FLIC TAPE NAME : 98286 CONTINUATION # : 1 PREVIOUS TAPE : COf4~ENT : ARCO ALASKA INC., PRUDHOE BAY GNI 2, API #50-029-22851-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/06/22 ORIGIN : FLIC REEL NAME : 98286 CONTINUATION # : PREVIOUS REEL : COM~4F2VT : ARCO ALASKA INC., PRUDHOE BAY GNI 2, API #50-029-22851-00