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Home My WebLink About198-199o7/27no • • Schtum6trger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # N0.5567 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD P2-16 BB6M-00027 LDL - 1 07/20/10 1 y F-03A AYKP-00096 SCMT ~ 1 - 07/22/10 1 1 V-225 S-100 BBKA-00039 BCZ2-00014 USIT USIT «- r ~ 07/01/10 07/14/10 1 1 1 1 2-58/5-09 BCZ2-00016 LDL 07/17/10 1 1 1-15/P-25 AYKP-00094 LDL _ 07/11/10 1 1 W-19A BCR0.00036 USIT 07/25/10 1 1 01-228 AZ2F-00042 MCNL _ 05/19/10 1 y B-20 AY1M-00042 RST - 05/07/10 1 1 04-20 6-18 OS-32A BCRJ-00020 AYKP-00082 89K5-00040 RST RST RST 05/30/10 06/02/10 05/19/10 1 1 1 i 1 1 H-25 P2-34 BCRD-00017 AVYO-00063 RST RST - 05/10/10 04/17/10 1 1 1 1 at FACE ACI[Nl1W1 cnr_o oen aor ov mnuu, r ..,.. ..r: ........... ....~ ........ _._.. __ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2635 ~W a«~. ~ a a~~r~ ~~ ib • • ~~tQ~[~ 0~ GI~Q~~Q /~..~.~LL~..~. Robert Tirpack ~~ Engineering Team Leader ` BP Exploration (Alaska), Inc. /~ ~ '~ 1~ P.O. Box 196612 s- , ,~t~,, ,;;~;^~, Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-19A Sundry Number: 310-148 Dear Mr. Tirpack: 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. 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, aniel T. Seamount, Jr. Chair DATED this ~ day of May, 2010. Encl. ' ,~ ~ ,. (~ STATE OF ALASKA ~~L°~ w ~ ,1I' I ALASKI~L AND GAS CONSERVATION COMMIS~I ,,G~~ ~~~~ S APPLICATION FOR SUNDRY APPROVAL MAY ~ 6 2010 ~"'"~ 20 AAC 25.280 1. Type of Request: ~ ~ ~ ~ ~mjg$~ ^ Abandon ®Plug for Redrill .. ^ Perforate New Pool ^ Repair Well ^ Change pprove ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 198-199 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22006-01-00 - 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 W-19A- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028263 & 028261 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11 • - -PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14500' - 9092' ~ 14406' 9065' None Yes, See Diagram Casin Len Size MD TVD Burst Colla Structural Conductor 11 11 ' Surface 2692' 1 -3/ " 2 2687' 4 27 Intermediate 104 9-5/ " 104 3' 417' 70 476 Production Liner 627' 7" 10 ' - 1 3 ' 8307' - 8768' 7240 5410 Liner 3721' 4-1/2" 1 774' - 144 5' 8646' - 9 91' 4 0 7 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11154' - 13980' 8904' - 9016' 4-1/2", 12.6# L-80 10779' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV 10723' / 8607' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 14, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG ~ Plugged ^ SPLUG Commission Representative: ~" ~/ _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garret Staudin er 564-4242 Printed Name obert Tirpack Title Engineering Team Leader Prepared By Name/Number: Signatur Phone 564-4166 Oate ~ ( ~ Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ,~,7,/ Sundry Number: ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance * 350 o p S ~, ~o P % -~- Other: // ~-Z 56 ~ ~ s c. Ann. ~-t !~ S'~ ~ `-'`-~~-- ^ ~~e~a.y eX ~cs'f'ih r~ L l~~s ~ccep~.~ ~. ZU ~~ L Z~S. Z ~'S ~~t b Subsequent Form Required: ~~ -~D ~ ~' Q ~ Approved By: COMMISSIONER THE OMMISSION Date S ~ `, FormF~MS MAY 12 ~ QR~~f~ ~~-~-~a ~~ ~-~ ~r Submit In Duplicate • • by ~ ~. W-19B/BL1 Rig Sidetrack Well Type: Producer Current Status: W-19A is completed with 4-1/2" liner and W-19AL1 is completed with 3-1/2" x 2-7/8" liner outside of a window in the 4-1/2" liner. 4-1/2" L-80 tubing is inside 9-5/8" casing with a 7" liner and is currently shut-in. Request: Abandon Reason for Sundry Application: As part of the rig sidetrack operation, the existing W-19A perforations and W-19AL1 slotted liner will be permanently abandoned as follows: W-19A P&A: A cement retainer will be set in the 4-1 /2" liner below the window for the AL1 lateral. 50 bbls of 15.8 ppg Class G cement will be pumped through the cement retainer by means of coil. The cement will be placed /squeezed into the W-19A lateral and 1 bbls will be laid on top of the cement retainer. The cement plug will be pressure tested to 2000 psi. W-19AL1 P&A: 34 bbls of 15.8 ppg Class G cement will be placed in the AL1 lateral by means of coil. A TOC will be targeted at 10,000' MD. Reason for Sidetrack: W-19A and W-19AL1 is shut in due to b~iyh water cif. In addition, a tubing caliper indicated that the tubing was generally in poor condition with possible buckled tubing. This prevents the option of a coil sidetrack. Current Status: W-19A was drilled in 1998 with IP = 700 BOPD with 45% WC. W-19AL1 was drilled in March 2003 with incremental production of 300 BOPD with 95% WC. Average production in 2006 was 190 BOPD with 95% WC. A patch was installed across W-19AL1 in 2007 to see what W-19A could produce.` The 2007 average production was 24 BOPD with 99% WC. A MIT-IA passed to 3000 psi on 2/16/2003. A MIT-OA failed on 2/14/2003 with a LLR of 2 bpm at 1200 psi. The tubing has had no pressure tests since completion. A caliper run on 5/8/2007 indicates up to 80% penetration at 6499' MD. 50% tubing penetrations over half of the tubing string with less than 10% body metal loss. The caliper also seemed to indicate buckled tubing from 7500' - 10600' MD. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. • C~ Scope of Work: Pump 50 bbls of cement through a cement retainer to P&A W-19A. Squeeze 34 bbls of cement into the W-19AL1 lateral, targeting a TOC at 10,000' MD. Cut and pull the 4-1/2" L-80 completion. Cut and pull the 9-5/8" L-80 intermediate casing. MASP: 2853 psi Estimated Start Date: May 14, 2010 Pre-riq prep work: P&A Existin W-19A & W-19AL1 roduction intervals: 1 S Drift 4 '/z" tubing to top of KB patch at 10926'MD. POOH LD Drift. Pull KB atch with GS s ear. 2 E RU E-line. Set cement retainer below W-19AL1 window. Set depth will be ' 11,075' MD in the middle of a full oint. 3 C RIH and sting into cement retainer. Pump/squeeze 50 bbls 15.8 ppg Class G cement to P&A W-19A. La 1 bbls above cement retainer. TOH. Add regular cementing nozzle to coil. TIH to top of the AL1 window at 10948' MD. Perform infectivity test. Pump 34 bbls of cement (open hole volume + 4 C 40% excess). Do NOT run aggregate. Objective of the P&A is to seal off of the water communication along the outside of the AL1 liner. Perform hesitation s ueezes as necessa .Tar et TOC at 10,000' MD. 5 F MIT Tubing to 2,000 psi for 30 minutes. 6 S RU Slickline. Drift 4-1/2" tubing and tag TOC. RIH and pull bottom GLM and leave o en for circulatin . 7 E RU E-line. PU and run Jet Cutter & CCL to approximately 3000 feet MD. ' Perform 4'/i" tubin cut in middle of a oint C«~ a roximatel 3000'MD. MIT T X PC to 2,500psi for 30 minutes. Displace the well to clean seawater by 8 F circulating down the tubing through the open GLM. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. Bleed casin and annulus ressures to zero. PPPOT-T (Positive Pressure Pack Off Test -Tubing) and PPPOT-IC (Positive 9 W Pressure Pack Off Test -Inner Casing). Tubing and 9 5/8" Casing will be ulled. All lock down screws need to be functional. Set a BPV in the tubing hanger. Secure the well. Remove the well house, 10 O level the pad as necessary. Provide total well preparation cost on the handover form. MIT OA with diesel or dead crude to 2000psi, record liquid leak rate (LLR) for 11 O 30 minutes and chart (last test in 2003 MIT OA leaked 2 bpm C~ 1250psi). Leave o en to bleeder tank and monitor OA for flow. Proposed Procedure: 1. MIRU Doyon 14. 2. Pull BPV. Circulate out freeze protection through tubing cut & displace well to seawater. 3. Install TWC and test f/below to 1000psi to confirm barriers. Combination MIT T x IA to 2500psi. 4. Nipple down tree and adaptor. 5. Nipple up and test BOPE to 3,500 psi. ~ 6. Pull TWC. (Blanking plug?) Back out lockdown screws. ' , 7. Pull tubing hanger, and 4-1 /2" tubing from the pre-rig cut. °~~ ~s'~ ~- P~ s 8. PU enough 5"DP and DC's to drill to 9 5/8" casing point (~ 10,500'MD) ' 9. MU 9-5/8" casing scraper assembly. RIH to 2900', circulate wellbore clean with seawater. TOH. 10. RU slickline. Set CIBP in 9 5/8" C~3 2850'MD. • 11. Run aUSIT/CCVGR from the CIBP to surface to determine 9-5/8" TOC & collar locations. RD slickline. 12. MU a 9-5/8" mechanical casing cutter assembly. RIH on DP and make cut per USIT log results. Primary plan is to make the cut at 2775' to facilitate an exit out the bottom of 13 3/8" shoe. Circulate to confirm cut, and assure the casing is clean by pumping (surfactant wash if needed). 13. Hang off mechanical casing cutter assembly with RTTS. 14. Change out upper rams to 9-5/8" rams. 15. Attempt to pull 9-5/8" pack-off to ensure that the pack-off can be pulled through the stack (pack- off is plastic packed). Replace 9-5/8" pack-off. Split the stack to clean casing spool of plastic packing if necessary. Test BOPE. 16. POOH and LD assembly. 17. MU a 9-5/8" casing spear assembly and unseat the casing. Circulate the Arctic Pack (to be confirmed) from the OA annulus with warm diesel followed by sea water and detergent sweeps. Pull the 9-5/8" casing from the cut and LD. 18. Change 9-5/8" fixed rams to 3-1/2" x 6" variable rams and test. Install wear bushing. 19. MU a 13-3/8" casing scraper assembly with an RTTS one joint above the scraper. RIH to 13-3/8" shoe, set the RTTS, and pressure test the casing to 3500 psi for 30 min. POOH and LD assembly. 20. MU cement plug assembly with stinger. RIH, circulate above CIBP, and set OH cement plug on top of CIBP and 300' u~ into 13 3/8" shoe. Displace with seawater. TOH. 21. PU 12 ~/a" Dir/GR/RES/PWD BHA with PDC bit. RIH to clean out 13-3/8" and displace wellbore to new LSND mud. KO cement plug and drill 20' of new formation. Pull into the shoe and conduct LOT. 22. Continue drilling to +/- 200' and above the HRZ, ensure mud is in condition to 11.0 ppg. During this time hold the pre-reservoir meeting highlighting kick tolerance and detection. 23. Directionally drill to 9 5/8" casing point into the Top Sag. This critical casing point will be picked by the operations geologist. 24. Circulate to clean hole. Short trip to the shoe and RBIH to TD. TOH standing back DP and LD BHA. 25. Change to 9-5/8" casing rams and test. 26. RU and run 9 5/8" 40# L-80 BTC x HYD 563 casing to Top Sag. Run an ES Cementer below the UG1 "cretaceous"/Schrader if necessary. RD casing running equipment. 27. RU, PT lines, and pump cement for 9 5/8" casing. Land on mandrel hanger. 28. Change to 3-1/2" x 6" variable rams and test. 29. PU 4" DP for tapered string to TD. 30. Drill the B interval: MU 8'h" Dir/GR/RES/PWD motor BHA and rock bit. TIH. 31. Swap out to 8.5ppg PowerVis mud system. 32. Drill out shoe plus 20' of new formation. Pull up into the shoe and conduct FIT. 33. Drill 8'/z" hole to 170' below the 9 5/8" casing shoe. TOH. LD bit/BHA. 34. MU 6 1/8" Dir/GR/RES/PWD BHA and PDC bit on bent housing motor. 35. Drill to W-196 TD in Ivishak Zone 4. 36. CBU, Short trip, circulate, and condition the hole for running the 4-1/2" production liner. Pull to 9 5/8" shoe, open circ sub, CBU or until hole cleans up, TOH. Rack back drill pipe. 37. Case & Cement the B interval: Run 7-5/8" 29.7# 13CR VAM Top x 4 ~/2" 12.6# 13CR VAM Top liner with 5 'h" x 4 '/z" seal bore receptacle (SBR) and swell packer on 5" DP and 2-7/8" inner string spaced out to pass the LWP into the 4 ~h" liner. Centralize 4~h" liner per RP. 38. Cement combination liner per plan with LH and LTP. Displace with pert pill and follow with Geovis drilling mud. Circ out excess cement. Contingency LT squeeze if severe losses occur. 39. Clean out B lateral with tapered DP string. 40. Perf W-19B 4 ~h" liner: RU SLB and RIH w/ 1500' 2-1/2" Powerjet Omega guns and a-fire head(s) set C 4 SPF. Tag PBTD. Put guns on depth and fire. 41. TOH, verify all shots have fired, LD guns. No CO run required. 42. RU a-line. TIH with retrievable IBP, and set above the 4 ~/z" SBR. 43. Drill the W-196L1 lateral: PU the 7-5/8" retrievable whipstock BHA with it spaced out to set down (~22K Ibs) on the 7-5/8" x 4 ~/z" crossover. Orient the whipstock to generally high side, set whip, shear off, swap to drilling fluid, mill window, TOH, LD BHA. Pe~ ~~Y • 44. PU 6 1/8" drilling assembly with TCI bit for the build and turn section. TIH & drill curve. Drill pilot hole plugback W-19BL1 PB1. PU hole to KO point for BL1 lateral and trench for open hole sidetrack. 45. POOH to change BHA. PU 6 1/8" rotatable drilling assembly with PDC bit to drill to TD. 46. TIH & pull whipstock and anchor. 47. Case & Cement the BLi interval: With the HR running tool with 2-7/8" inner string, run 4-~h" 13CR 12.6# VAM Top solid liner with 13CR bent joint and 13CR B-Hook Hanger with swell packers near the junction to be set in 6.125" drilled hole. Land hook on window. 48. Pump cement. Displace with pert pill volume to fill the liner. Latch up plug and liner wiper dart in the landing collar. 49. Pressure up to release the HR LRT, pick up, and run the spaced-out 2 7/8" inner string into the B lateral to clean out cement below hook hanger and to the top of the retrievable plug 50. TOH & rack back 5" / 4" DP and 2 7/8" inner string. 51. RU a-line. Conduct GRJB run, then USIT log from 7 5/8" LT to either surface or TOC, whichever is lower (for offset Kuparik and Schrader Bluff isolation assurance). 52. Perf W-196L1 4 ~h" liner: TIH and set drilling diverter which facilitates re-entry to the BLi lateral. TOH. 53. RIH to pert 1500' over 2000' distance with 2 1/2" Powerjet Omega guns and single ball-drop fire head set C~ 4 SPF. Tag PBTD. Put guns on depth and fire. 54. TOH, verify all shots have fired, LD guns. No CO run required. RD SLB. 55. TIH on DP to pull the drilling diverter. TOH. 56. TIH to pull retrievable plug. 57. TIH to set the LEM (Lateral Entry Module) with estimated 20klbs down force to latch in to collet. TOH Laying Down DP. 58. R/U, M/U 10,400' of 4-1/2" 13CR VAM Top completion tubing with 4'h" seal stem on bottom, 4 '/z x 9 5/8" production packer, 8 GLM's, and X-nipples. 59. Space the tubing into the top of SBR. Use minimal circ rate to wash SBR. Pick up to allow full circulation. 60. Reverse circulate to seawater with corrosion inhibitor. 61. Land tubing into 4 ~/2" SBR and hanger. RILDS. 62. Drop ball and rod to seat in RHC in X-nipple below packer, pressure up to initiate set, and continue up to test tubing and annulus separately to 3,500 psi each. Record the test. 63. TOH laying down DP. 64. Install and test TWC. 65. Nipple down BOP. 66. NU tree and adaptor flange, test tree to 5,000 psi. Pull TWC. 67. Reverse in diesel freeze protect to 2,200' U-tube. Install BPV. 68. Secure well. Release rig. D. Post-Rig Work: 1 O Install wellhouse and flowlines. S-riser modifications may be required. 2 S MIRU slick line. Pull the ball and rod. Install gas lift valves. Drilling Engineer: Garret Staudinger (907)564-4242 Production Engineer: Carolyn Kirchner (907)564-4190 Geologist: Allison Green (907)564-4710 ATTACH: Current Schematic Proposed Schematic 'FREE = ~ - 4-1 /16" CNV/FMC WELLHEAD = 13-5/8" FMC _ ACTUATOR = BAKER KB. ELEV = 80.25' BF. ELEV - ... .......54.15' KOP = 1510' Max Angle = 96 @ 11600' Datum MD = 11117' Datum TV D = 8800' SS W• ~ ~~ ~ ~ ( W ELL~RE 13 STILL OPEN 49'. W-19A 4-1 /2" HES X NIP, ID = 3.813" 13-3/8" CSG, 68#, L-80, ID = 12.415" ~~ 2692, Minimum ID = 3.80" @ 10767' 4-1/2" MILLED HES XN NIPPLE TOP OF 7" LNR ~-~ 10308' TOP OF CEMENT 10468 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 11560' PERFORATION SUMMARY FOR WELLBORE A & L1 REF LOG: SWS MWD MEM RES ON 11/29/98 ANGLE AT TOP PERF: 57 @ 11154' Note: Refer to R-oduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAKDOWN TOP OF 4-1/2" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 10935' MILLOUT WINDOW (W-19AL1)10948' - 10954' FISH: 3-1 /2" OD X 2-3/8" ID X 3-7/8" LONG ~~??? PBTD 14406' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 14495 10767 4-1/2" HES XN NIP (MILLED 02/25/03), ID = 3.80" 10779' 4-1/2" WLEG, ID = 3.958" I~ ELMD TT LOG NOT AVAILABLE 10926'-10966 4-1/2" BKR PATCH (09/29/07), ID = ???? 