Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
198-252
• • eei N Regg, James B (DOA) ( g6 �z6 9J� � ) From: Regg, James B (DOA) to Sent: Wednesday, October 03, 2012 10:33 AM � 3f i v To: Bulloch, Kenneth S; DOA AOGCC Prudhoe Bay Cc: Seymour, Len I; Schwartz, Guy L (DOA) Subject: RE: Red Dog #1 and Put River 33 -12 -13 Red Do #1 (PTD 1982520 Dog ( 1982520) Put River 33 -12 -13 PTD 1691040 ( 1691040) Postponing site visits and remediation at Red Dog #1 and Put River 33 -12 -13 until 2013 is acceptable. As noted by Mr. Grimaldi, AOGCC location inspection will be scheduled when remediation is completed Jim Regg AOGCC SCANNED APR 0 8 2013 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Bulloch, Kenneth S [mailto:BullocKSPBP.com] Sent: Wednesday, October 03, 2012 4:49 AM To: Grimaldi, Louis R (DOA) Cc: Seymour, Len I; Regg, James B (DOA) Subject: RE: Red Dog #1 and Put River 33 -12 -13 Thanks Lou, we will plan on postponing the site visits until 2013 unless we hear otherwise. Regards, Ken From: Grimaldi, Louis R (DOA) [mailto: lou.grimaldiOalaska.gov] Sent: Tuesday, October 02, 2012 4:48 PM To: Bulloch, Kenneth S Cc: Seymour, Len I; Regg, James B (DOA) Subject: Re: Red Dog #1 and Put River 33 -12 -13 Ken, I have Cc,d my supervisor Jim Regg on this inspection. I am not aware of specified timing. Lou From: Bulloch, Kenneth S [mailto: BullocKS@BP.com] Sent: Tuesday, October 02, 2012 04:39 PM To: Grimaldi, Louis R (DOA) Cc: Seymour, Len I <Len.Seymour@abp.com> Subject: RE: Red Dog #1 and Put River 33 -12 -13 Mr. Grimaldi, 1 • I am following up on the topic of the site visits for Red Dog #1 and Put River 33 -12 -13 yourself and Len Seymour had discussed September 22 If this is something that needs to be done this year I feel I had better start trying to making arrangements as soon as possible. Please advise, Ken Bulloch WSL, Special Project Office: 907 - 659 -5580 Cell: 907 - 602 -8149 Harmony: # 2382 Alternate: Len Seymour From: Grimaldi, Louis R (DOA) [ mailto: lou.grimaldaalaska.gov] Sent: Saturday, September 22, 2012 6:42 PM To: Seymour, Len I Cc: Regg, James B (DOA) Subject: RE: Red Dog #1 and Put River 33 -12 -13 Mr. Seymour, I appreciate the update on the remediation work on Red Dog #1 and Put River 33- 12 -13. My preferences can't interfere with or dictate changes to work schedules that have been agreed to or are conditional for permits. Permission for continuation of this work or final site clearance (A.O.G.C.C.) until next summer is not a call I can make from my position. I have Cc'd my supervisor, Jim Regg, on this e-mail. Thank you for the notice, Lou Grimaldi From: Seymour, Len I [mailto: Len.Seymour(abD.com] Sent: Saturday, September 22, 2012 3:17 PM To: DOA AOGCC Prudhoe Bay Cc: AK, D &C Well Services Operations Team Lead; AK, D &C Wells Special Projects; Bill, Michael L (ASRC); AK, D &C Well Integrity Coordinator; Worthington, Aras J Subject: Red Dog #1 and Put River 33 -12 -13 Mr. Grimaldi, this email is to let you know that the Remediation personnel called me today and let me know that they won't be flying out to Red Dog again until next summer for remediation work (still having some helicopter issues). Given our phone conversation two days ago in which you indicated a preference to visit the site after the remediation is completed, I'm assuming that it will be okay for us to not complete the final site clearance visit until next summer after remediation work is completed. Please get back with me to confirm that this acceptable. Len Seymour GWO- Well site leader Office 907 - 659 -5580 Cell 907 - 602 -8149 Harmony - 2382 Alternate — Ken Bulloch 2 • ( ' T 1 qt& 2 , , fo Regg, James B (DOA) From: Seymour, Len I [Len.Seymour @bp.com] Sent: Tuesday, September 18, 2012 4:45 PM To: DOA AOGCC Prudhoe Bay 1CeK 7 11 q(lv Cc: AK, D &C Wells Special Projects Subject: Red Dog post P &A site picture Attachments: IMGP0577.JPG AOGCC inspectors, enclosed is a photo of the Red Dog site taken about 1 month ago. The remediation folks are planning to head out there this Friday, to redistribute some of the fill into the area containing water. We are planning to go out with them in the helicopter. I will plan on calling you tomo night to see if you would like to go, or if there are further pictures you would like for me to obtain when we go out there. Seymour Len Se GWO- Well site leader Office 907 - 659 -5580 SUNNED Cell 907 - 602 -8149 SUNNED tA.A 0 7 ZU 1;3 Harmony - 2382 Alternate — Ken Bulloch II Red Dog #1 PTD 1982520 9/18/2012 Photo courtes of BPXA • .......... ,.......„.. --:, ,,,_„,„,„,,,,„„,„... _ , ... ,....._ ....„. ....,.... -„,,,, . . .. 410, . . _ _ . ,, _,.. . ... ..•_ ... ...,.....,4- . , . . . . ,., ..;....,,,,k. . ., _ ..... ,... . _. .. _.,. .. .. •,,,„. . . ..„... • . .... . . ._ .„,. .,.. . • ., .. .... . . •.- . .. - may. - � -y'� ° A ,y. • f 5 III STATE OF ALASKA ill ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 ❑ Development ® Exploratory ' ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero - ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 5/2/2012 198 - 252 • 311 - 331 3. Address: 6. Date Spudded: 13. API ■ so ber: 5'0-- 084 -2,o0 17 -orr -ce • • P.O. Box 196612, Anchorage, Alaska 99519 - 6612 1/25/1999 50-- - 20027 - 00 - 00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 3/26/1999 REDDOG -01 1683' FSL, 4507' FEL, Sec. 34, T10N, R21 E, UM 8. KB (ft above MSL): 43.95' 15. Field / Pool(s): Top of Productive Horizon: P rudhoe Ba Fiel dbfined Pt. 2825' FSL, 1443' FEL, Sec. 21, T10N, R21 E, UM GL (ft above MSL): 10.5' Y Total Depth: 9. Plug Back Depth (MD +TVD): Thom ooI / z - 4010' FSL, 1859' FEL, Sec. 21, T10N, R21 E, UM Surface Surface � �' ,1 fr 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: - Surface: x - 401725 y- 5914227 Zone ASP3 ' 19400' 12379' • ADL 390827 & 390826 TPI: x - 399639 y 5925957 Zone ASP3 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 399236 Y 5927148 Zone ASP3 None 18. Directional Survey: 0 Yes 181 No ' 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, GR, RES, Sonic, Gyro, GST, CDR, PWD, I- Sonic, ADN, RAB, FMI, DSI, NGT, RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, N/A CMR. AIT 23. CASING, LINER AND CEMENTING RECORD • SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM ToP I BOTTOM _ SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 110' Surface 110' 30" -260 sx Arctic Set 13 -3/8" 68# L -80 Surface 5302' Surface 4447' 16" 547 sx PF E, 538 sx Class 'G', 1800 sx PF E, 200 sx PF C 9 -5/8" 53.5# / 47# P -110 Surface 15850' Surface 9700' 12-1/4" 830 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 15723' 4 Abandonment Plugs w/ 342 Bbls Class 'G' MAY 2 4 2012 15687' Set EZSV with 7 Bbls Class 'G' above (100') �+ 30' - 2076' 160 Bbls of Arcticset I AOGCC Surface 3.5 Bbls of Cement. 1.9 gals Cement 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None JUL 2 5 alt RBDMS MAY 2 5 '2012 G At Form 10-407 Revised 12/2009 � 11 19 O N TINUED ON REVERSE i r a Original OpQ ,i) 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top of Canning 14035' 8821' None Top of Middle Brookian Sands 16843' 10191' Base of Middle Brookian Sands 18420' 11466' Top of Hue / Shale Wall 19295' 12277' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Work, Well Schematic Diagram, Picture of Welded ID Plate on Casing 32. I hereby certify that the • • : • oin i - d rrect to the best of my knowledge. ,, Signed: Joe Lastufka Title: Drilling Technologist Date: 5 J I%- �('I IZ REDDOG -01 198 -252 311 -331 Prepared By Name/Number Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Aras Worthington, 564 -4102 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only • REDD OG -01 Well History Date Summary 03/21/12 T /I /0 = TWCNAC /0 Set up pressure testing equipment to test gates. Tubing hanger in well just had one joint of tubing below it and is open to IA valve. Tested gates on master valve and swab valve individually to 500 psi. Both tests were good. Bled off pressure from tests. Rigged up lubricator with retrieving tool attached. Pressure tested tree with lubricator attached to 250/5000 psi. Both tests were good. Ran in hole with retrieving tool and tagged at 100 ". Maintained open bleed on IA to ensure on pressure while pulling TWC. Pulled TWC out of hole. Final WHP = 0/0/0. Closed all valves on dry hole tree. Pressure tested cap to 2500 psi. Good test. 03/21/12 T /I /0 = TWCNAC /0 Cycled all valve on dry hole tree, IA, and OA. Rigged up test pump to test barriers. Tested swab valve and master valve individually to 500 psi. Both tests were good. Rigged up lubricator with retrieving tool for 4" CIW TWC. Tested dry hole tree against TWC to 250/5000 psi. Good tests. Bled off pressure. Ran in hole with retrieving tool and retrieved 4" CIW TWC. Tagged at 100" Cycled and closed all valves. Tested tree cap against swab valve to 2500 psi. Good test. 03/23/12 T /1 /0= 0/0/0, Temp =SI. PPPOT-IC (PASS), P &A. PPPOT -IC: Stung into test port (0 psi). Pumped through void, good returns. Pressured void to 4000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS (ET style) all moved freely (1 "). Backed off all LDS on Tubing hanger, all moved freely (3/4 "). 03/23/12 T /I /0= 0/0/0. Temp= SI. MIT -T to 3500 psi- PASSED (Pre -Plug & Abandon). IA cemented & open to tubing. Used 60 gals diesel to increased TP from 0 psi to 3500 psi in 10 minutes. Tubing lost 97 psi in 15 minutes and 30 psi in 2nd 15 minutes, for a total loss of 127 psi in 30 minute test. Bled back TP to 0 psi. Monitored for 30 minutes during rig -down, WHPs unchanged. Final WHPs= 0/0/0. Job completed.SV,MV,IA,OA = closed. 03/24/12 RAN 3.80 CENT, 4 -1/2" TEL, 3.00" S- BAILER, TAGGED CEMENT AT 160' SLM. (SLM "0" @ TUBING HANGER). WORKED TOOLS TO 161' SLM, LOCATED TT AT 44' SLM. RAN 3.80" CENT, 5' x 3.00" DD- BAILER, SD AT 162' SLM, WORKED TO 163' SLM (recovered -1/2 cup cement). 03/25/12 T /I /0 = 0/0/0. Temp = SI. Circ fluid out of tubing with N2 (Plug & Abandon). IA cemented & open to tubing. Used N2 to increase IAP from 0 psi to 500 psi. Flow N2 from IA to circ out fluid through tubing to bleed trailer ( -2.25 bbls of fluid for returns). Bled T & IA to 0 psi. Monitored for 30 minutes during rig - down. T & IA FL's @ 40'. WHPs unchanged. Final WHPs = 0/0/0. Job completed. SV,MV,IA,OA = closed. NPEOVP. 1530. 03/26/12 T /I /0 = 0/0/200 Pulled 4 1/16" 10k dry hole tree and adaptor . Removed SBMS from tbhgr and Installed 4 1/2" NSCT x 4 1/2" IF crossover with picking eye to remove tubing hanger with 42' joint of tubing. Installed a new 4 1/16" 10k tree assembly with a Baker C actuator. torqued studs to 726 ftlbs (coated) 953 ftlbs (non- coated). PT tree and tubing void to low PT of 260 psi (PASS) high PT of 7132 psi (PASS). relieved pressure through IA valve to bleed tank. 03/27/12 Swap PCE to 10K. Swap pipe to 2 3/8" in preparation for REDDOG -01 P &A job. 03/28/12 Continue swapping unit to 10K PCE. Finished swapping pipe to 2 3/8" in preparation for REDDOG -1 P &A job. 03/29/12 CTU #9 Conversion to 10K equipment and 2.375" Coil Continue conversion on 3/30/2012 Page 1 of 3 • • REDDOG -01, Well History Date Summary 03/30/12 CTU #9 Conversion to 2.375" Coil and 10K equipment 04/05/12 Baker machine charges for machining shearout nozzle. 04/06/12 CTU #9 w/ 2.375 "CT. Job Scope: P &A Stage 1 - Under -ream and Mill Prep CTU #9 for CAT2 and 10k equipment. Perform successful shear test of 2.875" CT w/ upper shear' rams w/ boosters (1250 psi). Perform weekly BOP test on upper set of 10K BOPs. 04/07/12 CTU #9 w / 2.375" ct: MI RU CTU / Warm up well & underream «< continue WSR from 4/6/12 »> Function test BOP'S and push pull test 20k over & 20k down. Perform draw down test on BOP'S. 04/07/12 Assist Coil with Heatiing Fluids (Plug & Abandonment) Heat 60/40 meth transport to 65* F. In progress. 04/08/12 Assist Coil with Heating Fluids (Plug & Abandonment) Continued heating 60/40 meth transport to 65* F. Heat Geovis 150 *F and load upright. CTU #9 w/ 2.375 "CT. Job Scope: P &A Stage 1 - Under -ream and Mill. RIH w/ 3.70" nozzle to top of cement at 178'CTM. Circulate 45 bbls of 65 *F 60/40 followed by 258 bbls of 150 *F 2% Slick KCI to warm up well. FP CT and well w/ 65 bbls of 60 *F 60/40. POOH. RIH w/ 3.75" Cheveron Cement Mill, Haley Under - Reamer (3 stage: bottom 6.81", mid 7.92 ", top 8.30 "), 3.38" Motor, Hyd Cent (8.60" open). Tag TD at 177'CTM. PU to 173'CTM and come online to disp coil to Provis Gel (75K LSRV). Come online w/ MI re -circ system to clean mud. Establish full under - reamer blade engagement. Under -ream from 173'- 194'CTM performing frequent back - reaming trips (ROP -.15 fpm). Wait on re -circ system repair. Re -circ online. 04/09/12 Assist Coil Heat Uprights (Plug and Abandonment) Heat upright of Geovis to 140* F. CTU #9 w/ 2.375 "CT. Job Scope: P &A Stage 1 - Under -ream and Mill «< Continued WSR from 04/08/12 »> Continue under - reaming at 213'CTM to top of EZSV at 270.5'CTM while re- circulating gel system through MI and making frequent hole cleaning trips. Stall 3 times at 270.5'CTM under - reaming at min speed. Hard cement on top of plug. Pump bottoms up w/ gel, KCI spacer, and FP CT and well w/ 60/40. POOH to drop UR and PU mill. Under - reamer blades in good condition and indicate wear on cutting structure at appropriate stage lengths. Back of centralizer blades show wear from centralization in casing. Mill has 1 chip at the 3" diameter position of one of the blades which appears to be from metal further indicating the stalls were from sitting down on the EZSV. MI cuttings bin has -5 bbls of fine cement solids out of total -6.8 bbls milled. Re -circ rate -2.25 bpm. RIH w/ 2.4" Conical Opticut Mill (missle shape), 2.13" Motor, and 3.5" Hyd Cent (8.60" open). Tag TD at 273'CTM. Takes 1.0 bbls to pressure up CT and backside to 1650 psi. Begin time milling center punch hole through 9 -5/8" EZSV plug. Equalize plug at 273.9'CTM and 04/10/12 CTU #9 w/ 2.375 "CT. Job Scope: P &A Stage 1 - Under -ream and Mill . Travel to SLB yard to swap pipe from 2.375" to 1.75" ct . For stage two of the job. 04/11/12 CTU #9 w/ 2.375 "CT. Job Scope: P &A Stage 1 - Under -ream and Mill. SLB yard swap pipe from 2.375" to 1.75" ct . For stage two of the job Wittined BOP test on both sets of BOP'S. 04/12/12 CTU #9 w/ 2.375 "CT. Job Scope: P &A Stage 2 - Clean out and P &A «< Continued WSR from 04/11/12 »> MIRU / Function test BOP'S / HPT to 8600 psi. RIH w / cement BHA 1.80 SJN Tamed @ 2076' CTM. Contacted town engineer who contacted the AOGCC and it is OK to cement from 2076'. Perform MIT to 3027 psi start pressure final pressure after 30 mins 2897 psi. Passed AOGCC requirements for MIT as per John Crisp. Wait on cementers. Page 2 of 3 + • • REDDOG -01, Well History Date Summary 04/13/12 CTU #9 w/ 1.75" OD CT. Objective: P &A. Continued from WSR 04/12/12. Shear nozzle. Circulate wellbore to 2% KCL. Pump 20 bbl fresh water spear. Laid in 160 bbls of #15.8 arcticset 1 cement from 2076' to surface. RDMO. 04/14/12 CTU #9 w/ 1.75" OD CT. Road to shop. Standby for BOPE to be removed from Red Dog 01, place BOPE on unit. 04/16/12 0 /0. Tag TOC and PT to 3000 psi. Pressure tested 34' of void to 3000 psi. PASSED Pressure decreased 167 psi in 1st 15 min and 72 psi in 2nd 15 min. R/D. 04/17/12 Held PJSM T /I /O = 0 /0 /0 This well is in process of P &A. Cycled all valves to ensure 0 psi on well. Opened needle valve at top of tree to ensure 0 psi. Drained all fluids from tree. Removed upper tree and placed tree cap on top of master valve. Torqued nuts on tree cap to spec. No test needed because of numerous cement plugs in hole. Turned well over to WSL. 04/23/12 Rigged up Goliath Guillotine Pipe Saw to casing. Covered saw with vesgueen liner with a heater trunk place underneath to keep warm. 04/28/12 Plug and Abandon. MIRU to cut tree. Held PJSM. Rigged up crane, opened valves to atmosphere and monitored. No pressure, started cut. Cut through 20 ", 13 3/8 ", and 9 5/8" casing in approximately 1.5 hour cutting time. Cement in 9 5/8" casing was at 29' 10 ". Cement at surface between 9 5/8" and 13 3/8" casings. Cement was at 6' between 13/38" and 20" casings. Rigged down all equipment. 04/30/12 Pumped 3.5 bbls of cement down the 9 5/8" and 20" to have cement to surface. 05/01/12 Filled remaining void in 13 3/8 x 20 casing with -1.3 gals of cement. Filled remaining void in 9 5/8 casing with -0.6 gals of cement. DNR on location to take pictures. 05/02/12 Weld ID plate on casing, AOGCC witnessed (John Crisp),GBR made 3 weld passed. Turned over to roads and Pads to back fill and plant tundra. Page 3 of 3 rt 4 t." ,..„. „ ...t. - ..,!. . , .44 , I - : . . . ...„. , .. ..7 *7 NW ---:-.-..4-,, - „., .,.......,,. . . . ... .., ..,.. . , . , . ,,.... ,.. . .... . ,.. -, . . ... „ .. ..,,,,,,..n. ;., --t, .!t;:i:'•.!iii...i,..r,- ''', ,.., .... 4 .1.t......... „ . ..-...„ - ‘--..- ...., ., ..... ...., ..., -- - ... ., . . , ,, .... ... .. .. .... „,.. .......„ , .... ... „.... • Red Dog #1 1 Permit No. 198 -252 API No. 50- 029 - 20027 -00 -00 Final P&A Status Tundra Surface 4 f '� ♦�'►'♦♦ �''�'►'+' ♦'� d� 2 0" 91.5# H -40, BTC 80 M D (80' 80 TV D ►qti. 9 �� add @ ' ( ) Arcticset 1 15.8 ppg Cement in ti.; ti ti 9 -5/8" casing from 4t. '.;. ►; +b •� 'y'y ♦iii 2076' MD to surface .. p Water in 9 -5/8" casing from 3050' • :;.y MD to 2076' MD O9'i ►i +i +i♦ O�♦i ♦i ►iO'i ♦i'Oi►i'p+� Oi3��d�+O ��yy..;. ;�;� + ►0;:; 13 -3/8" 68# L -80, BTC @ 5302' MD (4447' TVD) 13.6 ppg KCI Drilling Mud in 9 -5/8" • casing from 3050' MD to 15,587' MD Estimated Top of Cement Behind the 9 -5/8" casing @ 13,500' MD ► ♦ ♦.; , ♦� Cement Plug #2 'a ♦'a;'►; y�.�►; 15,587' MD — 15,687' MD Shallowest hydrocarbon potential © • 14,050' MD �'�'� ''''�'♦ 9 -5/8" EZSV @ 15,687' MD ;dd 9 -5/8" 47# P -110, SLHC © 15,850' MD (9699' TVD) Cement Plug #1 -11P- 15.8 Possible Oil & Gas Bearing 15,723' MD to 19,292' MD Premium I Zones from 14,050' MD to Arctic Set 1 Cement i Cement i 19,250' MD Water 8 -'h" Openhole TD © 19,400' MD (12,371' TVD) 13.6 ppg Drilling Mud 15.8 ppg Premium Cement Cement in Place Prior to Abandonment • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ' �� 4 IZ -5 '1 z/ DATE: May 02, 2012 P. I. Supervisor FROM: John Crisp SUBJECT: Surface P &A Report Petroleum Inspector Red Dog #1 BPXA PTD 1982520 May 02, 2012: I traveled to BP Exploration (Alaska), Inc. Red Dog #1 to witness final plug & abandonment work (Sundry 311 -331). Casing strings were cut off approximately 5' below tundra level as documented by Bell & Associates Survey Company. Hard cement to surface in all casing strings. Marker plate welded to outermost casing string. - Summary: I witnessed successful final Plug & Abandonment on BPXA Red Dog #1 that meets regulation 20 AAC 25.120 (a) (b) & 20 AAC 25.170 (a) (1) Attachments: 5 Photos Non- Confidential *Al JUN Final P &A BPX Red Dog #1 05 -02 -12 Page 1 of 4 • • Surface Abandonment - Red Dog #1 (BPXA) PTD 1982520 Photos by AOGCC Inspector J. Crisp May 2, 2012 {� • ` yam • � A } J. 4 • � y ¥ .4„ + l y n y �� 1 j d' • .Y. - 4 Excavation and casing cut -off; cement to surface . f _ •t i 1 , . 0 c********) i i 1 i j A # i Y1 1 RWMwy, dMY� [ yY1F - , • t {f Final P &A BPX Red Dog #1 05 -02 -12 Page 2 of 4 • • • il' i r � 6 i Well head ij l . , C? Marker plate iie , ''' V in ..1 `..:. ` *10 Final P &A BPX Red Dog #1 05 -02 -12 Page 3 of 4 • • I - a. P .. 4 _ r - .. * .• t. ~ ".+' III, • r t , III ' fi n t: 4 k Installing marker plate Final P &A BPX Red Dog #1 05 -02 -12 Page 4 of 4 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: April 12, 2012 P. I. Supervisor FROM: John Crisp, SUBJECT: P&A Report Red Dog #1 Petroleum Inspector BPX - Sundry # 311 -331 PTD 198 -252 April 12, 2012: I traveled to BP Exploration (Alaska), Inc. Red Dog #1 to witness TD achieved with 1 3 /" tubing with 1.8" wash down nozzle. Coil tubing was in the hole waiting for instructions for what was required & witnessed by AOGCC prior to cementing this well from 2076' to surface. I requested a circulation rate of 1.6 bpm which had surface pressure of 3500 psi. Schlumberger proceeded with BPX Rep's Larry lmm's guidance to find up weight & neutral weight & down weight with coil. They proceeded to RIH & tag hard obstruction at 2076'. I requested that they tag once again to verify that the obstruction was solid & would not move. After second tag, with 8K weight on nozzle & with circulation rate of 1.6 bpm the BP Rep & I witnessed 60-40 methanol returns at the open top tank. This 60 -40 methanol was used for first circulation to keep coil from freezing. Seawater with 2% KCL will be used as circulation fluid for the entire welibore prior to cementing to surface. This will insure no freeze protect in well bore prior to cementing. I witnessed the annulus return line closed a d t the choke manifold & 3027 psi pressured thru coil to the choke manifold that will PT the well bore from 2076' to surface. 15 minutes after test pressure was applied I witness pressure beginning to stabilize @ 2931 psi. After 30 minutes the test pressure stabilized @ 2902 psi. Request was made to BPX Larry Imm to again tag obstruction @ 2076' to verify there was no movement of obstruction after the pressure test. Obstruction was again found @ 2076' with 8K weight on nozzle. Summary: I witnessed a tag of hard obstruction at 2076' on BPX Red Dog #1. Circulation was established & I witnessed there was no diesel freeze protect in the well bore. 3000 psi PT that stabilized at 2092 psi after 30 minutes was witnessed. AOGCC requirements have been met to allow cementing of this well from 2076' to surface. 5cANNED APR 1 2012 P &A BPX Red Dog #1 04 -12 -2012 ' r � • Page l of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 12, 2012 2:19 PM To: 'Worthington, Aras J' Cc: DOA AOGCC Prudhoe Bay Subject: RE: Red Dog P & A ( PTD 198 -252) Aras, The updated information makes sense now. By circulating from 2076' the diesel will be removed from wellbore as required and there is no reason to try to go deep and cleanout mud in the wellbore. Have you tested the casing since drilling through the plug? A pressure test of casing 9 9 9 p 9 P 9 should be done before laying in the cement to surface. Based on the new evidence you have approval to lay in cement from 2076' and to surface. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Thursday, April 12, 2012 2:07 PM To: Schwartz, Guy L (DOA) Subject: RE: Red Dog P & A ( PTD 198 -252) Guy, I need to correct/clarify the diesel freeze protection depth on Red Dog. Allow me to explain: The rig had originally circulated diesel into the well with the DP parked at 3,050' MD. However the rig pumped 135 bbls of diesel down the 9 -5/8" x DP annulus then allowed the diesel to u -tube and balance at surface before POOH. In the 53.5 # /ft 9 -5/8 casing with a 8.535" ID and (0.0708 bpf) 135 bbls of diesel equates to -1900' of diesel with the DP OOH. Although it is true that the rig "circulated diesel with the DP @ 3,050' MD" the volume the rig actually pumped was only 135 bbls which accordingly we had mis- labeled on our our schematic of the wellbore. So at this point we can safely say we've removed the 135 bbls of diesel from the wellbore and are most likely tagging up on ice or settled drilling mud. Again, given this clarified information we would like to pursue laying in cement from 2,076' MD without making further attempts to clean -out deeper in the wellbore. Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Worthington, Aras 3 Sent: Thursday, April 12, 2012 1:01 PM To: Schwartz, Guy L (DOA) Subject: RE: Red Dog P & A ( PTD 198 -252) Guy, 4/12/2012 Page 2 of 2 We have milled through the bridge plug @ 286' MD and are currently in the hole with 1 -3/4" CT and a nozzle as planned. We have tagged up at 2,076' MD (a hard tag). Our records indicated diesel down to 3,050' MD. If we circulate water through the nozzle at this depth we'll certainly swap out and circulate out any free diesel below us if it exists. Accordingly we propose that we circulate water at this depth and then start cementing from this depth leaving a solid cement plug laid in from 2,076' MD to surface. Please advise if this is acceptable to the AOGCC. Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 4/12/2012 • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, January 30, 2012 10:29 AM To: 'Worthington, Aras J' Subject: RE: Red Dog P & A ( PTD 198 -252) Aras, The proposed changes to the approved sundry (311 -331) are acceptable as we discussed. I will update the file with the new procedure and forward a copy to the slope inspectors. Regards, Guy Schwartz �� Senior Petroleum Engineers FEES AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Thursday, January 19, 2012 5:30 PM To: Schwartz, Guy L (DOA) Subject: RE: Red Dog P & A ( PTD 198 -252) Guy, As requested, here is a revised procedure for Red Dog #1 with the changes requested below included. Thanks, Aras Worthington Well Interventions Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 - 7692 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, January 19, 2012 10:11 AM To: Worthington, Aras 3; Cismoski, Doug A Cc: Foerster, Catherine P (DOA) Subject: Red Dog P & A ( PTD 198 -252) Doug /Aras, After further consideration on the procedure to P &A Red Dog #1 and especially regarding perforating the 9 5/8" casing followed by squeezing cement into the 13 3/8 x 9 5/8 "annulus. The Commission sees this as unnecessary risk that need not be undertaken. If BP removes the diesel in the well and fills the 9 5/8" casing with cement to surface they meet all regulations for P & A of the well. Perforating the casing and squeezing goes beyond our required regulations and should not be done. The approved sundry ,JoT - ' (311 -331) step # 7( perfing 9 5/8" ) should be deleted from the procedure as well as the reference to squeezing cement into the 9 5/8" x 13/3/8" annulus in Step #8. Commissioner Foerster was consulted and agrees with this decision. Please respond in writing to this change and send me an amended procedure as soon as possible for our well file. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) • 1/30/2012 • • P(° Summary of Proposed Work I, 30 - BP Exploration Alaska Inc (BPXA) p P &AProgram 7 Red Do g #1 PTD 198 -252 API No. 60- 089 -20027 Present Well Condition The well was drilled to a depth of 19,400' MD, and is cased as follows: Casing Size Weight Grade Depth (MD) Cementing Record Conductor 20" 91.5# H -40 80' 355 sks of 15.6# Permafrost C Surface 13 -3/8" 68# L -80 5302' 1 stage lead: 547 sks, 12# Permafrost E. Tail: 538 sks, 15.8 class G 2 stage lead: 1800 sks, 12# Permafrost E. Tail: 200 sks, 15.6# Permafrost C Intermediate 9 -5/8" 47# P -110 15,850' 170 bbls of 15.8# Premium Cement Maximum Anticipated Surface Pressure (MASP) is 0 psi (all openhole and casing shoe is cemented and plugged providing hydraulic isolation) per 20 AAC 25.036 (c.) Note: Regardless of 0 psi MASP, BP will proceed with this P&A operation as if formation pressure could have leaked through the cemented shoe and the CIBP with cement on top — therefore taking the most conservative approach to this P &A intervention. This "worst case" scenario yields a MASP of 7100 psi therefore the CT BOP stack will be constructed and tested to provide that pressure tolerance until hydraulic isolation from the reservoir can be re- verified by pressure test of those barriers. The final operation to plug and abandon the well is scheduled to be performed approximately April 2012 during the ice road season. With approval to complete the P &A from the AOGCC, it is desired that the sundry be approved until June 1, 2012. In April 1999, the well was suspended with the following cement in the wellbore: 1 5,723' — 19,292' Set cement plug across open hole oil and gas bearing zones. 15,587' — 15,687' Set cement plug on top of EZSV plug in 9 -5/8" casing. 186' — 286' Set cement plug on top of EZSV plug in 9 -5/8" casing. The procedure below outlines the steps to perform the final operations to abandon the well and install a subsurface marker plate a minimum of 3' below the original tundra surface. • • Procedure to Abandon the surface of Red Dog #1 for final abandonment: 1. Service and pressure test tree. 2. PT wellbore (9 -5/8" casing) to 7100 psi. 3. RU SL and tag top of downhole cement plug (expected TOC —180' MD) 4. RU CTU and Under -ream cement to top of EZSV @ —290' MD. Mill hole through center of EZSV. 5. Circulate out Diesel and Drilling mud to as deep as possible with a slick CT assy and nozzle. If solids in the drilling mud have settled out clean out to the deepest depth achievable (hard tag) and P &A (cement) from that point up. 6. Tag TOC @ — 15,587' MD (or as deep as achievable per above verbiage). Notify AOGCC inspector to witness tag and PT of wellbore (9 -5/8" casing and cement/CIBP) to 3000 psi. 7. Lay cement in 9 -5/8" casing to surface: Class G to 2500' MD ( -960 bbls if —15,600' MD is reached during clean-out) and Arctic Set I from 2500' MD to surface ( -185 bbls). 8. Notify AOGCC inspector to witness PT of the cement plug to 3000 psi and tag of the cement plug. 9. Excavate around the well and prep to remove casing and wellhead. 10. Cut off and remove the casing and wellhead a minimum of 3' below original tundra level. a. Notify Inspector of opportunity to witness cut off prior to welding plate. 11. Top off any unfilled annuli and tubing to surface with cement. 12. Place an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. Red Dog #1 PTD# 198 -252 API# 60- 089 -20027 -ic O c 1 C ze,/ z C 5 („,. ,n .n I • • Red Dog #1 Permit No. 198 -252 API No. 50- 029 - 20027 -00 -00 Current Status 4 -' /2" tubing joint Methanol fp.s. 'VA ; 1 7 20' to 186' MD + ► '' . 20" 91.5# H-40, BTC 80' MD 80' TVD) i■ S .',411. Cement Plug #4 4 ► (186' MD to 286' MD 9 -5/8" EZSV @ 286' MD Diesel Diesel 13 -3/8" ES Cementer @ 2133' MD 286' MD to 3050' MD 1 ' Downsqueeze cement in OA w/ Cement Plug + ....1 Premium /Class E to surface 13 -3/8" x OH x 20" annulus 13 -3/8" 68# L -80, BTC Permafrost E &C (2133' MD to surface) @ 5302' MD (4447' TVD) Permafrost E & Class G (Shoe to 2133' MD) 13.6 ppg 4 13.6 ppg KCI Polymer Drilling Mud KCI Mud (3050' MD to 15,587' MD Estimated Top of Cement Behind the 9 -5/8" casing @ ,, -13,500' MD (w /30% washout) 9 Top of shallowest hydrocarbon ►+:' ■ Cement Plug 15,587' MD - 15,687' MD potential @ 14,050' MD + +•�, ti► 9 -5/8" EZSV @ 15,687' MD ... 9 -5/8" 47# P -110, SLHC @ 15,850' MD (9699' TVD) Cement Plug (Pumped in three stages) --... i 15.8 ppg Possible Oil & Gas Bearing 15,723' MD to 19,292' MD i Premium i Zones from 16,840' MD to Cement i 19,250' MD 8-W Openhole TD @ 19,400' MD (12,371' TVD) Diesel 13.6 ppg KCI Polymer Drilling Mud 15.8 ppg Premium Cement Methanol X Cement in Place Prior to P.'s Abandonment • • Red Dog #1 Permit No. 198 -252 API No. 50- 029 - 20027 -00 -00 Proposed Status Tundra Surface 4 f •:* ii'3 4 ` � s 20" 91.5# H -40, BTC @ 80' MD (80' ND) iiiia0i ; ♦. +.� �. *.iii *ahiDa � r*�i,a 13 -3/8" 68# L -80, BTC r e �++�i* '• @ 5302' MD (4447' ND) Cement in 9 -5/8" from 15,500' MD to surface Estimated Top of Cement Behind the 9-5/8" casing @ .`♦ 13,500' MD ■ • O . A. . Cement Plug #2 ��� 15,587' MD — 1 5,687' MD Shallowest hydrocarbon potential @ 14,050' MD — 9 -5/8" EZSV @ 15,687' MD ,i,' `A; 9 -5/8" 47# P -110, SLHC @ 15,850' MD (9699' ND) Cement Plug #1 Possible Oil & Gas Bearing 15,723' MD to 19,292' MD Zones from 14,050' MD to 19,250' MD 8- Openhole TD @ 19,400' MD (12,371' ND) re i Proposed Cement • 15.8 ppg Premium Cement F: Cement in Place Prior to !a'�•'� Abandonment • • "'TOTE [fi] SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Doug Cismoski Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Undefined Pt. Thomson Pool, REDDOG -01 Sundry Number: 311 -331 , its Dear Mr. Cismoski: 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 reconsideration. A request for reconsideration 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. Sincerely, (;) Daniel T. Seamount, Jr. Chair ri DATED this Z day of November, 2011. Encl. OTE OF ALASKA V WI' 1°� y�� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL OCT 2 7 2011 r/ / 2 20 AAC 25.280 1. Type of Request: Alaska tJII 1St ties lions. uommission ® Abandon, ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approvellifthinge ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown C 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 198 452 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20027 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: REDDOG -01 - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 390827 & 390826 Prudhoe Bay Field / Undefined Pt. Thompson 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): 19400' 12379' 186' 186' 186' (Multiple) None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 5302' 13 -3/8" 5302' 4447' 4930 2270 Intermediate 15850' 9 -5/8" 15850' 9700' . Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: None Packers and SSSV None 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: April 1, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR _ ® Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564 -4102 Printed Name Doug Cismoski, P.E. Title Well Interventions Manager 1G I Prepared By Name /Number: Signature Phone 564 - 4303 Date / tr;/fiI Terrie Hubble, 564 -4628 • Commission Use Only Con itions of approval: Notify Commission so that a representative may witness 3 J / Sundry Number: ? I ( ; Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: — - hye c ,..4) r' a : iii 1; .c../ J (O V-- [10 P s- 7 S � r c1 Li -.red . Subsequent Form Required: /6 — yQ ►.� APPROVED BY j f Approved By: • ■ IS I T COMMISSION Date ! / Z.) 1 Form 10-403 - 0 NOV 0 3 et , . 1 A Submit In Duplicate • • • Summary of Proposed Work BP Exploration Alaska Inc (BPXA) P & A Program Red Dog #1 PTD 198 -252 API No. 60- 089 -20027 Present Well Condition The well was drilled to a depth of 19,400' MD, and is cased as follows: Casing Size Weight Grade Depth (MD) Cementing Record Conductor 20" 91.5# H -40 80' 355 sks of 15.6# Permafrost C Surface 13 -3/8" 68# L -80 5302' 1 stage lead: 547 sks, 12# Permafrost E. Tail: 538 sks, 15.8 class G 2 stage lead: 1800 sks, 12# Permafrost E. Tail: 200 sks, 15.6# Permafrost C Intermediate 9 -5/8" 47# P -110 15,850' 170 bbls of 15.8# Premium Cement `74140 5�- aur Maximum Anticipated Surface Pressure (MASP) is 0 psi (all openhole and casing shoe is cemented and plugged providing hydraulic isolation) per 20 AAC 25.036 (c.) Note: Regardless of 0 psi MASP, BP will proceed with this P&A operation as if formation pressure could have leaked through the cemented shoe and the CIBP with cement on top — therefore taking the most conservative approach to this P&A intervention. This "worst case" scenario yields a MASP of 7100 psi therefore the CT BOP stack will be constructed and tested to provide that pressure tolerance until hydraulic isolation from the reservoir can be re- verified by pressure test of those barriers. The final operation to plug and abandon the well is scheduled to be performed approximately April 2012 during the ice road season. With approval to complete the P &A from the AOGCC, it is desired that the sundry be approved until June 1, 2012. In April 1999, the well was suspended with the following cement in the wellbore: 15,723' — 19,292' Set cement plug across open hole oil and gas bearing zones. 15,587' — 15,687' Set cement plug on top of EZSV plug in 9 -5/8" casing. 186' — 286' Set cement plug on top of EZSV plug in 9 -5/8" casing. The procedure below outlines the steps to perform the final operations to abandon the well and install a subsurface marker plate a minimum of 3' below the original tundra surface. • • Procedure to Abandon the surface of Red Dog #1 for final abandonment: 1. Service and pressure test tree. 2. PT wellbore (9 -5/8" casing) to 7100 psi. 3. RU SL and tag top of downhole cement plug (expected TOC —180' MD) 4. RU CTU and Under -ream cement to top of EZSV @ —290' MD. Mill hole through center of EZSV. 5. Circulate out Diesel and Drilling mud to PBTD @ —15,500' MD. 3000rs 6. Tag to TOC @ —15,587' MD. PT wellbore (9 -5/8" casing and cement /CIBP) N l ' oI e try 7. Perforate 9 -5/8" casing 12,500' MD. / 8. Lay Class G cement in 9 -5/8" casing and squeeze annulus (OH x 9 -5/8 ") with cement targeting —55 bbls behind pipe + 300 bbls for casing fillup. 07S L Bd L/ pr ' ( D C *4 p 9. Tag & PT cement plug & squeeze perfs to 3000 psi. (TOC expected @ —11,500' MD). t 10. Lay cement in 9 -5/8" casing to surface, Class G to 2500' MD ( -660 bbls) and Arctic Set I from 2500' MD to surface ( -185 bbls). 4 1 Ou' 4 zseo 11. Excavate around the well and prep to remove casing and wellhead. 12. Cut off and remove the casing and wellhead a minimum of 3' below original tundra level. a. Notify Inspector of opportunity to witness cut off prior to welding plate. 13. Top off any unfilled annuli and tubing to surface with cement. 14. Place an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. Red Dog #1 PTD# 198 -252 API# 60- 089 -20027 0 0 Red Dog #1 Permit No. 198 -252 API No. 50- 029 - 20027 -00 -00 Current Status 4'/:" tubing joint .•..•∎∎..•∎'. f. -- Methanol .f ..�J.� • 4 .7Y . � +0. ' i .. t 20' to 186' MD �iO +ii +i +i •• . -: i + i + i " i + i i +� + �� � , � Oj� � +� + . ..4 +� + 20" 91.5# H-40, BTC @ 80' MD (80' TVD) ++i O ++i 1 i i■ • VA �QO +i Cement Plug #4 ;4 � + •$ � � ' . (186' MD to 286' MD + p4 ►,+ .•, �.+. + , ; + + + + � + + 4 .�.� . + +. � +.. 9 -5/8" EZSV @ 286' MD ■ Diesel 3:�: ∎�:: 0�;� , 13 -3/8" ES Cementer @ 2133' MD +p� X 00. • O v:: • 286' MD to 3050' MD p� +�,' 0 :4 *, 4 . 0• +; D ownsqueeze cement in OA w/ Cement Plug •'�'�' • +� '�' ' Premium /Class E to surface 13 -3/8" x OH x 20" annulus 13 -3/8" 68# L -80, BTC Permafrost E &C (2133' MD to surface) @ 5302' MD (4447' TVD) Permafrost E & Class G (Shoe to 2133' MD) 13.6 ppg 13.6 ppg KCI Polymer Drilling Mud KCI Mud (3050' MD to 15,587' MD Estimated Top of Cement Behind the 9 -5/8" casing @ K+ :, ., -13,500' MD (w/30% washout) •••••� � +• + � Top of shallowest hydrocarbon • • 444 Cement Plug • + � + . + + +p + 15,587' MD - 15,687' MD potential @ 14,050' MD �4;+; �;+;t :i i i'i ' iii • •ii O + ;: _W X 9 -5/8" EZSV @ 15,687' MD ✓ W. •00. ••••• OOO • . • ' � 9 -5/8" 47# P -110, SLHC i @ 15,850' MD (9699' TVD) I , Cement Plug (Pumped in three stages) is 15 8 ' Possible Oil & Gas Bearing 15,723' MD to 19,292' MD Peemi , Zones from 16,840' MD to I Cem� 19,250' MD 1 i • 8 -'/2" Openhole TD @ 19,400' MD (12,371' TVD) 111 Diesel ■ 13.6 ppg KCI Polymer Drilling Mud ■ 15.8 ppg Premium Cement ■ Methanol ���� • Cement in Place Prior to •. Abandonment • Red Dog #1 Permit No. 198 -252 API No. 50- 029 - 20027 -00 -00 Proposed Status Tundra Surface 4ft f` +f +� °'+ 20" 91.5# H -40, BTC @ 80' MD (80' TVD) ff HH N f�1 H 1f1f� 1t �f + 1 f � �l f rfftff �f �1 1 r f f l + f� l I + + 4 A - 1 F l f + • f + 4 aff ��O / * + * ♦fflff+ ♦!! N♦ !♦ +riff rN�1♦ ! ! ! f ♦, ii �1 �1 ! * � I ! !q� a fO f i 1 o f!fl�afOfi �i +ifi,�Offf flff�affffi • +Oyffff +�1�aOOi i �pp�Of 13 - 3/8" 68# L-80, BTC '' 'i +f +i.f.•` . +iOli !f @ 5302' MD (4447' TVD) Cement in 9 -5/8" from L — 15,500' MD to surface 1 Estimated Top of Cement Behind the 9 -5/8" casing @ 13,500' MD �• fff Cement Plug #2 • • Shallowest hydrocarbon potential @ : �i 15,587' MD — 15,687 MD .1 14,050' MD iifi — ����� 9 -5/8" EZSV @ 15,687' MD so. '''+ • 9 -5/8" 47# P -110, SLHC @ 15,850' MD (9699' TVD) Cement Plug #1 Possible Oil & Gas Bearing 15,723' MD to 19,292' MD Zones from 14,050' MD to 19,250' MD 8 -' /2" Openhole TD @ 19,400' MD (12,371' TVD) Proposed Cement ■ 15.8 ppg Premium Cement •; + Cement in Place Prior to ..e' Abandonment Page 1 of 1 • • Schwartz, Guy L (DOA) From: Worthington, Aras J [Aras.Worthington@bp.com] Sent: Wednesday, November 02, 2011 9:24 AM To: Schwartz, Guy L (DOA) Subject: RE: Red Dog #1 ( PTD 198 -252) Attachments: Red Dog #1 Sundry revised 11- 1- 11.doc Guy, I revised the procedural steps to include the detail requested below (please see attached). Thanks, Aras From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz ©alaska.gov] Sent: Monday, October 31, 2011 1:49 PM To: Schwartz, Guy L (DOA); Worthington, Aras 3 Subject: RE: Red Dog #1 ( PTD 198 -252) Aras , I forgot that the 9 5/8" retainer needs to be Tagged and charted /pressure tested before perfing the casing too. This would be added to step 5. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Monday, October 31, 2011 1:42 PM To: 'Worthington, Aras J' Subject: Red Dog #1 ( PTD 198 -252) Aras, As per our phone call this morning can you submit a revised procedure... or just respond to the numbered steps below: 1- what is your proposed BOP test pressure... also what is your expected MASP? Please elaborate a bit on the BOP equipment setup. 2- what pressure are you testing the 9 5/8" casing to before you drill the retainer at 286' md? 3- How much cement are planning on sqzing into the 9 5/8" x OH annulus? Where do expect the TOG to end up in the annulus? the sqz perfs should be tested at some point before filling the cement to surface. 4- What type of cement do you propose using and to what depths. Total volumes also of each kind. (9 5/8" casing in .0732 bbl /ft) Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 11/2/2011 Request for extension of suspended status of Red Dog #1 • Page 1 of 2' Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 30, 2011 1:29 PM To: 'Gathman, Brad' Cc: Cismoski, Doug A; Kara, Danny T; McMains, Stephen E (DOA) ps Subject: RE: Request for extension of suspended status of Red Dog #1 CP 1 $- ZSZ Brad, The Commission will extend the "Suspend" status for Red Dog #1 ¢RM1 until 12/31/14 but the expectation is that as soon as the next ice road to Badami or Pt Thomson is built is when the work will commence. The two outstanding P & A sundries for the well (310 -050 and 311 -096) will also be withdrawn per your request below. Further discussions should occur between the AOGCC and BP regarding the proposed P & A procedure before submitting a new sundry. Regards, Guy Schwartz r Senior Petroleum Engineer APR 20 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gathman, Brad [mailto:Brad.Gathman @bp.com] Sent: Tuesday, March 29, 2011 6:28 PM To: Schwartz, Guy L (DOA) Cc: Cismoski, Doug A; Kara, Danny T; Gathman, Brad Subject: Request for extension of suspended status of Red Dog #1 Mr. Guy Schwartz, Exploration well Red Dog #1 (PTD 198 -252) was drilled and suspended in 1999. The well was drilled from an ice pad near the Beaufort Sea coast, east of the Badami Unit. A suspended well inspection was completed on 9/20/10 and the results were reported on a Report of Sundry Well Operations dated 10/06/10. There were no discolorations or sheens in the area or in nearby water. Well pressures were: T /I /O = NA / Vac / 0. The well is secured with two mechanical casing plugs with cement above each and cement across the open hole section extending into the casing. No liner was run below the intermediate casing and the well was not perforated in the intermediate casing. The well is mechanically sound based on cemented casing, the plugs and pressure tests. BPXA received approval to plug and abandon the well in 2011 via Sundry 310 -050, and an extension of suspended well status until 12/31/11 via Sundry 310 -437. Our intent was to complete the P &A for Red Dog #1 before June of 2011 — this scope of work included replacing the top 186' and of methanol with cement, cutting off the wellhead a minimum of 3' below tundra and welding on the final name plate on the outer most casing string. All permits and equipment were secured to complete this work, however the scope of work was recently modified to conform to changes in our company policies. These changes are reflected in the Application for Sundry Approval dated 3/24/11 - the new scope of work includes milling through the cement plug from 186' - 286' md, milling through the EZSV at 286' and with the intent of recovering the diesel in the well and placing additional cement deeper in the well. 3/30/2011 • Request for extension of suspended status of Red Dog #1 Page 2 of 2 r • 4110 Due to the change in scope of work, the procedure to complete the P &A has become significantly more risky and complicated. With ice road season coming to an end, we do not feel there is adequate time to complete a revised comprehensive procedure and identify all the risks and necessary equipment to complete the Red Dog #1 P &A before the end of ice road season. We request an extension of suspended status for Red Dog #1 of up to 3 years, until 12/31/14 to complete the Red Dog #1 P &A. The request for up to 3 year extension is being driven on ice road availability. A variance to the provisions of 20 AAC 25./110(c)(2) is requested under 20 AAC 25.112 (i) to allow the well to remain suspended in its current condition. If this is acceptable, BP will withdraw Sundry 310 -050 and the latest Application for Sundry Approvals dated 3/24/11. Attached is a schematic of the current completion for Red Dog #1. Please contact me with any questions or concerns, I I Brad Gathman Well Intervention Engineer BP Exploration Alaska office +1 907 564 5778 Cell (907) 242 -2034 «Red Dog #1 Current Status Drawing.vsd» 3/30/2011 RE D DO EXPLORATION RATION L CONFIDENTIAL O FINAL SUSPENSION SCHEMATIC Dryhole tree installed (2 gate vales) Methanol' -- - a (20' to 186' MD) '0" 91.5# H -40, BTC @ 80' MD (80' TVD) Cement Plug #4 • (186' MD to 286' MD) 13 -3/8" ES Cementer Diesel 110- @ 2133' MD (2133' TVD) (286' to 3050' MD) 9 - 5/8" EZSV @ 286' MD 13 -3/8" 68# L -80, BTC @ 5302' MD (4447' TVD) Cement Plug #3 - 9 Crossover, 9 5/8 53.5# P-110, SLHC (9-5/8" by 13 -3/8" annulus) @ 6686' MD (5156' TVD) Permafrost E (surface to 2395' MD) Premium (2395' to 5292' MD 13.6 ppg KCL Polymer Drilling Muc (3050' MD to 15,587' MD) k. `, Cement Plug #2 Iti (15.587' MD - 15,687' MD) r Estimated Top of Cement . _ . � ` behind the 9 -5/8" Casing @ 13,950' MD (8780' TVD) 9 -5/8" EZSV @ 15,687' MD 9 -5/8" 47# P -110, SLHC 1 1 @ 15,850' MD (9699' TVD) Cement Plug #1 I (15,723' MD to 19,292' MD) I I I i Possible Oil & Gas Bearing Zones from 16,840' MD to 19,250' MD 1 1 I I I 1 Diesel IMP 8 -1/2" Openhole TD @ 19,400' MD (12,371' TVD) I 15.8 ppg Premium Cement M 13.6 ppg KCL Polymer Drilling Mud 15.6 ppg Permafrost "C" Cement 111 14.8 ppg KCL Polymer Drilling Mud 12.0 ppg Permafrost "E" Cement Cement In Place Prior to Abandonment • STATE OF ALASKA RECEIVECO// ALASKA& AND GAS CONSERVATION COMMIS• APPLICATION FOR SUNDRY APPROVAL BAR 2 4 ' ?`11,' 1. Type of Request: 20 AAC 25.280 ska TO & Pas Cot)4 j ® Abandon - ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved iikepoptie Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubin ❑ spe g Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. • mid TO , I Number BP Exploration (Alaska) Inc. ❑ Development - ® Exploratory 198 ' 5 3. Address: ❑ Service ❑ Stratigraphic ° • A umber: P.O. Box 196612, Anchorage, Alaska 99519 -6612 - 0- 029 -20027 -00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and umber property line where ownership or landownership changes: ,t Spacing Exception Required? ❑ Yes ® No ; r' REDDOG -01 - 9. Property Designation: 10. Field / Pool(s): , ` ADL 377013 - Prudhoe Bay F eld / Undefined Pt. Thomson Pool 11. - PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TV (ft): Plugs (measured): Junk (measured): 19400' - 12379' - 186' 6' ,T 186' (Multiple) None Casing length Size MD tc` D Burst Collapse Structural ''; 5\ Conductor 110' 20" 110' 110' 1490 470 Surface 5302' 13 -3/8" 5302' 7 • .. \ 4930 2270 Intermediate 15850' 9-5/8" 1585 ' -7',1' Production t Liner y . . . \ Perforation Depth MD (ft): Perforation Depth ft): ubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: None ' Packers and SSSV None MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal OP Sketch ❑ Detailed Operations Program - ® Exploratory ❑ Development ❑ Service 14. Estimated Date for / 15. Well Status after proposed work: Commencing Operations: Ap 1, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: a te: ❑ Gas ❑ GINJ ❑ GSTOR - Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is t . and correct to the best of my knowledge. Contact Brad Gathman, 564-5778 Printed Name Doug Cismoski ° .E. Title Well Interventions Manager Prepared By Name/Number. Signature ~ „// . Phone 564 - 4303 Date 2 VII Elizabeth Barker, 564-5674 G Commission Use Only / Conditions of approval: Notify • • mmission so that a representative may witness I Sundry Number X-0 �'t ( „ r: "i (0 ❑ Plug Integrity ❑ BOP est ❑ Mechanical Integrity Test ❑ Location Clearance Other. MALL) a1nil Subsequent Fo Required: APPROVED BY Approved -y: <: /1r., COMMISSIONER THE COMMISSION Date Form 10-403 Revised 01/2011703 MS MAR 31 ['� "� Submit In Duplicate ORIGINAL • • Summary of Proposed Work BP Exploration Alaska Inc (BPXA) P & A Program Red Dog #1 PTD 198 -252 API No. 50- 029 - 20027 -00 -00 BP Exploration Alaska Inc. is requesting approval of a new Sundry from the AOGCC to complete the final plug and abandonment work for Red Dog #1. The scope of work has changed from the original Sundry approved from the AOGCC (Sundry number 310 -050). Due to ice road availability, the plug and abandonment work on Red Dog #1 will start approximately April 1, 2011. Present Well Condition The well was drilled to a depth of 19,400' MD, and is cased as follows: Casing Size Weight Grade Depth (MD) Cementing Record Conductor 20" 91.5# H -40 80' 355 sks of 15.6# Permafrost C Surface 13 -3/8" 68# L -80 5302' 1 stage lead: 547 sks, 12# Permafrost E. Tail: 538 sks, 15.8 class G 2nd stage lead: 1800 sks, 12# Permafrost E. Tail: 200 sks, 15.6# Permafrost C Intermediate 9 -5/8" 47# P -110 15,850' 170 bbls of 15.8# Premium Cement In April 1999, the well was suspended with the following cement in the wellbore: 15,723' — 19,292' Set cement plug across open hole oil and gas bearing zones. 15,587' — 15,687' Set cement plug on top of EZSV plug in 9 -5/8" casing. 186' — 286' Set cement plug on top of EZSV plug in 9 -5/8" casing. The procedure below outlines the steps to perform the final operations to abandon the well and install a subsurface marker plate a minimum of 4' below the original tundra surface. Procedure to Abandon the surface of Red Dog #1 for final abandonment: 1. Install reconditioned tree. 2. Have valve crew pull TWC (4" CIW Type `H') • • 3. RU Coiled tubing and mill cement in 9 -5/8" casing from 186' MD to top of CIBP at 286' MD. 4. Mill pilot hole through CIBP. 5. Circulate out diesel and drilling mud with seawater in 9 -5/8" casing to a depth of 15,687' MD. 6. Freeze protect down to 2500' MD. 7. Perforate 9 -5/8" casing from 14,090' — 14,110' MD and 13,650' — 13,670' MD. 8. Establish injectivity rate into formation. 9. Pump fullbore cement job and fill 9 -5/8" casing with cement from 14,110' MD to surface. 10. Squeeze 20 bbls of cement into perforations before shutting down. 11. Excavate around wellhead and prep to remove casing and wellhead. 12. Cut off and remove the casing and wellhead a minimum of 4' below original tundra level. a. Notify Inspector of opportunity to witness cut off prior to welding plate. 13. Fill any other unfilled annuli to surface with cement. 14. Place an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. Red Dog #1 PTD# 198 -252 API# 50 -029- 20027 -00 -00 it • Red Dog #1 Permit No. 198 -252 API No. 50- 029 - 20027 -00 -00 Current Status Methanol Methanol 20' to 186' MD 20" 91.5# H-40, BTC @ 80' MD (80' TVD) Cement Plug #4 , (186' MD to 286' MD) 9518 " EZSV @286'MD Diesel faM1 286' MD to 3050' MD Ks, `? 13 -3/8" ES Cementer @ 2133' MD 13 -3/8" 68# L -80, BTC Cement Plug #3 @ 5302' MD (4447' TVD) 9 -5/8" x 13 -3/8" annulus Permafrost E surface to 2395' MD) KCI Polymer Drilling ( ) � 13.6 ppg y g Mud Premium (2395' to 5292' MD) (3050' MD to 15,587' MD Cement Plug #2 Estimated Top of Cement 15,587' MD — 15,687' MD Behind the 9 -5/8" casing @ AVAVA 13,950' MD (8780' TVD) 9 -5/8" EZSV @ 15,687' MD $5 9 -5/8" 47# P -110, SLHC @ 15,850' MD (9699' WD) 8 ppg Cement Plug #1 mum Possible Oil & Gas Bearing 15,723' MD to 19,292' MD ' Cement., Zones from 16,840' MD to 19,250' MD I � I I I i I I 14.8 ppg 8 -'h" Openhole TD @ 19,400' MD (12,371' TVD) Diesel 15.8 ppg Premium Cement 13.6 ppg KCI Polymer Drilling Mud 15.6 ppg Permafrost "C" 14.8 ppg KCI Polymer Drilling Cement Mud ■ 12.0 ppg Permafrost "E" Cement Cement in Place Prior to Abandonment • • Red Dog #1 Permit No. 198 -252 API No. 50- 029 - 20027 -00 -00 Proposed Status Tundra Surface 4ft i .414 Ihr; 20" 91.5# H -40, BTC @ 80' MD 80' TVD) Cement Plug #3 9 -5/8" x 13 -3/8" annulus Permafrost E (surface to 2395' MD) Premium (2395' to 5292' MD) 13-3/8" 68# L -80, BTC @ 5302' MD (4447' TVD) Proposed Perfs © 13,650' — 13,670' MD Estimated Top of Cement / / Behind the 9 -5/8" casing @ / 13,950' MD (8780' TVD) ► ;; Cement Plug #2 • 15,587 MD — 15,68T MD Proposed Perfs @ 14,090' — 14,110' MD ---10.;; 9 -5/8" EZSV @ 15,687' MD 9 -5/8" 47# P -110, SLHC @ 15,850' MD (9699' TVD) 1 15.8 ppg Cement Plug # el.i Premium ' Possible Oil & Gas Bearing 15,723' MD to 19,292' MD , Cement ') Zones from 16,840' MD to 19,250' MD i 14.8 ppg I 8 - + / Openhole TD @ 19,400' 1 KCI Mud I MD (12,371' TVD) Proposed Cement III 15.8 ppg Premium Cement 15.6 ppg Permafrost "C" 14.8 ppg KCI Polymer Drilling Cement Mud • 12.0 ppg Permafrost "E" Cement Cement in Place Prior to Vik Abandonment 'Request for extension of suspended status of Red Dog #1 Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 30, 2011 1:29 PM To: 'Gathman, Brad' Cc: Cismoski, Doug A; Kara, Danny T; McMains, Stephen E (DOA) Subject: RE: Request for extension of suspended status of Red Dog #1 �TL� 1 2 5 2 ) Brad ,Z5 The Commission will extend the "Suspend" status for Red Dog #1,(PTD IQ 9 F) until 12/31/14 but the expectation is that as soon as the next ice road to Badami or Pt Thomson is built is when the work will commence. The two outstanding P & A sundries for the well (310 -050 and 311 -096) will also be withdrawn per your request below. Further discussions should occur between the AOGCC and BP regarding the proposed P & A procedure before submitting a new sundry. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gathman, Brad [mailto:Brad.Gathman @bp.com] Sent: Tuesday, March 29, 2011 6:28 PM To: Schwartz, Guy L (DOA) Cc: Cismoski, Doug A; Kara, Danny T; Gathman, Brad Subject: Request for extension of suspended status of Red Dog #1 Mr. Guy Schwartz, Exploration well Red Dog #1 (PTD 198 -252) was drilled and suspended in 1999. The well was drilled from an ice pad near the Beaufort Sea coast, east of the Badami Unit. A suspended well inspection was completed on 9/20/10 and the results were reported on a Report of Sundry Well Operations dated 10/06/10. There were no P P rY P discolorations or sheens in the area or in nearby water. Well pressures were: T /I /O = NA / Vac / 0. The well is secured with two mechanical casing plugs with cement above each and cement across the open hole section extending into the casing. No liner was run below the intermediate casing and the well was not perforated in the intermediate casing. The well is mechanically sound based on cemented casing, the plugs and pressure tests. BPXA received approval to plug and abandon the well in 2011 via Sundry 310 -050, and an extension of suspended -4 7. Our intent was to complete the P &A for Red Dog #1 ended well status until 12/31/11 via Sundry 310 3 Ou tot g P ry P before June of 2011 — this scope of work included replacing the top 186' and of methanol with cement, cutting off the wellhead a minimum of 3' below tundra and welding on the final name plate on the outer most casing string. All permits and equipment were secured to complete this work, however the scope of work was recently modified to conform to changes in our company policies. These changes are reflected in the Application for Sundry Approval dated 3/24/11 - the new scope of work includes milling through the cement plug from 186' - 286' md, milling through the EZSV at 286' and with the intent of recovering the diesel in the well and placing additional cement deeper in the well. 3/30/2011 Request for extension of suspended status of Red Dog #1 Page 2 of 2 Due to the change in scope of work, the procedure to complete the P &A has become significantly more risky and complicated. With ice road season coming to an end, we do not feel there is adequate time to complete a revised comprehensive procedure and identify all the risks and necessary equipment to complete the Red Dog #1 P &A before the end of ice road season. I I We request an extension of suspended status for Red Dog #1 of up to 3 years, until 12/31/14 to complete the Red Dog #1 P &A. The request for up to 3 year extension is being driven on ice road availability. A variance to the provisions of 20 AAC 25./110(c)(2) is requested under 20 AAC 25.112 (i) to allow the well to remain suspended in its current condition. If this is acceptable, BP will withdraw Sundry 310 -050 and the latest Application for Sundry Approvals dated 3/24/11. Attached is a schematic of the current completion for Red Dog #1. Please contact me with any questions or concerns, Brad Gathman Well Intervention Engineer BP Exploration Alaska office +1 907 564 5778 Cell (907) 242 -2034 «Red Dog #1 Current Status Drawing.vsd» 3/30/2011 • • TIATIEE A[LASEA /SEANPARNELL , G OVERNOR �T ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATI ON COM IISSIOl` ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Gary Preble Date Management Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Exploratory Pool, REDDOG -01 Sundry Number: 310 -437 JAN Dear Mr. Preble: 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 reconsideration. A request for reconsideration 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. Sincerely, Z" Daniel T. Seamount, Jr. Chair DATED this day of January, 2011. Encl. ne.>0 � c o \ \ S TATE OF ALASKA V� q�' ALASKA. AND GAS CONSERVATION COMMISSIO DEC 2 1 2010 '�� y APPLICATION FOR SUNDRY APPROVALS v. 20 MC 25.280 Alaska a z i1 (as f nits. Conmi $ pn 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ ChangeAmeg aogram ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: RENEW SUSPENSION 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory Er 198 -2520 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 089 - 20027 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: REDDOG -01 ' Spacing Exception Required? Yes ❑ o ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 37701339027 PRUDHOE BAY Field / EXPLORATORY Pool` 11. PRESENT WELL CONDITION SUMMARY 1 Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 19400 • 12378.58 - 186 186 186' TOC NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H -40 SURFACE 110 SURFACE 110 1490 470 Surface 5302 13- 3/8 "68# L -80 SURFACE 5302 SURFACE 4447 4930 2270 Intermediate 15850 9- 5/8 "47# P -110 SURFACE 15850 SURFACE 9700 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - NONE _ _ 1 - - I Packers and SSSV Tvoe: NONE Packers and SSSV MD and ND (ft): 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory El - Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/4/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended - El 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Gary Pr bt Title Data Management Engineer Signature Phone Date 564 -4944 12/21/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 0 •-%431 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: g L X TG•+S iD P h yc,(6.1 4 �( 62/ 3y Lot/ ( Zoo A p /4,h "e n Subsequent Form Required: ^jerk 4-4): �I rn APPROVED BY r A / / � Otis Approved by: COMMISSIONER THE COMMISSION Date: / /45 / GR1Gl'° JAN 66 zoo /2/204 Form 10 -403 Revised 1/2010 3 ' Submit in Duplicate # • Red Dog 1 Technical Justification for Application for Renewal of Suspension Status December 17, 2010 Well Status Red Dog 1 (PTD 1982520) was suspended on 04/02/99 after drilling to TD and logging. The well was drilled from an ice pad near the Beaufort Sea coast, east of the Badami Unit. BP Exploration (Alaska), Inc. (BPXA) completed a suspended well inspection of Red Dog 1 on 09/25/10. The results of that inspection were submitted with a Report of Sundry Well Operations (form 10 -404) on 10/06/10. Red Dog 1 is secured with two EZSVs with cement plugs above each and cement across the open hole section and extending into the casing. No liner was run below the intermediate casing and the well was not perforated. The well is mechanically sound based on cemented casing, the plugs and pressure tests. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe, and not a threat to public health. The strata through which the lower portion of the well was drilled is mildly over pressured (about 13 ppg EMW) in the ramp up toward the geo- pressured Thomson sands. The well is planned to be plugged and abandoned during the winter of 2011. Sundry Application (310 -050) was approved to P &A this well. Condition of the Wellhead and Surface Location Red Dog 1 is located on the tundra with no remaining reserve pit, having been drilled from an ice pad. There is no discoloration and no sheens in the area of the ice pad or in nearby water. The current well pressure readings are: T /I /O = N/A / Vac / 0. Request BPXA requests approval for renewal of the existing suspension status for Red Dog 1 through 12/31/2011 to allow time for the planed P &A to be completed. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to be remain suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. MLB 12/17/10 f r • • • • Red Dog #1 Permit No. 198 -252 API No. 60- 089 -20027 Current Status Methanol Methanol +90 20' to 186' MD : o%.,.;:,. 20" 91.5# H-40, BTC @ 80' MD (80' TVD) ♦P1• ••n1 '• �•• S 1 °••1 Cement Plug #4 :;. «; � .•.�, (186' MD to 286' MD) ': 9 -5/8" EZSV @ 286' MD P•Off� _ i•� �1 l Diesel '+ .•.� 286' MD to 3050' MO si + 13 -3/8" ES Cementer @ 2133' MD . >•••• o.• ••i •s 1 7 13 -3/8" 68# L -80, BTC Cement Plug #3 @ 5302' MD (4447' TVD) 9 -5/8" x 13 -3/8" annulus Permafrost E (surface to 2395' MD) 13.6 ppg KCI Polymer Drilling Mud Premium (2395' to 5292' MO) (3050' MO to 15,587' MD Cement Plug #2 Estimated Top of Cement 15,587' MD — 15.687' MD Behind the 9-5/8" casing @ ?._p, 13,950' 13,950' MD (8780' TVD) • / •' �•� 1 • 1 •/ :;:;i�►� 9 -5/8" EZSV @ 15,687' MD • •`�� •:' 9 -5/8" 47# P -110, SLHC @ 15,850' MD (9699' TVD) • • Cement Plug #1 e„ Possible Oil & Gas Bearing 15,723' MO to 19,292' MD Zones from 16,840' MD to 19,250' MD 8 -'A" Openhole TD @ 19,400' ® MD (12,371' TVD) f >:x III 15.8 ppg Premium Cement 13.6 ppg KCI Polymer Drilling Mud T1 15.6 ppg Permafrost "C' 14.8 ppg KCI Polymer Drilling Cement Mud al 12.0 ppg Permafrost "E' Cement Cement in Place Prior to �• Abandonment STATE OF ALASKA ALASKA40L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Q INSPECT Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ WELL Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory 198 -2520 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 L 50- 089 - 20027 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 377013 ^ REDDOG -01 10. Field /Pool(s): PRUDHOE BAY FIELD / EXPLORATORY POOL 11. Present Well Condition Summary: Total Depth measured 19400 feet Plugs (measured) 186' TOC feet true vertical 12378.58 feet Junk (measured) None feet Effective Depth measured 186 feet Packer (measured) true vertical 186 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110 1490 470 Surface 5302 13- 3/8 "68# L -80 SURFACE - 5302 SURFACE - 4447 4930 2270 Intermediate 15850 9- 5/8 "47# P -110 SURFACE - 15850 SURFACE - 9700 Production Liner Liner f N OV Perforation depth: Measured depth: NONE - _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) NONE 0 _ Packers and SSSV (type, measured and true vertical depth) NONE I E'' r 12. Stimulation or cement squeeze summary: OCT Q 7 200 Intervals treated (measured): Mode (W & G83Con. x3io0 Treatment descriptions including volumes used and final pressure: Awbcma8 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: Si Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑� evelopment ❑ Service ❑ Daily Report of Well Operations X 16. Well Status after w . to SUSPENDED Oil 0 Gas LJ WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564 -4944 Date Red Dog 1, PTD 1982520 Suspended Well Inspection Report P completed BP Exploration Alaska Inc. B XA co ted a suspended well inspection of e Red Dog 1 on 9/25/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Jeff Jones witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • An as -built survey. There are no wells with a surface location within one - quarter mile radius of the Red Dog 1 well. • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • Red Dog 1 was suspended on 04/02/99 after drilling to TD and logging. • Red Dog 1 was drilled from an ice -a- near the coast east of the Badami Unit. • The strata through which the lower portion of the well was drilled is mildly over pressured (about 13 ppg emw) in the ramp up toward the geo- pressured Thomson sands. • The well is secured with two EZSVs with cement plugs above each and cement across the open hole section and extending into the casing. • The well is mechanically sound as proven by a casing pressure test after the lower cement plug was set. • A Sundry Application (310 -050) was approv to P&A the well during the w inter of 2011. MLB 09/28/10 .,/� 10-Z9• /o Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Red Dog 1 Field /Pool: Unidentified Pt. Thompson Pool Permit # (PTD): 198 -252 API Number: 60 -089 -20027 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 4/2/1999 Surface Location: Section: 34 Twsp: 10N Range: 21 E Nearest active pad or road: Badami Take to Location Digital camera Map showing well location /Aerial photos Brief well history Welibore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: None Surrounding area condition: Good Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: N/A Photographs taken (# and description): 4; wellhead Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: FMC Dryhole tree w/ 2 valves; all valves function Cellar description, condition, fluids: None Rat Hole: None Welihouse or protective barriers: Yes Well identification sign: Yes Tubing Pressure (or casing if no tubing): N/A Annulus pressures: IA = Vac; OA = 0 psi Wellhead Photos taken (# and description): 4; wellhead Work Required: None /— n — Operator Rep (name and signature): Jerry Murph AOGCC Inspector: Jeff Jones Other Observers: Ryan Holt Inspection Date: 9/25/2010 AOGCC Notice Date: 9/20/2010 Time of arrival: 12:00 PM Time of Departure: 12:20 PM Site access method: Fly Red Dog #1 Permit No. 198 -252 API No. 60- 089 -20027 Current Status Methanol Methanol 20' to 186' MD 20" 91.5# H-40, BTC @ 80' MD (80' TVD) Cement Plug #4 (186' MD to 286' MD) 9 -518" EZSV @ 286' MD Diesel 13 -3/8 " ES Cementer @ 2133' MD 286' MD to 3050' MD 13 -3/8" 68# L -80, BTC Cement Plug #3'� @ 5302' MD (4447' TVD) 9 -5/8" x 13 -3/8" annulus Permafrost E (surface to 2395' MD) 13.6 ppg KCI Polymer Drilling Mud Premium (2395' to 5292' MD) (3050' MD to 15,587' MD Cement Plug #f Estimated Top of Cement 15,587' MD — 15,687' MD Behind the 9 -5/8" casing @ 13,950' MD (8780' TVD) 9 -5/8" EZSV @ 15,687' MD 9 -5/8" 47# P -110, SLHC @ 15,850' MD (9699' TVD) Cement Plug #1 Possible Oil & Gas Bearing 15,723' MD to 19,292' MD Zones from 16,840' MD to 19,250' MD 8 -Y2" Openhole TD @ 19,400' MD (12,371' TVD) 15.8 ppg Premium Cement ® 13.6 ppg KCI Polymer Drilling Mud 15.6 ppg Permafrost 'C" 14.8 ppg KCI Polymer Drilling Cement Mud ® 12.0 ppg Permafrost "E" Cement Cement in Place Prior to Abandonment BEAU FORT SEA 30 29 I 28 27 26 BUUEN M RP 2— NORTH ((620.07') TO IED DOG Nd. 1 31 3 5 Y= 5914829.79 l NOM Sm W X= 401579.82 T N EL. = 3.60' a ° Eq 6 5 4 ^ V 3 2 c V d dn RP# i NORTH ((400.03') 7 9 ,o TO RED DOG f�0. 1 ® Y= 5914615.89 �l _ X= 401631.37 EL. = 6.64' a� N76'26'31 "'E 500' VICIMR MAP s +• ss RP 2 —EAST (610.01') OF A s_s• TO ED DOG NO. 1 Y= 914370.00 , X= 02318.00 � °° % 66 , EL. 7.67' RED DOG NO. 1 {y N M LO ° ° °° ° °° ................ Jeffrey J. Cotton Z es z 8.7' RP -EAST (399.99" � ° ° LS M TO RED DOG NO. 1 Y= 5914320.79 ssla X= 402113.84 9 " EL. = 8.52' PAP N76'26'31 E SURVE)flR'5 CERTIFICATE ' 500' 1 7 s s> 1 HEREBY CERTIFY THAT I AM �ti m PROPERLY Mq$TERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRE A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE N OTES CORRECT AS OF JANUARY 15, 1999. 1. DATE OF SURVEY: JANUARY 15, 1999. 2. REFERENCE FIELD BOOKS: LEGEND EX99 -01 (PG. 03 -04). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 3, ALASKA, NAD 27. — AS —B iLT CONDUCTOR 4. PAD SCALE FACTOR IS 0.999:9110 5. HORIZONTAL CONTROL IS BASED ON USGS A. AS—STAKED ICE PAD CORNER MONUMENTS "ELIZA" AND "SPARGO ". SET 6 SPIKE AND RED CHASER 6. ELEVATIONS ARE BADAMI M.S.L. DATUM. 