10978' 3-1/2" BRK DEPLOY SLV, ID = 3.00" 10981' 3-1/2" x 2-7/s" xo, ID = 2.441 " ~_`_ ~` \ \ `` ``` _ PBTD I2-7/8" LNR (SOLID &PRE-DRILLED), I 6.16#, L-80, .0058 bpf, ID = 2.372" TD I-~ 12701' DATE REV BY COMMENTS DATE REV BY COMMENTS 1990 J.JONES ORIGINAL COMPLETION 09/29/07 TEL/TLH PATCH SET 12/25/98 SIDETRACK(W-19A) 03/08/03 DAC/TL SIDETRACK(W-19AL1) 03/21/03 AF/KAK ADD TOP OF WINDOW 03/24/03 JIWKAK GLV GO 05/01/07 KCF/PJC XN NIP MILLED (02/25/03) PRUDHOE BAY UNff WELL: W-19AL1 PERMff No: 2022350 API No: 50-029-22006-01 SEC 21, T11 N, R12E, 695.7' FNL & 1181.2' F~ BP Exploration (Alaska) C,AS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 6 3071 2975 11 CA-MMG DOME RK 16 09/14/04 5 5398 4798 48 CA-MMG DOME RK 16 09/14/04 4 7154 5998 50 CA-MMG DOME RK 16 09/14/04 3 8489 6898 46 CA-MMG DOME RK 16 09/14/04 2 9586 7690 42 CA-MMG SO RK 24 09/14/04 1 10191 8135 43 CA-MMG DMY RK - 02/16/03 MILLOUT WINDOW (W-19A)10463' - 10513' 10712' H4-1/2" HES X NIP, ID = 3.813" I 10723' 7" X 4-1/2" BKR S-3 PKR ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" • W-19AL'r PERFORATION SUMMARY FOR WELLBOREA REF LOG: SWS MWD MEM RES ON 11/29/98 ANGLE AT TOP PERF: 57 @ 11154' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11154 - 11204 O 11/11/02 2-7/8" 4 11220-11236 O 11/11/02 2-7/8" 4 11250 - 11360 O 11/11/02 2-7/8" 4 11419 - 11500 O 11/11/02 2-7/8" 4 11530 - 11610 O 11/11/02 2-7/8" 4 11665 - 11750 O 12/24/98 2-7/8" 4 11844 - 11875 O 04/28/01 2-7/8" 4 11929 - 11960 O 04/28/01 2-7/8" 4 12010 - 12090 O 12/24/98 2-7/8" 4 12100 - 12200 O 11/11/02 2-7/8" 4 12520 - 12545 O 04/28/01 2-7/8" 4 12560 - 12580 O 04/28/01 2-7/8" 4 12690 - 12800 O 12/24/98 2-7/8" 4 12920 - 13000 O 12/24/98 2-7/8" 4 13000 - 13100 O 11/10/02 2-7/8" 4 13330 - 13380 O 11/10/02 2-7/8" 4 13420 - 13450 O 11/10/02 2-7/8" 4 13590 - 13720 O 11/10/02 2-7/8" 4 13780 - 13900 O 12/24/98 2-7/8" 4 13910 - 13980 O 12/24/98 PERFORATION SUMMARY FOR WELLBORE L1 REF LOG: SPERRY MWD SGRC ON 03/05/03 A NGLE AT TOP PERF: Note: Refer to R-oduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4 11249 - 11408 O 03/05/03 4 11706 - 11930 O 03/05/03 "PRE-DRILLED PIPE DATE REV BY COMMENTS DATE REV BY COMMENTS 1990 J.JONES ORIGINAL COMPLETION 09/29/07 TEL/TLH PATCH SET 12/25/98 SIDETRACK (W-19A) 03/08/03 DACITL SIDEfRACK(W-19AL1) 03/21/03 AF/KAK ADD TOPOF WINDOW 03/24/03 JIWKAK GLV C/O 05/01/07 KCF/PJC XN NIP MILL® (02/25/03) PRUDHOE BAY UNf>- WELL: W-19AL1 PERMIT No: 2022350 API No: 50-029-22006-01 SEC 21, T11 N, R12E, 695.7' FNL & 1181.2' FEL BP Exploration (Alaska) ~TREEg . WELLHEAD = _ ACTUATOR = KB. aEV = so.25' BF. ELEV = 54.15' KOP= 2800' Max Arx~le = 101 deg Datum MD = Datum TV D = 8800' SS ~ W-'19B W-19BL1 13-3/8" CSG, 72#, L-80, ID =12.415" ~-~ 2692' 9-5/8" CSG, 40#, L-80, HY D 563, ID = 8.835" I 8500' 41/2" x9-5/8" BKR PREMIER PKR 41/2" HES X NIP, ID = 3.813" 9-5/8" CSG, 40#, L-80, BTC, ID = 8.835" 10,317' 10500' 10267' -518" X 7-5/8" Baker ZXP Liner Top Packer 10,31T 9-5/8"x7-5/8" FLDCLOCK LH 10317' 9-5/8" CSG, 47#, L-80, BTC-M, ID = 8.681" 10467' 7-518" LNR, 29.7#, L-80, STL, ID = 6.875" ~~ 10600' 5-1/2" 13CR 17ppf,VT,ID=4.767" Drift I 10 636' 5-1/2" X41/2" SBR, ID = 4.767° Drift - 1 I5-1/2" X4-1/2" XO, ID= 3.958" ~ 10 662' Minimum ID = "~" BKR Hook Hanger w/ non-sealing LEM PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: ~ Note: Refer to Production 08 for historical pert data SIZE SPF INTERVAL 0pn/Sqz DATE 2-112" 4 O 2-12" 4 O 2-1/2" 4 O 2-12" 4 O 2-112" 4 O 2-12" 4 O 2-12" 4 O 2-12" 4 O S TES: ALL CHROME LINER's, JUN , S COMPLETION 2200' -j41/2" HES X NIP, ID = 3.813" GAS LIFT MANS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 6 5 4 3 2 1 610' ~ 7 5/8" X 5-112" 8KR ZXP LTP, ID = 3.875" ,510' Baker Lateral Entry Module MILLOUT WINDOW 10540-10553' 144q$' 4-1/2" LNR, 12.6#, 13CR, VT, ID = 3.958" ~~~ XXXX 05.85" Swell Pkr 13CR VT,ID = 3.958" XXXX' ~~5.85" Swell Pkr 13CR VT,ID = 3.958" t~vaq 8 4-1/2" LNR, 12.6#, 13CR VAM TOP, .0152 bpf, ID = 3.958" 13649' DATE REV BY COMMFMS DATE REV BY COMMBYfS PRUDHOE BAY UNff 03/0tiM0 GJS Proposed Completion WE1L: V1E198 / BL1 PH~MT No: API No: BP Exploration (Alaska) • Review of Sundry Applications 310-148 & 310-149 BP Exploration (Alaska) Inc. Well PBU W-19A & W-19AL1 AOGCC Permits 198-069 & 202-235 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to abandon the subject wellbores to prepare the well for a rig sidetrack. Recommendation: I recommend approval of Sundry Applications 310-148 and 31-149 to allow BPXA to perform this operation. Discussion: BPXA proposes to plug the subject wellbores to prepare the well for sidetracking. The W-19A well was brought on production in January 1999 and the W-19AL 1 well was brought online in March 2003. The W-19A well produced approximately 280 MBO before the W-19AL 1 lateral was added to the well. Prior to drilling the lateral the well was producing approximately 150 BOPD at a water cut of approximately 75%. After completion of the lateral production increased to approximately 450 BOPD but water cut also increased to approximately 85%. Production decreased and water cut increased steadily until November 2004 when oil production increased and water cut decreased dramatically apparently because an FOR gas slug reached the well. This is evidenced by the fact that the gas rate went from approximately 700 MCFPD to over 3,000 MCFPD in one month and continued to climb for several months peaking at just under 13,000 MCFP before dropping back to pre-slug levels. Also, during this time the well was switched from gas-lift to naturally flowing which is further evidence of a gas slug reaching the well. The elevated production lasted until about September 2005 when oil and gas production and water cut returned to earlier levels. The well remained on regular production until July 2006 at which time production was running about 150 BOPD and the water cut was over 95%. A couple of short attempts, totaling 34 days, have been made at restoring production from this well but oil rates have remained low and water cuts have remained over 95%. Cumulative production from this well is approximately 681 MBO. ~" Conclusion: Plugging these wellbores so a new wellbore can be drilled to a more favorable location appears to be the prudent choice for this well. Therefore, I recommend approving BPXA's requests. -~ ~~. David S. Roby. ~'~ Sr. Reservoir Engine May 7, 2010 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 16, 2007 11:18 AM To: 'Preble, Gary B (SAIC)' Subject:1~1R19A (198-199) Gary, I have reviewed the 404 for setting the patch across the window for W-19AL1 (202-235). Since the patch was actually set in the W 19 wellbore, have you submitted a 404 for W 19 as wetl? It may be in the stack and 1 just haven't gotten to it. Reporting work on wells with laterals gets "interesting". Call or message with any questions. Tom Maunder, PE AOGCC 10/22/2007 ~~t;El~,~ty STATE OF ALASKA ~"-' ~~ ALA•OIL AND GAS C NSERVATION OM~61TJ 1 ~ 2007 O C REPORT OF SUNDRY WELL OP~~jl~~ons. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ An~h~~~g~ther ~ Patch Tubing Performed: AlterCasing ~ Pull Tubing Perforate New Pool ~ Waiver Time Exiension~ Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska}, Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 19s-1990 3. Address: P.O. Box 196612 Stratigraphic '~ Service j 6. API Number: Anchorage, AK 99519-6612 50-029-22006-01-00 7. KB Elevation (ft): 9, Well Name and Number: 83.4 KB PBU W-19A 8. Property Designation: 10. Field/Pool(s): _ ADLO-047450 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 14500 feet Plugs (measured) None true vertical 9092.17 ~ feet Junk (measured) None Effective Depth measured 14406 feet true vertical 9065 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2612' 13-3/8" 68# L-80 Surface - 2692' Surface - 2687' 5020 2260 Intermediate 11560' 9-5/8" 47# L-80 Surface - 11560' Surface - 9006' 6870 4760 Liner 627' 7" 26# L-80 10308' - 10935' 8307' - 8768' 7240 5410 Liner 3721' 4-1/2" 12.6# L-80 10774' - 14495' 8646' - 9091' 8430 7500 Perforation depth: Measured depth: See Attached - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 10723' 0 0 - Packers and SSSV (type and measured depth) 7"x4-1/2" bkr S-3 10723' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~-j 1I) ~.,~j~rh~ ~~~,L~ `OC~a~O- ~(~~~p~O `~ Treatment descriptions including volumes used and final pressure: ~ ~ (1~.~` "% °~ ~~O% ~~.~ ~~ ~~ 7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 81 465 5564 195 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ WINJ WDSPL ~` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ - Phone 564-4944 Date 10/16/2007 Form 10-404 Revised 04/2006 \~ (.~.} Submit Original Only 1~~ V~~ Y/ 1~ 1 i r W-19A 198-199 TUBING PATCH ATTACHMENT Perforation Depth MD (ft) Opn/Sqz Perforation Depth TVD (ft) 11154' - 11204' Open 8892' - 8902' 11220' - 11236' Open 8904' - 8905' 11250' - 11360' Open 8906' - 8912' 12100' - 12200' Open 8977' - 8973' 11410' - 11500' Open 8918' - 8931' 11530' - 11610' Open 8935' - 8947' 13000' - 13100' Open 8945' - 8942' 13330' - 13380' Open 8936' - 8935' 13420' - 13450' Open 8934' - 8933' 13590' - 13720' Open 8930' - 8927' 11844' - 11875' Open 8974' - 8975' 11929' - 11960' Open 8976' - 8977' 12520' - 12545' Open 8957' - 8957' 12560' - 12580' Open 8956' - 8956' 11665' - 11750' Open 8953' - 8964' 12010' - 12090' Open 8978' - 8977' 12690' - 12800' Open 8953' - 8950' 12920' - 13000' Open 8947' - 8945' 13780' - 13900' Open 8925' - 8922' 13910' - 13980' Open 8922' - 8920' ~ ~~~ ~~ ~ ~~ ~~~ • • W-19A DESCRIPTION OF WORK COMPLETED NRW O OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/29/2007.;LOGGED PRESSURE TEMPERATURE DOWN FROM SURFACE TO 11,420'. STOPPED LOGGING DUE TO DEVIATION. `SET 4.5" BAKER KB PATCH FROM 10,926' TO 10,966' (ELEMENT TO ELEMENT) ACROSS 2 7/8" LATERAL EXIT WINDOW. '`'`'"'JOB COMPLETE*"** FLUIDS PUMPED BBLS 3 DIESEL 3 TOTAL Schlumberger NO. 4290 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth 1 ZOOl CommiS¡¡¡ÎOh1 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay C I C Well Job# LOll Description Date BL o or 0 L5-23 11733320 PRODUCTION PROFILE 04/30/07 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04/29/07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-08A 11686747 LDL 05/20/07 1 G-05 11773110 LDL 05/13/07 1 16-03 11686743 LDL 05/11/07 1 14-07 . 11637334 PRODUCTION PROFILE 05/08/07 1 V-03 11628770 MEM LDL 04/30/07 1 MPF-91 11628759 MEM TEMP SURVEY Ó3/09/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08/07 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE 05/22/07 1 04-10 11594498 LDL 05/19/07 1 B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A N/A LDL 05/09/07 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04/30/07 1 P1-16 11594494 INJECTION PROFILE 05/01/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. !oi('Il""t..U::n JUN 2 1 2007 Petrotechnrcal Data Center LR2-1 WÌi;iI',n'¡:.¡¡.,r 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: c--. -- Date Delivered: {'7~ -/9'7 p 06/07/07 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 695' FNL, 1181' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 907' FNL, 3377' FEL, Sec. 16, T11N, R12E, UM At effective depth 4054' FNL, 4816' FEL, Sec. 09, T11N, R12E, UM At total depth 4051' FNL, 4906' FEL, Sec. 09, T11N, R12E, UM 5. Type of Well: Development _X Exploratory_ Stratigraphic_ Service_ (asp's 612049, 5959561) (asp's 609767, 5964597) (asp°s 608291, 5966707) ~sp~ 608201,5966709) 6. Datum elevation (DF or KB feet) RKB 83 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-19A 9. Permit number ! approval number 198-199 10. APl number 50-029-22006-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 14500 feet 9092 feet Plugs (measured) Effective depth: measured 14406 feet true vertical 9065 feet Junk (measured) Casing Length Size Conductor 110' 20" Surface 2612' 13-3/8" Intermediate 10383' 9-5/8" Sidetrack Liner 627' 7" Sidetrack Liner 3721' 4-1/2" Perforation depth: . measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Cemented Measured Depth True Vertical Depth 72 c.f. Concrete 190' 190' 3723 c.f. Coldset II 2692' 2687' 2392 c.f. Class 'G' 10463' 8416' 174 c.f. Class 'G' 10308' - 10935' 8307' - 8768' 528 c.f. Class 'G' 10774' - 14495' 8646' - 9091' Open Peris Open Peris Open Peris Open Peris Open Peris Open Perfs Open Peris Open Peris 11154'-11204',11220'-11236',11250'-11360',11410'-11500',11530'-11610', 11665'-11750',11844'-11875',11929'-11960',12010'-12090',12100'-12200', 12520'-12545',12560'-12580',12690'-12800',12920'-13100',13330'-13380', 13420'-13450',13590'-13720',13780'-13900',13910'-13980'. 8904'-8930',8938'-8946',8952'-8994',9005'-9010',9008'-9001',8995'-8988', 8981'-8981',8980'-8980',8979'-8978',8979'-8981',9012'-9016',9018'-9021', 9029'-9025', 9015'-9008', 8996'-8999', 9003'-9005', !~~E r~'~i,' 9015'-9016'. 4-1/2", 12.6#, L-80 TBG to 10723'. Tubing Tail @ 10779'. DEC 1 g 2002 7" X 4-1/2" Baker Model'S' PKR @ 10723' MD, Alaska 0il & Gas Cons. Commission 4-1/2" H.E.S. X-Nipple @ 2111'. ~..n..chOr2~~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/02/2002 Subsequent to operation 12/06/2002 Representative Daily Averaqe Produ~ion orl~ection Data OiI-Bbl Gas-Mcf Wate>Bbl Casing Pmssum Tubing Pmssum 90 370 308 283 288 464 738 290 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _X Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~~ Ti fie: TechnicalAssistant DeWar/ne R. Schn6'rr ~--.--, Form 10-404 Rev 06/15/88 · Date December 09, 2002 Prepared b~' DeWar/ne R. S?hnorr 564-51 SUBMIT IN DUPLICATE W-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/02/2002 TESTEVENT --- 11/06/2002 PERFORATING 11/08/2002 11/09/2002 11/09/2002 11/10/2002 11/11/2002 1 2/06/2002 PERFORATING PERFORATING PERFORATING PERFORATING PERFORATING TESTEVENT --- BOPD: 104, BWPD: 312, MCFPD: 2,451, AL Rate: 2,170 :AC-BLEED; AC-TIFL :PERFORATING :PERFORATING : AC-LOAD; PERFORATING : PERFORATING :PERFORATING BOPD: 288, BWPD: 738, MCFPD: 2,194, AL Rate: 1,730 EVENT SUMMARY 11/02/02 TESTEVENT--- BOPD: 104, BWPD: 312, MCFPD: 2,451, AL Rate: 2,170 11/06/02 T/I/O=1880/1800/0. TIFL PASSED. (PREP FOR IA LOAD). INITIAL IA FL @ 8964' (480 BBLS). BLED IA FROM 1800 PSI TO 100 PSI IN 5 HOURS AND 45 MINUTES. POST IA BLEED FL @ 8960'. MONITORED FOR 30 MINUTES, NO CHANGE IN lAP. FINAL WHP's = 1860/100/0. 11/08/02 MI/RU COIL UNIT #4. HAMMER UP HARDLINE, PICK UP INJECTOR & LUBRICATOR. 11/09/02 FINISHED MAKING UP TO WELL. FUNCTION TEST BOPE, HYDRAULIC FLUID LEAKING FROM FACE OF RAM BODIES. REPAIRED SAME, (PINCHED O RINGS). FLUID PACK CT. UNABLE TO DO SO BECAUSE OF ICE PLUG. THAWED PLUG. TESTED BOP's, HAVE TO RE-DRESS BLIND SHEAR RAMS. MU BAKER MHA ON 2.88 WELDED ON CONNECTOR. MU SWS MEMORY GR/CCL IN GAUGE CARRIER WITH 3.0" NOZZLE. OAL- 19.97'. LOADED AND KILLED WITH 300 BBLS 2% KCL. PUMPED 150 BBLS CRUDE OIL DOWN IA TO FLUID PACK. IA ON A VACUUM. RIH TO 13,800', LOG UP FROM 12,950'- 12,450', (FLAGGED @ 12,787'). RBIH TO 13,800 AND LAYED IN 50 BBLS 150,000 LSRV FLO PRO. 11/09/02 LOAD IA W/500 BBLS CRUDE 11 / 1 O/O2 LAID IN 50 BBLS FLO PRO FROM 13,800', PAINT FLAG @ 12,787' CTM, 12,803' CORRECTED. POOH, LAY DOWN TOOLS. DOWNLOAD DATA & CORRELATE. FLAG IS @ 12,803' EOP, (CORRECTED). SAFETY MEETING FOR GUN DEPLOYMENT. RUN #1 PERF WITH 2-7/8" HSD PJ 2906, 4 SPF, RANDOM ORIENTATION, 180 DEGREE PHASING, INTERVAL 13330'- 13380', 13420'- 13450', 13590' - 13720'. RUN #2 13100' - 13100'. MEMORY LOG TO RE-FLAG PIPE. Page 1 11/11/02 W-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS RIH W/MEMORY LOGGING TOOLS & NEW MHA. LOGGED UP FROM 11,700'. PAINT FLAG @ 11,500', (UNCORRECTED), AND LOGGED UP TO 11,300'. EVALUATE DATA. FLAG IS @ 11,504' eop (CORRECTED). SAFETY MEETING & DEPLOY PERF GUNS. PERFORATE WITH 2-7/8" HSD PJ 2906, 4 SPF, RANDOM ORIENTATION, 60 DEGREE PHASING. RUN #3: 12100'-12200', RUN #4: 11154'. 11204' / 11220' - 11236' / 11250' - 11360' / 11410' - 11500' / 11530' - 11610. ASF. M/U 3" NOZZLE & RIH TO 2500'. F/P WELL WITH 60/40 METHANOL WATER. R/D UNIT #4. <<< JOB COMPLETED --- WELL SHUT-IN --- DSO NOTIFIED >>> 12/06/02 TESTEVENT --- BOPD: 288, BWPD: 738, MCFPD: 2,194, AL Rate: 1,730 Fluids Pumped BBLS 680 60/40 METHANOL WATER 1000 CRUDE 1225 2% KCL WATER 50 FLO PRO 2955 ADD PERFS 11/10 -11/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING 2-7/8" PJ, 4 SPF, 0/180 DEGREE PHASING, RANDOM ORIENTATION. 11154' - 11204' 11220' - 11236' 11250' - 11360' 11410' - 11500' 11530' - 11610' 12100' - 12200' 13000' - 13100' 13330' - 13380' 13420' - 13450' 13590' - 13720' Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ Add-Perfs Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 695' FNL, 1181' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 4373' FSL, 3377' FEL, Sec. 16, T11 N, R12E, UM At effective depth 819' FSL, 1741' FWL, Sec. 09, T11 N, R12E, UM At total depth 1228' FSL, 373' FWL, Sec. 09, T11 N, R12E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic._ Service__ (asp's 612049, 5959561) (asp's n/a) (asp's 609576, 5966320) (asp's 608201, 5966709) 6. Datum elevation (DF or KB feet) RKB 83 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-19A 9. Permit number / approval number 198-199 10. APl number 50-029-22006-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2612' Intermediate 10383' Sidetrack Liner 627' Sidetrack Liner 3721' 14500 feet Plugs (measured) 9092 feet 13000 feet Junk (measured) 9013 feet Window milled in 9-5/8" csg from 10463' - 10513'. Could not get beyond 13000' w/CT. Size Cemented Measured Depth True Vertical Depth 20" 190' 190' 13-3/8" 3723 c.f. Coldset II 2692' 2687' 9-5/8" 2392 c.f. Class 'G' 10463' 8416' 7" 174 c.f. Class 'G' 10308' - 10935' 8307' - 8768'. 4-1/2" 528 c.f. Class 'G' 10774' - 14495' 8646' - 9091' Perforation depth: measured Open Perfs 11665'- 11750', 11835'- 11875', 11920'- 11960', 12010'- 12090', 12520'- 12545', 12560'- 12580', 12690'- 12800', 12920' - 13000', 13780'- 13900', 13910' - 13980' true vertical Open Perfs 8995' - 8988', 8982' - 8981', 8981' - 8980', 8979' - 8978', 9012' - 9016', 9018' - 9022', Tubing (size, grade, and measured depth) 9029' - 9025', 9015' - 9013', 9011' - 9015', 9015'- 9016' 4-1/2", 12.6#, L-80 TBG to 10723'. Tubing Tail @ 10779'. 7"X 4-1/2" Baker Model'S' PKR @ 10723' MD, 4-1/2" H.E.S. X-Nipple @ 2111' Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary RECEIVED JUN I 9 2001 Alaska Oil & (~as (jons. Gommlsslu, Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Anchor~e 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is t,r..ue a, pd correct to the best of my knowledge. eW;~~e~,~~ ,~~?J')~~'/ Title: Technical ^sslstant D ayn R. Sohnorr ~ Date June 18, 2001 Prepared by DeWayne R. Sehnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE W-19A Description of Work Completed NRWO OPERATIONS 01/13/2001 02/05/2001 04/26/2001 04/27/2001 04/28/2001 05/17/2001 PERF(ADD-PERF): DRIFT 3-3/8" DUMMY GUN TO 10,930' (HAW, PRE ADPERFS) PERF(ADD-PERF): ADD PERF W/TRACTOR PERF(ADD-PERF): ADDPERF PERF(ADD-PERF): ADPERF PERF(ADD-PERF): ADDPERF PERF(ADD-PERF): TIFL PASSED SUMMARY 01/13/01 DRIFTED W/3.625" CENTRALIZER & 3 3/8" DUMMY GUN. SAT DOWN @ 10930' WLM & STUCK. RAN 3.0" CENTRALIZER & SAMPLE BAILER. OVERCOME BY DEVIATION @ 11313' WLM. SMALL AMOUNT OF FINE FORMATION SAND IN BAILER. RDMO. OK FOR 2-1/8" TRACTOR. RETURNED WELL TO OPER FOR PROD. 02/05/01 RIH W/3 1/8" TRACTOR, GR-CCL, 20' GUN, 4'X3.5" ROLLER STEM (58'), START TRACTORING @ 11350 TO 11450, TOOLS STOPPED TRIED MULTIPLE TIMES & POOH, RIH W/2 1/8" TRACTOR, GR-CCL (27.5'), START TRACTORING @ 11350 TO 11437, TOOLS STOPPED TRIED 3 TIMES. POOH, SUGGEST FCO WITH CTU AS RECOMENDED IN PROCEDURE AND SHOOT WELL BALANCED TO IMPROVE SUCCESSFUL RUNS AND RECOVERY OF TOOLS. 04/26/01 PERFORATED 12560' - 12580' AND 11844' - 11875' WITH 2 7/8 PJ, 60 DEGREE PHASING, RANDOM ORIENTATED PERFORATING GUN. - .... CONTINUATION OF PERFORATION TOMORROW ......... WELL FLOWING ..... 04/27/01 PERFORATED 11929' - 11960' AND 12519' - 12545' WITH 2 7/8 PJ, 4 SPF, 60 PHASING, RANDOM ORIENTATION. ----CONTINUATION OF PERFORATION TOMORROW ........ WELL FLOWING .... 04/28/01 COULD NOT PERFORATE BELOW 13000'. PERFORATED 11835'- 11875', 11920'- 11960', 12520'- 12545', 12560'- 12580' WITH 2 7/8 PJ, 4 SPF, 60 PHASING, RANDOM ORIENTATION. PEFORATION CONCLUDE. ----WELL FLOWING .... 05/17/01 TIFL PASSED. T/I/O = 220/1210/120. TEMP. = 74 DEG. TIFL PASSED. STACKED WELL TO 1360/1500/220. IA FL STAYED @ 10191' (STA. # 1) FOR DURATION OF TIFL. BLED 1ST HR TO 1420/1280/80. BLED 2ND HR TO 1420/920/80. BLED 3RD HR TO 1420/580/80. BLED 4TH HR TO 1420/300/80. MONITORED 30 MIN TO 1420/300/80. POPPED WELL PER OPERATOR. FINAL WHPS = 440/920/80. Fluids Pumped BBLS. Description 2 DIESEL FOR PT 260 60/40 METHANOL 300 2% KCL WATER 562 TOTAL ADD PERFS 04/28/2001 SUMMARY The following intervals were perforated using 2-7/8" HSD Power Jet gun, 4 SPF 60 degree phased, random orientation. 11835' - 11875' MD 11920' - 11960' MD 12520' - 12545' MD 12560' - 12580' MD VI,('=LL LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. Tol State of Alaska AOGC~ Lori Taylor 3001 Porcupine SL Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt.by returning a signed copy of this transmittal letter to the attention of' Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petrotechnical Data Center MB 3-~ 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT. WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM BLUELINE Open Hole I I 1 W-~ 9a 5-18~)O Res. Eval. CH I I 1 Mech. CH Caliper Survey I 'Rpt or ,---,- - o ;C; IVFD , BL Signed' Date' MAY 26 2000 Print Name: Maska 0it & ~ ~t~s. ColltlaJ~bll ProActive Diagnostic Services, Inc., Pouch' 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdsprudhoe~NA800.net Website: www. memorylog.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSJ~ WELL COMPLETION OR RECOMPLETION REPORT AND;,~OG '; '" 1. Status of Well Classification of$;~~. ~1 [] Oil [---] Gas I--] Suspended r--I Abandoned I--] Service "rO°]"~O ~'~ 2. Name of operator 7. Permit Number '/"~'""~!O~ BP Exploration (Alaska)Inc. 98-199 .3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22006-01 1 4. Location of well at surface 9. Unit or Lease Name 696' SNL, 1181' WEL, SEC. 21, T11 N, R12E, UM ~ 0~?.?;.!:':,~,,--,, .~,,-,; Prudhoe Bay Unit At top of productive interval ! "'~'~"' " ' ~i 10. Well Number 4373'NSL, 3377'WEL, SEC. 16, T11N, R12E, UM ~'/__~.Z~2-.3~!i ~ 11. Field and Pool W-19A At total depth i ......~,,.: :,.:.,~ ..... ...' 1227' USU, 4923' WEE, SEC. 09, T11N, R12E, UM ~ _.~..,p__Z.... ........ ..[" '----, .... · .... , ............ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 83.40'I ADL 028261 12/3/98 12/15/98 12/25/98 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14500 9092 FTI 14406 9066 FTI [~Yes r--'lNoI (Nipple) 2111' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, DIR, RES, ADN 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 13-3/8" 68# L-80 Surface 2692' 17-1/2" 3723 cu ft Coldset II 9-5/8" 47# L-80 Surface 10463' 12-1/4" 2392 cu ft Class 'G' 7" 26# L-80 10308' 10935' 8-1/2" 174 cu ft Class 'G' 4-1/2" 12.6# L-80 10774' 14495' 6" 528 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10779' 10723' MD TVD MD TVD 11665' - 11750' 8995' - 8988' 12010' - 12090' 8979' - 8978' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 12690' - 12800' 9029' - 9025' 12920' - 13000' 9015' - 9013' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13780' - 13900' 9011' - 9015' Freeze Protect with 152 Bbls of Diesel 13910' - 13980' 9015' - 9016' 27. PRODUCTION TEST ~ O ! ~ I ~ J~ I "[~atejanuaryFirst Production17, 1999 Iaeth°dGas Lift°f Operation (Flowing, gas lift, etc.) '~"'~ "' '!' :~ ~? ~ J ~ J~ L 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 O~L GRAWTY-API (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. 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. , ,, Sag River 10938' 8770' Shublik 10968' 8793' Eileen 11085' 8866' Sadlerochit 11150' 8901' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~._ .,._,. ~ A,]l ~')~ DanStone ,, Title Senior Drilling Engineer Date W-19A 98-199 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 otherwiseshown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 24 Nov 98 25 Nov 98 26 Nov 98 27 Nov 98 28 Nov 98 29 Nov 98 PB W Pad Progress Report Well W-19A Page 1 Rig Nabors 18E Date 15 January 99 Duration Activity 01:00-01:15 01:15-06:00 06:00-17:00 17:00-18:00 18:00-21:00 21:00-22:00 22:00-23:30 23:30-00:00 00:00-03:00 03:00-03:15 03:15-04:00 04:00-06:00 06:00-17:00 17:00-17:45 17:45-18:00 18:00-20:00 20:00-20:30 20:30-22:00 22:00-22:30 22:30-00:30 00:30-00:45 00:45-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-07:45 07:45-08:00 08:00-10:00 10:00-12:00 12:00-13:30 13:30-20:00 20:00-21:00 21:00-06:00 06:00-08:00 08:00-09:00 09:00-11:00 11:00-14:30 14:30-15:00 15:00-17:00 17:00-21:00 21:00-22:00 22:00-01:00 01:00-02:30 02:30-05:00 05:00-06:00 06:00-08:00 08:00-10:00 10:00-13:00 13:00-14:30 14:30-19:00 19:00-19:30 19:30-00:00 00:00-00:30 00:30-05:00 1/4hr 4-3/4 hr llhr 1 hr 3hr 1 hr 1-1/2 hr 1/2hr 3hr 1/4 hr 3/4 hr 2hr llhr 3/4 hr 1/4 hr 2hr 1/2 hr 1-1/2 hr 1/2 hr 2 hr 1/4 hr 3-1/4 hr lhr lhr lhr 3/4 hr 1/4 hr 2hr 2 hr 1-1/2 hr 6-1/2 hr lhr 9hr 2 hr lhr 2hr 3-1/2 hr 1/2 hr 2hr 4 hr 1 hr 3hr 1-1/2 hr 2-1/2 hr lhr 2hr 2hr 3hr 1-1/2 hr 4-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 4-1/2 hr Held safety meeting Rig moved 20.00 % Rig moved 100.00 % (cont...) Installed Accessories Retrieved Hanger plug Reverse circulated at 9490.0 ft Circulated at 9490.0 ft Cleared Flowline Circulated at 9490.0 ft Installed Hanger plug Removed Xmas tree Installed BOP stack Installed BOP stack (cont...) Installed Accessories Held safety meeting Tested BOP stack Retrieved Accessories Retrieved Hanger plug Rigged up Completion string handling equipment Circulated at 9490.0 ft Held safety meeting Conducted electric cable operations Worked stuck pipe at 9890.0 ft Circulated at 9890.0 ft Retrieved Tubing hanger Installed Emergency hang off assembly Tested Emergency hang off assembly Bleed down well Removed Seal assembly Installed Seal assembly Installed Seal assembly Removed Emergency hang off assembly Laid down Tubing of 7905.0 ft Laid down 9890.0 ft of Tubing (cont...) Rigged down Tubing handling equipment Made up BHA no. 1 Singled in drill pipe to 5030.0 ft Rigged up Kelly/top drive hose Tested Casing - Via annulus and string Singled in drill pipe to 9850.0 ft Milled Tubing at 9880.0 ft Jarred stuck pipe at 9880.0 ft Rigged down Wireline units Conducted electric cable operations Pulled out of hole to 9500.0 ft Conducted electric cable operations Fished at 9880.0 ft Pulled out of hole to 7600.0 ft Reverse circulated at 7600.0 ft Pulled out of hole to 1700.0 ft Pulled BHA Laid down fish Tested Casing Conducted electric cable operations Facility Date/Time 30 Nov 98 01 Dee 98 02 Dee 98 03 Dec 98 04 Dec 98 05 Dee 98 06 Dec 98 Progress Report PB W Pad Well W- 19A Rig Nabors 18E Page 2 Date 15 January 99 05:00-06:00 06:00-10:30 10:30-14:30 14:30-15:00 15:00-01:00 01:00-01:30 01:30-02:00 02:00-06:00 06:00-18:30 18:30-21:00 21:00-22:00 22:00-23:30 23:30-05:00 05:00-06:00 06:00-10:30 10:30-12:00 12:00-13:00 13:00-14:30 14:30-16:30 16:30-18:30 18:30-23:00 23:00-02:30 02:30-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-15:30 15:30-17:15 17:15-18:15 18:15-00:30 00:30-02:00 02:00-06:00 06:00-07:00 07:00-12:00 12:00-12:30 12:30-15:30 15:30-19:30 19:30-21:00 21:00-22:30 22:30-06:00 06:00-06:00 06:00-12:45 12:45-15:00 15:00-15:45 15:45-18:00 18:00-00:00 00:00-02:30 02:30-03:00 03:00-06:00 Duration lhr 4-1/2 hr 4 hr 1/2 hr 10hr 1/2 hr 1/2hr 4hr 12-1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 5-1/2 hr lhr 4-1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 2hr 2hr 4-1/2 hr 3-1/2 hr 1-1/2 hr 1 hr lhr 2hr 2-1/2 hr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-3/4 hr lhr 6-1/4 hr 1-1/2 hr 4hr lhr 5hr 1/2 hr 3hr 4hr 1-1/2 hr 1-1/2 hr 7-1/2 hr 24 hr 6-3/4 hr 2-1/4 hr 3/4 hr 2-1/4 hr 6hr 2-1/2 hr 1/2 hr 3hr Activity Made up BHA no. 2 R.I.H. to 10617.0 ft Circulated at 10617.0 ft Pulled out of hole to 10463.0 ft Milled Casing at 10478.0 ft Pulled out of hole to 9450.0 ft R.I.H. to 10478.0 ft Milled Casing at 10484.0 ft Milled Downhole tools at 10513.0 ft Circulated at 10513.0 ft Pulled out of hole to 9631.0 ft Circulated at 9631.0 ft Pulled out of hole to 0.0 ft Pulled BI-IA R.I.H. to 10399.0 ft Circulated at 10399.0 ft Washed to 10585.0 ft Circulated at 10585.0 ft Mixed and pumped slurry - 32.000 bbl Held 500.0 psi pressure on 3.000 bbl squeezed cement Pulled out of hole to 0.0 ft Tested BOP stack R.I.H. to 2557.0 ft Serviced Block line R.I.H. to 3689.0 ft R.I.H. to 10190.0 ft Drilled cement to 10380.0 ft Held drill (Kick (well kill)) Drilled cement to 10410.0 ft Held drill (Kick (well kill)) Drilled cement to 10468.0 ft Circulated at 10468.0 ft Circulated at 10468.0 ft Rig waited: Assessed situation Circulated at 10468.0 ft Circulated at 10460.0 ft Circulated at 10460.0 ft Circulated at 10460.0 ft Pulled out of hole to 0.0 ft Serviced BOP stack Made up BHA no. 5 R.I.H. to 10460.0 ft Circulated at 10460.0 ft Monitor wellbore pressures Drilled to 10485.0 ft Drilled to 10839.0 ft Drilled to 10935.0 ft Circulated at 10935.0 ft Pulled out of hole to 10463.0 ft Circulated at 10935.0 ft Pulled BHA Ran Liner to 627.0 ft (7in OD) Circulated at 627.0 ft Ran Dfillpipe in stands to 2000.0 ft Facili~ Date/Time 07 Dec 98 08 Dec 98 09 Dec 98 10 Dee 98 11 Dee 98 12 Dec 98 13 Dec 98 14 Dec 98 PB W Pad Progress Report Well W- 19A Rig Nabors 18E Duration Activity 06:00-08:30 08:30-09:00 09:00-10:30 10:30-13:30 13:30-13:45 13:45-15:30 15:30-17:00 17:00-18:30 18:30-23:00 06:00-07:00 07:00-09:00 09:00-10:30 10:30-11:00 11:00-12:00 12:00-14:30 14:30-18:00 18:00-18:30 18:30-19:30 19:30-20:45 20:45-21:00 21:00-06:00 06:00-02:30 02:30-04:00 04:00-04:45 04:45-05:00 05:00-05:30 05:30-06:00 06:00-14:30 14:30-16:30 16:30-21:00 21:00-22:00 22:00-23:00 23:00-23:15 23:15-23:30 23:30-02:00 02:00-02:30 02:30-03:00 03:00-03:30 03:30-05:30 05:30-06:00 06:00-09:30 09:30-10:30 10:30-06:00 06:00-01:00 01:00-03:00 03:00-03:45 03:45-04:30 04:30-06:00 06:00-06:00 06:00-21:30 21:30-22:30 22:30-22:45 22:45-05:00 05:00-05:30 2-1/2 hr 1/2 hr 1-1/2 hr 3hr 1/4 hr 1-3/4 hr 1-1/2 hr 1-1/2 hr 4-1/2 hr lhr 2 hr 1-1/2 hr 1/2 hr lhr 2-1/2 hr 3-1/2 hr 1/2 hr 1 hr 1-1/4 hr 1/4 hr 9hr 20-1/2 hr 1-1/2 hr 3/4 hr 1/4 hr 1/2 hr 1/2 hr 8-1/2 hr 2 hr 4-1/2 hr lhr lhr 1/4 hr 1/4 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 3-1/2 hr lhr 19-1/2 hr 19, hr 2hr 3/4 hr 3/4 hr 1-1/2 hr 24 hr 15-1/2 hr lhr 1/4hr 6-1/4 hr 1/2 hr Ran Liner in stands to 10380.0 ft Circulated at 10380.0 ft Ran Liner in stands to 10935.0 ft Circulated at 10935.0 ft Held safety meeting Mixed and pumped slurry - 31.000 bbl Functioned Mechanical packer Circulated at 10307.0 ft Laid down 4950.0 ft of 5in OD drill pipe Singled in drill pipe to 3500.0 ft R.I.H. to 10741.0 ft Drilled cement to 10840.0 ft Circulated at 10840.0 ft Tested Liner - Via annulus and string Drilled cement to 10927.0 ft Circulated at 10927.0 ft Drilled cement to 10935.0 ft Drilled to 10963.0 ft Circulated at 10963.0 ft Performed formation integrity test Drilled to 11247.0 ft Drilled to 11938.0 ft (cont...) Circulated at 11938.0 ft Pulled out of hole to 10900.0 ft R.I.H. to 11300.0 ft Washed to 11375.0 ft R.I.H. to 11938.0 ft Drilled to 12228.0 ft Circulated at 12228.0 ft Pulled out of hole to 170.0 ft Pulled BHA Downloaded MWD tool Retrieved Wear bushing Installed Hanger plug Tested BOP stack Retrieved Hanger plug Installed Wear bushing Downloaded MWD tool Made up BHA no. 7 R.I.H. to 2500.0 ft R.I.H. to 12116.0 ft (cont...) Washed to 12228.0 ft Drilled to 12689.0 ft Drilled to 13235.0 ft (cont...) Circulated at 13235.0 ft Pulled out of hole to 12211.0 ft R.I.H. to 13235.0 ft Drilled to 13265.0 ff Drilled to 13565.0 ft (cont...) Drilled to 13784.0 ft (cont...) Circulated at 13784.0 ft Flow check Pulled out of hole to 250.0 ft Downloaded MWD tool Page Date 3 15 January 99 Facility Date/Time 15 Dec 98 16 Dec 98 17 Dec 98 18 Dec 98 19 Dec 98 Progress Report PB W Pad Well W-19A Page 4 Rig Nabors 18E Date 15 January 99 05:30-06:00 06:00-08:30 08:30-12:30 12:30-13:30 13:30-14:30 14:30-15:00 15:00-06:00 06:00-00:00 00:00-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-12:00 12:00-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-21:30 21:30-22:00 22:00-23:00 23:00-23:30 23:30-00:15 00:15-00:30 00:30-06:00 06:00-10:00 10:00-12:00 12:00-15:00 15:00-17:00 17:00-19:00 19:00-20:30 20:30-22:30 22:30-00:00 00:00-02:00 02:00-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-10:30 10:30-11:00 11:00-11:30 11:30-13:30 13:30-15:30 15:30-19:30 19:30-20:00 20:00-06:00 06:00-17:30 17:30-20:30 20:30-22:00 22:00-23:00 23:00-00:00 Duration 1/2 hr 2-1/2 hr 4hr lhr 1 hr 1/2 hr 15hr 18hr 3-1/2 hr 2hr 1/2 hr 1/2 hr 2-1/2 hr 3 hr lhr 1/2 hr 4-1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 3/4 hr 1/4 hr 5-1/2 hr 4hr 2hr 3 hr 2 hr 2hr 1-1/2 hr 2hr 1-1/2 hr 2hr 4hr 1-1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 2hr 2hr 4hr 1/2 hr 10hr 11-1/2 hr 3hr 1-1/2 hr lhr 1 hr Activity Pulled BHA Made up BHA no. 8 R.I.H. to 10859.0 ft Serviced Block line R.I.H. to 13784.0 ft Circulated at 13745.0 ft Drilled to 14080.0 ft Drilled to 14500.0 ft (cont...) Circulated at 14500.0 ft Pulled out of hole to 10900.0 ft R.I.H. to 12500.0 ft R.I.H. to 14334.0 ft (cont...) Logged hole with LWD: Formation evaluation (FE) from 14334.0 ft to 14500.0 ft Circulated at 14500.0 ft Circulated at 14500.0 ft Flow check Pulled out of hole to 5544.0 ft Serviced Drillstring handling equipment Laid down 3180.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 2000.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Removed Drillstring handling equipment Rigged up Casing handling equipment Held safety meeting Ran Liner to 3697.0 ft (4-1/2in OD) Ran Liner on landing string to 10930.0 ft Circulated at 10930.0 ft Ran Liner on landing string to 13477.0 ft Retrieved Liner landing string Circulated at 13319.0 ft Retrieved Liner landing string Circulated at 10900.0 ft Retrieved Liner landing string Retrieved Liner hanger Pulled Liner in stands to 130.0 ft Pulled Liner in stands to 0.0 ft (cont...) Retrieved Wear bushing Installed Hanger plug Tested BOP stack Retrieved Hanger plug Installed Wear bushing Made up BHA no. 9 Singled in' drill pipe to 3250.0 ft R.I.H. to 10900.0 ft R.I.H. to 12372.0 ft Reamed to 13350.0 ft Reamed to 14500.0 ft (cont...) Circulated at 14500.0 ft Pulled out of hole to 10930.0 ft Serviced Block line Serviced Kelly/top drive hose Facility Date/Time 20 Dec 98 21 Dee 98 22 Dec 98 23 Dee 98 24 Dee 98 Progress Report PB W Pad Well W- 19A Rig Nabors 18E Page 5 Date 15 January 99 00:00-02:00 02:00-04:30 04:30-05:45 05:45-06:00 06:00-08:00 08:00-11:00 11:00-13:00 13:00-14:00 14:00-14:45 14:45-15:00 15:00-19:30 19:30-20:00 20:00-01:00 01:00-01:30 01:30-04:00 04:00-04:15 04:15-06:00 06:00-06:30 06:30-07:00 07:00-07:15 07:15-07:45 07:45-08:00 08:00-08:15 08:15-10:00 10:00-13:00 13:00-17:00 17:00-21:00 21:00-00:00 00:00-00:15 00:15-06:00 06:00-09:30 09:30-10:00 10:00-12:00 12:00-15:30 15:30-16:00 16:00-20:30 20:30-22:00 22:00-22:15 22:15-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-06:00 06:00-07:00 07:00-07:15 07:15-14:00 14:00-14:15 14:15-16:00 16:00-16:30 16:30-17:00 17:00-17:30 17:30-02:30 02:30-02:45 Duration 2 hr 2-1/2 hr 1-1/4 hr 1/4hr 2hr 3hr 2hr lhr 3/4 hr 1/4 hr 4-1/2 hr 1/2 hr 5hr 1/2 hr 2-1/2 hr 1/4 hr 1-3/4 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 1/4 hr 1/4 hr 1-3/4 hr 3hr 4hr 4hr 3hr 1/4 hr 5-3/4 hr 3-1/2 hr 1/2 hr 2hr 3-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/4 hr 3/4 hr lhr 1/2 hr 1/2 hr lhr 4hr lhr 1/4 hr 6-3/4 hr 1/4 hr 1-3/4 hr 1/2 hr 1/2 hr 1/2 hr 9 hr 1/4 hr Activity R.I.H. to 14500.0 ft Circulated at 14500.0 ft Circulated at 14500.0 ft Flow check Laid down 2100.0 ft of 5in OD drill pipe Pulled out of hole to 2500.0 ft Laid down 2000.0 ft of 3-1/2in OD drill pipe Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 3697.0 ft (4-1/2in OD) Installed Liner hanger Ran Liner on landing string to 10930.0 ft Circulated at 10930.0 ft Ran Liner on landing string to 14500.0 ft Rigged up High pressure lines Circulated at 14500.0 ft Pumped Water based mud spacers - volume 20.000 bbl Batch mixed slurry - 94.000 bbl Displaced slurry - 60.000 bbl Displaced slurry - 163.000 bbl Functioned Liner hanger Functioned Liner hanger Circulated at 10773.0 ft Circulated at 10773.0 ft Pulled Drillpipe in stands to 0.0 ft Perforated Serviced Perforating tools Held safety meeting Rigged up sub-surface equipment - Gun assembly Pulled out of hole to 0.0 ft Tested Liner - Via string R.I.H. to 1700.0 ft Rigged up sub-surface equipment - Gun assembly Rigged up sub-surface equipment - TCP R.I.H. to 14067.0 ft Rigged up High pressure lines Held safety meeting Functioned TCP Circulated at 11647.0 ft Functioned Mechanical firing head Functioned Retrievable packer Reverse circulated at 11645.0 ft Circulated at 11645.0 ft Circulated at 11645.0 ft (cont...) Flow check Laid down 8956.0 ft of 5in OD drill pipe Flow cheek Laid down 1800.