7. VERTICAL CONTROL IS BASED ON PUBLISHED ELEVATIONS AT STATIONS ELIZA & SPARGO O RP TO CONDUCTOR BY HERSCHBACH & ASSOC., 1994. GPS DATA SET 12" SPIKE AND RED CHASER WAS COMPUTED USING GPSURVEY, TRIMNET & TRIMMAP UTILIZING THE GEOID96 MODEL. LOCATED WITHIN PROTRACTED SEC. 34, T. 10 N., R. 21 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) P SIT10N(D.DD) BOX ELEV. OFFSETS Y= 5,914,227.39 N. N/A 70'10'30.511" 70.1751421 1,683' FSL RD -1 X= 401,724.97 E. N/A 146'47'28.054" 146.7911260' 10'5' 4,507' FEL F. Roblerit DRAIN: JA p EX PLORAT ION O �. D+ECKED:1 /1 LEY BP DATE: 1 X18 RAW: SHELT jR NO: REDO RED DOG NO. 1 0 t e lswEV FOR IWOWAWN dr � 1 of 1 'NO. DATE REY,SION BY DIK °a wEtt "n�rxm tee 1" =200' AS —BUILT iR�LL Cf�1DUCTUR _ F Flaxman Island ........... - Maguire Islantls Stockton Islands l 'ova, -0,,�•• R� 1 SOU DOUGH 3 REDDOG -01 2 ?� (f 8 �+ -� epop �` of � �•� r ��, S BP EXPLORATION (ALASKA) INC. \� POINT THOMSON AREA O N pL E SUSPENDED WELLS �e LOCATION MAP DATE: SCALE: June 2009 0 t t 3 MILES w115a59yt.dgn s � s +/ 1 (�' .. 4 x _ r+i r {r .� . . .:v r; ji \ 0 � VYYY ,,.,.sfF? ,. ,:,., a y i • t u » es r ** r . w • d . i t �¢ Aft V; ri-it N, ' � ' *. ' ,. , -fir � _�,.. � 4 t - ; � ?> . ,.��• "tr � d � �,r '!A r r "..... "�"" � .� - 1 e-,. � , � S a`._.w. , ` . *`•t R },.; * 6 � y .`" � ♦ ,,� i �s F. ^..�: - �r%3 t l t Y ' r � t" 611 � r . - , `t r * e in prl R ti ti ��'� r _ e� � �,. � � ��� T . �.: _ tx �� !{ � y� ti Ar i { � ��� <�#4 �� �� ` "'; t � �}� , � I �� � ke � �� k .} jy. 4 I J} '.. �n � � ��`�: �^� � .• i .. y i. � s 4 ^' ., � M �.. m � t ` m a '- yy�µB��� �..? e. - .. '' T..i ... ,, .. .. a ... . , ¢:- �.. � .t+.- �'�`�".�' Remote Suspended Wells Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) ~'~'~~ ~ ~ ~" Z ~ Z Sent: Wednesday, July 28, 2010 9:00 AM To: 'AK, D&C Well Integrity Coordinator' Cc: Maunder, Thomas E (DOA) Subject: RE: Remote Suspended Wells Torin, Regarding the individual suspended wells below... a visual inspection is required by 20 AAC 25.110( e) by September 2010. Section (f) describes the required info for the 10-404. Pressures are not required if not practical. As you mention below the remote wells would be difficult to get gauges installed ,valve handles etc. 1. Red Dog 1'- A visual inspection of the wellhead is required... doesn't sound like pressures are feasible/ ital. 2. Sourdough 3 - You will have to at least partially remove the barrier to get verification that the wellhead is intact and there are no leaks. Again pressures don't appear to be practical. 3. Gull Island - As we discussed it would be prudent to wait for the bird population to leave later in the fall (2010) before inspection .... An inspection and report as soon as this happens will be acceptable... if the inspection cannot be completed by the end of October 2010 notify the commission. Guy Schwartz r ~~ii, Senior Petroleum Engineer +~''~`~°~'~~~' .:`~i~ AOGCC 793-1226 (office) 444-3433 (cell) From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, July 26, 2010 1:34 PM To: Schwartz, Guy L (DOA) Subject: Remote Suspended Wells Guy, As discussed on the phone earlier, there are some obstacles that may need to be overcome on the remote suspended wells. Can you please review the following and provide guidance as to what the AOGCC is requiring on the wells? Red Dog 1 -All the valves are locked and bolt cutters will be needed to monitor the pressures. Also, the OA valve may be blinded and jewelry will need to be installed to monitor pressures. Sourdough 3 -All the valves are locked and valve handles have been removed. Bolts cutters and valve handles will need to be obtained if the pressure readings are required. The casing valves and well cellar are completely covered by a well barrier and wooden structure wrapped in hurculite. We will most likely have to use a saw or hammers to break down the barrier to obtain a view port if needed. Gull Island -Currently there are numerous seagull nests and hatchlings on the island. Depending on when the birds migrate out this year we may be pressed to complete these before the deadline. 7/28/2010 Remote Suspended Wells Page 2 of 2 Thank you for your help on this. Toxin Rosehinger (att. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 7/28/2010 • Mr. Doug Cismoski u Non-Rig Program Manager BP Exploration (Alaska) Inc ~~1 P.O. Box 196612 ~ ~~ O"" Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Undefined Pt. Thomson +Pool, REDDOG-01 Sundry Number: 310-050 Dear Mr. Cismoski: 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, Daniel T. Seamount, Jr. Chair f~ DATED this23 day of February, 2010. Encl. by February 16, 2010 • Ms. Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Red Dog #1 PTD 198-252 Dear Commissioner Foerster: iZ? i~~'~;,~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5006 REC~IIJ~D FHB ~. 7 ZQ1Q Aluks ~ ~ g8s Cam. COITwItISS10~ An~h>ar~g~ The purpose of this letter is to respond to your November 18, 2009 correspondence regarding submitting an Application for Sundry Approval to plug and abandon the referenced well and to provide a schedule to complete the work. Enclosed is the Application for Sundry Approval (form 10-403) to plug and abandon Red Dog #1 well. BP Exploration (Alaska) Inc. (BPXA) plans to conduct plug and abandon operations during the winter 2011 ice road season. Consequently we request the enclosed Application for Sundry Approval be valid through June 1, 2011 If you have any questions, please call me at 564-4194. Sincerely, ~~ Harold R. Engel Alaska Drilling & Wells Engineering Team Leader BP Exploration (Alaska) Inc. Enclosure: AOGCC 10-403 1. Type of Request: AnGheCaQ9 ® Abandon . ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ 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 198-252 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20027-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: REDDOG-01 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): _ ADL 377013 - Prudhoe Bay Field /Undefined Pt. Thomson Pool 11. - PRESENT WELLCONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 19400' - 12379' - 186' 186' 186' (Multiple) None Casin Len Size MD ND Burst Colla Structural Conductor 11 1 11 1 4 Surface 5 2' 13- / " 2' 4447' 4 30 227 Intermediate 1 9- / " 1 8 97 ' Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ®Exploratory ^ Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Early 2011 ^ 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 Brad Gathman 564-5778 Printed Name Doug Cismoski Title Non-Rig Wells Program Manager Prepared By Name/Number. Signature ~ Phone 564-4303 Date ~ Q Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ~/%, _ ~.T~ `/S / Sundry Number: l / /CJ ,_, , ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test l~ Location Clearance c 1 ~ / /^ y ,S~t.h...~.~- Z o~ t; Other: J e CtG~r'L ~p~ OTo S o ~ ~ ~.~T - o ~t p r r a r '~o £ ' f''F's. I" w t (~ t 4, P (Md f-~'~ Gomrni$%J'>ti Ta G~.i.'~r«SJ ScLrfre.e.L p~ '' ~~t.~s• Subsequent Form Required: ~ (~ ~07 APPROVED BY ~Z, 2 2 0 D t a e Approved By: COMMISSIONER THE COMMISSION Fon~~-3 ~~vis@~j/~~ ~~ Submit In Duplicate STATE OF ALASKA v3'I0 i~ ~+C~~V~~~'G~ ALASKA AND GAS CONSERVATION COMMIS ~v O ~/~'-/0 VALU- ~ ~E~ 1 7 ~01~ APPLICATION FOR SUNDRY APPRO ~~, 20 AAC 25.280 ~ •00 • • Summary of Proposed Work BP Exploration Alaska Inc (BPXA) P & A Program Red Dog #1 PTD 198-252 API No. 60-089-20027 Present Well Condition The well was drilled to a depth of 19,400' MD, and is cased as follows: Casio Size Wei ht Grade De th (MD Cementin Record Conductor 20" 91.5# H-40 80' 355 sks of 15.6# Permafrost C Surface 13-3/8" 68# L-80 5302' 1St stage lead: 547 sks, 12# Permafrost E. Tail: 538 sks, 15.8 class G 2na stage lead: 1800 sks, 12# Permafrost E. Tail: 200 sks, 15.6# Permafrost C Intermediate 9-5/8" 47# P-110 15,850' 170 bbls of 15.8# Premium Cement ~-1• pow„ saz 173 bbls ~' f 1'13 bi/s The final operation to plug and abandon the well is scheduled to be performed approximately Apri12011 during the ice road season. With approval to complete the P&A from the AOGCC, it is desired that the sundry be approved until June 1, 2011. In April 1999, the well was suspended with the following cement in the wellbore: 15,723' - 19,292' Set cement plug across open hole oil and gas bearing zones. 15,587' -15,687' Set cement plug on top of EZSV plug in 9-5/8" casing. 186' - 286' Set cement plug on top of EZSV plug in 9-5/8" casing. The procedure below outlines the steps to perform the final operations to abandon the well and install a subsurface marker plate a minimum of 4' below the original tundra surface. Procedure to Abandon the surface of Red Dog #1 for final abandonment: Install reconditioned tree. 2. Have valve crew pull TWC (4" CIW Type `H') 3. RU SL and tag top of downhole cement plug to verify the depth is at 186 ft MD. E 4. Run 1" CS hydrill to top of cement plug at 186 ft MD. RU Kelly hose to top of CS hydril and. line up to circulate out Methanol. ~ _ ,~ r i 5. Circulate Methanol to surface. 6. Circulate cement to surface. 7. Excavate around wellhead and prep to remove casing and wellhead. 8. Cut off and remove the casing and wellhead a minimum of 4' below original tundra level. a. Notify Inspector of opportunity to witness cut off prior to welding plate. 9. Fill any other unfilled annuli to surface with cement. 10. Place an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. Red Dog #1 PTD# 198-252 API# 60-089-20027 ` .. • Red Dog #1 Permit No. 198-252 API No. 60-089-20027 Current Status Methanol 20' to 186' M D Cement Plug #4 (186' MD to 286' MD) Diesel 286' M D to 3050' M D Cement Plug #3 9-5/8" x 13-3/8" annulus Permafrost E (surface to 2395' MD) Premium (2395' to 5292' MD) Estimated Top of Cement Behind the 9-5/8" casing @ 13,950' MD (8780' TVD) Methanol sel 20" 91.5# H-40, BTC @ 80' MD (80' TVD) ~ 9-5/8" EZSV @ 286' MD 13-3/8" ES Cementer @ 2133' MD 13-3/8" 68# L-80, BTC @ 5302' MD (4447 TVD) 13.6 ppg 13.6 ppg KCI Polymer Drilling Mud KCI Mud (3050' MD to 15,587' MD Cement Plug #2 15,587' MD - 15,687' MD 9-5/8" EZSV @ 15,687' MD 9-5/8" 47# P-110, SLHC @ 15,850' MD (9699' TVD) ^ 15.8 ppg Premium Cement ^ 12.0 ppg Permafrost "E" Cement ® Cement in Place Prior to Abandonment ^ 15.6 ppg Permafrost "C" Cement 15.8 PP9 Cement Plug #1 ~! premium i 15,723' MD to 19,292' MD , Cement i i i i ~ I 1 i ~ 14. PPS PP8 9 ii i KCI Mud i _~ Possible Oil & Gas Bearing Zones from 16,840' MD to 19.250' MD 8-'/~' Openhole TD @ 19,400' MD (12,371' TVD) ^ 13.6 ppg KCI Polymer Drilling Mud ^ 14.8 ppg KCI Polymer Drilling Mud ~, • Cement Plug #3 9-5/8" x 13-3/8" annulus Permafrost E (surface to 2395' MD) Premium (2395' to 5292' MD) Red Dog #1 Permit No. 198-252 API No. 60-089-20027 Proposed Status ^ Diesel Oft Cement in Place Prior to Abandonment • 20" 91.5# H-40, BTC @ 80' MD (80' TVD) Tundra Surface Cement Plug (Surface to 286' MD) Diesel 286' M D to 3050' M D 9-518" EZSV @ 286' MD 13-3/8" 68# L-80, BTC @ 5302' MD (4447' TVD) Estimated Top of Cement Behind the 9-5/8" casing @ 13,950' MD (8780' TVE) 6 ppg I Mud 13.6 ppg KCI Polymer Drilling Mud (3050' MD to 15,587' MD Cement Plug #2 15,587' MD - 15,687' MD 9-5/8" EZSV @ 15,687' MD 9-5/8" 47# P-110, SLHC @ 15,850' MD (9699' TVD) i a i i 15.8 ppg ~ Cement Plug #1 'Premium ~ ~i i 15,723' MD to 19,292' MD , Cement i i ~ ~ i ~ ~ i ~ ~ 14.8 ppg i i KCI Mud i 15.8 ppg Premium Cement ^ 15.6 ppg Permafrost "C" Cement ^ 12.0 ppg Permafrost "E" Cement Possible Oil & Gas Bearing Zones from 16,840' MD to 19,250' MD 8-'/z" Openhole TD @ 19,400' MD (12,371' TVD) 13.6 ppg KCI Polymer Drilling Mud ^ 14.8 ppg KCI Polymer Drilling Mud •~,p,EOFq,~~, • CONFIOENTI~L ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ^ Oil ^ Gas ®Suspended ^ Abandoned ^ Service 2. Name of Operator BP Ex !oration Alaska Inc. 7. Permit Number 98-252 399-047, 399-057 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 8. API Number 50-089-20027 4. Location of well at surface - --- 1683` NSL, 4507' WEL, SEC. 34, T10N, R21 E, UM ~ ``~~~ °'+- ` ~~'+ ". 9. Unit or Lease Name Exploration At top of productive interval f 1 ~ 2824' NSL, 1466' WEL, SEC. 21, T10N, R21 E, UM (-T~~, ~ ,~_ 10. Well Number Red Dog #1 a At total depth ~~ '°~"~l~ 4010' NSL, 1885 WEL, SEC. 21, T10N, R21 E, UM =_' "~^-_. _ ; ` ~ 11. Field and Pool Prudhoe Bay Field 1 Undefined Pt. 5. Elevation in feet (indicate KB, DF, etc.) DF = 43.95' 6. Lease Designation and Serial No. ADL377013 Thomson Pool 12. Date Spudded 1/25!99 13. Date T.D. Reached 3/26/99 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 4/2/99 N/A MSL 16. No. of Completions One 17. Total Depth (MD+TVDy 19400 12379 FT 18. Plug Back Depth (MD+TVD) 19400 12379 FT 19. Directional Survey ®Yes ^ Na 0. Depth where SSSV set N/A MD 21. Thickness of Permafrost 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, Sonic, Gyro, GST, CDR, PWD, I-Sonic, ADN, RAB, FMI, DSI, NGT, RES / AiT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, CMR, AIT 23. CASING LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 60 sx Arctic Set A rox. 13-3/8" 68# L-80 Surface 5302' 16° 7 sx PF E, 538 sx 'G', 1800 sx PF E, 200 sx PF C 9-5/8" 53.5# / 47# P-110 Surface 15850' 12-1 /4" 830 sx Class 'G' 24. Perforations open to Production (MD+TVD o f Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~ ~° ~ DEPTH INTERVAL (MD) AMOUNT $c KIND OF MATERIAL USED 15723 4 Abandonment Plugs w/ 342 Bbls Class 'G' y ~ ~, ~~ ~~~ 15687' Set EZSV with 7 Bbls Class 'G' above (100') ("' ~ t -} 286' Set EZSV with 7 Bbls PF 'C' m~jgSjpi": Surface - 3050' Freeze Protect wl 13 Bbls McOH & 135 Bbls Diesel 27, hOf"d t; PRODUCTION TEST Date First Production Not on Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure ALCULATED 4-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Middle Brookian Sands: 16,843-18,420' MD; Bedded to thin-bedded sandstones, light to medium gray quartz (60-90%) and lithic rock ragments (10-40%), very fine to fine grained, angular to sub-rounded, disaggregated, poorly to moderately sorted. Log porosity 14-184°, no fracturing evident; bed dips in interval are 5-10ra, generally to the northeast. Samples exhibit light to heavy oil staining, with faint yellow cut and fluorescence. Most sands had associated mudlog gas shows and the oil gravity in uppermost sand is 16e API. ORlGlNA~ Form 10-407 Rev. 07-01-$0 Submit In Duplicate a s uuNr~utN~i~~ Days ` -. ,, --_,..: ~ since MDITVD (ft) p g Daily Summary 06:00 to 06:00 Dat ( p ) s ud 25-Mar-99 58.3 18940/11940 14.7 POOH to s oe. Pertormed pen Hofe FIT to 16.8 ppg EMW. RIH to bottom. Drill to 18940 ft. Motor failed. POOH to 2500 ft. 26-Mar-99 59.3 19074/12065 14.7 POOH. Change mud motor. RIH to 18940 ft. Drill to 19074 ft. 27-Mar-99 60.3 19400/12379 14.9 Drill to 19400 ft. Well TD. Stood back one stand. Stuck pipe. Work pipe. Pipe came free. Circulate. 28-Mar-99 61.3 19400/12379 14.8 Backream to 18320 ft. POOH. M/U Mule shoe on 5° DP. RIH to 15850 ft. 29-Mar-99 62.3 19400/12379 14.8 RIH to 19292 ft. Circulate. Set suspension cement plugs at 19292 ft, 18386 ft and 17385 ft. 30-Mar-99 63.3 19400/12379 14.6 Set suspension plug at 16508 ft. POOH to top o cement at 15380 ft. Circulate. POOH. Repaired Top Drive. RIH with bit and scraper to 15000 ft. 31-Mar-99 64.3 15723/9638 14.2 RIH to top of cement at 15723 ft. Set down 30 klb. Circulate and condition mud. POOH. RIH with EZSV and running tool to 13000 ft. 1-Apr-99 65.3 15723/9638 13.6 RIH to 15687 ft. Selz EZSV. Con~- aet,wittk3aJi~1. Pump cement plug on top of EZSV. POOH to 14250 ft. Circulate and condition mud. POOH to 3050 ft. Test casing to 2500 psi for 10 min. Ok. Displace wellbore with water. HBR pump 135 bbl diesel. NOTE: Downsquee2ed 13-3/8" by 9-5/8` ann~d~ with i73 bbls Premi~n Cement and 143 bbd of Isam~#rost E Cemertt. 2-Apr-99 66.3 15723/9638 - 'U° tube diesel. POOH. R1N with EZSV to 286 ft. Set EZSV and circulate with water. Test with 500 psi for 5 min. Ok. Tag EZSV with 10 klb to verify set. a-tt~of EZ3V:~Circuiate and displace to methanol. POOH. Install tubing hanger andtwo-way check valve. N/D flow line. Remove BOP sections. 3-Apr-99 66.7 15723/9638 - Remove BOP stack. Install Xmas tree. Test to 50110 psi for 10 min. Ok. RIG RELEASE 1600 hr on 04/02/99. bp . . Date 05-24-2007 Transmittal Number:92892 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Log Top SW Name Date Contractor Run Depth Bottom Depth Log Type FINAL EDITED WELL LOG REDDOG-01 04-03-2007 BPXA DATA CD ROM 1h-.o_ oJkJ pi. <1""",,\ J.H.., Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center -# I !: I ~- cr Attn: Howard Okland \Aþ>.'i .2, 9 1.\)tJl S~t1e:> Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 "8- 2. )-l.. j /.;...... It( MICROFilMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm_marker.doc Subject: Re: Well linspections Date: Tue~ 07 Sep 1999 08:34:00 -0800 From: Blair Wondzell <blair wondzelN~3admin.state.~fl{.us> Organization: State of Alaska, DeN of Admire ~)il 8: Gas To: Leon lynch <leont((;dnr.state.ak.as> Thanks for your memo. Blair Leon Lynch wrote: All the sites were acc%~Sable to D~R for closure as they ~-ere free of trash and d~bris~ As I understand it~ the Com~ission also checks ~o see if P/A ~eils have sufficient mounding around well cellar to prevent ponding. This requirement ~as satisfied ac Meltwater South and Fiord 5~ Fiord 4 was drilled on a tidal flat and subject to wave action- no mound ~as located. Red Dog ~as suspended. Please cal me if you have anv further ~ues~ions. ' Blair Wondzell > Thanks for the > Could you > the wording in > DAFR; Red Dog > for a P~% locac Leon, z appreci, Thanks, Blair 9 9/7/99 8:34 AM MEMORANDUM State of Alaska - Department of Natural Resources - Division of Land 3700 Airport Way, Fairbanks, AK 99709-4613 To: FROM: Blair Wondzell AOGCC Leon Lynch Natural Resource Officer E-MAIL ADDRESS: ~: . . :~-' .~ : DATE: August 26, 1999 FILE NO.: TELEPHONE:451-2724 leonl@dnr, state, ak. us SUBJECT: WELL INSPECTIONS As you know, ARCO failed to contact the Commission prior to scheduled exploration well inspections during the first week in August 1999. To avoid having ARCO make two trips to these remote sites I offered to take pictures of the following well sites for the Commission and you agreed to this arrangement. In general I found all the well sites to be in good order. They were clear of trash and debris and with the exception of Fiord #4, there was adequate mounding around well cellar to prevent ponding. Fiord 4 was on a mud flat subject to tide action and no mound was present. The pilot had been to the Fiord 4 location prior to my visit with an ARCO surveyor, and by using the same GPS coordinates, he was confident of general well location I am enclosing the following photos taken from helicopter: I apologize for the Red Dog photos but as John Spaulding can attest it was a very foggy day; the pilot got in and out fast. 40- 2 5-? Photos #1 and #2 Red Dog. qg-oo(o Photo #3, Meltwater South. 99-0~:~ Photo ~4, Fiord #5. --- - 99-0/6 Photo #5 Fiord #4. - - Attention: Subject: BP EXPLORATION, Alaska Date: Trans: 0412711999 90473 Howard Okland (Alaska Oil & Gas Conservation Commission) RED DOG - MULOGS & CORRECTED DIGITAL LOG DATA Enclosed are the materials listed below. If you have any questions please contact David Douglas in the BP Exploration (Alaska), Inc. Petrotechnical Data Center at (907) 564-5929. Record Type Record Date Company Description Media/Quantity WELL SUMMARY APRIL 1999 SPERRY ADT FINAL WELL SUMMARY 1 BINDER W/COLOR PLOTS & ASCII DISKS MUDLOG 23-FEB-1999 thru SPERRY COMBINATION GAS SHOW 1 BLUEPRINT & I SEPIA 26-MAR-1999 LOG (MD 2'/100') 1 FILM MUDLOG 25-JAN-1999 thru SPERRY COMBINATION MUD LOG 1 BLUEPRINT & 1 SEPIA 26-MAR-1999 (MD 2"/100') 1 FILM MUDLOG 25-JAN-1999 thru SPERRY COMBINATION MUD LOG 1 BLUEPRINT & 1 SEPIA 26-MAR-1999 (TVD 2"/100') 1 FILM MUDLOG 25-JAN-1999 thru SPERRY ENGINEERING LOG 1 BLUEPRINT & 1 SEPIA 26-MAR-1999 (MD 2"/100') 1 FILM CORRECTED 04-15-1999 SCH & ANA EDITED WIRELINE & LWD 1 8MM TAPE with LISTING TAPE DATA (TAR FORMAT) Please sign and return one copy of this transmittal letter. RECEIVED Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA CONFIDENTIAL ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 98-252 399-047, 399-057 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-089-20027 .,. 4. Location of well at surface ....... ~r 9. Unit or Lease Name 1683' NSL, 4507' WEL, SEC. 34, T1 ON, R21 E, UM~....~" "':¢:"~';;"~:' :;::.; '''r~r) Exploration "~ :Uir'! At top of productive interval ~/¢'/-"'?;,~,,-~_ :- ' ,10. WellNumber · 2824' NSL, 1466' WEL, SEC. 21, T10N, R21E, UM ;- ........ +~. Red Dog #1 At total depthr,q~_~_~.,_~U ..... ;- , il 1. Field and Pool 4010' NSL, 1885 WEL, SEC. 21 T10N, R21E, UM ....... '; ........ Prudhoe Bay Field / Undefined Pt. 5. Elevation in foot (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Thomson Pool DF = 43.95' ADL377013 12. Date Spudded1/25/99 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if Offsh°re I 16' NO' Of C°mpletiOns3/26/99 4/2/99 N/A MSLI One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+-I-VD)I19. Directional Survey 120. Depth where SSSV set 121 . Thickness of Permafrost 19400 12379 FTI 19400 12379 FTI [~Yes I--}No N/A MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, Sonic, Gyro, CST, CDR, PWD, I-Sonic, ADN, RAB, FMI, DSl, NGT, RES / AlT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, CMR, AlT 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-I-rOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) ........ 13-3/8" 68# L-80 Surface 5302' 16" 547 sx PF E, 538 sx 'G', 1800 sx PF E, 200 sx PFC 9-5/8" 53.5#/47# P-110 Surface 15850' 12-1/4" 830 sx Class 'G' .... 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD i26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~,, 15723 4 Abandonment Plugs w/342 Bbls Class 'G' i.~i,.~¥ (~,~-; lt?)~!!i; 15687' Set EZSV with 7 abls Class 'G' above (100') 286' Set EZSV with 7 Bbls PF 'C' ,,f"0~iSSiO~': Surface - 3050' Freeze Protect w/13 Bbls MeOH & 135 Bbls Diesel 27. ~.li~l'.~"" '~ ~,~,h-0ragl?, PRODUCTION TEST ' Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL [CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I FioTM Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE ..... 28. CORE DATA ........ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Middle Brookian Sands: 16,843-18,420' MI'); Bedded to thin-bedded sandstones, light to medium gray quartz (60-90%) and lithic rock fragments (10-40%), very fine to fine grained, angular to sub-rounded, disaggregated, poorly to moderately sorted. Log porosity 14-18%, no fracturing evident; bed dips in interval are 5-10~, generally to the northeast. Samples exhibit light to heavy oil staining, with faint yellow cut and fluorescence. Most sands had associated mudlog gas shows and the oil gravity in uppermost sand is 16~ APl. ORIGINAL 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. Top of Canning 14035' 8821' Top of Middle Brookian 16843' 10191' Sands Base of Middle Brookian 18420' 11466' Sands Top of Hue/Shale Wall 19295' 12277' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Formation Integrity Tests (One copy of each of the Surveys and Disks have already been distributed to you by the PDC department.) ~2. I hereby certify~hat the ~or~s true and correct to the best of my knowledge ~'/~/~ Signed ~~ - 5~ Floyd Hernandez Title Senior Drilling Engineer Date Red Dog #1 98-252 399-047,399-057 Prepared By Name/Number: Terrie Hubble, $64-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 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 Operator BP Exploration Performance Enquiry Report Date 23:40, 21 Apr 99 Formation Integrity Test- Red Dog 01 Page CONRDENTIAL The analysis is from - 11:00, 12 Feb 99 - to - 08:30, 24 Mar 99 Programs in Result Table: Red Dog 1 Drill and Complete Well Type Red Dog 1 Event Red Dog 1 Event Time From Time TO Duration Description E.M.W.