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 3300.0 ft Pulled out of hole to 2300.0 ft Held safety meeting Laid down fish Removed Wear bushing Facility Date/Time 25 Dec 98 PB W Pad Progress Report Well W-19A Page 6 Rig Nabors 18E Date 15 January 99 Duration Activity 02:45-03:00 03:00-03:30 03:30-03:45 03:45-04:00 04:00-04:45 04:45-05:00 05:00-06:00 06:00-15:30 15:30-19:00 19:00-19:30 19:30-23:00 23:00-03:00 03:00-06:00 06:00-12:00 1/4 hr 1/2hr 1/4 hr 1/4hr 3/4 hr 1/4hr 1 hr 9-1/2 hr 3-1/2 hr 1/2 hr 3-1/2 hr 4hr 3hr 6hr Installed Hanger plug Rigged up Top ram Tested Top ram Removed Hanger plug Rigged up Completion string handling equipment Held safety meeting Ran Tubing to 1000.0 ft (4-1/2in OD) Ran Tubing to 10779.0 ft (4-1/2in OD) Circulated at 10772.0 ft Stung into Production packer Set packer at 10722.0 ft with 4000.0 psi Removed BOP stack Installed Xmas tree Freeze protect well - 152.000 bbl of Diesel Anadrill Client: BP Exploration (Alaska), Inc. Field: Prudhoe Bay Well Name: W-19a APl number: 50-029-2206-01 Job umber: 4E+07 Rig: Nabors 18-E County: NSB State: AK Survey Calculations Calc method for p~ Minimum Curvature Calc method for DL Mason & Taylor Depth references Permanent datum Depth reference Drill Floor, GL above Permanent KB above Permanent DF above Permanent MSL 52.90 83.40 81.90 Vertical section origin ii Latidude (+N/S-): 0 Departure (+E/W-): 0 Azim from rotary table to targ~ 277.00 FT FT FT FT degrees SURVEY REPORT Schlumberger ANADRILL Survey Rel~ ,. Seq Measured Inci Azimuth Course TVD Vertical # Depth angle angle length depth section (ft) (deg) (deg) (ft) (ft) (ft) 1 10462.80 46.10 346.7 0.00 8416.20 2548.29 2 10489.65 44.21 343.5 26.9 8435.17 2555.39 3 10527.90 44.10 339.0 38.2 8462.59 2566.96 4 10560.29 43.98 335.1 32.4 8485.88 2578.22 5 10591.00 43.25 331.4 30.7 8508.11 2589.98 6 10623.56 42.34 330.8 32.6 8532.04 2602.96 7 10653.76 41.45 330.2 30.2 8554.51 2614.96 8 10686.03 41.23 329.6 32.2 8578.69 2627.79 9 10717.46 40.83 330.6 31.5 8602.45 2640.20 10 10749.36 40.54 330.8 31.9 8626.64 2652.52 11 10780.25 40.36 331.0 30.8 8650.08 2664.29 12 10811.29 40.37 330.5 31.1 8673.78 2676.20 13 10841.62 40.25 331.1 30.3 8696.88 2687.77 14 10872.75 40.23 331.9 31.1 8720.62 2699.44 15 10908.22 40.12 333.1 35.5 8747.75 2712.41 16 10940.97 41.09 334.3 32.8 8772.65 2724.13 17 10971.48 44.24 335.4 30.5 8795.08 2735.12 18 11002.81 46.97 336.5 31.3 6816.57 2746.84 19 11033.53 52.38 339.5 30.7 8836.03 2758.34 HECEIVED DEC 3 u 1998 BPXA PDC Spud Date: Last survey date: Total accept, ed surveys: MD of first survey: MD of last survey: Geomagnetic data Magnetic Model: Magnetic Date: Magnetic field strengl~: Magnetic dec (+E/VV-): Magnetic Dip: 02-Dec-98 10462.80 FT ORIGINAL BGGM 1996 Version 1146.05 HCNT 27.563 degrees 80.67 degrees ,. MWD Survey Reference Cdteda Reference G: 1002.68 mGal Reference H: 1146.85 HCNT Reference Dip: 80.67 degrees Tolerance G: 4 mGal Tolerance H: 6 HCNT Tolerance Dip: 0.3 degrees Correction Magnetic dec (+E/VV-): 27.56 degrees Gdd convergence (+E/VV-): 0.00 degrees Total az corr (+E/W-): 27.56 degrees Displacement +N/S- +E/W- (ft) (ft) 4631.10 -1998.80 4649.52 -2003.69 4674.70 -2012.26 4695.43 -2021.06 4714.33 -2030.68 Total at Azm DLS Srvy Tool displacement (degl tool quality (fl:) (deg) 10Of) type type 5044.04 336.65 0.00 TIP 5062.89 335.69 10.93 MWD_M 5089,41 336,71 8.39 MWD_M 5111.92 336.71 8.16 MWD_M - 5133.05 3,36.70 8.65 MWD 6-axis 4733.72 -2041.29 4751.27 -2051.22 4769.68 -2061.88 4787.60 -2072.19 4805.74 -2082.37 5155.09 336.67 3.06 5175.14 336.65 3.23 5196.26 336.62 1.41 5216.81 336.60 2.44 5237.5 336.57 1.00 MWD_M MWD_M MWD MWD MWD 6-axis 6-axis 6-axis 4823.20 -2092.09 4840.77 -2101.93 4857.88 -2111.49 4675.54 -2121.08 4895.85 -2131.65 4914.99 -2141.11 4933.70 -2149.89 4954.46 -2159.14 4976.48' -2168.62 5257.38 336.55 0.72 5277.42 336.53 1.04 5296.92 336.51 1.34 5316.94 336.49 1.66 5339.78 336.47 2.20 MWD_M MWD MWD MWD MWD_M 5361.10 336.46 3.80 MWD_M 5381.76 338.45 10.61 MWD_M 5404.50 336.45 15.33 MWD 5428.23 336.46 13.43 MWD 6-axis 6-a)ds 6-a,,ds . .. 6-axis 6-axis Page 1 Schlumberger ANADRILL Survey Rep~ I Seq Measured Incl Azimultt Course TVD Vertical Displacement Total at Azm DLS Sn/y Toe # Depth angle angle length depth sec'don +N/S- +E/W- displacement (deg/ tool quail (ft) (deg) (deg) (fi) (ft) (ft) (ft) (fi) (ft) (deg) 100f) type tyl~ 20 11065.39 56.29 343.3 31.9 8854.63 2769.51 5001.04 -2176.27 5454.04 336.48 15.61 MWD 6-axJ 21 11097.05 56.19 343.1 31.6 8872.19 2780.11 5026.19 -2183.86 5480.13 336.52 0.61 MWD 6-a~ 22 11128.74 56.67 343.5 31.7 8889.72 2790.73 5051.49 -2191.45 5506.36 336.55 1.84 MWD 6-axi 23 11160.81 58.07 345.0 32.1 8907.03 2801.18 5077.50 -2198.78 5533.15 336.59 5.87 MWD 6-a~ 24 11190.90 56.31 346.5 30.1 8922.89 2810.45 5102.30 -2205.08 5558.40 336.63 4.31 MWD 6-a~ 25 11222.36 60.08 347.5 31.5 8939.03 2819.70 5128.66 -2211.16 5585.01 336.68 6.25 MWD 6-ax 26 11254.03 62.80 349.0 31.6 8954.13 2828.62 5155.83 -2216.81 5612.20 336.73 9.56 MWD 6-ax 27 11286.20 65.85 351.3 32.2 8968.08 2837.02 5184.42 -2221.77 5640.43 336.80 11.45 MWD 6-ax 28 11316.99 68.22 353.9 30.8 8980.10 2844.07 5212.53 -2225.41 5667.71 336.88 10.94 MWD 6-ax, 29 11348.80 72.68 355.4 31.8 8990.74 2850.47 5242.36 -2228.20 5696.25 336.97 14.71 MWD 6-ax 30 11381.21 77.32 354.8 32.4 8999.12 2856.92 5273.53 -2230.87 5725.99 337.07 14.43 MWD 6-ax 31 11412.43 80.78 357.0 31.2 9005.05 2862.82 5304.68 -2233.06 5754.98 337.17 13.07 MWD 6-ax 32 11442.84 84.85 358.9 30.4 9008.85 2867.56 5334.22 -2234.14 5783.18 337.27 14.75 MWD 6-ax 33 11472.91 89.21 359.4 30.1 9010.41 2871.66 5364.27 -2234.68 5811.08 337.39 14.58 MWD 6-ax 34 11505.28 93.19 0.7 32.4 9009.73 2875.58 5396.65 -2234.55 5840.98 337.51 12.92 MWD 6-ax 35 11537.14 98.08 2.1 31.8 9007.44 2878.68 5428.36 -2233.78 5869.99 337.63 7.39 MWD 6-ax . · 38 11568.40 95.35 2.1 31.3 9004.59 2881.34 5459.51 -2232.64 5698.38 337.76 0.86 MWD 6-ax 37 11600.34 95.98 4.0 31.9 9001.45 2883.52 5491.20 -2230.95 5927.09 337.89 6.25 MWD 6-ax 38 11631.79 95.91 3.7 31.5 8998.18 2685.25 5522.48 -2228.84 5955.28 338.02 0.97 MWD 6-ax 39 11662.45 94.70 7.8 30.7 8995.34 2885.91 5552.87 -~5.78 5982.35 338.16 13.87 MWD 6-ax 40 11694.73 94.46 12.2 32.2 8992.77 2884.23 5584.47 -~'~0.21 6009.63 338.32 13.64 MWD 6-ax 41 11726.65 94.68 10.8 31.9 8990.17 2881.74 5615.63 -2213.87 6038.26 338.48 4.57 MWD 6-ax 42 11758.28 94.60 9.0 31.7 8987.55 2880.14 5646.75 -2208.44 6063.25 338.64 5.73 MWD 6-ax 43 11789.91 95.01 10.5 31.6 8984.91 2878.63 5677.78 -2203.11 6090.23 338.79 4.90 MWD 6-ax 44 11821.35 94.60 10.8 31.5 8982.27 2876.63 5708.63 -2197.31 6116.91 338.95 1.61 MWD 6-ax 45 11852.65 90.99 10.2 31.3 8980.74 2874.72 5739.36 -2191.61 6143.57 339.10 11.69 MWD 6-ax 46 11682.16 89.93 12.0 29.5 8980.50 2872.61 5768.31 -2165.93 6168.60 339.25 7.08 MWD 6-ax 47 11914.59 90.89 11.7 32.4 8980.27 2869.88 5800.02 -2179.28 6195.92 339.41 3.10 MWD 6-ax 48 11977.44 91.00 10.2 62.8 8979.24 2865.55 5861.68 -2167.35 6249.52 339.71 2.39 MWD 6-ax 49 12008.76 90.86 9.1 31.4 8978.73 2864.10 5892.62 -2162.09 6276.75 339.85 3.53 MWD 6-ax 50 12940.46 90.86 10.0 31.7 8978.25 2862.69 5923.87 -2156.83 6304.30 339.99 2.64 MWD 6-ax 51 12071.93 89.93 11.4 31.4 8978.03 2860.66 5954.72 -2151.00 6331.31 340.14 5.35 MWD 6-ax 52 12103.82 68.53 14.3 31.9 8978.46 2857.41 5985.82 -2143.91 6358.17 340.29 10.09 MWD 6-ax 53 12135.96 68.73 14.0 32.2 8979.23 2853.40 6017.03 -2138.04 6384.93 340.46 1.12 MWD 6-ax 54 12167.73 68.46 10.8 31.7 8980.01 2850.42 6047.98 -2129.23 6411.84 340.61 10.13 MWD 6-ax 55 12193.05 68.32 10.3 25.4 8980.72 2848.85 6072.94 -2124.58 6433.65 340.72 2.04 MWD 6-ax 56 1~')~4.66 87.63 10.2 31.6 8981.64 2647.06 6104.02 -2118.96 6461.35 340.86 2.21 MWD 6-ax 57 12258.60 85.26 9.2 31.9 8983.82 2845.56 6135.40 -2113.60 6489.25 340.99 8.06 MWD 6-ax 68 12288.26 63.96 4.7 31.7 8986.80 2845.59 6168.72 -2109.78 6517.64 341.11 14.72 MWD 6-ax 59 12320.02 64.95 3.5 31.7 8989.86 2847.18 6198.19 -2107.53 6546.69 341.22 4.89 MWD 6-ax 60 12351.31 85.68 359.8 31.3 8992.42 2850.09 6229.38 -2106.63 6575.93 341.32 12.01 MWD 6-ax 61 12383.03 86.47 357.4 31.7 8994.59 2854.71 6260.98 -2107.40 6606.13 341.40 7.95 MWD 6-ax 62 12412.68 64.37 355.3 29.9 8996.97 2860.22 6290.72 -2109.30 6634.93 341.46 9.92 MWD 6-ax 63 12~.~.~..83 82.47 353.8 31.9 9000.63 2867.05 6322.26 -2112.31 6665.80 341.53 7.57 MWD 6-ax 64 12475.65 81.57 350.6 31.1 9004.95 2874.91 6352.77 -2116.48 6696.06 341.57 10.59 MWD, 6-ax 65 12507.58 81.54 347.3 31.7 9009.60 2884.63 6383.54 -2122.49 6727.15 341.61 10.30 MWD 6-ax Page 2 $?hlumberger ANADRILL Survey Rel~ Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DLS Srvy Tool # Depth angle angle length depfl~ section +N/S- +E/VV- displacement (dc=g/ tool quality (ft) (deg) (deg) (ft) (ft) (ft) (fi) (ft) (fi) (deg) 10Of) type type 66 12538.72 81.02 344.2 31.1 9014.32 2895.77 6413.33 -2130.06 6757.81 341.63 9.99 MWD 6-axis 67 12567.73 80.88 343.0 29.0 9018.88 2907.14 6440.81 -2138.14 6786.43 341.64 4.11 MWD 6-axis 68 12599.11 82.06 339.5 31.4 9023.54 2920.63 6470.21 -2148.13 6817.48 341.63 11.65 MWD 6-axis 69 12631.88 84.99 337.4 32.8 9027.24 2936.20 6500.51 -2160.10 6850.01 341.62 10.97 MWD 6-axis 70 12662.56 68.25 337.8 30.7 9029.05 2951.25 6528.84 -2171.77 6880.68 341.60 10.70 MWD 6-axis 71 12692.82 90.93 333.6 30.2 9029.27 2966.93 6556.36 -2184.20 6910.61 341.57 16.50 MWD 6-axis 72 12724.63 91.92 331.6 31.8 9028.47 2984.89 6584.56 -2198.63 6942.01 341.53 7.02 MWD 6-axis 73 12755.64 92.47 329.3 31.0 9027.29 3(X33.34 6811.52 -2214.1 6972.41 341.49 7.62 MWD 6-axis 74 12787.59 93.63 326.5 32.0 9025.56 3023.48 6638.59 -2231.08 7003.47 341.42 9.46 MWD 6-axis 75 12617.90 95.15 324.4 30.3 9023.26 3043.52 6663.47 -2248.21 7032.52 341.36 8.54 MWD 6-axis 76 12850.15 95.98 321.5 32.3 9020.13 3065.87 6689.13 -2267.58 7063.63 341.27 9.30 MWD 6-axis 77 12878.98 94.53 319.0 28.8 9017.49 3086.76 6711.17 -2265.92 7089.80 341.19 10.00 MWD 6-axis 78 12910.21 92.91 316.0 31.2 9015.47 3110.43 6734.13 -2306.95 7118.32 341.09 10.91 MWD 6-axis 79 12941.61 91.71 313.4 31.4 9014.20 3135.25 6756.19 -2329.25 7146.43 340.98 9.11 MWD 6-axis 80 12973.22 91.03 311.8 31.6 9013.45 3160.94 6777.57 -2352.50 7174.24 340.86 5.50 MWD 6-axis 81 13004.14 91.89 313.3 30.9 9012.66 3186.07 6798.46 -2375.25 7201.45 340.74 5.59 MWD 6-axis 82 13035.29 92.51 313.0 31.2 9011.46 3211.24 6819.78 -23,98.00 7229.10 340.63 2.21 MWD 6-axis 83' 13067.37 93.29 311.2 32.1 9009.84 3237.47 6841.28 -2421.79 7257.28 340.51 6.10 MWD 6-axis 84 13096.93 93.77 311.0 29.5 9008.02 3261.65 6860.63 -2443.97 7282.94 340.39 1.76 MWD 6-axis 85 13126.89 93.84 311.1 30.0 9006.03 3286.65 6880.29 -2466.55 7309.05 340.28 0.41 MWD 6-axis 86 13156.14 94.18 308.9 31.2 9003.85 3312.76 6900.29 -2490.39 7335.95 340.15 7.12 MWD 6-axis 87 13189.74 94.26 308.4 31.6 9001.53 3339.58 5919.98 -2515.00 7362.83 340.03 1.60 MWD 6-axis 88 13221.39 94.87 308.4 31.7 8999.00 3366.55 6939.61 -2539.76 7389.76 339.90 1.92 MWD 6-axis 89 13253.43 94.50 308.7 32.0 8996.39 3393.73 6959.48 -2564.71 7417.01 339.77 1.49 MWD 6-axis 90 13284.68 91.37 308.2 31.3 8994.79 3420.40 6978.92 -2589.18 7443.73 339.65 10.13 MWD 6-axis 91 13316.69 88.70 308.5 32.0 8994.77 3447.72 6998177 -2614.28 7471.09 339.52 8.40 MWD 6-axis 92 13348.22 85.65 306.7 31.5 8996.26 3474.80 7017.96 -2639.20 7497.81 339.39 10.70 MWD 6-axis 93 13380.01 84.79 303.6 31.8 8998.86 3502.74 7036.21 -2665.11 7524.03 339.25 10.27 MWD 6-axis 94 13411.41 85.09 301.8 31.4 9001.63 3530.92 7053.11 -2691.43 7549.18 339.11 5.79 MWD 6-axis 95 13439.86 85.68 300.3 28.5 9003.92 3556.87 7067.76 -2715.77 7571.57 338.98 5.64 MWD 6-axis ,,. 96 13471.52 87.15 299.2 31.6 9005.90 3585.95 7083.41 -2743.15 7596.02 338.83 5.81 MWD 6-axis 97 13503.18 89.28 298.2 31.7 9006.88 3615.38 7098.62 -2770.94 7620.27 338.68 7.42 MWD 6-axis 98 13535.00 90.75 299.5 31.8 9006.68 3644.90 7113.96 -2798.79 7644.72 338.52 6.17 MWD 6-axis 99 13565.94 90.99 293.0 30.8 9006.82 3674.85 7125.53 -2827.55 7666.04 338.38 7.63 MWD 6-axis 100 13596.84 91.65 291.0 30.9 9006.11 3704.69 7137.10 -2856.19 7687.39 338.19 6.81 MWD 6-axis 101 13628.47 90.51 268.8 31.7 9005.51 3735.58 7147.89 -2685.99 7708.51 338.01 7.82 MWD 6-axis 102 13657.57 89.21 287.1 29.1 9005.58 3764.15 7156.65 -2913.67 7727.23 337.85 7.35 MWD 6-axis 103 13690.12 88.01 285.1 32.5 9006.37 3798.23 7165.86 -2944.68 7747.38 337.66 7.17 MWD 6-axis 104 13721.67 87.12 281.5 31.6 9007.71 3827.60 7173.13 -2975.60 7768.82 337.47 11.73 MWD 6-axis 105 13749.19 87.15 280.1 27.5 9009.08 3855.01 7178.27 -3002.58 7780.94 337.30 5.09 MWD 6-axis 106 13782.92 87.39 279.1 33.7 9010.69 3888.63 7163.89 -3035.77 7798.98 337.09 3.05 MWD 6-axis 107 13813.81 87.91 277.0 30.9 9011.96 3919.50 7188.21 -3066.34 7814.91 338.90 7.00 MWD 6-axis 108 13845.11 68.22 274.7 31.3 9013.01 3950.77 7191.40 -3097.45 7830.10 336.70 7.41 MWD 6-axis 109 13877.61 87.50 271.1 32.5 9014.23 3963.16 7193.04 -3129.68 7844.49 336.48 11.29 MWD 6-axis 110 13909.11 68.01 259.7 31.5 9815.46 4014.43 7193.26 -3161.36 7857.30 338.28 4.73 MWD 6-axis 111 13940.05 89.21 270.3 30.9 9016.21 4045.09 7193.26 -3102.25 7869.78 338.07 4.34 MWD 6-axis 112 13971.38 91.47 270.0 31.4 9016.03 4076.26 7193.34 -3223.65 7882.64 335.68 7.26 MWD 6-axis Page 3 Sohlumberger ANADRILL Survey Rep~ ISeq 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/ tool quality (fl:) (deg) (deg) (ft) (ft) (ft) (fl:) (ft) (ft) (deg) lOOf) type type 113 14004.28 91.99 269.4 32.9 9015.03 4108.88 7193.17 -3256.53 7895.99 335.64 2.41 MWD 6-axis 114 14034.84 91.92 271.3 30.5 9013.99 4139.15 7193.36 -3287.01 7908.78 335.44 6.23 MWD 6-axis 115 14066.64 89.52 271.1 31.8 9013.59 .4170.79 7194.02 -3318.80 7922.65 335.23 7.57 MWD 6-axis 116 14098.31 88.90 270.5 31.7 9014.93 4202.30 7194.46 -3350.49 7936.33 335.03 2.72 MWD 6-axis 117 14129.87 88.87 269.3 31.6 9014.65 4233.65 7194.41 -3382.09 7949.72 334.82 3.80 MWD 6-axis 118 14161.04 88.05 270.4 31.1 9015.48 4264.50 7194.33 -3413.17 7962.92 334.62 4.41 MWD 6-axis 119 14193.34 65.16 270.7 32.3 9017.39 4296.53 7194.64 -3445.41 7977.07 334.41 9.00 MWD 6-axis 120 14224.40 81.88 271.3 31.1 9020.90 4327.26 7195.18 -3476.31 7990.95 334.21 10.72 MWD 6-axis 121 14254.92 78.79 271.6 30.5 9026.02 4357.18 7195.94 -3506.36 8004.75 334.02 10.18 MWD 6-axis 122 14286.51 75.88 271.9 31.6 9032.95 4387.88 7196.88 -3537.17 8019.14 333.83 9.26 MWD 6-axis 123 14316.04 74.20 271.7 29.5 9040.57 4416.26 7197.77 -3565.66 8032.55 333.65 5.73 MWD 6-axis 124 14348.58 74.02 272.0 32.6 9049.49 4447.49 7198.78 -3597.00 8047.41 333.45 1.04 MWD 6-axis 125 14379.73 73.53 271.3 31.1 9058.18 4477.22 7199.64 -3626.84 8061.57 333.26 2.67 MWD 6-axis 126 14411.23 73.55 271.5 31.5 9067.11 4507.29 7200.38 -3857.04 8075.86 333.07 0.61 MWD 6-axis 127 1~.~.~0.22 73.45 271.8 29.0 9075.34 4534.97 7201.18 -3684.64 8089.20 332.90 1.05 MWD 6-axis 128 14500.00 73.45 271.8 59.8 9092.38 4592.06 7202.98 -3742.13 8117.05 332.55 0.00 MWD_M - Page 4 GeoQuest 3940 Arctic Bird Anchorage, AK 99503 ATTN: Sherrie NO. 12274 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1/26/99 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape R-40 '/~ )~'~:~ 7 ~,~ 99026 IMPULSR GR 981113 1 1 I R-40 -- ' 99026 IMPULSR GR 1VD 981113 1 1 W-19A ~ ~'~ 99022 IMPULSE-ADN 981215 1 ! 1 W- 19A 99022 IMPULSE-ADN TVD 981215 1 1 W-19A 99022 DENSITY/NEUTRON 981215 1 1 W-19A 99022 iDENSlTY/NEUTRON TVD 981215 1 I R-20A L~,I, (.~ ~l~l 98623 IMPULSE 980715 i *REDO-TO ADD A&H CURVES TO EDITED FILE. PRINTS ARE CORRECT. R-.23A ~ ~>~ (.~ I 99006 JlMPULSE 971120 1 *REDO-TO ADD A&H CURVES TO EDITED FILE. PRINTS ARE CORRECT. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 9013 E. Benson Blvd. Anchorage, Alaska 99519-6612 RE(.;EIVED Date Delivered: J::EJ 04 1999 0ii & Gas Cons. Commission Schlumberger Geo©uest 8940 Aroti¢ Blvd Anchorage, AK 9951~ d / 198-199-0 PRUDHOE BAY UNIT Roll #I: Start: Stop Roll #2: MD 14500 TVD 09092 Completion Date: W-19A 50- 029-22006-01 BP EXPLORATION (ALASKA) INC Start Stop 12/25/98 Completed Status: 1-OIL Current: T Name Interval D 9564 I PDS GLS ,~L GLS FINAL 0-11118 ,,,L IMP-ADN-MD FINAL 10400-14400 ~,-L IMP-ADN-TVD FINAL 8450-9000 L IMP-NDT-MD FINAL 10400-14400 ,,/.L IMP-NDT-TVD FINAL 8450-9000 R SRVY RPT SCHLUM 10462.80-14500. T 8969 1 SCHLUM IMP-ADN Sent Received .. CH 5/26/00 5/26/00 CH 1 5/26/00 5/26/00 OH 1/26/99 2/4/99 OH 1/26/99 2/4/99 OH I/26/99 2/4/99 OH I/26/99 2/4/99 OH 2/I 7/99 2/22/99 OH 1/27/99 2/4/99 T/C/D Thursday, January 25, 2001 Page 1 of 1 TONY KNOWLE$, GOVERNOR ALASK& OIL ~ GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 27g-1433 '907) 276-7542 October 14. 1998 James E. Smith Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit W- 19A BP Exploration (Alaska) Inc. Permit No: 98-199 SurLoc: 696'SNL. I181'WEL. Sec. 21.TllN. RI2E. UM Btmholc Loc. 1319'NSL. 208'WEL. Sec. 08. TI IN. RI2E. UM Dear Mr. Smith: Enclosed is thc approved application for pcrmit to rcdrill the ab~(;~'i:.i-efcrcnccd well. · , ., The permit to rcdrill does not exempt you from obtaining addition~.t~:pc(rnits required by lax'`' from other governmental agencies, and docs not authorize conducting drilling operations un(il all other required permitting determinations arc made. Blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allo'`'`' a representative of the Commission to witness a test o~:' BOPE installed prior to drilling new hole. Notice naa,,' be r4vcn by contacting the Commission petroleum field inspector on thc North Slope pager at 6'59-3~07. Chairman '"'~)"::~'~'i;;i!~':::.i':':'. '.': ~ .. BY ORDER OF THE COMMIssION dlf/Enclosurcs cc: Department of Fish & Game. Habitat Section w/o CllCl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA !, -AND GAS CONSERVATION COM,. ,SSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory r'! Stratigraphic Test [] DeveloPment Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 82.60' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047450-' 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025i 696' SNL, 1181' WEL, SEC. 21, T11N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 4682' NSL, 3371' WEL, SEC. 16, T11 N, R12E, UM W-19A At total depth 9. Approximate spud date Amount $200,000.00 1319' NSL, 208' WEL, SEC. 08, T11 N, R12E, UM 10/20/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028261,208'I No Close Approach 2560 15113' MD / 8915' TVDss ~;6". :1'o be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 10500' Maximum Hole Angle 96.20° i Maximum surface 2879 psig, At total depth (TVD) 8815' / 3760 psig ~18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 608' 10350' 8249' 10958' 8704' 123 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-Mod 4305' 10808' 8568' 15113' 8915' 524 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11560 feet Plugs (measured) true vertical 9201 feet Effective depth: measured 11396 feet Junk(measured) true vertical 9132 feet Casing Length Size Cemented M D 'FVD Structural Conductor 110' 20" 146' 146' Surface 2728' 13-3/8" 3723 cuft Coldset II 2692' 2690' Intermediate 10999' 9-5/8" 2392 cuft Class 'G' 10963' 8831' Production Liner 870' 5-1/2" 357 cuff Class 'G' 10690' - 11560' 8576' - 9201' Perforation depth: measured 11252' - 11288', 11300' - 11320' !!!, ~:';:DL... ~. '~-:, ,,1_.: true vertical subsea ' 8891' - 8940' (two intervals) Aiaska 0]! & Gas £',0~s. _~;..,~:;hor~.g~~, '~'~';"~ffachments [] 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: Saud Jumah, 564-5726 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby cert'~ fo~goi~and correct to the best of my knowledge Signed Jame~E. Smith Title Senior Drilling Engineer Date ~'- Commission Use Only P ~j~m~t ~N U~mc~b~r APl Number I ApprovaI,Dat~¢ I See cover letter 50-029-L3ge6-e,1 ~. A (30 ~o - O I ,/~--//~---' for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes [~No Hydrogen Sulfide Measures j~Yes r-I No Directional Survey Required [~'Yes [] No Required Working Pressure for BOPE [] 2K; ~ 3K; I-I 4K; I~ 5K; [-] 10K; ~ 15K Other: by order of ~igll~O Approved By Commissioner the commission Date. -~ :... ..... .%., ~..~..~ Form 10-401 Rev. 12-01-85 David Submit In Triplicate ( Iwe' Name: Iw-19a ] Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 696' FNL, 1181' t-EL, Sec. 21, T11N, R12E X = 612050.18, Y = 5959559.86 Tie-in Survey: 3959' FSL, 3174' FEL, Sec. 16, T11N,R12E X = 609976.36, Y= 5964185.97 Target Start Location: 4682' FSL, 3371' FEL, Sec. 16, T11N,R12E, TVD ss = 8944' X = 609767, Y = 5964906 Bottom Hole Location: 1319' FSL, 208' VEL, Sec. 08, T11 N, R12E, TVD ss = 8915' . X = 607617, Y = 5966792 I AFENumber: 14Pl107 I I Rig: I Nabors18E I I Estimated Start Date: 110/20/98 / I Operating days to complete: 1 26 I KOP MD: TD MD: 10500' 15113' IKOP ! TVD: 8359' ss TD TVD: 8915' ss levation a.m.s.I) I Well Design (conventional, slimhole, etc.): I Extended Horizontal Sidetrack Producer I Obje,~ive: I Selectively ~leo-steer well to optimally drain I - Ivishak Zone 4 tar~let Formation Markers Formation Tops MD TVD (SS) Kingak D . 8192 Tie-In Survey 10499 8354 KOP 10500 8359 Curve 8°/100', From Whipstock 10685 8494 End 8°1100' cuwe Top Sag River 10951 8699 7" Liner point 10958 8704 Approx. 7' in the Sag River 10969 8713 Curve 12°/100, '~ Sh~blik 10989 8728 CGOC 11054 8775 TOP OF Z4 11108 8815 Target Start 11504 8948 _ 11597 8944 End 12°/100' curve 1 ~P06 8892 Curve 10°/100' 14363 8949 End 10°/100' cuwe .. 4 ~" Liner Point 15113" 8915 I u REMARKS: - Geosteer well path to say 25' above OOWC - OOWC 8970' - HOT is at 8970' TVD ss Casinc/Tubing Proqram Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVDss MD/TVDss 8-1/2" 7" 26# L-80 BTC-Mod 608' 10350'/8249' 10958'/8704' 6" 4-1/2" 12.6~ L-80 IBT-Mod 4305' 10808'/8568' 15113'/8915' tubing 4-1/2" 12.6# L-80 IBT-mod 10808' Surf. 10808'/8568' General Mud Program Intermediate Mud Properties: Fresh Water 8-1/2" hole section LSND Density Viscosity Yield 10 sec 10 min APl HTHP (PPG) Point gel gel Filtrate Filtrate LSND 10.5 Production Mud Properties: Quik 6" hole section Driln/BHne DensitY LSRV 10 sec 10 min pH "n" VALUE (PPG) gel gel 8.6 60 - 80000 > 20 > 22 9.0 - 9.5 0.2 - 0.3 , Directional IKOP: Maximum Hole Angle: Close Approach Well: ±10500' MD (estimated) 96.20° None Surface Wells SHUT-IN For Rig Moves Are W - 18 & W - 20 AT 30' On Either Side. Cement First Stage Second Stage Casing/U'ner Sx I Wt I Yield Sx I Wt I Yield Comments 7" Intermediate Premium Tail: None Single Stage, Single Slurry Job ,Class liner 123/15.8/1.14 cement. "; Full cement across liner interval (608'). 30% excess 4-1/2" Liner 524 / 15.8/1.19 None Class "G" cement, 50% excess in open ~ hole · Remark :- 150' liner lap, TOC 200' above TOL with DP in the hole. Logping Propram LWD Logging: 8-1/2" Hole 6" Hole Open Hole Logs (DPC) : 8-1/2" Hc:~- 6" Hc",¢ Hole Lon=s (DPC): MWD/GP,/directional MWD directional I GR I Res. (R'i') None 1) DPC P~fform Express (GR/RES/LDT @Horizordal/NUF_JSonic), RI-I"S None Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics will be provided when determining rig (rig will be in the current fleet of north slope rigs and the schematics are therefore on file with AOGCC). Maximum anticipated bottom hole pressure is 3760 psi at 8815'TVDss. Maximum anticipated surface pressure assuming gas in entire annulus (0.1 ppg) is 2879 psi. Hazards This well will penetrate -600' of lower Kingak at 46° in the 8-1/2" section. Good drilling practices, including optimized flow rates of 410-430 gpm, slower trip and connection speeds, pumps at 40% when reaming connections, larger nozzle area for reduced sidewall erosion, all will Assure a trouble free interval. Possibility of lost circulation in the TOP of SAG RIVER There is a 40' down south fault is expected in the reservoir approximately at 12,139' MD, the well will penetrate fault plane almost perpendicularly. Low reservoir pressure and lost circulation due to Iow pore pressure within the reservoir interval. Disposal Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC- 2A for disposal. W-19a Short Well Summary Pre-Rig Work: NOTE: If any problems are observed with the 9=/,'' packoff during pre-rig operations, notify the Operations Drilling Engineer, Nabors 18E Company Representative and the wellhead manufacturer. Repairs will be made prior to initiation of rig work. f2. 3. 4. 1. RU slickline and drift 3 ~" tbg. If cannot get coil tbg to production packer ( due to I.D restriction @ 10,602' ), notify Operations Drilling Engineer. P & A Open perforation (11,252' - 11,320').With 10 bbls of class "G" cement, Top of Cement MUST NOT be above 10,900' (Minimum per AOGCC = 11,1 52' or 100' above uppermost maraseal squeezed perforation ). Tag and test cement plugback. Notify AOGCC of tag & test. Pressure test 9 5/8" to 3,000 psi. Report results to ODE in Anchorage. RU electric line and make a chemical cut of tubing in the second full joint above production packer +_ 10,530' MD. NOTE: Cut depth should be very close to 10530',as the stub will determine final Kick Off point. Circulate well to seawater through the cut. Freeze protect to _ 2,200' MD. 5. Pressure test the 9 5/8" packoff. Carefully cycles LDS. 6. Set a BPV in preparation of the rig sidetrack. 4 Riq Work: 1. MIRU. Cimulate out freeze protection. ND tree, NU and test BOPE. Cimulate well clean. 2. Pull the 3 ~" tubing completion. Tubing cut at _+ 10,530' MD. 3. Replace the leaking 9 5/8" packoff if necessary. 4. RIH w/GR/JB to top of cut tubing. 5. Set 9 5/8"whipstock on top of cut tubing and mill window. {5. Kick-off and directionally drill 8 1/2" hole to 10,958'. 7. Run and cement 7" ,26~, L-80 liner. 8. Directionally drill the Zone 4 horizontal section to TD _+ 15,113' MD. 9. DPC log at horizontal (_+ 11,600' ) log suite are; Platform Express and Sonic, RFT. 10. Run and cement 4 ~", L-80 solid production liner. ] 1. Perforate. 12. Run 4 ~", L-80 tubing completion. ]3. ND BOPE, NU and test tree. RDMO. /t I~- ~ _ ~ SSSV Landing Nipple i__.- o,~. ~.75o-~,.i.D.) [ 21os L-80, Btrs. Gas L~ Mandmb, ~ER~) 1-1/~. ~ La~h ~ No. MD-BKB WD~ A~. BI G; , 12 ~nqsfl ~RPgR ~ a~ e _ TDS. Non-IPC ;I.D. = 2.~2" , Dr~ = 2.867" ~apac~ = 0.00871 bb~t ~ 3-1~ Otis "~ N~p~ I I ~ / 2.750' vin. LO.. ~, ,, ¢ '1~ ~ ~' X ~ ~ Seal A~Y' ~'W' ' ~[" 10602 I OP= 2800 / (SBR, 12' Lo~) (5.438' O.D.) ax. Ang.= 50° ~' 9-~8"Packer - I 10617'. ~Q~ ~h~ ~9% / ~ /3-112", 9.2fiAt, L~0, TDS. Tai~e ~ ~-,,~'O..'X'.~.,e i~°622 ~ 0~ Q~ ~,.~e~ ~ I ~ ~ ~ ~ 2.750- uh. ~.o. ~ ~~9~. ~ I I ~ ~ 3-1/2"Otis"X'N~ple I' TOPOF 5-1~' [ 10690 I ~ ~ ~ .(Landedi~linerhanger LINER , t~ack s~eve) L-SO NSCC ~ . k PERFORA~ON SU. MMARY ' REF. LOG: BHCS 1-2-90 ~ZE SPF INTERVAL STATUS % 33~ 6 11252-11288 Open ~ MARKER JOINT J 11141 6 11300-11320 Open DATE BY REVIS~N PRUDHOE BAY WELL: W-lO ~6~o SA Ne~ Co~letion .APl NO. 50-029-22006 {26-16-11-12) SEC.. 21, T-11 N, R-12E I - BP EXPLORATION (ALAS~) Inc. m WELLHEAD: 13-5/8' McEvoy ACTUATOR: Otis Proposed W-19a Completion (Section Sidetrack out of 9-5/8" Casing) KB 1 _ ELEV= BFI MSL ELEV= 54.15' 13-3/8' 72#/ft L-80, BTRS I' '692' I I X. Nipple (3.813' ID) I4 112', 12.6 #, L-80 Production Tubing with 6 4-1/2' GLMs 0350' MD ~ 7" X 9 5/8' Hanger/Packer KOP 1"10500' MD ! jTop of bridge plug at ~10590' MD J JTop Cement ~xxx' MD g-5/8", 47.-- J 10963' MDI 7', Production Packer J @ -~10608' MD I ~.__j Tubing cut at -10600' WLM T°P°f j=10808'MD J 4-1/2' Liner TD 15113' md 7' Liner Shoe J+1o958' UPI J41/2" cemented and perforated' J DATE 912J98 7", 29/~, L-80 Liner I11560' MD I REVISED BY Bruce W. Smith . COMMENTS Proposed Sidetrack Completion IPRUDHOE BAY UNIT WELL: W-19a APl NO 50-0~9-22006-01 BP Exploration (Alaska) WELL PAD W 1996 RELIEF PAD Tee avail to gas line SUMP ,o,, w W 31 17 30 16 29 15 27 ~ 26 25 500 ~~ 501B 501 C 501A · SUMP' 34 35 36 37 38 39 4o~ . 42 ~ 1 3~ S~. 7.~ 6 8 9W 10 11.~. 12 44 TO SPINE ROAD WELL, 4" PRODUCTION LINE AND 3" GLT LINE ~'~ // CELLAR, 4" PRODUCTION LINE ^ND 3" Anadril] Schlumber~ger Alaska ~istrict llll East 80th Avenue Anohorage, AK 99518 349-45[1 ~ax 344-2:60 DIReCtIONAL ~ELL PLA~ for SHAP.~D SERVICBS DRILLING Well ......... : W-19A (P4A) Field ........ : Prudhoe Bay Computation..: M~B±mum Curvature Units ........ : FEET Surface Lat..: 70,29~46~87 N Surface I~;ng.: 149.0925597~ · Legal D~scription Surface ...... : ~5~2 FSL 1~80. FE~ S2~ T11N ~2B U~ T/e-An survey: 39~9 FSL 3~74 FEL-S~5 TllN ~2~ rTE ~b .......... : 1319 FSL 209 ~ S~8 TllN R~ZE ~ ~0CATIONS - ALASKA Zone= % X-Coord X-Coord 612050./8 5959559.86 609976.36 5964185.97 609~67.00 5964906.00 607617.00 59667~2.G0 PROPOS~D W~T.L PRDFILII gTATION MEA~LTR~D INC~N D~R~CTION VE~TIC~L-DE~THS ~P K~K ~75.50 ~393.00 TJD 8274.60 8192.00 TIE-IN B~ 10499.50 46.37 347,08 844L.54 8358.94 ~P / ~RV~ 8/100 10500.00 46.~7 ~47.09 8441.88 8359.28 1~600.00 42.51 337.07 8~13.35 54~0.76 SECT I ON DEPART Prepared ..... : ~9 Au9 1998 Vert sec2 az.: 318.70 KB elevation.: 82.60 £t Na~netic Dcln: +27.524 (~) Scale Factor.: 0.99991426 Co~ver~jence..: +0.85432818 ANADR~L[ AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR XfiCUTION PLAN -- COORDIEATBS-~ROM AI~%SKAZone 4 TOOL DL/ WELLKE~D X Y FAC~ 100 482L.62 4656.92 N 2004.78 4821.94 465?.2? N 200&.87 4885.94 4723.~ ~ 2026.I5 509976.36 5964L85.97 NS 60~976.27 5964L86.32 L22L l.Ll 609954.00 5964252.49 LlSL 8.00 END 8/]00 CURVE 10685.19 40.00 327.45 8577.46 8494.86 4940.38 4973.41 N 2052.13 W 609927.29 5964301.73 H$ 8.00 TO~ SAG RIVER 109~1.66 40.00 327.45 878L.60 869g.00 5109.65 4917.77 N 2144.28 ~ 609833.00 5964444.69 HS 0.DO 7" CASING BT 1~955-18 40.00 327.45 8786.60 8704.00 SLL3.80 4921.31 N 2146.54 W 609830.69 5964448.19 H9 O.OO CURVE I2/100 10969.93 40.00 327.45 8795.60 8713.00 ~121.26 4927.67 N 2150.60 W 609826.53 596445&.50 5~R 0.00 TOP SHIIBLIK 109sg-v= 41.40 330.38 $810.60 8728.~0 $~$5.95 ~938.72 N 2157.26 ~ 609S19.?[ 5964465.&4 53R 12.00 11000.00 42.16 33L.84 $816.27 ~735.67 5L40.65 ~44.72 ~ 2160.57 W ~09816.31 5964471.39 51R L2.00 (Anadrill (c)78 W[gAP4 3.2C 1L:55 AM PI W-NgA (P4A) 17 Aug 1998 Pa~e 2 STATION ~RA~URED INCL~T IOSNTI~XCATION DEPTH ANGL~ C-'~]OC 22054,96 46.50 lll00.O0 50-35 11200-00 59.53 END L2/100 CURV'B 11294.22 68,69 CURV~ 12/100 11326.05 68.69 TARGET START **'***' E~TD 12/100 CURVE cuaw~ lO/lOO 11400.00 77.47 11500.00 89,47 11504.&0 90.00 11597.02 94.89 12206.64 94.89 DIP~ECTION VERTICAL-DEDTHS 338.96 8857.60 87~5.00 344.04 8887.49 880&.89 353.51 8944.97 8862.37 0,88 0986.L1 8903.51 0.88 8997.97 891~.37 SECT I ON DSPART 5177-35 520~.3~ 5278.79 5344.86 5367.39 COOED~ NATES- FROM WSLLAKAD 5011.57 5091.69 5176.19 5206,59 0.88 9019.23 8936.63 5419.20 5276.49 0.88 9030.58 8945.98 5492.68 53?5.65 0.88 9030.60 8940.00 5495.94 5380.05 10.$? 9026,64 8944.04 5558.75 5471,96 10.87 8974.~2 8892.12 593].21 6068.46 ALASKA Zo~e 4 X Y 2176.45 ~ 609799.92 5964506.06 2187.09 W 609788.80 5964537,83 22O2.60 W 609~72.10 5964617.70 2206.53 W 609766.91 2206,06 W 609766.93 5964732,53 2204.99 W 609~66.96 5964802.44 2203.47 W 609767.00 59649D~.60 2203.40 W 609767.00 5964906.00 2L93.95 W 609775.07 5964998.03 2079.36 W 609880.75 5965596.12 46R ~2.00 43R L2.D0 38R ~2.00 ~2.00 0.00 liS 12,00 HS ]2.O0 64R ~2.00 HS 12.00 [70L 0.00 12256,28 90.00 12300.00 88.73 12400.00 85.$8 12500.00 03 · 12600.00 80.59 10.00 8972.60 8890.00 596].91 5.81 8973.08 8890.48 5990.a6 356.22 8977.79 8895.19 6064.22 346,56 8987.39 8904,~9 6147.87 336.T9 900Z.50 89LB.98 6238.87 6117.21 ~ 2070.38 W 609889.00 5965645.00 6260.50 ~ 2064.37 W 609894.37 5965688.37 6260.25 N 2062.59 W 609894.66 5965788.12 6358.54 N 2037.45 W 609878.33 5965886.18 6452.40 N 2/08.51 W 609845.8B 5965979.55 L07L ]0.00 L0~L ]0.00 L06L ]0.00 1050 L04L 10.00 lo/loo ~%rE 10/100 END 10/100 CL11~.VB CURVE 10/200 12638,73 78.73 12709,12 78.77 12800.00 07.86 12821.43 90.00 12900-00 92.13 13000.00 94.78 I3055.89 96.20 ]3340,83 96,20 13400.00 90.29 13402.~7 90.00 329.00 9015.71 8933.11 6313.89 329.00 9021.63 8939.03 6343,22 329.00 9032.20 8949,60 6431,93 329.00 9032.60 8950.00 6453.01 32L,44 9031.~4 8948.54 6531.00 311.78 9025.10 6942.50 6630.62 306.35 9019.75 8939.15 6685,45 306.35 8988.96 8906.36 6962.17 306.35 8985.61 8903.01 ?019,85 306.35 8985.60 8903.00 7022,66 6521.30 N 2143.76 W 609809.61 5966047.91 HB 10.00 6546.84 N 2~59.11 W 609793.89 5966073.22 H$ 0.00 6624.14 N 2205.54 W 609746.31 59fi6L49.81 HS ]0.00 6642,50 ~ 2216.58 W 609735.00 5966168,00 7¢G 10.00 6~06,97 ~ 2261.35 W 609689.27 ~966231.79 741 10.00 6779.42 N 2329.83 6814.47 N 2373.01 6982.35 N 2601.17 7017.35 N 2648.73 ?029,05 N 2651.05 609619.73 5966303,21 609576.03 5966337.60 609345.41 5966502.05 609297.34 5~66536.33 609295.00 5966538,00 75L ~0,~0 HS 30.00 T..,S 0,00 LS ]0,00 971 ]0.00 END 10/L00 CURVE [3500.00 88,78 13600.00 87,57 13691.74 86-5] (AnadriLL (c}98 WL~A?4 3.2C 11:55 ~(P) 296.71 8986,63 8904.03 7215.34 7069.78 206-78 8989.83 8907,23 7204.32 7106.76 27~.65 8994.58 891].98 7277.9/ 7126,13 2733.73 W 609211.58 5966587.48 97b ]0.00 2826.45 W 609118.33 5966623.08 971 10-00 2915.90 W 609028.60 5966642.1~ HS ]0.00 ANADR!LL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION 17 AUg 2998 9;- 19A ( ~4AJ ~TAT ION ~S~D I [DE~I F I~TION DEPTH ~ ~0/100 ~4299,~7 86,51 14300,00 86,59 14334-06 90 E~ 10/100 ~R~ 1~363.31 ~2.62 4-1/2" ~ PT~{ {> 15[~3,5~ 92,62 OO~C Tv.2 R~CT EOI1 V~RTECAL- DE~T~ AZIMUT~ TVD SUB-SHA 277.65 90%1,54 894~,94 ~7~.65 9831.59 89&~.99 277.65 90B2.60 fl95~,~0 276.36 9031,93 8949-33 276,36 8997,6~ 8915.~O 9052.60 8970.00 9058.60 8976-00 9110.60 9028.00 9162.60 9080-00 SECTION 77~.~0 7783,33 8337.3~ OOORDINATE$-¥ROM ALASKA zone 4 ~206.87 N 3516.8~ W 608426.61 $96~712.87 72~6.95 N 3517.62 W 6~842S.80 ~9~6712.9~ 7211.5L ~ 3551.36 W 608392.00 $96671~.00 7215.08 N 3580.38 W 608362.93 5966720.13 7295.09 N 4325-22 W 607617.00 5966792.00 ?oou D~/ FACJ~3 ~OO HS 0.O0 H$ ~0.00 26L ~0.00 Hg [0.0~ D.00 (Anal-rilL (c)~8 W19AP~ 3,2C L~:55 ~M P) ANADR'[L AKA-DPC FEASI L!TY PLAN h;OT APPROVED FOR EXECUTION SHARED ' CERVTCES DRILLING ............. ~ £--- L III1_ iii i III II I II IP4A) VERTICAL SECTION VlE~ section at: 3~8.70 TVB Scale.' ! inch = ~§00 feet Dep Sca)e ' ~ inch - ~500 feet ..... Drawn ' J7 Aug :t998 ~DRILL AKA- )PC _ ,r'ZA C" 'l"\/ r I Al,,, N,::)T/,P OVED FC,R ,4nadri]] . ii i _ _ ii [-'~~r-"~'-~ ,-r-~/"~ ~ ~ Narker Identification MO 8K8 9ECTN INOLN /4f~ BI 1(aP / CURVE 8/100 10500 8442 4822 46.37 --'" '' .... ~5'~ C) E,D 8/100 CURVE 10685 8577 4980 40.CO ;- . El CURVE J2/JO0 tOqTO 8796 512:1 40.00 F) END t~/tO0 CURVE :1t294 8966 5345 88.69 Gl CURVE 12/J00 1t327 8998 5367 68,69 I FI) TARCET START *~N*~M* lt504 9031 5496 90.00 ]:) END t~/iO0 CURVE ~J597 9027 5559 94,99 d) CURVE lO/lO0 ~207 8975 593~ 94.89 '"~ K) ENO lO/tO0 i2679 90~6 63t4 78.77 j % L] CURVE ~0/~00 t370g §022 8343 78.77 NI ENO lO/JO0 CURVE ~3056 90~0 6685 g6.20 ~, NI CURVE JO/tOO t334! 8989 6962 96,20 .... O) END t0/~00 CURVE t368~ 8995 7878 §6,5t P) CURVE lO/lO0 J4299 9032 7735 86.5t a] ENB tO/t00 CURVE t4363 9032 7783 §~.6~ R) fD 4-~/~' LNR Pr<l I> J§~4 8998 8337 98,6~ ............ ........... ........... ..... ...... ~E~ ~:~ .... :: ---~ ............ ...... , 0 750 t500 2~50 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 Section Depart. ure ' ¢'HARED SERVICES 'DRI:L[ING ' ii ii _ i iiiiiii iii ................. II IIII i i im Il I /lnadr j ] ] Schlumberger ! ! __ N-19A (P4A) VERTICAL SECTION VIEW ! · Section at: ............................................... ' TVD Sca]e,: I inch ; 500 feet ANA)RILL &KA-CPC ~Dep Scale.: ~ incl~ 500 feet F_'AS!B!L!"~Y__P _A.N i~ ..... : ~7 ~u~ N()T A PPR()VF~ FO ~ __ B) [~ / CURVE B/JO0 1~00 8442 4822 46.: r C)E~ 81100 CURVE ..... "'- D) 7' CASING Pl 109~ 8787 5~4 40,m E) :~VE ~2/)00 10970 8796 5~21 40.m F) E~ 12/~00 CURVE 1~2B4 8986 5345 68.1 ._~ .... ~4~ ~ -- - ..-, 6~ C~vE ~/¢~0 tzar7 B9~8 5367 · ~8.~ H) TARGET STARI ~)N~)N~ [ t504 903t 5495 90.m I) E~ ~/~00 CURVE [~597 9027 5559 94.J J) CURVE lO/tO0 [22D7 8975 593i '~- K) END ~O/JO0 [2579 9016 6314 78.' L) CURVE ~0/$00 [27D9 gO~2 6343 78.' M) END ~O/JO0 CURVE [3056 9020 66~ gc.; = ............... N) CURVE tO/~O0 ~3341 8989 6952 96.; D) END lO/JO0 ~RVE ~3592 Bg95 7278 86J ~ P) CURVE tO/lO0 ~4299 g032 7735 86. % g) END [OJ~O0 CURVE [4363 903~ 7783 - ~_~ R) TD 4-1/2" L~ Pl<lJ> [5114 BggB 8337 g2.q ~ ................ , ........ ' : ..... ~~ ~c '~-~- } ...............~:.. , ,. ...... ~.,, -- ~_,,,..~,.,-. ~: , , ~ ~ .................... -::-: .[ ....... ~ ...... iE ...... % .................. : : ..... ........... ~ .... 7500 775 4500 4750 5000 52§0 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 I)500 1)750 90D0 Section Departure ~dr~)) (c)¢'~;4 3.~c n:~ AHP) ................... SE Marker Ident i ficat ion MD N/S E/ii ~0970 4928 N 2~5t ~ B) KOP / CURVE 8/100 C) ENO 8/100 CURVE O) 7' CASING PT E) CURVE 12/J00 F] END 12/t00 CURVE GJ CURVE 12/100 H) TARGET SlART x~x~)~, I) END ].2/I00 CURVE d) CURVE 10/100 K) END 10/10o L) CURVE 10/t00 H) END 10/~.00 CURVE N) CURVE 10/100 O) END 10/I00 CURVE P) CURVE 10/100 11294 5~76 N 2207 W 11327 §207 N 2206 11504 5380 N 2203 t~597 5472 N 2t94 12207 6068 N 2079 i2679 §§2~ N 2t44 J2709 6547 N 2159 13056 6814 N 2373 13341 6982 N 260t 13692 7126 N 29t6 14299 7207 N 3517 W-19A (P4A) PLAN VTE CLOSURE ..... : 8483 feet et Azimuth 329.35 DECLINATION.: +27.624 (E) SCALE .......: I inch = ~200 feet DRAWN .......: J7 Aug J998 /nadpl ] ] SchYumberger' 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 ~BO0 2200 600 0 §00 <- WEST' E~ST -> C) END 8/t00 CURVE 10685 4773, ~05~" PLAN VIEW D) 7" CASING PT ]0958 492] N 2147 W~ ..... E] CURVE [2/100 ]0970 492B N 2~5t ~ CLOSURE ..... : 8483 feet at Azimuth 329 35 F) END t2/~O0 CURVE ~t294 5176 N 2207 N ' 6) CURVE J2/tO0 ti327 5207 N 2206 ~ DECLINATION,' +27.624 (E} H) TARGET START ,~,~, ~t504 5380 N ~203 U SCALE ' J ~nch = 500 feet I) END ~2/~00 CURVE ii597 5472 N 2~g4 ~ ....... J) CURVE tO/tO0 ~807 6068 N ~079 U DRAWN ' ]7 Aug J998 .K) ENO ~0/~00 ~ST~ ~. ~44. L) CURVE ~O/iO0 ~70g S547, ~g, .) E,O ~OnO0 CU.V~ ~305~ SS~4, ~373. ...... N) CU.VE ~0/~00 ~3~ ~.a~. ~O~. PI CURVE ]0/~00 ]4299 7207 N 35]7 N ...... R) TD a-~/~ LNR PT:II> 15', 7E~]B N 3~5 N R 7~50- ~ ~ ~ ~ 7000 .................................. 6750- - ' ............ 6500 .... 6250- - ·................ 6ooo.. ~ ~,,HADR~LI AF A-DPC ~ ' FEt~SIBILIT~' PD~N ...... /, ~z~o--- NO3' AP'>RO~/ED :OR ~ ...... EXECUTION ...... ~~ _ ~~ .... 5~50 - - .............. 5000 ,,, 4750 ......... 4000 ~ ~ ... 4500 4250 4000 3750 3500 3~50 3000 ~750 ~500 8250 ~000 ~750 ]500 ]250 ~000 <- WEST Alaska hared ervlces rilling WELL NAME W-19a DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET This cover sheet is auolicable to: (only one cateeorv ocr cover sheet) [~ Permit Documentation Prepared: ODE: Date: Permit Application. Reviewed: s~,~s: q..r'~..~ ['~ PRE-RIG WORK Pre-Rig ~e~l~ Reviewed: SDE/ES: ~ ~ Date: Pre-Ri~VIemo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Saud,Jumah Date: 9/10/98 Pre-Rig ~un.d~ Application Reviewed: SDF_2ES:,~,/~' Date: Pre-Rig ~u~ry Application Submitted: TA: Date:,~ SUNDRY NOTICE Sundry Documentation Prepared: ODE: Date: Sundry Application Reviewed: SDE/ES: Date: Sundry Application Submitted: TA: Date:~ NOTE: I~ su~o~Y is ~o~ PR~-Rm WOR!q, Pmg-lUa wog~ S~.CTIO~ ~ ~,LOW AND CI~,CK "ABANDON" BOX BELOW Reason for Sundry (Check.all that avolv) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): APPROVAL TO PROCEED Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate mi} 1 ....... ,I-,,,,--<,,",,.', m ,f,~.~ ;'~ ~ I 4,, ',, G. ~ I IApproved AOGCC Permit/Sundry Received TA: Date: I Approval to Commence Operations SDE/ES: Date: ared WELL NAME. W- 19 a ' .rv!o s I I This cover sheet is a licable to: onl one cate o er cover sheet ODE: Date: ' I ODE: Date:~ Permit A0plication Reviewed: .../ , I D sundry Application Reviewed: Permit.~lbplic, ation Sub. nli~ted: n, ,_ IJ ~ Sundry Application Submitted: PRE-RIG WORK SDE/ES: ~ ~ Date: , Pre-Ri~/Iemo Sent to Slope: ODE: Date: .. Pre-Rig Sundry Documentation PrePared: ODE: SaudJumah Date: 9/10/98. Pre-Rig ~un~d~ Application Reviewed: SDF_.~S: Date: .Pre-Rig ~u~ry Application Submitted: TA: Date: ,. NOTE,.', IF SUNDRY IS FOR PRE-RIG WORI~ USE PRE-RIG WOI/K SECTION AT BELOW LEF ,T. AND cmz. CK "ABANDON" BOX BELOW Re~._son for Sundry (Check,ali that apolv)_ ..... Abandon Alter Casing 'Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): APPROVAL TO PROCEED Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimuhte Approved AOGCC Permit/Sundry Received Approval to Commence Operations TA' SDE/ES:_ Date: Date: [w.,. ,,,.,o= I w-19a i Well Plan Summary Target Start Location: -Bottom Hole Location: Type of Well (producer or injector):, } Producer Surface Location: 696' FNL, 1181' i-~-L, Sec. 21, T11N, R12E X = 612050.18, Y = 5959559.86 Tie-in Survey: 3959" FSL, 3174' t-EL, Sec. 16, T11N,R12E X = 609976.36, Y= 5964185.97 4682' FSL, 3371' FEL, Sec.. 16, T11N,R12E, TVD ss = 8944' X = 609767, Y = 5964906 1319' FSL, 208' i-~_L, Sec. 08, T11N, R12E, TVD ss = 8915' X = 607617, Y = 5966792 i AFE Number: I4P1107 I Estimated Start Date: 0/20/98 MD: 10500' TD MD: 15113' IRig: I Nabors 18E IO,,perating days to complete: 126' I , KOP I TVD: 8359' ss TD TVD: 8915' ss We!! Design (conventional, sliml~le, etc.): levation a.m.s.I) I Extended Horizontal Sidetrack Producer ! Objective: '1Selectively..ge°'stcc; we!! to optirr~__!_h/drain I - Ivishak Zone 4 ta.r, get ~ Formation Markers [ Fo.,.--_--_=]on Tops MD TVD (ss) .... - Kin?_k D 8192 .. . - Tic In Survi~y 10499 8354 _ KOP 10500 8359 Curve 8°1100', From Whipstock 10685 8494 End 8°1100' curve _ -Top Sag River 10951 8699 7" Liner point 10958 8704 Approx. 7' in the Sag .River _ 10969 8713 Curve 12°1100' , .. - , Shublik '10989 8728 CGOC 11054 8/[5 ~ , - TOP OF Z,4 11108 81~15 _ Target Start 11504 8948 , - 11597 89.~. End 12°/100' curve ., I P~06 8892 Curve 10°/100' _ ' 14363 8949 End 10°/100' curve 4 ~" Liner POint 151'13 8915 I L) REMARKS: - Geosteer well path to say 25' above OOWC .. - OOWC 8970' - HOT is at 8970' TVD ss Casinc rrubing Proqram Hole SiZe Csg/ Wt/Ft Grade Conn Length Top Tbg O.D. MD/TVDss MD/TVDss -- 8-1/2' 7' 26# L-80 BTC-Mod 608' 10350'18249' 10958'/8704' - 6' 4-1/2' 12.6~ L-80 I BT-Mod 4305'" 10808'/8568' 15113'/8915' tubing 4-1/2" 12.6~ L-80 IBT-mod 10808' Surf. 10808'/8568' , General Mud Program Intermediate Mud Properties: Fresh Water 8-1/2' hole section LSND , · Density Viscosity Yield 10 sec 1~) mir~" APl HYHP (PPG) Point gel 9el Filtrate Filtrate LSND 10.5 , . , ,, Produc,.tion Mud Properties: Quik 6" hole section Driln/Brine Dens'.~y LSRV 10 sec 10 mi'n pH , n" VALUE" (PPG) eel gel 8.6 60- eoooo > 20 > .~p ' "9.0 - 9.5 ' 0.2- 0.3 , Directional 'KOP: Maximum Hole An~lle: Close Approach Well: ±10500' MD (estimated) 96.2O° None Surface Wells SHUT-IN For Rig Moves Are W - 18 & W - 20 AT 30' On Either Side. Cement First Stage Second Stage Ce-_<ing/L~her Sx/Wt / Yield. Sx / Wt / Yield Comments. . " 7" Intermediate Premium Tail: None Single Stage, Single Slurry. Job ,Class "G"' liner 123/15.8 / 1.14 cement. ",~ Full cement across liner interval (608'). 30% excess , 4-1/2" Liner 5241 15.8/1.19 None Class "G" cement, 50% excess in open ~ hole , Remark :- 150' liner lap, TOC 200' above TOL with DP in the hole. Loaai.na Proar LWD Logging: 8-1/2" Hole 6" Hole Open Hc;= Logs (DPC) : 8-1/2" Hc:= 6" Hc;c, C-_s.-~l Hole Lo=~ (DPC) ~m MWD/GR/directional MWD directional I GR / Re-s= (RT) None 1) DPC Pb;fform, Express (GR/RES/LD~ @Horlzo~tal/NUE/Sonic), R~-I'S None .?' Well Control Well control equipment 'consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics will be provided when determining rig (rig will be in the current fleet of north slope rigs and the schematics are therefore on file with AOGCC). Maximum anticipated bottom hole pressure is 3760 psi at 8815'TVDss. Maximum anticipated surface pressure assuming gas in entire annulus (0.1 ppg) is 2879 psi. Hazards · This well will penetrate -600' of lower Kingak at 46° in the 8-1/2" section. Good drilling practices, including optimized flow rates of 410-430 gpm, slower trip and connection speeds, pumps at 40% when reaming connections, larger nozzle area for reduced sidewall erosion, all will Assure a trouble free interval. Possibility of lost circulation in the TOP of SAG RIVER · There is a ~t0' down south fault is expected in the reservoir approximately at 12,139' MD, the well will penetrate fault plane almost perpendicularly. · Low reservoir pressure and lost circulation due to Iow pore pressure within the reservoir interval. Disposal. Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC- 2A for disposal. W-19a Short Well Summary Pre-Rig Work:, NOTE: If any problems are observed with the 9~/;' packoff during pre-rig operations, notify the Operations Drilling Engineer, Nabors 18E Company Representative and the wellhead manufacturer. Repairs will be made prior to initiation of rig work. ~[. RU slickline and drift 3 ~" tbg. If cannot get coil tbg to production packer ( due to I.D restriction @ 10,602' ), notify Operations Drilling Engineer. 2. P & A Open perforation (11,252' - 11,320').With 10 bbls of class "G" cement, Top of Cement MUST NOT be above 10,900' (Minimum per AOGCC = 11,152' or 100' above uppermost maraseal squeezed perforation ). Tag and test cement plugbaclc Notify AOGCC of tag & test. 3. Pressure test 9 5/8" to 3,000 psi. Report results to ODE in Anchorage. 4.. RU electric line and make a chemical cut of tubing in the second full joint above production packer +_ 10,530' MD. NOTE:. Cut depth should be very close to 10530',as the stub will determine final Kick Off point. Circulate well to seawater through the cut. Freeze protect to + 2,200' MD. :~. Pressure test the 9 5/8" packoff. Carefully cycles LDS. 6. Set a BPV in preparation of the rig sidetrack. Rip Work: 1. MIRU. Circulate out freeze protection. NE) tree, NU and test BOP£. Circulate well clean. 2. Pull the 3 ~" tubing completion. Tubing cut at + 10,530' MD. 3. 'Replace the leaking 9 5/8" packoff if necessary. 4. RIH w/GR/JB to top of cut tubing. :5. Set 9 5/8"whipstock on top of cut tubing and mill window. Kick-off and directionally drill 8 1/2" hole to 10,958'. ?. Run and cement 7" ,26#, L-80 liner. $. Directionally drill the Zone 4 horizontal section to TD + 15,113' MD. 9. DPC log at horizontal (:1: 11,600' ) log suite are; Platform Express and Sonic, RFT. 10. Run and cement 4 l~", L-80 solid production liner. 11. Perforate. 12. Run 4 ~", L-80 tubing completion. 13. ND BOPE, NU and test tree. RDMO.. ~_,ELLI'IEAD: 13-5/8'- 5.000psi. FM~,~ BF ELEV: 54.15 ft. . ~ SSSV Landing Nipple I.~_~ '-' -- Otis. (2.750' Min. I.D.) [ 2105 i , 13-318-, L-80. Btrs. I 2692 I ~ ~[ I Gas Lift Mandrels, (MERLA) 1-1/2', RA Latch I ' No. MD-BKB 'rVDss Ang. i ,i 3~112'. 9.2#/t't. L-80. --~ ! I .~n¢.~ R~Q7 ! .4~ o TOS, Non-IPC I.D. = 2.992' Drift = 2.867' i ~.apacity = 0.00871 bbl/[t ~,j 3-1/2' Otis '3(' Nipple ~ =.~o-~.,.~.. I ~o~ I ~ -~' s.,^.~.~,w) . J..~o~o~ .oo I . ~ ~ {SBR, 12' Lo~) {5.4a8' O.DJ Max. Ang.= S0° ~" 9-5/8'Packer ~ I 10617' I 3-1/2' Otis 'X' Nipple ~0 ~[t"'~O~o ~ i , I ' ~ (Landed in'liner hanger TOP OF 5-1/2' ! ! LIN E R 10690 tie-back sleeve) i _ L-B0 NSCC ~ PERFORATION SUMMARY · REF. LOG: BHCS 1-2-90 .... ~ ' S~ZIZE SPF INTERVAL STATUS 3 3/8 6 11252-11288 Open "~'---~ MARKER JOINT 6 11300-11320 Open s'm"'7#n" L' I I i i i ii i DATE DY nEWS~N . PRUDHOE BAY WELL: W-19 2/6/90 S.A New Corr~etion APl NO. 50-029-22006 (26-16-11.-12_.) SEC. 21, T-11N, R-12E ~ BP EXPLORATION (ALASKA) Inc. iii WELLHEAD: 13-5/8" McEvoy ACTUATOR: Otis Proposed W-19a Completion (Section Sidetrack out of 9-5/8" Casing) KB I MSL ELEV= BF I MSL ELEV= 54.15' 13-3/8' 72#/ft L-80, BTRS Nipple (3.813' ID) 4 112', 12.6 #, L-80 Production Tubing with 6 4-1/2' GLMs 0350' MD I 7" X 9 5/8' Hanger/Packer KOP 10500' MD I Top of bridge plug at -10590' MD J Top Cement ~xxxx' MD Production Pack~.r J @ +10608' MD Top of 4-112" Liner _.___~ Tubin9 cut at - 10600' WLM g-5/8', 47= 7' Liner I 10963, MD! Shoe 1+10958' MDJ =10808'MD '] TD 15113' md 4 1/2" cemented and perforated' 7', 29#, L-80 Liner I11560' MD ! DATE REVISED BY COMMENTS 9/2/98 Bruce W, Smith Proposed Sidetrack Completion IPRUDHOE BAY UNIT WELL: W-19a APl NO 50-029-22006-01 BP Exr)loration (Alaska) WELL PAD W TO SPINE ROAD RELIEF PAD Tee avail Io gas line O ~. 32 ~ ~31 ~ 30 ~ 29 5~ 27 -- SUMP 24 W 23 .~ 22 ~ - ~00 ~ ~IC 501A 37 SUM s. 8 40 ~ 9 ~ 4 10 ~ ~ 12 44 / SUMP NOTES: WELL, 4" PRODUCTION LINE AND 3" GLT LINE GAS CAP INJECTION WELL CELLAR, 4" PRODUCTION LINE AND 3" GLT LINE -- NO WELL HEAD Anadril] S¢:h h]n~%e ~ger Alaska Dimtrict 1111 East BOth Avenue 349-4511 ~ax 344-2160 DIR~CTiONA~ NELL PLAN for 8HAPPED SERVICE? DRILLING Welk ......... : W-19A (P4A) Field ........ : Prudhoe Bay Computation..: Minimum Cuz-vature Uni=s ........ : FEET &'urface Lat..: 70.2984618? ~urf&ce I~ong.: 149.09255976 Legal DescrlDtion Surface ...... : 4582 FSL 2180 FEb Tie-i~ survey: 39~9 FSL 3~74 F~Ta Tarc3et ....... : ~682 FS~ 3371 FEL ~HEL .......... : 1319 FSL 209 FEL LOCATIO~6 - A/~ASKAZo~e: ~ X-Coord Y-Coord S21 T11N ~12~ IFR ~12~50.18 59595S9.86 SL6 TllN ~1~ UM 609976.~6 596~185.97 SL6 TllN RZ2E T.;M 609~67.00 5964906.00 S08 TllN R~2E UM 607617.00 S966792.00 PROPOSED W~r,r, i=RDPILE STATION ~~D I ~ ~P K[~K TJD TIE-IN S~ 10499.50 46.37 Y~P / ~RW8 8/100 1~00.~0 46,37 1~600. ~0 42.51 D~P.~CT~ON V~RT~C2~-DE~PTHS 7%75.60 7393.00 8274.60 8192.00 347.08 8441.54 8358.94 . 3%~.09 8441-88 8359.28 33~.07 8S~3.36 8430.76 SECTION DEPART &88s.g& Drepared ..... : L? Aug 1998 Vert sec: az.: 518.70 KB elevation.: 82,60 ~t ~Eagne:i¢ Dcln: +27.62~ (~) Scale ~ac~or.: 0. 99991426 Convince..: +0.85432818 ANADR~LL AKA-DPC FEASIBILITY NOT APPROVED FOR EXECUTION 74, :~ ,~ - ~::: ....... ~ ........ -.= ...... - ~ ~O~2~T~S-~M ~8~ Zone 4 WELL~ X Y =__- TOOL DL/ FAC~ 4656.92 N 2004.28 4659.27 N 2Q04.87 4?23.77 N 2026.~5 609976.36 5964L85.gq HS 609976.27 5964186.32 L22L l.LL 609954.00 5964252.49 L15L 8.00 END 8/100 CIJ'RVB 10685.19 ~0.00 TOP SAG RIVER 1095L.66 40,00 7" C~I~ DT 109S$.18 40.00 CURVE /2/100 10969.93 40,00 TOP SHUBLIK 10989.7~ %1.40 327.45 8577.46 8~94.86 4940.38 4773.41 N 2052.13 W 609927.29 5964301.73 HS 8.00 327.45 878L.60 8699.00 5109.65 4917.37 N 21%4.28 N 609833.00 5964444.69 ES 0.DO 327.45 8786.6~ 8704.00 5115.80 4921,31 N 2146.54 W 609830.69 5964448.19 ~S 0.00 3~T.45 8795.60 8713.00 ~121.26 4927.67 N 2150.60 W 609826.53 596445~.50 5SR 0.00 330.38 8510.60 8728.00 $13~.95 4938.72 N 2157.26 N 609819.7l 5964465.44 53R 12.00 11000.00 42.16 33~-84 G8~8.27 8735.67 5140.65 4944.72 ~ 2160.57 W 6098L6.