(equivalent mud weight) 11:00, 12 Feb 99 11:00, 12 Feb 99 0 hr 0 min Obtained leak off 12.5 08:30, 24 Mar 99 08:30, 24 Mar 99 0 hr 0 min Obtained required level of integrity 16.8 Depth MDR 6675.0 18940.0 Hole Size MDR 12-1/4 8-1/2 REd-dOG #1 - DALLY OPERATIONS R'r=-~r--~RT CONFIDENTIAL Report MD/TVD (ft) Date Daily Summary 06:00 to 06:00 26-Jan-99 0.3 305/305 8.8 Spud Red Dog #1 well at 2330 hrs on 1/25/99. Drill to 128 ft. Circulate and condition cement contaminated mud. Drill to 305 ft. 27-Jan-99 1.3 1019/1019 8.9 Drill F/305 ft to 1019 ft. P/U HWDP. Service Top Drive. 28-Jan-99 2.3 1537/1537 9.7 Drill/Slide F/1019 ft to 1537 ft. Circulate. POOH. Change bit and motor bend. RIH to 1537 ft. Repair Top Drive. 29-Jan-99 3.3 2966/2932 9.8 Drill F/1537 ft to 1634 ft. Repair Top Drive and break saver sub. Drill and slide F/1634 ft to 2966 ft. 30-Jan-99 4.3 3780/3594 9.8 Drill/Slide F/2966' to 3478'. Short Trip to 1500'. Some tight spots RIH. Drill/Slide to 3780'. 31-Jan-99 5.3 4200/3575 9.8 Drill/Slide F/3780' to 4158'. Build rate unacceptable. Trip for new bit and MWD. Service Top Drive. RIH hit tight spot at 3388'. Washed to 4158'. Drill/Slide to 4200'. 1-Feb-99 6.3 5303/4448 10.1 Drill/Slide from 4200' to TD at 5303'. TD picked by geologist. Circulated hole clean. Wiper trip. 2-Feb-99 7.3 5303/4448 10.1 RIH. Circulate and condition mud to run casing. BHA Laid out. P,/U casing. Run 13-3/8" casing to 4200ft breaking circulation at 3100'. 3-Feb-99 8.3 5303/4448 10.1 Run csg to 5301' -130 jts 13-3/8" 68# L-80 BTC. FS 5301.5. FC 5258', LC 5215.5', ES cmtr 2133'. Pump 1st stage: 547sx lead, 538 sx tail. 6 BPM. Displace w/mud. Open ES cmtr. Pump 2nd stage. (1800sks lead, 200sks tail). Drop closing plug. N/D divertor. Set slips and make rough cut on 13-3/8" casing 4-Feb-99 9.3 5303/4448 10.1 Make final cut on 13-3/8" casing. Weld transition nipple and test. Allow weld to cool. Clean pits and perform maintenance on top drive. R/U wellhead and test to 1000 psi. R/U BOPE. 5-Feb-99 10.3 5303/4448 8.7 N/U BOPE. Slip/Cut Drill line. RIH p& PU new drill pipe. Repair Top Drive. Tag ES cementer at 2133'. Circ mud out w/water. Test BOP & ES w/1000 3si. Test OK. Drill out ES and test same. Top rams and Hydril were leaking. Currently investigating. 6-Feb-99 11.3 5303/4448 8.7 Attempt to test csg after drilling ES cementer -Failed. BOP rams leaking. Ram elements and seals OK. POOH & L/D BHA. Test surface equip-OK. Test csg with shear rams. Test failed. RIH with RTTS at 60', 20 stands DP below R-I-I-S. Perform pressure test on Hydril to 3000 psi. Test OK. Pressure tested down DP below R-I-I-S. Test failed. RIH and tag up at 3231'. RTTS at 1263'. R-I-I-S failed to set. POOH to ~nspect RTTS. While POOH found galled threads on Top Drive saver sub. 7-Feb-99 12.3 5303/4448 8.8 POOH and stand back DP stinger. RepairTop Drive. RIH w/R'IFS & bypass valve to 2120' below ES cmtr. Set R-I-r's and test annular side to 3000 psi-OK, ES cmtr not leaking. Test down DP. Test failed. POOH. RIH with BHA #5 and hit resistance at 2540'. Wash and ream to 3374' while tagging up at 3762', 3956', and 4447'. 8-Feb-99 13.3 5303/4448 8.8 Wash & ream to TOC @ 4970'. Close annular & test to 3000 psi-Failed. Drilled 3ast Float collar to 5278'. Pressure test to 850 psi-Failed. POOH & LD HWDP. RIH w/RTTS to 5180'. Set RTTS & close annular. Pressure test annulus to 3000 psi. Test successful. Skid Rig 3" to align BOP with rotary. POOH to test BOPE. 9-Feb-99 14.3 5303/4448 8.8 LD 6 jt.s of DP w/galled threads while POOH. LD RTTS & bypass valve. Left 1 drag block and 4 springs off the R-IFS in hole. M/U another R-I-I-S & RIH to 986'. Test annular to 3000 psi-OK. Test top Variable Bore Rams (VBR) to 3000 psi-Failed. Change VBR to solid 5-1/2" bore rams & test to 3000 psi-OK. POOH and L/D RTTS. Larry Wade w/ AOGCC on location to witness BOPE test. Annular failed during test. Replaced annular packing element. · I I Report I since I MD/TVD (ft) Daily Summary 06:00 to 06:00 Date I spud l (PPg) CONFIBENTI L 10-Feb-99 15.3 5303/4448 8.8 CO Hydril element & test to 3500 psi-OK. M/U Mill & boot baskets & RIH. Mill cement & junk from 5278' to 5300'. Drill float shoe & rat hole to 5303'. Perform 4 LOT w/Halliburton and once with Rig pumps. Results skewed. Evaluate LOT with office. 1 l-Feb-99 16.3 5303/4448 8.8 Perform LOT retest. Results show possible permeable zone. POOH. Recover 2 springs & metal filings. RIH with mule shoe. Perform injection tests. 1 BPM = 1030 psi. 2 BPM = 1160 psi. Pumped 60 bbls. of balanced cement plug. Pulled 8 stands. Performed hesitation squeeze with 200 psi and 10 min intervals to 850 psi. Total of 7 bbls. squeezed. Hold back pressure for 4 hrs. Bled back to 650 in 4 hrs. POOH. 12-Feb-99 17.3 5303/4448 8.8 POOH. RIH with singles to 2310' and then rack back 22 stands. M/U BHA #8. RIH to 5020' with singles, tag cement. Drill cement F/5020' to 5291'. Circulate and condition mud prior to drilling last 12' for FIT at shoe. 13-Feb-99 18.3 6675/5150 8.9 Pressure test casing at .5 BPM to 500 psi. Test good. Performed FIT at shoe to 11.7 EMW. Test good. Drilled 10' of new formation. Performed LOT and obtained 12.5 EMW. LOT witnessed by AOGCC's Lou Grimaldi. Displace mud to LSND. Drilled F/5314' to 5588'. Stopped to circulate due to shakers blinding off. Drilled F/5588' to 6675' while optimizing shakers and ~ncreasing flow rate from 730 GPM to 850 GPM. 14-Feb-99 19.3 7845/5758 9.3 Drilled to 6774'. C&C for short trip to shoe. Pulled tight @ 6495'. Backreamed to 5051'. RIH & hit tight spot @ 6495'. Wash & ream to 6774'. Circulate until @ 850 GPM & shakers clean up. Drilled F/6774' to 7456'. Stopped to repair washout in standpipe. Drilled to 7845'. Circulate for gyro run. 15-Feb-99 20.3 8925/6332 9.3 Circulated for gyro run. Run Gyro. Circulate to condition hole. Drilled F/7845' to 8925' while stopping intermittently to change shaker screens. EP Mud Lube added to mud to reduce torque. 16-Feb-99 21.3 9010/6377 9.6 Drilled F/8925' to 9010'. Circulate two bottoms up for trip. POOH. Hole swabbing and tight. Backream to shoe. POOH to BHA. L/D BHA. Service Top Drive. 17-Feb-99 22.3 9010/6377 9.6 Serviced Top Drive. Test BOPE. Test ok. RIH to 4100' with singles to have enough DP to reach TD. Slip and cut drill line. RIH to 6400'. Reamed to 6515' to perform roll test for in hole reference. Ream through clays to 7359'. 18-Feb-99 23.3 10425/7101 9.7 RIH to 9010'. Roll test MWD @ gyro interval - azimuth no good due to magnetic interference. Reaming clays to TD. New surveys OK. Drill to 10019'. Circ hi destiny sweep. Short trip to 8950'-max 280K PU. MAD pass for sonic. RIH to 10019'. Drill to 10425'. 19-Feb-99 24.3 11283/7535 9.7 Drilled to 11284'. CBU. Perform wiper trip to shoe. Hi/lo sweep did not show increase in cuttings. POOH to shoe. Hole clean. RIH to 6612' & perform roll test at IHR depth. RIH to 11284'. CBU. Drill to 11445'. 20-Feb-99 25.3 13050/8303 9.8 Drilled to 13030'. Pumped sweep and CBU. Hole in good condition. Short trip over drilled interval to 11187'. RIH. Drilled to 13050'. 21-Feb-99 26.3 14051/8829 9.9 Drilled to 13707'. Top drive failed - serviced top drive pipe handler. Drilled to 14061' 22- Feb-99 27.3 15055/9316 10.9 Drilled to 14289'. CBU 2 volumes. Raise MW to 10.3 ppg. Short trip to 12640'. Service top drive. RIH to 14192 reaming to bottom (precaution). Drilled top 14968'. Raise MW to 10.8. CBU. Drilled to 15055', increasing MW to 10.9 ppg. 23-Feb-99 28.3 15853/9700 10.5 Drilled to 15322'. CBU while determining casing point. Drilled to 15853', 9700' TVD. CBU. POOH to 11800'. Circulate to clean hole of cuttings & excess wall cake. 24-Feb-99 29.3 15853/9700 11.0 CBU at 11800'. Continue to POOH, backreaming intermittently from 10408'- 7700'. Circulte and POOH to shoe. LD 18 jts excess drill pipe. Slipped & cut drill line. Serviced top drive motor & changed out ele~fo~ ~"3~ TD, no tight spots. CBU. & Gas Cons, Anchorage ReportIsince MD/TVD (ft Daily Summary 06:00 to 06:00 Datei spud ( ) 25-Feb-99 30.3 15853/9700 11.0 Circulate Sweeps. Top Drive Motor Failure. Circulate while diagnose top drive. Spot 3% Lube-tex pill on bottom. POOH to shoe. Service top drive. Backreamed to 5000' to clean any cuttings beds inside casing. 26-Feb-99 31.3 15853/9700 11.0 Continued backreaming to 2960'. POOH to 500'. LD BHA. Prepapred to run 9- 5/87" casing. Ran casing to 160'. Stopped to re-align top drive over hole. Ran casing to 500'. Stopped to thaw pressure lines. 27-Feb-99 32.3 15853/9700 11.0 Attempted top thaw standpipe. Unable to thaw - decide to run casing to shjoe and thaw at that time. Ran casingto 5265'. Dsplaced annuls with new mud/EP Mudlube pill. Rigged up standpipe to Frank's tool. Ran casing to 7887'. 28-Feb-99 33.3 15853/9700 11.0 Ran 9-5/8" casing to 15845'. Circulated, bringing rate up to 12 bpm. Rigged up cement head, Mixed and pumped slurry. 1-Mar-99 34.3 15853/9700 11.0 Pumped 170 bbl cement. Bump plug. Remove BOP. Set slips with 160 klb. Cut casing. Trouble installing pack off. Test pack off to 4000 psi. 2-Mar-99 35.3 15853/9700 11.0 Pressure test casing to 3500 psi for 30 min. Ok. RIH with 5-1/2" DP. Lay down pipe. 3-Mar-99 36.3 15853/9700 10.9 Continued laying down 5-1/2" drill pipe. Change rams to 5% Prepare for BOPE test to 9000 psi. 4-Mar-99 37.3 15853/9700 10.7 Test BOP to 9000 psi. Ok. Replaced top drive traction motor. Pick up 5" drill pipe and rack back. 5-Mar-99 38.3 15853/9700 11.4 Pick up 5" DP and stand back. Make up 8-1/2" BHA. RIH to 8050 ft. 6-Mar-99 39.3 16003/9771 11.5 RIH to 15720 ft (Landing Collar) and test casing to 5050 psi for 30 min. Ok. Drilled out. High torque. Displaced well to 11.4 ppg KCI polymer mud. Drill 20 ft new hole. Performed FIT to 17.5 ppg EMW. Drilled to 16003 ft. 7-Mar-99 40.3 16645/10079 12.0 Drilled to 16645 ft. Unable to drop angle. Circulate bottoms up. 8-Mar-99 41.3 16645/10079 12.3 POOH. Change GST motor. RIH to 16016 ft. Wash down to 16645 ft. 9-Mar-99 42.3 17012/10290 12.4 Drilled to 17012 ft. 10-Mar-99 43.3 17358/10559 12.7 Drilled to 17358 ft. 11-Mar-99 44.3 17364/10568 13.2 Drilled to 17364 ft. Circulate. 8 std short trip. Increase mud weight to 13.2 ppg. POOH to 13050 ft. 12-Mar-99 45.3 17364/10568 13.2 POOH. Test BOP. Make up BHA #13 w/S73HPX PDC bit. RIH to 15920 ft. Circulate at 9-5/8" casing shoe. 13-Mar-99 46.3 17790/10919 13.5 RIH to 17364 ft. Hole in good condition. Circulate and increase mud weight to 13.5 ppg. Drilled to 17790 ft. 14-Mar-99 47.3 18706/11722 14.0 Drilled to 18706 ft. 15-Mar-99 48.3 18740/11754 14.0 Drilled to 18740 ft. Short trip 5 std. Wiper trip to shoe. POOH. 16-Mar-99 49.3 18740/11754 14.0 R/U Schlumberger. RIH and log with FMI+DSI+NGT. FMI failed, Re-run FMI. Unable to get down in open hole. RIH with FMI (reconfigured tool). Wireline short. Change out wireline spool. 17-Mar-99 50.3 18740/11754 14.0 RIH and log with FMI. RI H with PEX+CMR+AIT. Unable to get below 16300 ft. Make up BHA #14 to perform a wiper trip. Wipe out possible ledges. 18-Mar-99 51.3 18740/11754 14.0 Circulate on bottom (18740 ft). Perform wiper trip to shoe. Hole in good condition. POOH. 19-Mar-99 52.3 18740/11754 14.0 RIH with PEX+CMR+AIT in wireline. Unable to get down in openhole. POOH. Run PEX+CMR+AIT in drillpipe. RIH to 15920 ft. 20-Mar-99 53.3 18740/11754 14.0 Log down with PEX+CMR+AIT conveyed on 5" drillpipe to 18740 ft. Log out of hole to 15850 ft. Circulate and condition mud at shoe (barite sag). 21-Mar-99 54.3 18740/11754 14.0 Circulate and condition mud. POOH. Test BOP to 9000 psi. Ok. RI H with RFT conveyed on 5" drillpipe to 10000 ft. 22-Mar-99 55.3 18740/11754 14.0 RIH with RFT. Take pressures and samples. Set down on ledge at 17427 ft. Tool failed. POOH to 15800 ft. 23-Mar-99 56.3 18740/11754 14.0 POOH. Make up drilling assembly. RIH. Shallow test MWD. Failed. POOH. Change receiver sub. RIH to 15800 ft. 24-Mar-99 57.3 18740/11754 14.5 Circulate and condition mud at shoe. Rill to 17385 ft. Precautionary wash down to 18740 ft to condition mud. Circulate on bottom. POOH to shoe to perform integrity test. UUNklU NIIt L ReportIsinceIMD/I'VD (ft Daily Summary 06:00 to 06:00 DateI spud l ( ) 25-Mar-99 58.3 18940/11940 14.7 POOH to shoe. Performed Open Hole FIT to 16.8 ppg EMW. RIH to bottom. Drill to 18940 ft. Motor failed. POOH to 2500 ft. 26-Mar-99 59.3 19074/12065 14.7 POOH. Change mud motor. RI H to 18940 ft. Drill to 19074 ft. 27-Mar-99 60.3 19400/12379 14.9 Drill to 19400 ft. Well TD. Stood back one stand. Stuck pipe. Work pipe. Pipe came free. Circulate. 28-Mar-99 61.3 19400/12379 14.8 Backream to 18320 ft. POOH. M/U Mule shoe on 5" DP. RIH to 15850 ft. 29-Mar-99 62.3 19400/12379 14.8 RIH to 19292 ft. Circulate. Set suspension cement plugs at 19292 ft, 18386 ft and 17385 ft. 30-Mar-99 63.3 19400/12379 14.6 Set suspension plug at 16508 ft. POOH to top of cement at 15380 ft. Circulate. POOH. Repaired Top Drive. RIH with bit and scraper to 15000 ft. 31-Mar-99 64.3 15723/9638 14.2 RIH to top of cement at 15723 ft. Set down 30 klb. Circulate and condition mud. POOH. RIH with EZSV and running tool to 13000 ft. 1-Apr-99 65.3 15723/9638 13.6 RIH to 15687 ft. Set EZSV. Confirm set with 30 klb down. Pump cement plug on top of EZSV. POOH to 14250 ft. Circulate and condition mud. POOH to 3050 ft. Test casing to 2500 psi for 10 min. Ok. Displace wellbore with water. HBR pump 135 bbl diesel, NOTE: Downsqueezed 13-3/8" by 9-5/8" annulus with 173 bbls Premium Cement and 143 bbls of Permafrost E Cement. 2-Apr-99 66.3 15723/9638 "U" tube diesel. POOH. RIH with EZSV to 286 ft. Set EZSV and circulate with :water. Test with 500 psi for 5 min. Ok. Tag EZSV with 10 klb to verify set. Pump cement on top of EZSV. Circulate and displace to methanol. POOH. Install tubing hanger and two-way check valve. N/D flow line. Remove BOP sections. 3-Apr-99 66.7 15723/9638 Remove BOP stack. Install Xmas tree. Test to 5000 psi for 10 min. Ok. RIG RELEASE 1600 hr on 04/02/99. RED F NAL Methanol (20' to 186' MD) Cement Plug #4 (186' MD to 286' MD) Diesel (286' to 3050' MD) Cement Plug #3 (9-5/8" by 13-3/8" annulus) Permafrost E (surface to 2395' MD) Premium (2395' to 5292' MD) EXPLORATION L IJSPENSION SCHEMATIC Dryhole tree installed (2 gate vales) 91.5# H-40, BTC @ 80' MD (80' TVD) 13-3/8" ES Cementer @ 2133' MD (2133'TVD) 286' MD 13-3/8" 68# L-80, BTC @ 5302' MD (4447' TVD) Crossover, 9-5/8" 53.5# P-110, SLHC @ 6686' MD (5156' TVD) -- 13.6 ppg KCL Polymer Drilling Mu( (3050' MD to 15,587' MD) Estimated Top of Cement behind the 9-5/8" Casing @ 13,950' MD (8780' TVD) Cement Plug #2 5,587' MD - 15,687' MD) 9-5/8" EZSV @ 15,687' MD Cement Plug #1 (15,723' MD to 19,292' MD) 9-5/8" 47# P-110, SLHC @ 15,850' MD (9699' TVD) Possible Oil & Gas Bearing Zones from 16,840' MD to 19,250' MD Diesel ~ 15.8 ppg Premium Cement ~15.6 ppg Permafrost "C" Cement 12.0 ppg Permafrost "E" Cement 8-1/2" Openhole TD @ 19,400' MD (12,371' TVD) 13.6 ppg KCL Polymer Drilling Mud I 14.8 ppg KCL Polymer Drilling Mud [] Cement In Place Prior to Abandonment ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 31 2750.00 20.53 352.2 32 2800.00 22.10 352.0 33 2850.00 23.26 352.0 34 2900.00 24.27 352.4 35 2950.00 25.16 352.6 36 3000.00 26.50 352.7 37 3050.00 27.45 352.5 38 3100.00 29.27 351.9 39 3150.00 30.72 351.5 40 3200.00 32.08 351.1 41 3250.00 32.88 351.2 42 3300.00 34.23 351.4 43 3350.00 35.23 351.6 44 3400.00 36.45 351.6 45 3450.00 37.41 351.8 46 3500.00 38.62 352.1 47 3550.00 39.36 352.4 48 3600.00 40.36 352.4 49 3650.00 41.53 352.6 50 3700.00 42.72 352.8 Course length (ft) TVD depth (ft) 26-Mar-99 20:10:34 Page 3 of 10 51 3750.00 44.36 353.0 52 3800.00 46.14 353.2 53 3850.00 47.30 353.7 54 3900.00 47.97 354.3 55 3950.00 47.82 355.1 56 4000.00 48.11 355.4 57 4050.00 47.76 356.2 58 4100.00 48.61 356.3 59 4150.00 48.03 356.7 60 4200.00 48.05 357.0 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 50.00 2733.08 133.04 131.93 -17.31 133.06 352.52 3.28 MWD_M - 50.00 2779.66 151.22 149.93 -19.81 151.23 352.47 3.14 MWD_M - 50.00 2825.79 170.49 169.02 -22.49 170.51 352.42 2.32 MWD_M - 50.00 2871.55 190.64 188.98 -25.23 190.66 352.40 2.05 MWD_M - 50.00 2916.97 211.54 209.71 -27.95 211.57 352.41 1.79 MWD_M - 50.00 2961.97 233.32 231.31 -30.76 50.00 3006.53 256.00 253.80 -33.70 50.00 3050.53 279.75 277.33 -36.93 50.00 3093.83 304.74 302.06 -40.54 50.00 3136.51 330.79 327.81 -44.48 50.00 3178.69 357.64 354.34 -48.61 50.00 3220.35 385.28 381.66 -52.79 50.00 3261.45 413.76 409.83 -57.00 50.00 3301.98 443.04 438.80 -61.28 50.00 3341.95 473.08 468.52 -65.61 50.00 3381.34 503.87 499.01 -69.92 50.00 3420.20 535.33 530.18 -74.16 50.00 3458.58 567.37 561.95 -78.40 50.00 3496.35 600.13 594.43 -82.68 50.00 3533.43 633.67 627.70 -86.94 3569.67 3604.87 3639.15 3672.84 3706.37 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 668.10 661.88 -91.20 703.59 697.12 -95.49 739.98 733.28 -99.67 776.89 770.02 -103.53 813.93 806.96 -106.96 850.99 888.01 925.15 962.35 999.38 843.97 -110.04 880.99 -112.76 918.17 -115.19 955.45 -117.47 992.57 -119.52 3739.85 3773.35 3806.68 3839.93 3873 .36 233.35 352.43 2.68 256.03 352.44 1.90 279.78 352.42 3.68 304.77 352.36 2.93 330.82 352.27 2.75 357.66 352.19 1.60 385.30 352.13 2.71 413.78 352.08 2.01 443.05 352.05 2.44 473.10 352.03 1.93 503.89 352.02 2.45 535.35 352.04 1.53 567.39 352.06 2.00 600.16 352.08 2.35 633.69 352.11 2.40 668.13 352.16 3.29 703.63 352.20 3.56 740.03 352.26 2.48 776.95 352.34 1.61 814.02 352.45 1.22 851.11 352.57 0.73 888.17 352.71 1.38 925.37 352.85 1.71 962.64 352.99 1.30 999.74 353.13 0.45 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M [(c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD depth (ft) 61 4250.00 48.34 356.9 50.00 3906.69 62 4300.00 50.13 356.7 50.00 3939.34 63 4350.00 51.53 356.6 50.00 3970.92 64 4400.00 53.45 356.6 50.00 4001.36 65 4450.00 54.85 356.4 50.00 4030.64 66 4500.00 56.86 356.2 50.00 4058.71 67 4550.00 58.68 355.6 50.00 4085.37 68 4600.00 60.54 354.6 50.00 4110.67 69 4650.00 60.99 353.5 50.00 4135.09 70 4700.00 60.91 353.3 50.00 4159.36 71 4750.00 61.36 353.3 50.00 4183.50 72 4800.00 61.38 353.2 50.00 4207.46 73 4850.00 60.96 351.7 50.00 4231.57 74 4900.00 60.61 351.0 50.00 4255.98 75 4950.00 60.60 350.9 50.00 4280.52 76 5000.00 61.11 350.9 50.00 4304.87 77 5050.00 61.22 351.0 50.00 4328.98 78 5100.00 61.71 351.0 50.00 4352.87 79 5150.00 61.90 351.0 50.00 4376.49 80 5200.00 62.58 351.1 50.00 4399.78 81 5250.00 62.57 351.1 50.00 4422.81 82 5300.00 62.54 351.3 50.00 4445.85 83 5350.00 61.85 351.3 50.00 4469.18 84 5400.00 61.73 351.2 50.00 4492.81 85 5450.00 61.43 351.2 50.00 4516.61 86 5500.00 60.95 351.1 50.00 4540.70 87 5550.00 60.56 351.1 50.00 4565.13 88 5600.00 60.31 351.2 50.00 4589.80 89 5650.00 59.97 351.4 50.00 4614.70 90 5700.00 59.28 351.5 50.00 4639.98 26-Mar-99 20:10:34 Page 4 of 10 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 1036.49 1074.20 1112.81 1152.32 1192.70 1233.93 1276.11 1319.16 1362.75 1406.43 1450.20 1494.07 1537.87 1581.50 1625.06 1668.73 1712.53 1756.45 1800.52 1844.76 1889.14 1933.51 1977.74 2021.80 2065.77 1029.79 -121.50 1036.93 353.27 0.60 1067.60 -123.61 1074.73 353.40 3.59 1106.29 -125.88 1113.43 353.51 2.80 1145.89 -128.23 1153.04 353.61 3.84 1186.34 -130.71 1193.51 353.71 2.82 MWD_M MWD_M MWD_M MWD_M MWD_M 1227.63 -133.38 1234.85 353.80 4.03 MWD_M 1269.81 -136.40 1277.12 353.87 3.78 MWD_M 1312.78 -140.09 1320.24 353.91 4.10 MWD_M 1356.18 -144.61 1363.87 353.91 2.12 MWD_M 1399.60 -149.64 1407.57 353.90 0.38 MWD_M 1443.09 -154.75 1451.36 353.88 0.90 MWD_M 1486.67 -159.91 1495.24 353.86 0.18 MWD_M 1530.09 -165.66 1539.03 353.82 2.76 MWD_M 1573.23 -172.22 1582.63 353.75 1.41 MWD_M 1616.25 -179.07 1626.14 353.68 0.18 MWD_M 1659.37 -185.98 1669.76 353.61 1.02 1702.63 -192.87 1713.52 353.54 0.28 1746.01 -199.74 1757.40 353.47 0.98 1789.54 -206.64 1801.43 353.41 0.38 1833.25 -213.52 1845.64 353.36 1.37 MWD__M MWD__M MWD_M MWD__M MWD__M 2109.58 2153.21 2196.69 2240.06 2283.19 1877.09 -220.39 1889.99 353.30 0.02 MWD_M 1920.94 -227.17 1934.33 353.26 0.36 MWD_M 1964.66 -233.86 1978.53 353.21 1.38 MWD_M 2008.21 -240.57 2022.57 353.17 0.30 MWD_M 2051.67 -247.29 2066.51 353.13 0.60 MWD_M 2094.95 -254.03 2110.30 353.09 0.98 2138.06 -260.78 2153.90 353.05 0.78 2181.03 -267.47 2197.37 353.01 0.53 2223.89 -274.03 2240.71 352.98 0.76 2266.55 -280.45 2283.83 352.95 1.39 MWD_M MWD_M MWD_M MWD_M MWD_M [(c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 5 of 10 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 91 5750.00 59.37 351.3 92 5800.00 58.89 351.2 93 5850.00 58.75 351.1 94 5900.00 58.09 351.0 95 5950.00 58.51 351.6 96 6000.00 58.78 350.1 97 6050.00 58.59 349.9 98 6100.00 57.93 349.6 99 6150.00 57.94 349.4 100 6200.00 58.45 349.3 101 6250.00 58.76 349.1 102 6300.00 58.78 348.9 103 6350.00 58.32 348.7 104 6400.00 58.84 349.2 105 6450.00 58.58 349.1 106 6500.00 58.71 348.8 107 6550.00 58.34 348.7 108 6600.00 58.46 348.6 109 6650.00 58.25 348.2 110 6700.00 59.17 348.2 111 6750.00 59.89 348.2 112 6800.00 59.35 348.3 113 6850.00 59.24 348.0 114 6900.00 58.45 348.0 115 6950.00 58.07 347.8 116 7000.00 57.68 347.9 117 7050.00 57.58 347.9 118 7100.00 58.66 348.6 119 7150.00 58.46 348.8 120 7200.00 57.93 348.7 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 4665.49 4691.14 4717.03 4743.21 4769.48 4795.50 4821.49 4847.79 4874.34 4900.69 4926.74 4952.66 4978.75 5004.81 5030.78 5056.80 5082.90 5109.10 5135.34 5161.30 5186.66 5211.95 5237.48 5263.34 5289.65 5316.24 5343.00 5369.41 5395.49 5421.84 2326.20 2369.11 2411.89 2454.48 2497.02 2539.71 2582.41 2624.91 2667.26 2709.72 2752.36 2795.07 2837.67 2880.30 2922.98 2965.63 3008.22 3050.75 3093.25 3135.90 3178.92 3221.98 3264.90 3307.60 3350.03 3392.29 3434.43 3476.82 3519.42 3561.86 2309.07 -286.88 2351.49 -293.41 2393.75 -300.02 2435.82 -306.69 2477.86 -313.16 2520.01 -319.98 2562.08 -327.40 2603.92 -334.97 2645.58 -342.69 2687.34 -350.54 2729.27 -358.54 2771.24 -366.70 2813.08 -374.98 2854.96 -383.16 2896.91 -391.24 2938.81 -399.46 2980.64 -407.78 3022.38 -416.20 3064.07 -424.79 3105.89 -433.53 3148.08 -442.34 3190.31 -451.13 3232.38 -459.96 3274.24 -468.85 3315.81 -477.76 3357.21 -486.68 3398.50 -495.53 3440.07 -504.17 3481.90 -512.53 3523.58 -520.82 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 2326.82 352.92 0.39 2369.72 352.89 0.98 2412.48 352.86 0.44 2455.05 352.82 1.32 2497.57 352.80 1.20 2540.24 352.76 2.45 2582.91 352.72 0.51 2625.38 352.67 1.42 2667.69 352.62 0.34 2710.11 352.57 1.03 2752.72 352.52 0.71 2795.39 352.46 0.34 2837.96 352.41 0.98 2880.55 352.36 1.35 2923.21 352.31 0.62 2965.84 352.26 0.43 3008.40 352.21 0.76 3050.90 352.16 0.42 3093.38 352.11 0.66 3136.01 352.05 1.84 3179.00 352.00 1.44 3222.05 351.95 1.09 3264.94 351.90 0.56 3307.63 351.85 1.58 3350.06 