~1 5964471.39 SIR 12.00 (A4%adrill (c)78 WLgAP4 3.2C ll:55 ~4 D] H-29A (P4A} 17 Aug L998 Page 2 STATI I D~.NT I FI CAT I 0N __ OGOC ~.~.~ ~2/~0o CURW co~v3 32/~oo E~m L2/lOO CURVE ~ so/soo [(E2%SUR~D INCL,? DIP,~C~IOIT DEPTH A/qGLE AZI[413T~ 22054.96 46.50 338.96 11100.00 50,35 344,04 11200.00 59.53 353.51 11294.22 68.69 0.88 11326.8~ 68.69 0.88 11400.00 11500.00 89,47 11504.40 90,00 11597.02 94.89 12206.64 94,89 L2256.28 90,00 L2300.00 88,73 L2400.00 85,88 L2500.00 B3.L3 'L2600,00 80.59 0.88 0.88 0.88 10.87 10.87 V-ERTl CA.L- DE [~fHS TVD SECT I ON DEPART 8857.60 B775.00 8887.49 8804.89 8944.97 8862.37 8986.L~ 8903.5L 8997.97 8915.37 5177.35 5208.37 5278.79 5344.86 5367.39 9019.23 8936.63 9030.58 8947.98 9030.60 8948.00 9026.64 8944.0& 8974.72 8892.22 54L9.20 S492.68 S495.9& 5558.75 5931.21 10.00 8972.60 8890.00 5963.9l 5.8L 8973.08 8890.48 5990.46 356.22 8977.79 8895.19 6064.22 346.56 8987.39 8904.79 6L47,87 336.79 9001.58 8918.98 6238.87 C00RDINATEB-FRO[~ WELLKKAD 4979.63 N 2176.45 5015.57 N 2187.09 5091.69 N 2202.60 51~6,19 ~ 2206.53 5206,$9 N 2206.06 KI.~SKA Zone 4 X Y 609799,92 5964506.06 609788,80 5964537.83 609722.10 5964617.70 609~66,9L 5964~02.13 609766.93 5964732.53 FAC~ LO0 46R ~2.00 43R 12.00 38R 12.00 HS 12.00 lis 0.00 5276.49 N 2204.99 W 609766.96 5966802.44 :-Lg 12.00 5375,65 N 2203.47 W 609767.00 5964901.60 HS 22.00 5380,05 ~ 2203.40 W 609767.00 596~906.00 64R ~2.00 54~1,96 ~ 2L93.97 W 60977S.07 5964998.03 HS 22.00 6068.46 ~ 2079.36 W 609880.75 5965596.12 £70~ 0.00 6117.21 ~ 2070.38 W 609889.00 5965645.00 L07L ~0.00 6~60.50 ~ 2064.37 W 609894.37 5965688.37 L0qL ~0.00 5260.25 ~ 2062.59 W 609894.66 5965788.12 106L lO.00 6358.54 ~ 2077,4S W 609878.33 5965886.18 LOSL lO.00 6452,40 ~ 2L08.51 W 609845.88 5965979.55 104L lO.00 ~ lO/lOO CURVE 10/S00 ~ND 10/100 CURVB CURVE L0/200 L2678.73 78.77 L2709.12 78.77 L2800.00 87.86 L2821.43 90.00 L2900.00 92.L3 13000.00 94.78 13055.89 96.20 13340.83 96.20 13~00.00 90.29 13~02.87 90.00 329.00 329.00 329.00 329.00 32L.4& 3LL.TB 306.35 306.35 306.35 306.35 9015.71 8933.11 9021.63 8939.03 9032.20 8949.60 9032.60 8950.00 903L.24 8948.54 9025.20 8942.50 9019.75 8937.15 8988.96 8906.36 8985.6~ 8903.01 8985.60 8903.00 6313.89 6343.22 6431,93 6453.01 6531.00 663'0.62 6685.45 $962.17 ~7019.85 7022.66 6521.30 N 2183.76 W 609809.6~ 5966047,91 HS 10.00 6546.84 N 2159.1L W 609793.89 S966073.22 H8 0.00 6624.14 ~ 2205.54 W 609746.31 5966L49.81 HS 20.00 6642,50 ~ 2216.58 W 609735.00 5966L68,00 ?¢~ 20.00 6706.97 N 2261,35 W 609689.27 5966231.79 7~L ~0.00 6779,42 N 2329,83 W 609619.73 5966303,2L ?5L 6814.47 N 2373.0L W 609576.03 5966337,60 HS 20.00 6982.35 N 2601.17 W 609345.41 5966502.05 L~S 0.00 7017.35 N 2648.73 W 609297.34 5966536.33 LS 10.00 7029,05 ~ 2651.05 H 609295.00 5966538.00 97L 20.00 E2~ID lO/L00 CIIP. VE 13500.00 88.78 13600.00 87.57 13691.74 86.52 (bn~adrLLl (c)98 WL7AP4 3.2C 11:55 AZ(P) 296.72 286-78 277.65 8986.63 8904.03 8989.83 8907.23 8994.58 89L1.98 7215,34 7204.32 7277.9L 7069.78 ~T 2733.73 W 60921L.58 5966587.48 971', 20.00 7106.76 N 2826.45 W 609118.33 5966623.08 97L 10.00 7226,13 1T 2915,90 W 609028.60 5966643.11 I-IS 30.00 ANADR [LL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION W--'gA (P4A] 17 Aug 1998 Page STAT lOB' ~EA SUR. ED I NCI~; [DS~I F ICAT/ON Dm. PTH CXIRVE 10/ZOO 14299.37 86.51 14300.00 86 14334.06 90 .(]0 HOT OOWC TZ3 PROPOSED WEI~L PROFILE DIRECTZOIT VSRTICAL-DEPTHS AZIMrJTI4 TV]) SUB-SEA 277.65 9031.54 8945.94 277.65 98B2.60 895~.88 276.]6 9031,93 8949.33 276.36 8997.60 8915.00 9052.60 8970.~0 9058.60 8976.~0 9110.60 9028.00 9162,6~ 90~.00 SECTION 7735.20 ?735.82 7761.49 7783.33 8337.3~ OOORDINATES-FROM ALASKA Zone ~ T006 ~L~D X y FACE 9206.87 N 3516.8/ W 608426.61 $9~6712.87 HS 7206.98 N 3~k7.62 W 608425.80 ~966712-97 H$ 7211.5l H 3551.36 W 7215.08 N 3580.38 W 7295.09 N 4325.22 W ~t/ ~00 0.00 10.00 608392.00 5~66719.00 26L ~0.00 608362.93 5966720.13 H~ LO.O0 607617.00 5966792.00 . O.OO (A_~adril[ (c) 98 W19AD~ 3,2C I1:55 A~¢ D) ANADR'[L AKA-DPC FEASIEILITY PLAN NOT APPROVED FOR. EXECUTION PLAN SHARED SERVICES DRILLING N- gA (P4A) VERTICAL SECTION VIEW section at: 318.70 TVD Scale.' 1 inch = ~500 feet Dep Scale.' 1 inch -- 1500 feet ~DRILL AKA- )PC ~lr'z_ A C DIt IT\/ r~l A kI N,DT MiPPROVED FC R .... .ill $£h]umber ! I"\L~PF'"! I'-r'lAIk ! Hanker Identification MD 8K8 SECTN [NCLN /,,/~ 81 KOP / CURVE 8/100 ~.0500 8448 4822 46.37 i ...... , D) 7' CASING PT 10958 8787 5114 40,00 F) ENO 1Z/lO0 CURVE 11294 8986 5345 88.69 G} CURVE 12/t00 Jt327 8998 5367 68,69 ' !~ H) TARGET START ~a)M~ 11504 903t 5496 90.00 I) END 12/100 CURVE t~597 9027 5559 94.89 d) CURVE IO/~OD ~2207 8975 593~ 94.89 ) ,. K) END 10/100 12679 90~6 63t4 78.77 L) CURVE t0/~00 12709 9022 6343 78.77 M) END ~0/~00 CURVE ~3056 9020 6685 96.20 % .m N) CURVE ~0/~00 ~3341 8989 6962 96,20 ' " O) END ~0/~00 CURVE 13692 8995 7278 86,51 P) C~VE I0/100 ~4299 9038 7735 86.5~ G) END 10/100 CURVE ~4363 9032 7783 9~.62 ~ R) TD 4-~/Z' LNR PT<II> ~5~14 8998 8337 98.6~ ~- ~- .... 7' - ,,. ............... ... ,,,,, ...... ,.... .---= .. =ZZ ' ~-- =,, =~ Z . ,.~.. ...,.,..., i __ .. O 750 1500 2250 3000 3750 4500 5250 8000 6750 7500 8250 9000 9750 Section Departure 7500 77 8500 BT.' SHARED SERVTCES DRzLEiN¢" i lllllll iii i i il iii i ~nadr]l] Schjumberger W-19A (P4A) VERTICAL SECTION VIEW ! Section at: 3~B.70 50O feet ~,KA-DPC ANADRILL IDep sce]e.: I inch: 5oo feet --' N(F)TFZASIBIL'!"-'Y'APPR()VE[) p ANFO..... : ,, ,ug ~ j A) lIE-IN SURVEY iOSO0 B442 4B22 46.3 ~ ....... .......... C) E~ B/tOO CURVE tODD5 8577 4940 40.8 ...... D) ?' OASIS6 Pl tO9~ 87B7 5tt4 40.~ E) C~VE 1~/]0~ tgg?O B798 5tSt F) E~ i~/JO0 CURVE 11294 8986 5345 -:~::~,~,-~ ~ .... ~- G) C~VE 12/~00 11327 899B 5387 J H) )ARGEI STARl ~)N~)N~ i1504 9031 5496 I) E~ i2/~00 CURVE 11597 90~7 5559 g4.E J) CURVE 10/~00 1~07 B975 593i 94.E .... K) END ~0/]00 12679 9016 6314 78.l L) CUflVE 10/~00 12709 g0~2 6343 78. M) END lO/JO0 CURVE 13056 9020 6B~ 96.~ __ ....... N) CURVE lO/lO0 13341 89B9 6962 96. D) END lO/JO0 ~RVE 13692 B995 727B 86.( k P) CURVE lO/lO0 14~99 g032 7735 86.~ %,, D) END tO/JO0 CURVE 14363 9032 77B3 92.( .~_~ , R) TD 4-1/2" L~ Plq m > 15114 BggB B337 92.( ....... )..~ .. ......... ~0~ - ~ .- .................. , -..:..,: ,~ ,. .'L~ , ~ ............ ~ ......... ~ .... N ...... O .... ' ..... ' ~" ....................... -TI)- -~ fi ~ ................ F ~ -T~2 9 t 63 .. ~ . i ......... iii ~1 i iii i i I 4500 4750 5000 52'50 5500 5750 6000 6250 6500 6750 7000 Sect ion Departure r,..m-))) (c)9S 'Nt~,l;4 3.~C ]]:56 AW P) ........ 7250 7500 7750 8000 8250 B500 B750 gO00 SHARED SERVICES DRILLING BI KOP-/ C) ENID 8 D) 7" CASZNG PT I095R 4921 N 2t47 W ~ ........ - E] CURVE 12/100 10970 4928 N 2t5t W CLOSURE ..... : 8483 feet at AZimuth 329.35 ~1294 5176 N ~207 W §207 N 2206 w DECLINATION' +27.624 (E) F] END i2/100 CURVE G) CURVE 12/100 11327 H) TARGET START ~*~**~* it504 5380 N 2203 I) END 12/100 CURVE 11597 5472 N 2t94 J) CURVE tO/tO0 12207 6066 N 2079 K) END 10/100 12679 6521N 2t44 L) CURVE 10/100 12709 6547 N 2159 H) END 10/100 CURVE 13056 6814 N 2373 N) CURVE tO/tOO 13341 6982 N 260t O) END t0/100 CURVE 13692 7126 N 29t6 P) CURVE tO/tO0 14299 7207 N 35i7 SCALE · I inch : ~200 feet DRAWN · 17 Aug 1998 lin /lnadr j ] ]Sch]umberger t"kfl"i & ~' · ~ f~v 11 R) ;'O 4-t/2' LNR PT< 1> 15t d 72c.3 N 4i2§N R ~- P fl ,I " __ I T~ et (Point) I, , i.Z NADR LL AI<',A-DPC i FE/~SIBILIT'~' PDkN NO-f APf~RO\/[D :O'R- EXB 5UT ON. ..... ....... ...., .... ~_. . _ -- - KB 7800 7200 6600 6000 5400 a800 4200 3600 3000 2An'~ ~ onn 1 ~nn Rnn a 600 <- WEST ' EAST -> Hark~r Ioent~f~cat~on B] KOP / CURVE B/lO0 i0500 4657 N 2005 C) END 8/100 CURVE 10685 4773N 2052 D) 7' CASING PT ]0958 492] N 2]47 E] CURVE 12/100 ~0970 492B N 2~5t F) ENO t2/100 CURVE t~294 5176 N 2207 G) CURVE 12/100 11327 5207 N 2206 H) TARGET START ~ ~1504 5380 N 2203 II ENO 32/100 CURVE 11597 5472 N 2194 J) CURVE ~0/I00 1~07 6068 N ~079 K) ENB 10/100 ~2679 6521N 2~44 L) CURVE 30/300 1270g 6547 N 2t59 N) ENO 10/100 CURVE 13056 68t4 N 2373 N) CURVE ~0/~00 3334J 6982 N 2~! O) ENO lO/lO0 CURVE 33692 7126 N 29tG PI CURVE t0/100 34299 7207 N 35t7 SHARED SER-VICES MO N/S E/id DRILLING -19A (P4A) PLAN V'I;EN CLOSURE ..... : 8483 feet at Azimuth 329.35 DECLINATION.: +27.624 (E) SCALE ....... ; ~ inch = 500 feet DRAWN ....... : ~7 Aug J998 a Illil Anadri ]] Schlumberger I TO ~-1/2 LNR PT :Il > 15', 14 72 ~8 N t325 H R ~ D .......... . . ._ ............ , ........... Al< A-DPCt ,J £,,NADR !L! ...... FEtxSIBI LIT'h' PL; ~,N / I~-I' AP)RO~IED :OR EXE,..UTION ...... " --~ -----'---- ~ Ti ~H ·_ _ _ ,, 4500 4250 4000 3750 3500 3250 3000 2750 8500 2250 2000 ]750 ]500 ]2! <- NEST 141169 VENDOR DATE INVOICE · CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 073198 CKO73198H lO0. O0 i00. O0 HANDL!INQ INST' S/H TERRIE HUBBLE X4628 YHE AT[ACHED CHECK IS I. PAYMENT FOR ITEMS DESCRIBED ABOVE. COMPANY ADMINISTRATION ENGINEERING APPR _~ WELL NAME INIT CLASS PROGRAM: exp [] dev L~redrll.,~serv [] wellbore seg II ann. disposal para re_q_ !1. ON/OFF SHORE 0 ~%..._, _.. GEOLAREA Permit fee attached ....................... 1. 2. Lease number appropriate ................... 3. Unique well name and number .................. N 4. Well Iocaled in a defined pool .................. 5. Well located proper dislance from drilling unit boundary ............ N 6. Well located proper distance from other wells .......... 7. Sufficienl acreage available in drilling trait ................................... 8. If deviated, is we,bore plat included ............... 9. Operator only affected party ................... )N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N 14. Conductor string provided ................... 15. SuHace casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CM I' vol adequale to tie-in long string to surf csg ........ 18. CMI will cover all known productive horizons .......... 19. Casing designs adequate for C. T. B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a ~0-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .,~OO~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. UNIT# Y N Y N Y N Y N N N GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... ~,.,~-Y N 31. Data presented on potential overpressure zones ~ Y N 32. Seismic analysis of shallo~~ ..... ,Y, N 33. Seabed con(Jition surve, y..(~) ............. Y N AIrieR D~rE ~ _., ,~ 34. Congress reports ....... Y N __ ~ .~ .,~, Dry only/ ANNULAR DISPOSAL §,~:"' With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) wiii '~i0t impair...mechanical integrity of the well used for disposal; .................... (!')) will not damage producing formation or irnpair recovery from a pool; and (E) will not circumvent 20 ~C 25.252 or 20 AAC 25.412. ENGINEERING: UICIAnnular COMMISSION: JD" ~~ RNC ~' CO ~ohs~ - '- I Y N Comments/Instructions: M chel~lisl i~ev 05/29198 dlf C ~III,H')III( ¢?~wt)ft'JiRll~fll;Iflil~, I.'l I. I1' 1 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process 'but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * ....... SCHLUMBERGER ....... * COMPANY NAME : B.P. EXPLORATION WELL NAME : W-19A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22006-01 REFERENCE NO : 99022 * ALASKA COMPUTING CENTER * ****************************** * * ....... SCHLUMBERGER ....... * COMPANY NAME : B.P. EXPLORATION WELL NAME : W- 19A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22006-01 REFERENCE NO : 99022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PA~E : **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/01/21 ORIGIN : FLIC REEL NAME : 99022 CONTINUATION # : PREVIOUS REEL : COb~4ENT : B.P. EXPLORATION, PRUDHOE BAY W-19A, API #50-029-22006-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/21 ORIGIN : FLIC TAPE NAME : 99022 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : B.P. EXPLORATION, PRUDHOE BAY W-19A, API #50-029-22006-01 TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: BIT RUN 1 99022 BARNEY REID TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING W-19A 500292200601 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 21-JAN-99 BIT RUN 2 BIT RUN 3 21 liN 12E 83.40 81.90 52.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 10463.0 6.000 7.000 10930.0 LIS T~-.Fe Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 3RD STRING PRODUCTION STRING REF~%RKS: Well drilled 03-DEC through 15-DEC-98 with GR, IMPULSE and ADN. Data was collected in four bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFJMBER: 1 EDITED MERGED~fWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMbL~Y LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10420.0 14501.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... BIT RUN NO. MERGE TOP MERGE BASE 1 ,10420.0 10934.0 2 10843.0 12228.0 3 12031.0 13783.0 4 13694.0 14501.0 No depth adjustments were made to this data as per G. Dudley. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/PEL/PER. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center _ 25-JAN-1999 13:27 PAGE: 3 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 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 NUMB SAMP ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPXX MWD O~ 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD O~ 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD O~ 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD O~ 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD 0H~44000300 O0 000 O0 0 1 1 1 4 68 0000000000 RAS MWD OH~ 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RAM MWD 0H~44000300 O0 000 O0 0 1 1 1 4 68 0000000000 RAD MWD O~ 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RHO2MWD G/C3 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 TNRAMWD 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 LIS T~Pe Verification Listing Schlumberger Alaska Computing Center ., 25-JAN-1999 13:27 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TRPM ~ RPM 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10431.000 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 RAS.MWD -999.250 RAM. MWD -999.250 RAD.MWD RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.MWD -999.250 NPHI.MWD -999.250 TNRA.MWD -999.250 PEF.MWD TRPM. MWD -999.250 DEPT. 11000.000 ROP.MWD 48.780 FET.MWD 1.283 GR.MWD RPXX.MWD 18.930 RPX.MWD 16.680 RPS.MWD 15.860 RPM.MWD RPD.MWD 16.150 RAS.MWD 17.500 RAM.MWD 16.410 RAD.MWD RHO1.MWD 2.550 RHO2.MWD 2.730 RHO3.MWD 2.550 RHO4.MWD DRHO.MWD 0.026 NPHI.MWD 27.253 TNRA.MWD 14.223 PEF.MWD TRPM. MWD 0.000 DEPT. 12000.000 ROP.MWD 113.990 FET.MWD 1.392 GR.MWD RPXX.MWD 5.250 RPX.MWD 6.620 RPS.MWD 7.850 RPM.MWD RPD.MWD 9.570 RAS.MWD 9.640 RAM.MWD 9.830 RAD.MWD RHO1.MWD 2.560 RHO2.MWD 2.560 RHO3.MWD 2.560 RHO4.MWD DRHO.MWD 0.277 NPHI.MWD 21.110 TNRA.MWD 11.514 PEF.MWD TRPM. MWD 0.000 DEPT. 13000.000 ROP.MWD 56.420 FET.MWD 1.225 GR.MWD RPXX.MWD 7.470 RPX.MWD 7.800 RPS.MWD 7.960 RPM. MWD RPD.MWD 7.750 RAS.MWD 8.330 RAM.MWD 8.360 RAD.MWD REO1.MWD 2.640 RHO2.MWD 2.650 REO3,MWD 2.670 REO4.MWD DRHO.MWD 0.133 NPHI.MWD 21.918 TNRA.MWD 12.190 PEF,MWD TRPM. MWD 68.000 DEPT. 14000.000 ROP.MWD 44.450 FET.MWD 2.066 GR.MWD RPXX.MWD 4.930 RPX.MWD 5.500 RPS.MWD 5.980 RPM. MWD RPD.MWD 6.430 RAS.MWD 6.830 RAM.MWD 7.020 RAD.MWD RHO1.MWD 2.670 REO2.MWD 2.670 RHO3.MWD 2.670 RHO4.MWD DRHO.MWD 0.038 NPHI.MWD 22.047 TNRA.MWD 12.251 PEF.MWD TRPM.MWD 0.000 DEPT. RPXX. MWD RPD.MWD RHO1.MWD DRHO.MWD TRPM. MWD 14501 000 -999 250 -999 250 -999 250 -999 250 -999 250 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RAS.MWD -999.250 RAM. MWD -999.250 RAD.MWD RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD NPHI.MWD -999.250 TNRA.MWD -999.250 PEF. MWD 60.857 -999.250 -999.250 -999.250 -999.250 104.050 15.900 15.200 2.560 3.340 24.480 8. 740 9. 750 2.S60 2.190 75.410 7.890 8.180 2.650 2.890 37. 930 6.270 6. 930 2. 670 6. 040 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS T,-~Fu Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IV UMBER: 2 EDITED MERGEDMAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE .............. $ MERGED DATA SOURCE LDWG TOOL CODE $ REM-ARKS: This is the MAD data run after drilling Bit Run 4. It has been clipped for valid data. $ START DEPTH STOP DEPTH 14251.0 14500.0 MAD RUNNO. MAD PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS ~ape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 255 5 66 6 73 7 65 8 68 0.5 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 2 1 1 4 68 ROP MAD F/HR 4000300 O0 000 O0 0 2 1 1 4 68 FET MAD HR 4000300 O0 000 O0 0 2 1 1 4 68 GR MAD GAPI 4000300 O0 000 O0 0 2 1 1 4 68 RPXXMAD OR_M~4000300 O0 000 O0 0 2 1 1 4 68 RPX MAD O~ 4000300 O0 000 O0 0 2 1 1 4 68 RPS MAD O~ 4000300 O0 000 O0 0 2 1 1 4 68 RPM MAD O~ 4000300 O0 000 O0 0 2 1 1 4 68 RPD MAD 0HF~44000300 O0 000 O0 0 2 1 1 4 68 RAS MAD OH~M 4000300 O0 000 O0 0 2 1 1 4 68 RAM MAD OH~M4000300 O0 000 O0 0 2 1 1 4 68 RAD MAD 0I~4~4000300 O0 000 O0 0 2 1 1 4 68 RHO1 MAD G/C3 4000300 O0 000 O0 0 2 1 1 4 68 RE02 MAD G/C3 4000300 O0 000 O0 0 2 1 1 4 68 RE03 MAD G/C3 4000300 O0 000 O0 0 2 1 1 4 68 RH04 MAD G/C3 4000300 O0 000 O0 0 2 1 1 4 68 DRHOMAD G/C3 4000300 O0 000 O0 0 2 1 1 4 68 NPHI MAD PU-S 4000300 O0 000 O0 0 2 1 1 4 68 TNRAMAD 4000300 O0 000 O0 0 2 1 1 4 68 PEF MAD 4000300 O0 000 O0 0 2 1 1 4 68 TRPMMAD RPM 4000300 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** LIS ~Fe Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: DEPT. 14251.000 ROP.MAD -999.250 FET.MAD RPXX. MAD -999.250 RPX.MAD -999.250 RPS.MAD RPD.MAD -999.250 RAS.MAD -999.250 RAM. MAD RHO1.MAD -999.250 RHO2.MAD -999.250 RHO3.MAD DP. HO.MAD -999.250 NPHI.MAD 20.405 TNRA.MAD TRPM. MAD -999.250 DEPT. 14499.000 ROP.MAD 118.420 FET.MAD RPXX.MAD -999.250 RPX.MAD -999.250 RPS.MAD RPD.MAD -999.250 RAS.MAD -999.250 RAM. MAD RHO1.MAD -999.250 RHO2.MAD -999.250 RHO3.MAD DRHO.MAD -999.250 NPHI.MAD -999.250 TNRA.MAD TRPM. MAD -999.250 -999.250 GR.MAD -999.250 RPM.MAD -999.250 RAD.MAD -999.250 RHO4.MAD 11.468 PEF. MAD -999.250 GR.MAD -999.250 RPM.MAD -999.250 RAD.MAD -999.250 RHO4.MAD -999.250 PEF. MAD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED MAD PA~SES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH MAD 14250.0 $ STOP DEPTH .......... 14500.0 LIS T~Fe Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH MAD $ REMARKS: This is the MAD data from the pass run after Bit Run 4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 255 5 66 6 73 7 65 8 68 O.S 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 ROP MAI F/HR 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 FET MAI HR 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 GR MAi GAPI 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RPXXMA1 OHMM 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RPX MAi OH~ 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RPS MAI OH~ 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RPM MAi OH~ 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RPD MAI OHI~ 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RAS MAi OHM~ 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Ta~ue Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RAM MAi OHM~ 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RAD MAi OHM~ 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RHO1 MAi G/C3 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RH02 MAI G/C3 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RH03 MAi G/C3 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 RH04 MAI G/C3 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 DRHOMA1 G/C3 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI MAI PU-S 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA MAi 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 PEF MAi 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 TRPMMA1 RPM 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 14251 RPXX.MA1 -999 RPD.MA1 -999 RHO1.MA1 -999 DRHO.MA1 -999 TRPM. MA1 -999 000 ROP.MA1 -999.250 FET.MA1 -999.250 GR.MA1 250 RPX.MA1 -999.250 RPS.MA1 -999.250 RPM. MA1 250 RAS.MA1 -999.250 RAM. MAi -999.250 PAD.MAI 250 RHO2.MA1 -999.250 RHO3.MA1 -999.250 RHO4.MA1 250 NPHI.MA1 20.405 TIFRA.MA1 11.468 PEF. MA1 250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER * *** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001 CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-l'g99 13:27 PAGE: 10 FILE NUMBER 4 RAW MWD Curves and log header da=a for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... MWD 10420.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10934.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): 15-DEC- 98 5.0 5.0 MEMORY 14501.0 10420.0 14501.0 60 40.2 46.1 TOOL NUMBER CDR 7077 8.500 10463.0 BRINE 8.70 36.0 O. 274 70.0 O. 294 70.0 O. 340 70.0 ( LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: 11 EWR FREQUENCY (HZ): REMARKS: *** RUN 1 GR 10463'-10935'*** *** RUN 2 IMP/ADN 10935'-12228'*** *** RUN 3 IMP/ADN 12228'-13784'*** *** RUN 4 IMP/ADN 13784'-14501'*** RUN 1 - CDR RAN FOR GR MAD PASS DATA COLLECTED IMP/ADN 14250'-14500' DATA FROM DOWNHOLE M~4ORY, VS.0C SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 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 ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 ROP LW1 F/HR 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW1 GAPI 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS ~ Verification Listing Schlumberger Alaska Computing Center 25-JAN-lmm9 13:27 PAGE: 12 DEPT. 10425.000 ROP.LW1 -999.250 GR.LW1 62.024 DEPT. 10934.500 ROP.LW1 14.598 GR.LW1 138.750 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH MWD 10843.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) STOP DEPTH 12228.0 15-DEC-98 5.0 5. OC MEMORY 14501.0 10420.0 14501.0 55 F' LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PA GE: 13 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE IMP RESIST./GR ADN AZIM. DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 40.2 88.5 TOOL NUMBER IMP 012 ADN 023 8.500 10463.0 BOREHOLE CONDITIONS MUD TYPE: BRINE MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 3 6.0 MUD PH: MUD CHLORIDES (PPM) : 46000 FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.274 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 0.294 MUD CAKE AT (MT): O. 340 NEUTRON TOOL MA TR IX: SANDS TONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1 GR 10463'-10935'*** *** RUN 2 IMP/ADN 10935'-12228'*** *** RUN 3 IMP/ADN 12228'-13784 '*** *** RUN 4 IMP/ADN 13784'-14501'*** RUN 1 - CDR RAN FOR GR MAD PASS DATA COLLECTED IMP/ADN 14250'-14500' DATA FROM DOWNHOLE MEMORY, VS.0C SOFTWARE $ LIS FORMAT DATA 70.0 70.0 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 120 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 8 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 ELM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ROP LW2 F/HR 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 TAB LW2 HR 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 TABR LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 TABD LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW2 GAPI 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 PiOH LW2 0H~4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P16H LW2 OHM~ 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P22H LW2 0H~4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P28H LW2 0Pk4~4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P34H LW2 O~ 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 A22H LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 A28H LW2 0~4~4000300 O0 000 O0 0 5 1 1 4 68 0000000000 A34H LW2 OI4~J~ 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH LW2 PU 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ROBB LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ROBU LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ROBL LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ROBR LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 DRHB LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 DRHU LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 DRHL LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 DRHR LW2 G/C3 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 PEB LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 PEU LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Ta~,,¢ Verification Listing Schlumberger Alaska Computing Center 25-JAN-l~m9 13:27 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) PEL LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 PER LW2 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 RPM LW2 RPM 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 DCALLW2 IN 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10842.500 ROP. LW2 1656.264 TAB.LW2 0.000 TABR.LW2 TABD.LW2 0.000 GR.LW2 71.726 PIOH. LW2 0.105 P16H. LW2 P22H. LW2 0.300 P28H. LW2 0.113 P34H.LW2 1000.000 A22H. LW2 A28H. LW2 300.000 A34H.LW2 300.000 TNPH. LW2 55.357 TNRA.LW2 ROBB. LW2 2. 293 ROBU. LW2 2. 277 ROBL. LW2 2. 285 ROBR. LW2 DRHB.LW2 -0. 493 DRHU. LW2 -0.500 DRHL.LW2 -0. 467 DRHR.LW2 PEB.LW2 59.312 PEU. LW2 78.036 PEL.LW2 265.141 PER.LW2 RPM. LW2 142. 000 DCAL. LW2 O. 140 DEPT. 11000. 000 ROP.LW2 48. 778 TAB.LW2 1.283 TABR.LW2 TABD.LW2 7800. 000 GR.LW2 104. 047 PiOH. LW2 18. 929 P16H.LW2 P22H. LW2 15.862 P28H. LW2 15.899 P34H. LW2 16.149 A22H.LW2 A28H. LW2 16.406 A34H. LW2 15.201 TNPH.LW2 27.253 TNRA.LW2 ROBB.LW2 2.553 ROBU. LW2 2.730 ROBL.LW2 2.553 ROBR.LW2 DRHB.LW2 O. 026 DRHU. LW2 O. 095 DRHL.LW2 O. 026 DRHR.LW2 PEB.LW2 3.341 PEU. LW2 3.261 PEL.LW2 3.316 PER.LW2 RPM. LW2 O. 000 DCAL. LW2 O. 008 DEPT. 12000. 000 ROP. LW2 113. 986 TAB. LW2 1. 392 TABR. LW2 TABD.LW2 7647. 750 GR.LW2 24. 483 PiOH.LW2 5.253 P16H.LW2 P22H. LW2 7. 853 P28H. LW2 8. 743 P34H. LW2 9. 572 A22H. LW2 A28H. LW2 9. 834 A34H. LW2 9. 746 TNPH. LW2 21.110 TNRA.LW2 ROBB. LW2 2. 559 ROBU. LW2 2. 559 ROBL. LW2 2. 559 ROBR. LW2 DRHB.LW2 0.277 DRHU. LW2 0.277 DRHL.LW2 0.277 DRHR.LW2 PEB. LW2 2.195 PEU. LW2 2.195 PEL. LW2 2.195 PER. LW2 RPM. LW2 O. 000 DCAL. LW2 O . 000 DEPT. 12228. 000 ROP. LW2 31. 971 TAB. LW2 3. 414 TABR. LW2 TABD.LW2 14227.188 GR.LW2 24.144 PiOH.LW2 4.798 P16H.LW2 P22H. LW2 5.176 P28H. LW2 5.407 P34H. LW2 5.531 A22H. LW2 A28H.LW2 6.663 A34H. LW2 6.751 TNPH. LW2 19.933 TNRA.LW2 ROBB. LW2 2. 509 ROBU. LW2 2. 418 ROBL. LW2 2. 544 ROBR. LW2 DRHB.LW2 0.099 DRHU. LW2 0.188 DRHL.LW2 0.344 DRHR.LW2 PEB.LW2 2. 431 PEU. LW2 1. 708 PEL.LW2 1. 803 PER.LW2 RPM. LW2 55. 875 DCAL. LW2 O. 638 0 000 0 107 1 069 27 187 2 352 -0 467 273 440 4110.000 16.679 17.502 14.223 2.556 0.029 3.324 4752. 406 6. 624 9. 640 11.514 2. 559 0.277 2.195 11940.844 4.944 6.399 10.987 2.446 0.055 2.098 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE~ 16 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001 CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 19I]MBER 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH LOG HEADER DATA DATE LOGGED: SOFTWARE: 12031. SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13783.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE IMP RESIST./GR ADN AZIM. DENS./NEUT. $ 15-DEC-98 5.0 5. OC MEMORY 14501.0 10420.0 14501.0 55 40.2 88.5 TOOL NUMBER IMP 066 ADN 023 LIS (,~Fe Verification Listing Schlumberger Alaska Computing Center 25-JAN-lm99 13:27 PAGE: 17 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 10463.0 BOREHOLE CONDITIONS MUD TYPE: BRINE MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 36.0 MUD PH: MUD CHLORIDES (PPM) : 46000 FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): O. 274 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): O. 294 MUD CAKE AT (MT): O. 340 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN 1GR 10463'-10935'*** *** RUN 2 IMP/ADN 10935'-12228'*** *** RUN 3 IMP/ADN 12228'-13784'*** *** RUN 4 IMP/ADN 13784'-14501'*** RUN 1 - CDR RAN FOR GR MAD PASS DATA COLLECTED IMP/ADN 14250'-14500' DATA FROM DOWNHOLE MEMORY, VS. OC SOFTWARE $ LIS FORMAT DATA 70.0 70.0 70.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 120 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS ~. ~e Verifica.tion Listing Schlumberger Alaska Computing Center 13:27 PAGE: 18 TYPE REPR CODE VALUE .............................. 11 66 8 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 ELD CODE (HEX) O0 000 O0 0 6 1 1 4 68 0000000000 FT 4000300 F/HR 4000300 HR 4000300 4000300 4000300 GAPI 4000300 OH~ 4000300 OH~ 4000300 OH~ 4000300 OH~ 4000300 OH~M 4000300 4000300 OH~ 4000300 OHM~ 4000300 PU 4000300 4000300 G/C3 4000300 G/C3 4000300 G/C3 40003O0 G/C3 400030O G/C3 4OOO3OO G/C3 4000300 G/C3 4000300 G/C3 4000300 4000300 4000300 4000300 4000300 RPM 4000300 IN 4000300 DEPT ROP LW3 TAB LW3 TABR LW3 TABD LW3 GR LW3 P1 OH LW3 P16H LW3 P22H LW3 P28H LW3 P34H LW3 A22H LW3 A28H LW3 A34H LW3 TNPH LW3 TNRA LW3 ROBB LW3 ROBU LW3 ROBL LW3 ROBR LW3 DRHB LW3 DRHU LW3 DRHL LW3 DRHR LW3 PEB LW3 PEU LW3 PEL LW3 PER LW3 RPM LW3 DCAL LW3 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS '~pe Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: 19 DEPT. 12030. 500 ROP. LW3 TABD. LW3 0 . 000 GR. LW3 P22H. LW3 5 . 333 P28H. LW3 A28H. LW3 8 . 433 A34H. LW3 ROBB. LW3 2.404 ROBU. LW3 DRHB.LW3 O. 132 DRHU. LW3 PEB.LW3 2. 768 PEU. LW3 RPM. LW3 0 . 000 DCAL. LW3 DEPT. 13000. 000 ROP. LW3 TABD . LW3 9280.000 GR. LW3 P22H. LW3 7. 956 P28H. LW3 A28H. LW3 8 . 365 A34H. LW3 ROBB. LW3 2.636 ROBU. LW3 DRHB. LW3 0.133 DRHU. LW3 PEB. LW3 2 . 895 PEU. LW3 RPM. LW3 68 . 000 DCAL. LW3 DEPT. 13783.500 ROP. LW3 TABD. LW3 222 64.344 GR. LW3 P22H. LW3 6.472 P28H. LW3 A28H. LW3 6. 644 A34H. LW3 ROBB. LW3 2.544 ROBU. LW3 DRHB . LW3 0.130 DRHU. LW3 PEB . LW3 2.271 PEU. LW3 RPM. LW3 0 . 000 DCAL. LW3 2220. 208 TAB. LW3 15 . 693 P1 OH. LW3 5. 973 P34H. LW3 8. 641 TNPH. LW3 2. 404 ROBL. LW3 0.132 DRHL.LW3 2. 768 PEL.LW3 0.000 56. 424 TAB. LW3 75. 414 PiOH. LW3 7. 894 P34H. LW3 8.178 TNPH. LW3 2 . 646 ROBL. LW3 0. 224 DRHL. LW3 2.112 PEL.LW3 0.318 29. 413 TAB. LW3 28. 983 P1 OH. LW3 6.365 P34H. LW3 6.540 TNPH. LW3 2.544 ROBL. LW3 O . 130 DRHL . LW3 2.271 PEL.LW3 0.000 0. 000 TABR. LW3 3. 692 P16H. LW3 6. 520 A22H. LW3 21.191 TNRA. LW3 2. 404 ROBR.LW3 0.132 DRHR.LW3 2. 768 PER. LW3 1 225 TABR. LW3 7 469 P16H. LW3 7 751 A22H.LW3 21 918 TNRA. LW3 2 674 ROBR.LW3 0 254 DRHR.LW3 2 371 PER.LW3 5 244 TABR.LW3 6 834 P16H. LW3 6 232 A22H. LW3 16 045 TNRA.LW3 2 544 ROBR.LW3 0 130 DRHR.LW3 2 271 PER.LW3 0.000 4.514 7.924 11.843 2.404 0.132 2.768 4040.000 7.800 8.333 12.190 2.647 0.097 2.754 18550.281 6.600 6.519 9.364 2.544 0.130 2.271 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: 2O FILE NUMBER 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUF~W~%RY VENDOR TOOL CODE START DEPTH MWD 12031.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH .......... 13783.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE IMP RESIST./GR ADN AZIM. DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 15-DEC-98 5.0 5. OC MEMORY 14501.0 10420.0 14501.0 55 40.2 88.5 TOOL NUMBER IMP 066 ADN 023 8.500 10463.0 BRINE 8.70 36.0 46000 O. 274 70.0 O. 294 70.0 O. 340 70.0 SANDSTONE 2.65 LIS T~pe Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: 21 TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REFL~RKS: *** RUN1GR 10463'-10935'*** *** RUN2 IMP/ADN 10935'-12228'*** *** RUN 3 IMP/ADN 12228'-13784'*** *** RUN 4 IMP/ADN 13784'-14501'*** RUN 1 - CDR RAN FOR GR MAD PASS DATA COLLECTED IMP/ADN 14250'-14500' DATA FROM DOWNHOLE MEMORY, VS.0C SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 120 4 66 255 5 66 6 73 7 65 8 68 9 65 FT 11 66 8 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 ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 ROP5 MA4 F/HR 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 TAB MA4 HR 4000300 O0 000 O0 0 7 1 1 4 68 '0000000000 TABRMA4 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 TABD MA4 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 GR MA4 GAPI 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 PiOHMA4 OH~ 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 P16HMA4 OH~ 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 P22HMA4 OH~ 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 LIS ~'ape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) ....................................................................................... P28HMA4 0H~4000300 P34HMA4 A22HMA4 4000300 A28HMA4 OH~4 4000300 A34HMA4 OH~4 4000300 TNPHMA4 PU 4000300 TNRA MA4 4000300 ROBB MA4 G/C3 4000300 ROBUMA4 G/C3 4000300 ROBLMA4 G/C3 4000300 ROBR MA4 G/C3 4000300 DRHB MA4 G/C3 4000300 DRHUMA4 G/C3 4000300 DRHL MA4 G/C3 4000300 DRHR MA4 G/C3 4000300 PEB MA4 4000300 PEU MA4 4000300 PEL MA4 4000300 PER MA4 4000300 RPM MA4 RPM 4000300 DCAL MA4 IN 4000300 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 .000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT, 14249,500 TABD,MA4 0,000 P22H,MA4 4,224 A28H,MA4 4,246 ROBB,MA4 2,548 DRHB,MA4 0,035 PEB,MA4 3,418 RPM, MA4 0,000 DEPT, 14499,500 TABD,MA4 5120,000 P22H,MA4 1,515 A28H,MA4 1,633 ROBE.MA4 2,521 DRHB,MA4 0.160 PEB.MA4 2,825 RPM, MA4 41,000 ROPS,MA4 83,342 TAB,MA4 0,000 TABR,MA4 GR,MA4 32,694 PiOH,MA4 3,720 P16H,MA4 P28H,MA4 4,275 P34H,MA4 4,241 A22H.MA4 A34H,MA4 4,040 TNPH,MA4 20,449 TNRA,MA4 ROBU, MA4 2,548 ROBL,MA4 2.548 ROBR.MA4 DRHU,MA4 0,035 DRHL,MA4 0,035 DRHR,MA4 PEU, MA4 3.418 PEL,MA4 3,418 PER,MA4 DCAL,MA4 0.000 ROPS,MA4 123.270 TAB.MA4 0,975 TABR,MA4 GR,MA4 16.129 PiOH,MA4 1,412 P16H,MA4 P28H,MA4 1,534 P34H,MA4 1,517 A22H,MA4 A34H,MA4 1,601 TNPH,MA4 25,149 TNRA,MA4 ROBU,MA4 2,483 ROBL,MA4 2,487 ROBR,MA4 DRHU. MA4 0,217 DRHL,MA4 0,184 DRHR,MA4 PEU, MA4 2,066 PEL,MA4 2,507 PER.MA4 DCAL,MA4 0,156 0,000 4,014 4,327 11,489 2,548 0,035 3.418 2420, 000 1,463 1,617 13,717 2,581 0,233 2,900 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 13:27 PAGE: 23 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/01/21 ORIGIN : FLIC TAPE NAME : 99022 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : B.P. EXPLORATION, PRUDHOE BAY W-19A, API #50-029-22006-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/21 ORIGIN : FLIC REEL NAME : 99022 CONTINUATION # : PREVIOUS REEL CO~I~ENT : B.P. EXPLORATION, PRUDHOE BAY W-19A, API #50-029-22006-01