351.80 0.83 3392.30 351.75 0.80 3434.44 351.70 0.20 3476.82 351.66 2.47 3519.42 351.63 0.53 3561.86 351.59 1.07 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD_M [(C)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) Course length (ft) 121 7250.00 57.71 348.9 122 7300.00 59.17 350.1 123 7350.00 58.31 349.8 124 7400.00 58.37 349.5 125 7450.00 58.31 349.4 50.00 50.00 50.00 50.00 50.00 126 7500.00 58.74 349.5 127 7550.00 58.93 349.9 128 7600.00 59.93 350.5 129 7670.95 59.76 349.9 130 7767.97 59.81 349.6 50.00 50.00 50.00 71.00 97.00 131 7866.48 59.58 349.9 132 7962.18 59.03 350.2 133 8060.14 58.42 350.0 134 8157.45 58.04 349.2 135 8255.80 57.52 349.7 98.50 95.70 97.90 97.40 98.30 136 8352.85 57.18 350.8 137 8449.26 57.56 350.7 138 8545.83 56.81 351.9 139 8643.42 57.11 351.9 140 8741.74 56.61 352.7 97.00 96.50 96.50 97.60 98.30 141 8836.54 57.08 352.2 142 8933.26 57.20 353.0 143 9030.81 57.57 351.5 144 9127.49 57.85 352.1 145 9223.77 57.60 352.3 94.80 96.80 97.50 96.70 96.30 146 9320.41 58.92 351.2 147 9417.48 58.67 351.2 148 9514.54 58.62 350.4 149 9612.23 59.90 350.7 150 9708.51 59.70 350.6 96.60 97.10 97.00 97.70 96.30 TVD depth (ft) 5448.47 5474.64 5500.59 5526.83 5553.07 5579.18 5605.06 5630.49 5666.15 5714.97 5764.67 5813.52 5864.35 5915.63 5968.04 6020.37 6072.41 6124.70 6177.92 6231.66 6283.50 6336.03 6388.58 6440.24 6491.66 6542.48 6592.79 6643.26 6693.20 6741.64 26-Mar-99 20:10:34 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3604.13 3646.70 3689.43 3731.96 3774.49 3817.10 3859.86 3902.90 3964.27 4048.05 4133.05 4215.31 4298.96 4381.71 4464.81 4546.46 4627.72 4708.82 4790.64 4872.94 4952.30 5033.59 5115.71 5197.45 5278.87 5361.02 5444.07 5526.89 5610.85 5694.07 3565.09 -529.04 3606.98 -536.80 3649.06 -544.26 3690.93 -551.91 3732.77 -559.70 3774.69 -567.51 3816.79 -575.16 3859.21 -582.48 3919.70 -592.93 4002.19 -607.85 4085.87 -622.98 4166.92 -637.20 4249.35 -651.59 4330.80 -666.53 4412.55 -681.76 4493.04 -695.59 4573.26 -708.65 4653.42 -720.93 4734.42 -732.45 4815.99 -743.48 4894.67 -753.91 4975.30 -764.38 5056.67 -775.46 5137.58 -787.12 5218.25 -798.17 5299.55 -809.96 5381.62 -822.67 5463.37 -835.98 5546.19 -849.84 5628.32 -863.36 Page 6 of 10 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 3604.13 351.56 0.56 3646.71 351.54 3.56 3689.43 351.52 1.79 3731.97 351.50 0.52 3774.50 351.47 0.21 3817.12 351.45 0.88 3859.88 351.43 0.78 3902.92 351.42 2.25 3964.30 351.40 0.77 4048.08 351.36 0.27 4133.09 351.33 0.35 4215.36 351.31 0.63 4299.02 351.28 0.65 4381.79 351.25 0.80 4464.91 351.22 0.68 4546.57 351.20 1.02 4627.83 351.19 0.40 4708.93 351.19 1.30 4790.74 351.21 0.31 4873.04 351.22 0.85 MWD__M MWD_M MWD__M MWD_M MWD__M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD__M MWD__M MWD__M MWD_M MWD__M MWD MWD MWD MWD 4952.39 351.24 0.66 MWD 5033.67 351.27 0.71 MWD 5115.78 351.28 1.35 MWD__M 5197.53 351.29 0.60 MWD_M 5278.94 351.30 0.31 MWD__M 5361.08 351.31 1.67 5444.13 351.31 0.26 5526.96 351.30 0.79 5610.93 351.29 1.36 5694.15 351.28 0.23 MWD_M MWD_M MWD__M MWD_M MWD_M 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- [ (c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report __ Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 151 9806.70 59.45 350.5 152 9904.90 59.20 351,9 153 10002.89 58.85 350.1 154 10101.18 59.77 349.6 155 10199.80 59.51 351.2 Course length (ft) 98.20 98.20 98.00 98.30 98.60 156 10295.49 59.27 348.5 157 10392.36 59.03 348.6 158 10489.45 60.05 348.8 159 10586.88 59.90 349.0 160 10638.76 59.31 348.3 95.70 96.90 97.10 97.40 51.90 161 10781.31 59.25 348.3 162 10877.68 60.43 347.4 163 10974.67 60.22 347.8 164 11071.61 59.99 348.2 165 11169.48 60.99 349.1 142.50 96.40 97.00 96.90 97.90 166 11268.41 60.72 347.9 167 11366.91 60.90 349.3 168 11461.88 61.80 350.0 169 11559.05 61.86 349.7 170 11657.48 62.02 350.1 98.90 98.50 95.00 97.20 98.40 171 11753.94 62.92 351.5 172 11850.88 63.09 351.1 173 11947.05 63.44 350.9 174 12043.88 63.40 351.6 175 12140.66 64.15 352.5 96.40 97.00 96.10 96.90 96.80 176 12238.00 63.95 352.8 177 12335.03 63.51 352.7 178 12432.29 63.42 352.4 179 12528.98 63.49 352.8 180 12625.72 63.34 352.5 97.30 97.00 97.30 96.70 96.70 TVD depth (ft) 6791.37 6841.47 6891.91 6942.08 6991.92 7040.65 7090.34 7139.57 7188.30 7214.56 7287.36 7335.79 7383.81 7432.11 7480.33 7528.50 7576.54 7622.09 7667.98 7714.27 26-Mar-99 20:10:34 Vertical section (ft) 5778.73 5863.19 5947.20 6031.69 6116.75 6199.06 6282.13 6365.72 6449.96 6494.66 Displ Displ Total +N/S- +E/W- displ (ft) (ft) (ft) 5711.85 -877.26 5778.82 5795.31 -890.19 5863.28 5878.29 -903.33 5947.30 5961.50 -918.23 6031.80 6045.38 -932.42 6116.87 6126.45 -946.93 6199.20 6207.98 -963.44 6282.30 6290.04 -979.91 6365.91 6372.78 -996.22 6450.18 6416.67 -1005.03 6494.90 6616.96 6536.63 -1029.87 6617.26 6700.13 6618.11 -1047.42 6700.48 6784.21 6700.42 -1065.51 6784.61 6868.05 6782.59 -1082.98 6868.51 6953,13 6866.12 -1099.74 6953.64 7039.38 6950.76 -1116.96 7039.94 7125.25 7035.06 -1133.96 7125.86 7208.57 7117.07 -1148.93 7209.21 7294.22 7201.41 -1164.03 7294.88 7381.02 7286.90 -1179.26 7381.71 7758.82 7466.49 7371.28 -1192.92 7467.19 7802.85 7552.92 7456.72 -1206.00 7553.61 7846.09 7638.74 7541.49 -1219.42 7639.44 7889.44 7725.40 7627.14 -1232.61 7726.10 7932.22 7812.23 7713.14 -1244.62 7812.91 Page 7 of 10 7974.80 8017.73 8061.20 8104.41 8147.69 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 351.27 0.27 351.27 1.25 351.26 1.61 351.24 1.03 351.23 1.42 351.21 2.44 351.18 0.26 351.15 1.05 351.12 0.31 351.10 1.63 351.05 0.04 351.01 1.47 350.96 0.42 350.93 0.43 350.90 1.30 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M 350.87 1.09 MWD_M 350.84 1.25 MWD 350.83 1.15 MWD 350.82 0.28 MWD 350.81 0.39 MWD 350.81 1.59 MWD 350.81 0.41 MWD 350.82 0.41 MWD 350.82 0.65 MWD 350.83 1.14 MWD 7899.70 7799.91 -1255.81 7900.36 350.85 0.35 7986,67 7886.19 -1266.79 7987.29 350.87 0.46 8073,71 7972.51 -1278.07 8074.30 350.89 0.29 8160,20 8058.29 -1289.21 8160.77 350.91 0.38 8246,66 8144.06 -1300.28 8247.21 350.93 0.32 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 8 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 181 12722.77 62.95 352.6 182 12816.95 62.77 352.2 183 12915.06 62.72 352.6 184 13013.48 62.28 352.4 185 13110.45 62.15 352.2 186 13206.83 61.58 352.6 187 13303.58 61.35 352.4 188 13400.30 60.91 352.2 189 13496.65 60.15 350.8 190 13592.08 60.60 349.4 191 13688.50 60.47 347.8 192 13784.86 60.11 346.0 193 13881.97 60.73 344.4 194 13979.45 60.91 342.7 195 14076.05 60.94 342.8 196 14175.34 60.90 342.8 197 14271.27 61.30 343.3 198 14369.04 61.09 342.0 199 14465.67 60.72 343.0 200 14562.40 60.65 343.0 201 14659.86 60.73 341.7 202 14756.32 60.92 342.9 203 14853.22 61.11 342.6 204 14950.18 61.01 342.7 205 15047.64 61.20 342.7 206 15145.60 61.27 342.7 207 15242.90 61.18 342.5 208 15339.97 60.98 343.0 209 15436.98 61.15 342.9 210 15533.78 61.11 342.6 TVD depth (ft) Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 97.10 8191.55 8333.27 8229.96 -1311.51 94.20 8234.52 8417.09 8313.05 -1322.59 98.10 8279.45 8504.29 8399.49 -1334.13 98.40 8324.88 8591.56 8486.03 -1345.52 96.90 8370.06 8677.29 8570.98 -1357.01 8415.51 8461.75 8508.44 8555.82 8603.03 96.40 96.80 96.70 96.30 95.50 8762.29 8655.24 -1368.25 8847.32 8739.56 -1379.35 8931.99 8823.47 -1390.70 9015.83 8906.39 -1403.08 9098.81 8988.17 -1417.36 96.40 8650.45 9182.63 9070.44 -1433.95 96.40 8698.23 9266.07 9151.98 -1452.92 97.10 8746.17 9349.98 9233.62 -1474.49 97.50 8793.71 9434.27 9315.26 -1498.60 96.50 8840.60 9517.61 9395.80 -1523.61 99.30 8888.86 9603.37 9478.71 -1549.27 96.00 8935.26 9686.48 9559.10 -1573.77 97.70 8982.33 9771.05 9640.81 -1599.30 96.70 9029.36 9854.49 9721.40 -1624.71 96.70 9076.70 9937.86 9802.03 -1649.36 97.50 96.40 96.90 97.00 97.40 98.00 97.30 97.10 97.00 96.80 9124.43 9171.43 9218.38 9265.32 9312.38 9359.54 9406.38 9453.34 9500.27 9547.01 10021.77 9883.04 -1675.14 10104.83 9963.23 -1700.73 10188.59 10044.18 -1725.87 10272.45 10125.20 -1751.18 10356.70 10206.62 -1776.54 10441.57 10288.64 -1802.08 10525.81 10370.02 -1827.59 10609.79 10451.19 -1852.79 10693.72 10532.35 -1877.68 10777.48 10613.31 -1902.82 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 8333.80 350.95 0.41 8417.60 350.96 0.42 8504.78 350.97 0.37 8592.04 350.99 0.48 8677.74 351.00 0.23 8762.72 351.02 0.70 8847.74 351.03 0.30 8932.40 351.04 0.49 9016.23 351.05 1.49 9099.23 351.04 1.36 9183.09 351.02 1.45 9266.59 350.98 1.66 9350.61 350.93 1.57 9435.03 350.86 1.53 9518.54 350.79 0.10 9604.48 350.72 0.04 9687.78 350.65 0.62 9772.57 350.58 1.19 9856.23 350.51 0.98 9939.83 350.45 0.07 10024.00 350.38 1.17 10107.34 350.31 1.10 10191.38 350.25 0.33 10275.52 350.19 0.14 10360.08 350.13 0.20 10445.27 350.07 0.07 10529.84 350.01 0.20 10614.15 349.95 0.50 10698.42 349.89 0.20 10782.53 349.84 0.27 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 9 of 10 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 211 15630.72 61.16 342.8 212 15727.11 61.02 342.6 213 15748.75 61.11 342.6 214 15868.40 61.51 342.7 215 15960.60 62.12 343.0 216 16054.69 62.04 342.8 217 16151.46 61.65 342.5 218 16241.79 61.69 342.6 219 16332.89 61.43 342.5 220 16425.86 61.16 343.6 221 16523.13 60.69 343.2 222 16619.65 59.79 342.1 223 16713.72 57.38 342.9 224 16807.99 54.07 344.2 225 16903.64 51.28 343.4 226 16992.20 47.41 343.7 227 17088.10 43.61 344.7 228 17184.99 39.64 345.3 229 17286.80 36.58 345.0 230 17380.18 34.74 344.6 231 17474.29 34.43 344.3 232 17563.47 34.24 343.8 233 17658.60 33.78 343.5 234 17753.48 33.04 342.7 235 17847.66 32.10 341.3 236 17941.01 31.59 340.9 237 18034.46 30.82 340.0 238 18129.13 29.92 340.0 239 18222.83 29.04 338.9 240 18317.14 28.28 339.1 96.90 96.40 21.70 119.60 92.20 94.10 96.80 90.30 91.10 93.00 97.20 96.50 94.10 94.30 95.60 88.60 95.90 96.90 101.80 93.40 94.10 89.20 95.10 94.90 94.20 93.30 93.50 94.60 93.70 94.30 TVD depth (ft) 9593.78 9640.39 9650.89 9708.30 9751.85 9795.91 9841.59 9884.44 9927.83 9972.49 10019.73 10067.63 10116.67 10169.78 10227.74 10285.45 10352.64 10425.06 10505.15 10581.03 10658.51 10732.16 10810.99 10890.21 10969.60 11048.85 11128.83 11210.44 11292.01 11374.76 Vertical section (ft) 10861.32 10944.69 10963.45 11067.09 11147.42 Displ Displ Total At DLS +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (deg) 100f) __ 10694.33 -1928.06 10866.74 349.78 0.19 10774.90 -1953.15 10950.49 349.73 0.23 10793.02 -1958.83 10969.33 349.71 0.41 10893.16 -1990.12 11073.46 349.65 0.34 10970.82 -2014.08 11154.16 349.60 0.72 11229.61 11313.92 11392.42 11471.53 11552.19 11050.29 -2038.53 11236.75 349.55 0.21 11131.75 -2063.98 11321.48 349.50 0.49 11207.58 -2087.81 11400.38 349.45 0.11 11284.00 -2111.83 11479.91 349.40 0.30 11362.02 -2135.62 11560.99 349.35 1.08 11636.28 11719.03 11798.32 11875.46 11950.77 11443.43 -2159.88 11645.48 349.31 0.60 11523.39 -2184.86 11728.69 349.26 1.36 11599.97 -2209.02 11808.43 349.22 2.66 11674.69 -2231.09 11885.96 349.18 3.69 11747.69 -2252.29 11961.65 349.15 2.99 12017.31 12085.14 12149.07 12211.49 12265.56 11812.14 -2271.33 12028.53 349.12 4.38 11877.95 -2289.97 12096.68 349.09 4.03 11940.10 -2306.64 12160.86 349.07 4.12 12000.83 -2322.73 12223.54 349.05 3.01 12053.37 -2337.00 12277.84 349.03 1.99 12318.56 12368.44 12421.12 12472.80 12522.80 12104.83 -2351.32 12331.08 349.01 0.38 12153.20 -2365.15 12381.21 348.99 0.38 12204.25 -2380.12 12434.17 348.96 0.51 12254.24 -2395.31 12486.15 348.94 0.91 12302.47 -2410.97 12536.49 348.91 1.28 12571.20 12618.73 12665.58 12710.67 12754.80 12349.04 -2426.91 12585.26 348.88 0.59 12394.69 -2443.12 12633.18 348.85 0.96 12439.64 -2459.48 12680.44 348.82 0.95 12482.82 -2475.66 12725.94 348.78 1.10 12525.04 -2491.87 12770.51 348.75 0.81 Srvy tool type MWD MWD MWD MWD_M MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 10 of 10 Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 241 18404.34 27.41 337.8 87.20 11451.86 242 18501.51 26.44 337.2 97.20 11538.52 243 18597.26 25.68 336.1 95.80 11624.58 244 18631.51 25.22 336.6 34.20 11655.47 245 18688.26 24.67 336.7 56.80 11706.97 246 18783.05 23.45 336.1 94.80 11793.53 247 18876.08 21.11 335.7 93.00 11879.58 248 18969.20 19.07 334.3 93.10 11967.01 249 19062.77 18.31 333.1 93.60 12055.68 250 19156.07 17.55 332.5 93.30 12144.44 251 19246.95 16.53 331.7 90.90 12231.35 252 19296.00 16.07 332.0 49.00 12278.38 final 253 survey projected to total depth for well 19400.00 15.00 332.0 104.00 12378.58 --. Vertical Displ section +N/S- (ft) (ft) 12794.47 12562.92 12837.16 12603.58 12877.82 12642.22 12892.00 12655.69 12915.14 12677.68 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type -2506.82 12810.59 -2523.66 12853.76 -2540.33 12894.93 -2546.23 12909.29 -2555.73 12932.72 348.72 1.22 MWD 348.68 1.04 MWD 348.64 0.94 MWD 348.62 1.48 MWD 348.60 0.97 MWD 12952.44 12713.10 12986.39 12745.28 13017.04 12774.27 13045.58 12801.16 13072.77 12826.71 -2571.19 12970.50 -2585.58 13004.90 -2599.08 13036.00 -2612.36 13065.00 -2625.49 13092.65 348.57 1.31 MWD 348.53 2.52 MWD 348.50 2.25 MWD 348.47 0.91 MWD 348.43 0.84 MWD 13097.88 12850.25 -2637.95 13118.22 348.40 1.15 13110.83 12862.38 -2644.44 13131.40 348.38 0.95 13137.07 12886.97 -2657.51 13158.13 348.35 1.03 MWD MWD MWD_M 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID5_0C_03R] RECEIVED APR I 6 1999 B.P. EXPLORATION RED DOG PROSPECT, WELL NO. '1 NORTH SLOPE, ALASKA Gyro Continuous Multishot Survey Inside 5.5" DRILLPIPE Survey date: 14- FEBRUARY, 1999 Job number' AK0299GCE521 CONTENTS JOB NUMBER ' AK0299GCE521 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' AK0299GCE521 Tool 777 was run in WELL# 1 on SCHLUMBERGER 7/32" wireline Communication errors didn't allow an outrun continuous survey to be taken. were good. inside 5.5" DRILLPIPE. The inrun survey results SURVEY CERTIFICATION SHEET JOB NUMBER: AK0299GCE521 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK0299GCE521 CLIENT: B.P. EXPLORATION RIG: NABORS 28 E LOCATION: RED DOG PROSPECT WELL: LATITUDE: 70.20 N LONGITUDE: 147.5 W SURVEY DATE: SURVEY TYPE : DEPTH REFERENCE: MAX. SURVEY DEPTH: 14 - FEBRUARY, 1999 GYRO CONTINUOUS MULTISHOT ROTARY TABLE ELEVATION 43.95' 7600' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 0-7600' APl NUMBER: TARGET DIRECTION: 050-089-2002700 351.59 GRID CORRECTION: CALCULATION METHOD: N/A MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, NORTH SLOPE, ALASKA Job Number: AK0299GCE521 Run Date: 14-Feb-99 09:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.200000 deg. N Sub-sea Correction from Vertical Reference: 43.95 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 351.590 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal ReferenCe A Gyroda t a D i r e c t i ona i Survey ~.P. EXPLORATION HELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, lob Number: AK0299GCE521 NORTH SLOPE, ALASKA ~EASURED DEPTH feet I N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 0 100 200 300 400 .0 .0 .0 .0 .0 .00 0.00 .20 70.58 .15 139.25 .24 135.57 .26 210.78 .00 0.0 .20 100.0 .21 200.0 .08 300.0 .30 400.0 -44 56 156 256 356 .0 .0 .0 .0 .0 500 600 700 800 900 .0 .0 .0 .0 .0 .21 196.76 .31 162.81 .46 144.31 .56 146.91 .41 132.95 .07 500.0 .18 600.0 .19 700.0 .10 800.0 .19 900.0 456 556 656 756 856 .0 .0 .0 .0 .0 1000.0 1100.0 1200.0 1300.0 1400.0 .42 133.98 .52 133.98 .61 142.70 .74 148.10 .89 158.57 .01 1000.0 .11 1100.0 .12 1200.0 .14 1300.0 .21 1400.0 956 1056 1.156 1256 1356 .0 .0 .0 .0 .0 1500 1600 1700 1800 1900 .0 .0 .0 .0 .0 .96 159.58 .89 156.08 .35 218.64 .49 287.35 .04 310.87 .07 1499.9 1456 .09 1599.9 1556 .79 1699.9 1656 .49 1799.9 1756 .63 1899.9 1856 .0 .0 .0 .0 .0 2000 2100 2200 2300 2400 .0 .0 .0 .0 .0 2 3 6 8 11 .46 341.68 .90 351.04 .42 352.04 .98 352.63 .69 350.51 1.66 1999.9 1.53 2099.7 2.52 2199.3 2.56 2298.4 2.73 2396.8 1955.9 2055.8 2155.3 2254.4 2352.8 Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 0.0 .0 - .0 - .3 - .7 -1.0 -1.4 -2.1 -2.9 -3 .6 -4.2 -4.8 -5.6 -6.7 -8.0 -9.6 -11.2 -12.1 -12.1 -11.3 -8.5 -2.9 6.1 19.5 37.4 0.0 0.0 .2 70.6 .4 87.6 .7 109.4 .9 129.8 1.1 151.3 1.5 158.6 2.1 156.5 3.0 153.4 3.8 150.7 4.5 148.0 5.3 145.8 6.3 144.7 7.5 144.9 8.9 146.3 10.5 148.2 12.0 149.5 12.9 151.2 12.8 153.8 11.6 157.1 8.7 158.6 3.3 143.8 6.3 6.0 19.5 356.7 37.4 354.2 0.0 N 0.0 E .iN .2 E .ON .4 E .2 S .7 E .6 S .7 E .9 S .5 E 1.4 S .5 E 2.0 S .9 E 2.7 S 1.4 E 3.3 S 1.9 E 3.8 S 2.4 E 4.4 S 3.0 E 5.1 S 3.6 E 6.1 S 4.3 E 7.4 ~'S 4.9 E 8.9 S 10.4 S 11.3 S 11.4 S 10.7 S 8.1 S 2.7 S 6.2 N 19.5 N 37.2 N 5.5 E 6.1 E ~ 6.2 E 5.6 E 4.5 E 3.2 E 2.0 E .7 E 1.1 W 3.8 W A Gyro da t a D i re c t i o na i Survey {.P. EXPLORATION ~ELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, lob Number: AK0299GCE521 NORTH SLOPE, ALASKA Page ~EASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2500.0 14.04 351.69 2550.0 15.24 351.78 2600.0 16.37 352.27 2650.0 17.67 352.35 2700.0 18.89 352.16 2.37 2494.2 2.40 2542.6 2.27 2590.7 2.60 2638.5 2.44 2686.0 2450 2498 2546 2594 2642 .3 .7 .8 .6 .1 59 72 85 100 116 .7 .3 .9 .6 .2 59.7 353.1 72.3 352.8 85.9 352.7 100.6 352.6 116.3 352.6 59.2 N 7.2 W 71.8 N 9.0 W 85.2 N 10.9 W 99.7 N 12.9 W 115.3 N 15.0 W 2750.0 20.53 352.16 2800.0 22.10 352.03 2850.0 23.26 351.96 2900.0 24.27 352.40 2950.0 25.16 352.60 3.29 2733.1 3.14 2779.7 2.31 2825.8 2.05 2871.5 1.80 2917.0 2689 2735 2781 2827 2873 .1 .7 .8 .6 .0 133 151 170 190 211 .1 .3 .6 .7 .6 133.1 352.5 151.3 352.5 170.6 352.4 190.7 352.4 211.6 352.4 132.0 N 17.3 W 150.0 N 19.8 W 169.1 N 22.5 W 189.0 N 25.2 W 209.8 N 27.9 W 3000.0 26.50 352.65 3050.0 27.45 352.46 3100.0 29.27 351.93 3150.0 30.72 351.47 3200.0 32.08 351.11 2.68 2962.0 1.91 3006.5 3.67 3050.5 2.94 3093.8 2.76 3136.5 2918 2962 3006 3049 3092 .0 .6 .6 .9 .6 233 256 279 304 330 .4 .1 .8 .8 .8 233.4 352.4 256.1 352.4 279.8 352.4 304.8 352.4 330.9 352.3 231.4 N 30.7 W 253.9 N 33.7 W 277.4 N 36.9 W 302.1 N 40.5 W 327.9 ~N 44.5 W 3250.0 32.88 351.16 3300.0 34.23 351.43 3350.0 35.23 351.57 3400.0 36.45 351.62 3450.0 37.41 351.79 1.59 3178.7 2.73 3220.4 2 .00 3261.4 2.45 3302.0 1.92 3341.9 3134 3176 3217 3258 3298 .7 .4 .5 .0 .0 357 385 413 443 473 .7 .3 .8 .1 .1 357.7 352.2 385.4 352.1 413.8 352.1 443.1 352.1 473.1 352.0 354.4 N 48.6 W 381.7 N 52.8 W 409.9 N 57.0 W 438.9 N 61.3 W 468.6 N 65.6 W 3500.0 38.62 352.13 3550.0 39.36 352.38 3600.0 40.36 352.40 3650.0 41.53 352.63 3700.0 42.72 352.84 2.46 3381.3 1.51 3420.2 2.01 3458.6 2.35 3496.4 2.39 3533.4 3337.4 3376.3 3414.6 3452.4 3489.5 503.9 535.4 567.4 600.2 633.7 503.9 352.0 535.4 352.0 567.4 352.1 600.2 352.1 633.7 352.1 499.1 N 69.9 W 530.2 N 74.2 W 562.0 N 78.4 W 594.5 N 82.7 W 627.8 N 86.9 W A Gyro da t a D i r e c t i ona i Survey 3.P. EXPLORATION ~ELL: 1, 5.5" D.P. ~,ocation: RED DOG PROSPECT, ~ob Number: AK0299GCE521 NORTH SLOPE, ALASKA Page ~EASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL DEPTH feet SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 3750.0 44.36 353.03 3.29 3800.0 46.14 353.15 3.56 3850.0 47.30 353.71 2.47 3900.0 47.97 354.33 1.62 3950.0 47.82 355.09 1.16 3569.7 3604.9 3639.2 3672.8 3706.4 3525 3560 3595 3628 3662 .7 .9 .2 .9 .4 668.1 703.6 740.0 776.9 814.0 668.2 352.2 703.7 352.2 740.1 352.3 777.0 352.4 814.1 352.5 661.9 N 91.1 W 697.2 N 95.4 W 733.3 N 99.6 W 770.1 N 103.4 W 807.0 N 106.8 W 4000.0 48.11 355.44 .79 4050.0 47.76 356.17 1.28 4100.0 48.61 356.28 1.70 4150.0 48.03 356.69 1.30 4200.0 48.05 356.95 .38 3739.9 3773.4 3806.7 3839.9 3873.4 3695 3729 3762 3796 3829 .9 .4 .7 .0 .4 851.0 888.0 925.2 962 .4 999.4 851.2 352.6 888.2 352.7 925.4 352.9 962.7 353.0 999.8 353.1 844.0 N 109.9 W 881.1 N 112.6 W 918.2 N 115.1 W 955.5 N 117.4 W 992.6 N 119.4 W 4250.0 48.34 356.87 .60 4300.0 50.13 356.67 3.60 4350.0 51.53 356.63 2.79 4400.0 53.45 356.57 3.83 4450.0 54.85 356.38 2.83 3906.7 3939.3 3970.9 4001.4 4030.7 3862 3895 3927 3957 3986 .7 .4 .0 .4 .7 1036.5 1037.:0 353.3 1074.3 1074.8 353.4 1112.9 1113.5 353.5 1152.4 1153.1 353.6 1192.7 1193.6 353.7 1029.8 N 121.4 W 1067.7 N 123.6 W 1106.4 N 125.8 W 1145.9 N 128.2 W 1186.4 ~N 130.7 W 4500.0 56.86 356.21 4.03 4550.0 58.68 355.57 3.80 4600.0 60.54 354.58 4.08 4650.0 60.99 353.50 2.08 4700.0 60.91 353.33 .35 4058.7 4085.4 4110.7 4135.1 4159.4 4014 4041 4066 4091 4115 .8 .4 .7 .1 .4 1234.0 1234.9 353.8 1276.2 1277.2 353.9 1319.2 1320.3 353.9 1362.8 1363.9 353.9 1406.5 1407.6 353.9 1227.7 N 133.4 W 1269.9 N 136.4 W 1312.8 N 140.1 W 1356.2 N 144.6 W 1399.7 N 149.6 W 4750.0 61.36 353.27 .90 4800.0 61.38 353.22 .10 4850.0 60.96 351.73 2.76 4900.0 60.61 350.98 1.48 4950.0 60.60 350.86 .20 4183.5 4207.5 4231.6 4256.0 4280.5 4139.6 1450.3 1451.4 353.9 4163.5 1494.1 1495.3 353.9 4187.6 1537.9 1539.1 353.8 4212.0 1581.6 1582.7 353.8 4236.6 1625.1 1626.2 353.7 1443.1 N 154.8 W 1486.7 N 159.9'W 1530.2 N 165.7 W 1573.3 N 172.2 W 1616.3 N 179.1 W A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION NELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, gob Number: AK0299GCE521 NORTH SLOPE, ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 5000.0 61.11 350.89 5050.0 61.22 350.97 5100.0 61.71 350.96 5150.0 61.90 351.00 5200.0 62.58 351.07 1.03 4304.9 4260 .26 4329.0 4285 .98 4352.9 4308 .38 4376.5 4332 1.38 4399.8 4355 .9 1668.8 1669.8 353.6 .0 1712.6 1713.6 353.5 .9 1756.5 1757.5 353.5 .5 1800.6 1801.5 353.4 .8 1844.8 1845.7 353.4 1659.4 N 186.0 W 1702.7 N 192.9 W 1746.1 N 199.8 W 1789.6 N 206.7 W 1833.3 N 213.6 W 5250.0 62.57 351.06 5300.0 62.54 351.27 5350.0 61.85 351.34 5400.0 61.73 351.20 5450.0 61.43 351.24 · 04 4422.8 4378 · 39 4445.9 4401 .39 4469.2 4425 .35 4492.8 4448 · 60 4516.6 4472 .9 1889.2 1890.0 353.3 .9 1933.6 1934.4 353.3 .2 1977.8 1978.6 353.2 .9 2021.9 2022.6 353.2 .7 2065.8 2066.6 353.1 1877.1 N 220.5 W 1921.0 N 227.3 W 1964.7 N 234.0 W 2008.2 N 240.7 W 2051.7 N 247.4 W 5500.0 60.95 351.12 5550.0 60.56 351.10 5600.0 60.31 351.17 5650.0 59.97 351.36 5700.0 59.28 351.49 .99 4540.7 4496 .78 4565.1 4521 .51 4589.8 4545 .76 4614.7 4570 .40 4640.0 4596 .8 2109.6 2110.4 353.1 .2 2153.3 2154.0 353.0 .8 2196.8 2197.4 353.0 .7 2240.1 2240.8 353.0 .0 2283.3 2283.9 352.9 2095.0 N 254.1 W 2138.1 N 260.9 W 2181.1 N 267.6 W 2223.9 N 274.1 W 2266.6'N 280.6 W 5750.0 59.37 351.31 5800.0 58.89 351.18 5850.0 58.75 351.05 5900.0 58.09 351.04 5950.0 58.51 351.55 · 36 4665.5 4621 .97 4691.1 4647 .36 .4717.0 4673 .32 4743.2 4699 .20 4769.5 4725 .5 2326.3 2326.9 352.9 .2 2369.2 2369.8 352.9 .1 2411.9 2412.5 352.9 .3 2454.5 2455.1 352.8 · 5 2497.1 2497.6 352.8 2309.1 N 287.0 W 2351.5 N 293.5 W 2393.8 N 300.2 W 2435.9 N 306.8 W 2477.9 N 313.2 W 6000.0 58.78 350.12 6050.0 58.59 349.85 6100.0 57.93 349.63 6150.0 57.94 349.42 6200.0 58.45 349.26 2.49 4795.5 4751.6 .59 4821.5 4777.5 1.38 4847.8 4803.8 .35 4874.3 4830.4 1.06 4900.7 4856.7 2539.8 2540.3 352.8 2582.5 2583.0 352~7 2625.0 2625.4 352.7 2667.3 2667.7 352.6 2709.8 2710.2 352.6 2520.1 N 320.0 W 2562.1 N 327.4 W 2604.0 N 335.0 W 2645.6 N 342.7 W 2687.4 N 350.6 W A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, Job Number: AK0299GCE521 NORTH SLOPE, ALASKA Page 5 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 6250.0 58.76 349.06 6300.0 58.78 348.89 6350.0 58.32 348.68 6400.0 58.84 349.19 6450.0 58.58 349.05 .71 4926.7 .30 4952.7 .99 4978.8 .35 5004.8 .56 5030.8 4882.8 2752.4 2752.8 352.5 4908.7 2795.1 2795.4 352.5 4934.8 2837.7 2838.0 352.4 4960.9 2880.3 2880.6 352.4 4986.8 2923.0 2923.3 352.3 2729.3 N 358.6 W 2771.3 N 366.8 W 2813.1 N 375.1 W / 2855.0 N 383.3 W 2896.9 N 391.3 W 6500.0 58.71 348.81 6550.0 58.34 348.68 6600.0 58.46 348.55 6650.0 58.25 348.20 6700.0 59.17 348.20 .5O 5056.8 .77 5082.9 .33 5109.1 .73 5135.3 .83 5161.3 5012.9 2965.7 2965.9 352.3 5039.0 3008.3 3008.5 352.2 5065.2 3050.8 3051.0 352.2 5091.4 3093.3 3093.4 352.1 5117.4 3136.0 3136.1 352.1 2938.9 N 399.5 W 2980.7 N 407.9 W 3022.4 N 416.3 W 3064.1 N 424.8 W 3105.9 N 433.6 W 6750.0 59.89 348.16 6800.0 59.35 348.25 6850.0 59.24 347.98 6900.0 58.45 347.97 6950.0 58.07 347.84 1.45 5186.7 1.10 5211.9 .51 5237.5 1.58 5263.3 .78 5289.7 5142.7 5168.0 5193.5 5219.4 5245.7 3179.0 3222.0 3264.9 3307.6 3350.1 3179.1 352.0 3222.1 351.9 3265.0' 351.9 3307.7 351.8 3350.1 351.8 3148.1 N 442.4 W 3190.3 N 451.2 W 3232.4 N 460.1 W 3274.3 N 469.0 W 3315.8"N 477.9 W 7000.0 57.68 347.92 7050.0 57.58 347.91 7100.0 58.66 348.61 7150.0 58.46 348.77 7200.0 57.93 348.71 .79 5316.2 .20 5343.0 .45 5369.4 .47 5395.5 .06 5421.8 5272.3 3392.3 3392.4 351.7 5299.1 3434.5 3434.5 351.7 5325.5 3476.9 3476.9 351.7 5351.5 3519.5 35'19.5 351.6 5377.9 3561.9 3561.9 351.6 3357.2 N 486.8 W 3398.5 N 495.6 W ~, 3440.1 N 504.3 W 3481.9 N 512.6 W 3523.6 N 520.9 W 7250.0 57.71 348.87 7300.0 59.17 350.12 7350.0 58.31 349.79 7400.0 58.37 349.54 7450.0 58.31 349.41 .53 5448.5 .61 5474.6 .79 5500.6 .45 5526.8 .25 5553.1 5404.5 3604.2 3604.2 351.6 5430.7 3646.8 3646.8 351.5 5456.6 3689.5 3689.5 351.5 5482.9 3732.0 3732.0 351.5 5509.1 3774.5 3774.6 351.5 3565.1 N 529.2 W 3607.0 N 536.9 W 3649.1 N 544.4 W 3691.0 N 552.0 W 3732.8 N 559.8 W A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, Job Number: AK0299GCE521 NORTH SLOPE, ALASKA Page MEASURED DEPTH feet I N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 7500.0 58.74 349.46 7550.0 58.93 349.92 7600.0 59.93 350.49 .88 5579.2 5535.2 3817.2 3817.2 351.4 3774.7 N 567.6 W .87 5605.0 5561.1 3859.9 3859.9 351.4 3816.8 N 575.3 W 2.21 5630.5 5586.5 3903.0 3903.0 351.4 3859.2 N 582.6 ~ Final Station Closure: Distance: 3902.98 ft Az: 351.42 deg. A Gyroda t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, NORTH SLOPE, ALASKA Job Number: AK0299GCE521SS Run Date: 14-Feb-99 09:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.200000 deg. N Sub-sea Correction from Vertical Reference: 43.95 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 351.590 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i re c t i ona I Survey B.P. EXPLORATION WELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, Job Number: AK0299GCE521SS NORTH SLOPE, ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL VERTICAL CLOSURE SEVERITY DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet -44.0 0.00 0.00 0.00 0.0 .09 31.02 .09 100.0 .18 100.76 .20 200.0 .19 137.63 .15 300.0 .25 168.63 .18 0.0 44.0 144.0 244.0 344.0 0.0 .0 -- .0 - .2 0.0 0.0 .2 31.0 .4 78.1 .7 97.2 .9 118.4 0.0 N 0.0 E .0 N .1 E .0 N .3 E .1 S .5 E .4 S .7 E 400.0 .24 204.62 500.0 .26 181.83 600.0 .38 154.68 700.0 .50 145.46 800.0 .49 140.77 .20 .12 .18 .15 .14 444.0 544.0 644.0 744.0 844.0 -.8 -1.2 -1.7 -2.4 -3.2 1.1 139.3 1.5 154.5 2.1 157.7 3.0 155.1 3.8 152.2 .7 S .6 E 1.1 S .5 E 1.6 S .7 E 2.3 S 1.1 E 3.0 S 1.6 E 900.0 .41 133.40 1000.0 .46 133.98 1100.0 .56 137.82 1200.0 .67 145.07 1300.0 .80 152.70 .11 .05 .11 .13 .17 944.0 1044.0 1144.0 1244.0 1344.0 -3.8 -4.4 -5.2 -6.1 -7.3 4.5 149.5 5.3 147.0 6.3 145.4 7.5 144.8 8.9 145.5 3.6 S 2.1 E 4.1 S 2.7 E 4.7 S 3.3 E 5.6 S 3.9 E 6.7 S~ 4.6 E 1400.0 .92 159.01 1500.0 .93 158.04 1600.0 .65 183.62 1700.0 .41 248.89 1800.0 .73 297.71 .15 .08 .40 .66 .55 1444.0 1544.0 1644.0 1744.0 1844.0 -8.7 -10.3 -11.6 -12.1 -11.8 10.5 147.2 12.0 148.8 12.9 150.3 12.8 152.4 11.6 155.3 8.0 S 5.2 E 9.5 S 5.8 E 10.8 S 6.2 E 11.4 S 6.0 E 11.1 S 5.1 E 1900.0 1.67 324.44 2000.0 3.10 345.81 2100.0 5.02 351.48 2200.0 7.58 352.31 2300.0 10.24 351.65 1.08 1.60 1.97 2.54 2.64 1944.0 2044.0 2144.0 2244.0 2344.0 -10.0 -6.0 1.1 12.1 27.8 8.7 157.8 3.3 152.1 6.3 82.6 19.5 1.8 37.4 355.5 9.6 S 3.9 E 5.7 S 2.6 E 4.3 N 1.4 E 12.2 N .9 W 27.7 N 2.4 W A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, Job Number: AK0299GCE521SS NORTH SLOPE, ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL VERTICAL CLOSURE SEVERITY DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 2400.0 12.83 351.08 2500.0 15.28 351.80 2600.0 17.81 352.33 2700.0 20.90 352.13 2800.0 23.66 352.13 2.56 2.40 2.59 3.25 2.21 2444.0 2544.0 2644.0 2744.0 2844.0 48.2 72.7 102.3 137.3 178.6 59.7 353.6 85.9 352.8 116.3 352.6 151.3 352.5 190.7 352.4 47.9 N 5.5 W 72.1 N 9.1 W 101.5 N 13.1 W 136.2 N 17.9 W 177.0 N 23.6 W 2900.0 25.96 352.63 3000.0 28.99 352.01 3100.0 32.22 351.12 3200.0 34.80 351.51 3300.0 37.47 351.81 2.33 3.40 2.55 2.31 1.95 2 944.0 3044.0 3144.0 3244.0 3344.0 224.7 276.3 335.6 401.7 474.7 233.4 352.4 279.8 352.4 357.7 352.3 413.8 352.1 503.9 352.0 222.7 N 29.6 W 273.9 N 36.4 W 332.6 N 45.2 W 397.9 N 55.2 W 470.1 N 65.8 W 3400.0 39.98 352.39 3500.0 43.19 352.89 3600.0 47.40 353.80 3700.0 48.07 355.53 3800.0 48.04 356.72 1.82 2.65 2 .35 .85 1.19 3444.0 3544.0 3644.0 3744.0 3844.0 555.2 643.7 745.3 855.6 966.8 567.4 352.1 668.2 352.1 777.0 352.3 888.2 352.6 999.8 353.0 549.9 N 76.8 W 637.7 N 88.1 W 738.6 N 100.1 W 848.6 N 110.2 W 960.0 N' 117.6 W 3900.0 50.34 356.66 4000.0 55.80 356.30 4100.0 60.96 353.44 4200.0 60.78 351.35 4300.0 61.53 350.97 3 .48 3.40 1.45 2.11 .71 3944.0 4044.0 4144.0 4244.0 4344.0 1079.9 1212.3 1378.7 1560.1 1740.1 1113.5 353.4 1234.9 353.8 1407.6 353.9 1582.7 353.8 1757.5 353.5 1073.3 N 123.9 W 1206.0 N 132.0 W 1372.1 N 146.5 W 1552.0 N 169.0 W 1729.9 N 197.2 W 4400.0 62.54 351.26 4500.0 60.90 351.11 4600.0 59.29 351.46 4700.0 58.10 351.06 4800.0 58.02 349.66 .36 .96 1.23 1.32 1.27 4444.0 4544.0 4644.0 4744.0 4844.0 1929.9 2115.4 2290.0 2455.7 2618.8 1934.4 353.3 2154.0 353.1 2326.9 352.9 2497.6 352.8 2625.4 352.7 1917.4 N 226.7 W 2100.7 N 255.0 W 2273.2 N 281.6 W 2437.1 N 307.0 W 2597.9 N 333.9 W A Gyr oda t a D i re c t i o na I Survey B.P. EXPLORATION WELL: 1, 5.5" D.P. Location: RED DOG PROSPECT, Job Number: AK0299GCE521SS NORTH SLOPE, ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL VERTICAL CLOSURE SEVERITY DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 4900.0 58.77 348.95 5000.0 58.65 348.93 5100.0 58.56 348.20 5200.0 59.04 347.98 5300.0 57.62 347.94 .44 4944.0 2780.8 2795.4 352.5 .53 5044.0 2944.6 2965.9 352.3 1.10 5144.0 3107.5 3136.1 352.1 .78 5244.0 3275.6 3307.7 351.9 .28 5344.0 3436.0 3476.9 351.7 2757.2 N 364.0 W 2918.1 N 395.5 W 3078.0 N 427.7 W 3242.9 N 462.3 W 3400.0 N 496.0 W 5400.0 57.75 348.84 5500.0 58.33 349.46 5586.5 59.93 350.49 .62 5444.0 3597.0 3604.2 351.6 · 32 5544.0 3759.8 3774.6 351.5 2.21 5630.5 3903.0 3903.0 351.4 3558.1 N 527.8 W 3718.3 N 557.1 W 3859.2 N 582.6 W Final Station Closure: Distance: 3902.98 ft Az: 351.42 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER' AK0299GCE521 TOOL NUMBER' 777 MAXIMUM GYRO TEMPERATURE ' 75.46 C MAXIMUM AMBIENT TEMPERATURE · 29.11 C MAXIMUM INCLINATION' 62.58 AVERAGE AZIMUTH ' 351.41 WIRELINE REZERO VALUE · 0.0 REZERO ERROR / K · N/A CALIBRATION USED FOR FIELD SURVEY' 2807 CALIBRATION USED FOR FINAL SURVEY' 2807 PRE JOB MASS BALANCE OFFSET CHECK: -.90 POST JOB MASS BALANCE OFFSET CHECK~ · USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -1.10 UPON ARRIVAL AT RIG · UPON COMPLETION OF SURVEY' UPON RETURN TO ATLAS · OK OK OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD FINAL SURVEY 7573 59.47 350.50 5621.31 3839.00 -577.7 7600 59.93 350.49 5630.50 3859.20 -582.6 FUNCTION TEST JOB NUMBER: AK0299GCE521 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2499 14.04 14.04 14.04 14.04 14.04 AZIMUTH M.D. ft 1 2 3 4 5 2499 351.48 351.49 351.39 351.51 351.55 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK0299GCE521 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 777 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0159 POWER SUPPLY C0111 PRINTER C0083 INTERFACE A0433 A0085 A0079 A0143 BACKUP TOOL No. 761 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0147 POWER SUPPLY C0089 PRINTER C0086 INTERFACE A0467 A0107 A0029 A0055 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 7/32" RUNNING GEAR 2.25" HOUSING w/ECCENTRIC BAR TOTAL LENGTH OF TOOL: 30' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 220 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK0299GCE521 THURSDAY,02/04/99-MONDAY, 02/08/99 12:00 CHECK TOOLS, STANDBY, RIG HAVING PROBLEMS, RETURN ANCHORAGE FRIDAY, 02/12/99 09:00 TO SLOPE 11:00 CHECK TOOLS, LOAD OUT EQUIPMENT. 14:00 SHIP TOOLS TO RED DOG, FLY TO BADAMI. 18:00 CHECK TOOLS ON WIRELINE, PCMIA CARD BAD .. SATURDAY, 02/13/99 15:00 RECIEVE NEW CARD CHECK TOOLS. O.K. 19:00 SPOT UNIT, READY FOR JOB EARLY A.M. SUNDAY, 02/14/99 05:00 06:30 08:15 09:00 11:45 13:30 14:30 18:00 ALERTED. MU TOOL RU SCHLUMBERGER, WARM UP TOOL PICK UP GYRO, RIH SURVEY IN TO 7600', RIH 70 FPM, SURVEY OUT, OUT RUN BAD COMMUNICATION ERRORS. LD TOOL, RD SCHLUMBERGER. PROCESS SURVEY MONDAY 12:00 SHIP TOOLS ON CATCO, FLY TO DEADHORSE. SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS Anchorage, Alaska BP E~LO~TION Red Dog ~1 ~/: ~ v ~ 0 1999 No~ Slope, ~ka _A1~ ~t & G~ ~n~. ~mmi~n M~e Final Report Summary April 1999 PREPARED FOR: BP EXPLORATION PREPARED BY: John Patton Sperry-Sun Drilling Services Logging Systems Anchorage, Alaska TABLE OF CONTENTS Introduction ............................................................................................................................. .~A Well Diagram ............................................................................................................................ B Well Summary By Intervals ..................................................................................................... C Conclusions ............................................................................................................................. D Graphical Analysis ........................................................................................................... E & F Well History: .............. E Pore Pressure Evaluation: .............. F 1) Days Drilling 2) Rotating Hours 3) Bit Hours 4) Bit Footage 5) Torque 6) Time Distribution- Hours 7) Time Distribution - Percent Allocation 1) Pore Pressure- Mud weight- TVD 2) Condensed Resistivity- TVD 3) Condensed Sonic- TVD 4) Condensed Pressure Parameters 5) "Dc" Exponent - TVD Log Packet ............................................................................................................................... G 1) Engineering Log (250'/inch) 2) Condensed MWD - TVD Log (250'/inch) 3) Data Disks Bit Record ................................................................................................................................ H Drilling Mud Record ................................................................................................................. I Survey Record ............................................................................................................................ J 1) Anadrill Survey Data Show Reports ........................................................................................................................... K 1) Show Log - Mud Log over Zone of Interest 2) Show Reports - Zones of Interests 3) Pixler Paper- Reference Material ADT Morning Reports ............................................................................................................. L INTRODUCTION Drilling operations for Red Dog #1 were initiated 25 January, 1999 by BP Exploration. The well was drilled by Nabors Alaska Drilling Rig 28-E on an ice pad location that had been c6hstmcted earlier in the winter. The ice pad was located in Section 34, Township 10 North, Range 21 East just outside of the western boundary line of the Point Thompson Unit. The well was planned as an extended reach directional hole to penetrate targeted sands found in a Tertiary turbidite section predicted by seismic data on this location. Red Dog #1 was drilled to a depth of 18,740' on 3-14- 99. The total number of operating days that was required to reach this depth were 48 days including the spud in date. Electric log evaluations of the 8 ½" interval were completed on 3-22-99 where the decision was made to deepen the well. Red Dog #1 was drilled to a total depth of 19,400' on 3-26- 99. The total number of operating days that was required to reach this depth was 60 days. Operations to suspend the well were initiated 3-28-99. A Sperry-Sun Logging Systems LS2000 Unit was in operation fi.om surface to TD providing full mud logging and applied drilling technology services. The 2000 Unit and crew provided assistance in the drilling of Red Dog #1 by monitoring essential drilling parameters and gas levels. Also provided were fluid hydraulics information, pore pressure vs. necessary mud weight evaluations, and a wide range of geologic interpretations and sampling services. Additional services included the integration of real-time Gamma Ray, EWR, and Sonic information fi.om data supplied by a separate MWD company, Anadrill Schlumberger. The following pages of this report are designed to supply concise historical data of the events that occurred on Red Dog #1, along with some analysis and recommendations for specific problems that were experienced during different sections of the hole. All of the information compiled in this report was acquired and recorded by the LS2000 Unit at the well site. The sensors incorporated in this unit are independent from the rig sensors and may differ slightly from those reported by the rig contractor. In addition, any evaluations in this report regarding formation evaluations, pore pressure estimates, or other geologic interpretations are made entirely by Sperry-Sun personnel from examination of the data collected by the LS2000 Unit and reference material made available by the Operator at the rig site. B.P. E~lorotion ~ELL DI~GR[~M RED DOG ~1 Lithologg / C~sing Progr~ For~ation~ . ~ . . . . . ~'.'. '.' .'.t 'o ~'r'~ ~ ~ - .. T~RGET ?v' i~ ~ t' ., ~ CRETACEOUS ] Interval: 110'-5,303' WELL SUMMARY BY INTERVALS Days: 17 Average WOB: 25 klb Hole Size: 16.0" Average RPM: 125 No. Bits: 3 Average GPM: 850 Rotating Hours: 66.8 Average SPP: 1850 psi Deviation: 61.2 deg Average ROP: 78 fl/hr Mud Weight: 8.7-10.1 ppg Mud Type: Spud Mud Nabors Alaska Drilling Rig 28-E was positioned on location prior to the spud in date of the 25th of January, 1999. Conductor pipe had been set to a depth of 110'. After completing the rig up, a surface diverter system was function tested. Drilling operations were initiated by drilling out the structural casing with Bit No. 1. This bit was nm into the hole on a directional assembly with a 1.5 degree motor. The directional part of the well was started at approximately 2,000' occasionally sliding to build angle and maintain direction. The angle of the hole was steadily built to a maximum for this interval of 61.2 degrees recorded from a survey taken at 5,036'. Penetration rates for the first bit run were poor while drilling through the Permafrost section in mostly frozen gravel and sand. Gravel drilled in this formation was not very large in diameter and did not appear, to slough excessively. The mud weight used to drill this hole interval was 8.7/9.9 ppg. The base of the Permafrost was logged at approximately 1,838'. Gas hydrates were not present on this location. Bit No. 1 was used to drill a depth of 1,537' with slow penetration rates logged in the permafrost. Drilling was continued with Bit No. 2 to 4,158'. Moderately slow penetration rates were experienced in the angle build section of the hole. Bit No. 3 was then used to drill to the 13 3/8" casing point at 5,303' recording good penetration rates. The hole was conditioned with a wiper trip of 42 stands and additional circulating time in preparation for running casing. The maximum trip gas recorded circulating after this trip was 91 units. 13 3/8" - 68 lb/ft casing was nm to a shoe depth of 5,302'. The casing was then cemented in place using a two-stage cement job. Problems were experienced on this section of the hole with the cement job. After a failed attempt to test the casing, an RTTS tool was used to verify that the failed test was caused by a poor cement job at bottom. This required additional time to squeeze cement at the shoe to get a proper leak off test. In addition, more rig time was also needed to work on the rig top drive and BOP's. An additional 5-6 days of rig time were needed to complete this hole section because of trouble time. This part of the well is believed to be normally pressured, 8.5-8.7 ppg. Low background gas and no connection gas readings were logged in this interval. The mud weight used ranged from 8.7-10.1 ppg and was sufficient to stabilize the well bore. No significant hole problems were experienced in this section of the hole. Interval: 5,303' to 15,853' Days: Hole Size: No. Bits: Rotating Hours: Deviation: Mud Weight: 22 Average WOB: 40/17 klb 12 1/4" Average RPM: 210 2 Average GPM: 930 gpm 83.5 Average SPP: 3000 psi 62-56 deg Average ROP: 126 fVhr 8.8/11.0 ppg Mud Type: LSND Discussion: Bit No. 4, a 12 1/4" insert type bit, was used to drill out of the 13 3/8" surface casing and 11 feet of new hole to 5,314' on 2-12-99. The hole was then displaced with 8.8 ppg LSND mud in preparation for running a leak off test prior to drilling ahead. The test that was performed at this depth yielded a fi'acture pressure equivalent to 12.5 ppg. The 12.5 ppg leak off value that was observed at this casing seat is somewhat low but falls within the expected range for this area of the North Slope. Bit No. 4 was nm on a directional assembly with a .78 degree motor and used to drill ahead after completing the leak off test. Connection gas readings of three times background were logged fi.om connections at 5,996', 6,094', and 6,192'. The pore pressure estimate was increased from 8.7 to 9.0 ppg to reflect the change in gas readings and required an increase in mud weight to 9.4 ppg to provide adequate overbalance. A short trip was made at 6,774' to condition the hole pulling the bit back to the 9 5/8" shoe. The hole pulled tight starting at 6,380' and was backreamed fi.om 6,482'. After drilling ahead, the maximum gas recorded fi.om this trip was 425 units. Good penetration rates were recorded on this bit run at this depth in mostly coarse sand with occasional gravel.. A wireline gyro was run at 7,845' for MWD in-hole referencing. While drilling ahead, the formation changed from sand to predominately clay at 8,350' (6,025' TVD). Problems were experienced in dropping the hole angle on this run and the decision was made to pull Bit No. 4 out of the hole at 9,010' to make changes to the BHA. Tight hole conditions were again encountered on this trip and the hole was backreamed fi.om 6,450' on the trip out. The hole took an additional 20-30 barrels of mud on the trip out displacement. This was the results of sands drilled in the upper part of the interval taking some fluid due to seepage and normal water loss. Upon inspection at the surface, Bit No. 4 was graded as 3/8" out of gauge. After testing the Bop's Bit No. 5, a PDC type bit, was run in the hole on a 1.15 degree motor. The hole was washed and reamed with 9.6 ppg mud fi.om 6,400' to bottom without problems. Drilling was continued with this bit to 10,019' and to 11,284' where short trips were performed to condition the hole. The maximum trip gas readings recorded while drilling after these trips were 158 and 425 units. The predominate lithology in this part of the hole was claystone. Poor sample quality was experienced while drilling with a PDC type bit. Hydration of the drill cuttings and the mechanical action of the PDC bit primarily caused this situation. The result of this was that a considerable amount of the cuttings were going into solution with the mud. Another short trip was performed at 13,030' to condition the hole. The maximum trip gas recorded after drilling ahead was 510 units. The predominate lithology changed to siltstone after penetrating into the Canning Formation at 14,250'+/-. Sample quality continued to be poor for this formation as well. The mud weight was steadily increased in the section of the hole below 13,500' in anticipation of drilling into a pressure transition zone expected in the Canning. The mud weight was increased to 10.2 ppg by 14,220', to 10.5 by 14,800', and to 11.0 ppg by 15,200' (9,375'TVD) based on a predetermined weight up schedule. Pore pressure estimates were increased primarily using real- time sonic and resistivity data in comparison with the two closest control wells previously drilled in this area: Point Thompson No. 4 and East Mikkelsen Bay No. 1. The beginning of the abnormal pressure trend for this well appears to start at 9,250' TVD or about 300' into the Canning. Pore pressure estimates were steadily increased from 9.4 ppg to 9.9 ppg by 9,600 TVD (15,700'MD). Two additional short trips were made to condition the hole, one at 14,289' and the other was made after drilling to the total depth for the 12 ¼" interval of 15,862'. This depth was later corrected to 15,853' (9700'TVD) upon finding an error in the BHA length tally. This casing point was selected using correlation data from other wells in an attempt to get far enough into the anticipated pressure gradient to get an adequate leak off test without going too far into the transition zone and encounter problems. Additional time was spent in conditioning the hole at 15,853' in preparation to clean up the hole for running casing. Moderate drag was experienced on trips back to the shoe that required circulating and backreaming to condition the hole. This condition appeared to be caused by wall cake buildup from mud seepage in upper sands that were normally pressured. 9 5/8" 47# and 53.5# casing was then mn to the bottom of the hole and set at 15,850'. The casing was cemented in place without problems. Approximately three days were needed during the casing/cementing operations for this interval to make repairs to the Rig's top drive unit and lay down an entire string of 5.5" drill pipe. A complete string of 5"drill pipe was subsequently picked up prior to drilling out of the 9 5/8" shoe. ~ The lithologies of this section consisted of gravel, sand, clay, siltstone, and sandstone. No abnormal gas readings were encountered. The pore pressure estimate for this section of the hole ranged from 8.7 to 9.9 ppg establishing an increasing gradient below 9,250' TVD'. Hole problems for the interval were moderate and were mostly associated with problems with extra drag on trips through areas of the hole that contained wall cake buildup in sands. Interval: 15,853' to 19,400' Days: Hole Size: No. Bits: Rotating Hours: Deviation: Mud Weight: 21(to TD) Average WOB: 40/13 klb 8 1/2" Average RPM: 330 (PDC) 3 Average GPM: 490 gpm 93.7 Average SPP: 4000 psi 61.5- 16.1 deg Average ROP: 37.9 ft/hr 11.5/14.9 ppg Mud Type: KCL Poly Discussion: Bit No. 7, a PDC type bit, was run into the hole on a 1.15 degree motor. The casing was tested to 5,500 psi (over an 11.0 ppg mud weight) prior to drilling out the cement with this bit from 15,720'. The rest of the cement, float equipment, and casing shoe were then drilled along with 20' of new hole to 15,873'. The hole was then displaced with weighted 11.4 ppg KCL Poly mud. A formation integrity test was performed yielding a pressure equivalent of 17.5 ppg. This test was not taken to the leak off point. The high value for the integrity test is a good indicator that the formation at this depth is quite dense and forms an effective seal for tl~e pore pressure gradient experienced on this well. Drilling rates were good for Bit No. 7 averaging about 53 feet per hour. The mud weight was raised to 12.3 ppg during the bit run. The main problem experienced while drilling with this bit was in trying to drop the angle of the hole. Additional lubricants were added to the mud system in attempts to help slide and correct the angle but were not successful. Bit No. 7 was used to drill to 16,645' and pulled out of the hole to change to a milled tooth bit and modify the BHA to be able to slide and correct the angle. The pore pressure estimate at this depth was 10.5-10.8 ppg. Bit No. 8, a rock bit, was mn into the hole on a .75 degree motor. The maximum trip gas recorded after getting back to bottom and drilling ahead was 295 units. A number of slides were made with this assembly to drop the hole angle.. The first significant show in the 8 ½" interval was logged on this bit run in sand extending from 16,840'-16,880'. Pore pressure estimates were steadily raised while drilling; however, the gradient was estimated to change significantly below 17,150'. The initial evidence of this degree of change came from connection gas readings logged at 17,200' and 17,293'(10,500'TVD). Gas peaks from both of these connections, while drilling with 12.5 ppg mud, totaled 585 and 427 units respectively with the peaks at 300-400 units over background. Sonic data at 10,450-10,550' TVD (Please refer to the graph Condensed Sonic in Section F of this report) was somewhat inconclusive in displaying a decreasing pressure trend at this point making the pore pressure estimate more difficult. The pore pressure estimate was increased to 12.5 ppg based primarily on trip gas data after drilling to 17,364' and performing an 8 stand short trip. The maximum gas reading from this trip was 1,720 units with 12.7 ppg mud weight. The mud weight was then increased to 13.2 ppg before pulling out of the hole to change the bit and the BHA. The pressure estimate was re-evaluated and changed to 12.8-13.0 ppg after getting back to bottom with Bit No. 9, a PDC type bit. The maximum trip gas logged from this trip was 6,265 units after being out of the hole for 24 hours. The mud weight was then increased to 13.5 ppg before drilling ahead. After drilling another 100', interpretations of the trend on the Condensed Sonic Plot confirmed the shift in pore pressure identified by the gas readings. The top of the main target interval for this well was logged at approximately 17,520'. Moderately high background gas readings averaging around 1,200 units were recorded in a silty-sandy formation extending to 17,910'. Minor to sometimes moderate amounts of oil fluorescence was logged in the drill cuttings collected over this section. Ratio analysis of chromatograph readings from steam still samples indicated that this zone contained oil. Pore pressure estimates were gradually increased to reflect a continuing trend interpreted from the sonic data reaching an estimate of 13.5 ppg at 18,450' (11,500' TVD). The mud weight was gradually increased to 14.0 ppg to counter this trend. Bit No. 9 was then used to drill to 18,740' on 3/14/99 where the decision was made to evaluate the open hole with electric logs. The hole was conditioned with two short trips prior to pulling out of the hole. The last short trip was made all of the way back to the shoe and recorded a maximum trip gas of 515 units while circulating. Seven days were spent for logging operations at the 18,740' depth. This time included wiper trips and additional rig time needed to make the last two logging runs using drill pipe conveyed tools. It should be noted that a significant problem developed with the mud system at the end of logging operations. This was discovered while circulating with the RFT tool in the hole near the 9 5/8" casing shoe. Mud returns at this point started coming back light. The mud was weighted up from 13.0 - 13.5 ppg average to 14.0 ppg. This operation required considerably more barite than calculated and indicated that the barite was not blending well and possibly dropping out of the mud into the open hole. After completing logging operations, the decision was made to deepen the well to evaluate potential secondary targets. Bit No. 11 (RR Bit 9) was re-mn back into the hole on 3/23/99 staging in the hole to condition the mud and minimize the effects of expected high ECD's. An additional day was spent on this procedure conditioning heavy and light mud coming back from the open hole. The maximum gas recorded from the trip in was 1,263 units while blending and weighting up the mud system to 14.5 ppg. Prior to drilling ahead, a short trip was made back to the shoe to perform a formation integrity test. This test was taken to a 17.0 ppg equivalent at the casing shoe to verify potential weak zones in the open hole. Drilling was continued with Bit No. 11 after getting back to bottom from the short trip. The maximum gas recorded from this trip was 225 units. Higher on bottom torque and somewhat slower penetration rates were recorded on this bit mn averaging 38 fph. These parameters were interpreted to be from the formation changing to harder rock. Bit No. 11 drilled to 18,940' while weighting up the mud to 14.7 ppg. This bit and assembly was pulled out of the hole to replace a failed mud motor. After replacing the motor, the same bit was re-run back into the hole and used to drill to the total depth of 19,400' on 3/26/99 for Red Dog No. 1. The mud weight was increased to 14.9 ppg while drilling ahead with this bit. A significant hole problem was encountered after reaching total depth. This occurred while circulating and conditioning the hole prior to pulling the bit. After pulling a stand out of the hole, the drill string became stuck while circulating and working the pipe down. The string was worked for five hours while reducing the mud weight to 14.6 ppg before pulling free. The mud weight was again conditioned to 14.8 ppg and Bit No. 12 was pulled out of the hole. Operations to suspend the well were then initiated on 3/28/99. Pore pressure estimates were steadily increased in the interval of the hole below the logging depth of 18,740'. The primary reference for this pressure evaluation was sonic data. The mud weight was steadily increased to 14.9 ppg by 19,200' in anticipation of encountering sand that could contain pressures equivalent to the Cretaceous age shale expected at a lower depth. The top of this shale formation was interpreted at approximately 15,300' using the shift displayed on the Resistivity Plot. Red Dog No. 1 was drilled to a total depth of 19,400 penetrating 100' of the Shale Wall Formation. The maximum formation pressure estimate for this Well of 14.5 ppg was made at total depth. Five show reports were filled out for the 8 1/2" interval of this well relative to the main targeted zone of interest. Minor to sometimes moderate oil shows of fluorescence and cuts were recorded in drill cutting samples collected in this interval. The first good sand logged in this interval was between 16,840-16,885' and appeared to have good porosity, however ratio analysis of chromatograph readings suggested that this sand contained gas or perhaps oil with a high gas-oil ratio. Moderately high background gas readings and ratio analysis from gas chromatograph. samples taken in additional show areas indicated the presence of oil in the zone logged between 17,520-17,910'. In this section, poor gamma ray response and low overall resistivity values contributed to the overall low porosity estimates for this zone. No other show reports were filled out for the secondary targeted sands. This section of the~hole was logged mainly as siltstone. The lithologies of this interval consisted of siltstone, sandstone, and shale. Hole problems for the 8 ½" interval were moderate and included some additional time to weight up to maintain proper overbalance. Barite settling in the mud was noted at the end of logging operations causing one day of rig time to condition the mud. All of the logging tools could not be run on wire line. This required approximately two extra days to complete two logging runs conveyed on drill pipe. One stuck pipe situation was encountered after reaching total depth. The mud weights used to drill this section provided sufficient overbalance to safely drill through the observed pressures that changed significantly in this interval. CONCLUSIONS GENERAL: The drilling program for Red Dog No. 1 was designed as an extended reach directional well to penetrate to an estimated measured depth of 19,000' and evaluate sands located in the Canning Formation predicted below 10,700' tree vertical depth. This well was drilled to a depth of 18,740' in 48 days very close to the predicted time of 47 days for the original total depth. After evaluating the 8½" interval with electric logs, the decision was made to deepen the hole rather than running a liner to test the well. Red Dog No. 1 was drilled to a total depth of 19,400' on 3-26-99 taking 60 days to reach TD. The most significant problems that were experienced on Red Dog No. 1 that required additional rig time did not happen during the drilling phase of this well. In comparing the actual drilling time curve with the predicted drilling curve, drilling operations were done efficiently. Most of the delays were recorded after reaching the interval casing depths and during logging operations. Approximately 3-4 days additional days were needed to verify and perform a cement squeeze job at the 13 3/8" casing shoe when it was identified that the casing would not test. Mechanical problems were experienced with the top drive unit and the BOP that also caused delays in affecting repairs. In the 12 ¼" section, some additional rig time was needed to condition the hole for running 9 5/8" casing. More time was also required to evaluate the 8 ½" hole with the electric logs where two of the logging runs had to be run drill pipe conveyed. Hole problems that occurred in the first interval of the well were minor. Slow penetration rates were experienced on the first two bit runs while drilling through the permafrost and in the main angle build section of the hole. In this deviated section of the hole, the angle build and direction was performed adequately as only minor amounts of drag were experienced on trips. The probable causes for the drag were swelling clays and some wall cake buildup in sands. The short trips employed while drilling this section proved to be an adequate means to clean and condition the hole. The kick off point for this well was started in the first well bore interval below 2,000'. From here, the hole angle was gradually built to an average of 60 degrees and an azimuth of 350 +/- degrees by 4,600'. This angle and direction was maintained in the 8 ½" interval until 16,500' were the angle was gradually dropped to an average of 16 degrees by 19,300'. Good penetration rates were observed on this well with the proper use of rock and PDC type bits while drilling through a variety of different types of formations. Three PDC bits were used to drill over 9,671 of formation. The slowest penetration rates were experienced while trying to slide in the 8 1/2" hole interval while using a PDC bit. Problems were experienced with the mud system at the end of logging operations for the ~ ½" hole interval. On the last logging run, an RFT, the hole was circulated out at the 9 5/8" casing shoe prior to pulling the tool all of the way out. At this time, the mud coming back fi.om the hole was light. This situation occurred while circulating at a reduced rate (4 barrels per minute) and the resulting weight up to bring 13.0-13.5 ppg mud to 14.0 ppg took considerably more barite than calculated. It became apparent after the subsequent trip in that much of the barite in the mud was settling out down hole. An additional day of rig time was needed to condition the mud to the 14.5 ppg value that was used to drill ahead. The probable cause for the barite settling included temperature effects and insufficient fresh gel in the mud to properly suspend the barite for long periods of time in a stagnant condition. One stuck pipe situation was encountered after reaching total depth and circulating to condition the hole prior to tripping out. This situation occurred after standing back a stand of pipe and circulating and washing down. The drill string came free after circulating and working pipe for five hours. Although the hole did not appear to pack off, the stuck pipe situation was probably caused by part of the hole falling in near the BHA. This section of the hole did not appear to have any permeable zones that would have caused differential sticking. PORE PRESSURE: Pore pressure estimates for this well were made generally from observing overall mud gas readings relative to the current mud weight in conjunction with analysis of trends established by sonic data. Additional correlation data from nearby wells also contributed to the analysis. "Dc" Exponent data for this well was not conclusive for pore pressure analysis primarily because of the extensive use of PDC type bits. Red Dog No. 1 appeared to be near normally pressured extending fi-om the surface to 9,250' TVD. Using the Condensed Sonic Plot (refer to Section F) for reference, the beginning of an increasing pore pressure gradient is believed to start below this depth. Pore pressure estimates were steadily raised after penetrating into the Canning Formation. An estimate of 9.9 ppg was made for the 9,700' 9 5/8" casing seat depth. Pore pressure estimates were increased to 11.0 ppg by 16,875' (10,200' TVD). Using sonic data estimates were steadily raised while drilling. However, the gradient was believed to change more significantly below 17,150' (10,400' TVD). The initial evidence of this degree of change came from connection gas readings logged at 17,200' and 17,293'. Although sonic data at this point did not fully support the degree of change, connection gas readings at these depths indicated near balance drilling with 12.5 ppg mud weight. After weighting up to 13.2 ppg, a maximum trip gas value of 6,265 units was recorded on a trip at 17,364' to change the BHA. The pore pressure estimate was raised to 13.0 ppg to reflect the high amount of trip gas recorded from bottom on this trip. Pore pressure estimates were gradually increased below this depth primarily on the trend displayed by sonic data. The maximum pore pressure estimate for this well was 14.5 ppg at total depth in The Shale Wall Formation. ZONES OF INTEREST: Shows of oil cut fluorescence were first noted on the mud logs from depths beginning around 16,850' in the Canning Formation. The first show interval extended from 16,845-16885'. Moderate background readings were recorded in this zone. The sand logged in this interval found in drill cuttings came back mostly unconsolidated making oil cut fluorescence interpretation more difficult, but analysis of chromatograph readings from steam still samples of the mud indicated that this interval contained gas and oil. Porosity estimates were good for this sand interval. Shows of oil fluorescence and moderately high background gas readings were logged in the primary target zone extending from 17,520-17,910'. Ratio analysis of chromatograph readings from this interval also indicated the presence of oil in this zone; however, overall porosity estimates were low. Although good percentages of sand were logged in this section, much of the unconsolidated sand appeared to be dispersed in a siltstone/clay matrix. Please refer to Section K of this report (Show Reports) for more information on this zone. No additional shows were logged in the secondary targeted sands. The lithology for the lower section of the hole was logged as predominately siltstone. t000 2000 3000 4000 5000 6000 7000 8000 9000 10000 ~t1000 ~12000 13000 14000 15000 16000 17000 18000 19000 20000 -------Prognosis ~'Actuat P~ Al 0 5 10 15 20 25 30 35 40 45 50 55 80 65 DAYS ~ ROTFITING HOURS vs. DF--F-i~H 100 200 MB .... ~_ ............................................. ~ .M ............ 2888. ...........~lr ........... I,i~ .... ~~ ...... _i~ir ........ . ..... ~ _~ ..... I ~888 .............................. ~ ..... ~ I I ~ . G~ .............. I~ J .............. ~ ........... ~ .......... i ...................... --- '~ ~ ..................... I I ....... ~ ............. ~ .............. L ..... I ............ J .............. ~ ............. ............... ~~ ....................... I i I .............. ~ ............ L ...... L ~ ..... ! ............. I .............. ............................................. ........................................ _~_..~ ............. ~ .............. ~ ...... ~ .... ~ .......... 12888~ -~ ................... ............ . .... ~ ........ ~ ................ ................ ~ ...... ~ ,~ ~ ~ __~ .......... ~ ....................... ~ ~ ~ ....... l~OO~.................... ~ 18888 18888 -i ...... ~ ..... w .......... ~-~ ............... BIT NO.12 BIT NO. 11 BIT NO, 10 BIT NO, 9 BIT NO. 8 BIT NO. 7 BIT NO. 6 BIT NO. 5 BIT NO. 4 BIT NO. 3 BIT NO. 2 BIT NO, 1 BIT HOURS 0 10 20 30 40 50 60 70 Red Dog #1 BIT FOOTAGE BIT NO. 12 BIT NO.11 BlT NO.10 BIT NO. 9 BIT NO. 8 BIT NO. 7 BIT NO. 6 BIT NO. 5 BIT NO. 4 BIT NO. 3 BIT NO. 2 BIT NO, 1 o 4000 2000 3000 4000 5000 ~ooo 7000 8000 Red Dog #1 TIME DISTRIBUTION TRIPPING DRILLING CIRCULATING LOGGING TEST BOP OTHER RUN & CEMENT CASING NIPPLE UP/DOWN RIG REPAIR RIG SERVICE/CUT LiNE RIG UP/DOWN REAMING CEMENT SQUEEZE 0 50 100 150 200 250 300 350 400 450 Hours % THVIE DiSTRiBUTION TRIPPING 26% BOP TEST 6% RUN & CMT CSG 5% CI RC/CONDITION 15% RIG UP/DOWN 1% NIPPLE UP/DOWD 4% OTHEF 6% LOGGING 6% DRILLING 24% RIG SERVICE 2% RIG REPAIR & CUT LINE 4% ~EAMING 1% TIME DISTRIBUTION -ALLOCATION NOTES I. Trip time includes: 1. Making up kelly. 2. Filling pipe. 3. Pulling - standing back pipe. II. 1. 2. 3. 111. Rig 1. 2. IV. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Drilling time includes: Drilling on bottom. Making connections. MWD directional surveys. Services includes: Slip and Cut Line Lube Rig Other includes: Safety Meetings Logging with MWD Unload MWD Rig up Schlumberger Rig up Cement Lines and Equipment Mix Mud Run Leak Off Test Test Casing Make up BHA Miscellaneous Down Time PORE ~E$$LIRE 9 10 11 12 MUD WL~_~ HT ll~/gc~l 1: :1: I PORE PRESSORE EST, Ih/gal 2l 8I3 ~ ,-._.~ PORE PRESSURE -~,uM~ '~-~SONIC - US/F ~ EST lb/gal ~ · 288 28 8 13 T~ ~ ~ .~ ................. I . _ ~ ~ - ~-~ ..... 7eec ~ ................................. I-' :' -: '~ : ' - .......... ~ .... ~'~' I 8888 _ -'- _:_ - ~ -' _.-_ _ -- ~ --.~ :~-~ - _.._. I .. '~ ohm-~ SONIC - ~/F EST. lb/gal 58 100 TVD 1 10 100 10 8 · -- 1888 ~~l ........ ~ ........................ ~ .................. 8888 .... ' ....... ~,,, ........... ~- ..................................... , .... .................. ~~_~ ~,, .................. ~ ........... :l ...............................'.~. ........ ; . -- 8888 : , ..... 18888 ........ --~ .......... ~--~ .................. . . , ............. ~ .... ~ ............ ......... ........ ~ ...... l~a ......... ...................... - ~- -- 12888 ~ ~ MOD IF lED ~- ~: "D'" EXPONENT 688~ 9888 ~ _ 11080 ......................................................~ 12888 -- -~~~--- ..... ......................... s pe rry-s u n ' Customer: BPXA Casing Program 20 inch at 110 ft~ Well: RED DOG#1 . ~ inch at 5'~ft~ Area: NORTH SLOPE, AK ~ inch at l'--~'~--ft~ ~ Lease: ~ inchat ~ff~ DRILLING SERVICES Rig: NABORS 28 E ~ inch at ~ft~ Mud Company: BAROID ~ inchat ~ft~ BitRecord ,, , ,, Job No.: 850134 , , ,~ Date Bit Bit Serial Size TFA Depth Depth Feet Hours ROP WOB RPM Flow 8SP MW GRADE No. Type Number In Out It/hr gpm psi ppg (~i' J 1/26/99 1 i 2JSC LA2432 ' 16.00 1.264 110 1537 1427 26.01 55 19 54 806 1330 9.8 22WTA41NOIN0 [] 1/27/99 2 GT09D JSSCR ' 16.00 1.4021 1537 4158 2621 29.8188 26 49 930 1830 9.8 22WTAEONOINO 2/1/99 3 MSDSSH 16.00 1.320: 4158 5303 1145 11.0 104 48 104 930 2100 10.1 22WTAEONOPTD [] 2/16/99 4 MXCI T94Y2 12.25 '1.190 5303 9010 ' 3707 23.0 161 40 210 900 2200 9.3 45VVTAE3/gRGBHA [] 2/25/99 5 S73 HpX- PDC JR7513' 12.25 1.320 9010 15853 6843 60.5 t13 15-20 2i0 930 3300 9.6/11 41CRCXOBT-PTD 3/02/99 6 MF.D.SSHL LK1776 , 8.50 oPEN 9700 16645 " J 3/08/99 7 DS70- PDC 22154 : 8.50 1.035 15853 16645 792' '1419' "53 i 10-20' 310 510 3600 11.5/12 01CTHXINOBHA 3111/99 8 MX1. L84186 8.50 0.997 16645 17364 719 32.7 22 ! 40/75' ' '230 520 3850 12.5 22WTAE1/16RGHRS J~ 3/15/99 9 , S73 ENPX J R6916 8.50 1.037 17364 18740' 1376 26.3 52 13 ' 345 500 4200 14.0 00E RAXI NOT D 3117/99 10 MXC1 C70DL 8.50 0.997 ' 18740 18740 ' ' 515 3500 14.0 CLEANOUT 3/25/99 11-RR S73ENPX'PDC '" JR6916 8.50 1.988 18740 1'8940 200 5.3 38' ' 14 340 490 4500 14.7 11WTAXICTDMF 3/27/99 12-RR S73 ENPX- PDC jR6916 ' 8.50 1.988 18940 ' 19400 460 14.5 32 12 330 480 4400 14.9 31WTAX1CTTD ' , "'" .... , ' ",' ',," , ,' ,,',', ,,, , ' , ', , ,' , ~ ' ~.~jjj I E}RIILLSNG SERVICES Waterbase ~V~ud Record Customer: BPXA Well: RED DOG ¢1 Area: NORTH SLOPE, AK, Lease: Rig: NABORS 28E Mud Company: BAROID DRILLING FLUIDS Job No.: 851034 Casing Program 20 inch at 1 1 0 ft 1 3 3f8 inch at 5302 ft 9 5/8 inch at 15850 ~t ........ inch at ft inch at ~ inch at ~ Date Pf / Mf Chlorides Commen~s pprn 01/26/99 01/27/99 . 1/.25 800 01/28/99 .11,25 700 01/29/99 .1/.3 700 01/30/99 .1/.3 1200 01/31/99 . 151.3 1400 02/01/99 . 15/.30 1400 02/02/99 ,05/.25 1400 02/03/99 02/04/99 02/05/99 ,3/.7 200 02/06/99 .3/. 7 200 02/07/99 ,3/.8 200 02/08/99 .4/.8 200 02/09/99 ,7/1.1 300 02/10/99 ,6/1. '1 300 02/11/99 .8/1.1 300 02/12/99 .6/1.'1 300 02/13/99 ,9/1,3 350 02/14/99 .2/,4 02/15/99 ,1/.2 800 02/16/99 ,1/.2 800 02/17/99 1 /6 800 02/18/99 . 15I..5 800 02/19/99 . 10/. 55 800 02/20/99 .1 /6 700 02/21/99 .I 41.5 700 02/22/99 1 18 700 02/23/99 ,1/.6 700 02/24/99 .15/.4 700 02/25/99 .1/.55 800 02/26/99 1/,4 600 02/27/99 .1/,5 700 02J28/99 .15/50 700 03/01/99 . 1/.55 800 03/02/99 .15/.70 1200 LSND Customer: BPXA Casing Program 20 inch at 110 ft s pe rrv-sun Well'. RED DOG #1 ~1 3 3/8 inch at 53~~ft5302 ft · '~ Area: NORTH SLOPE, AK. 9 5/8 inch at 15850 ft Lease: ~ inch at ~ft DRILLING SERVICES Rig'. NABORS 28E ' ~~ inch at ~ft Mud Company: BAROID DRILLING FLUIDS ~ inch at Wate[b~se Mud Record .... Job No.: 8510,,34 , , Date Depth I Weight Vis I PV YP Gels Fltr HTHP Cake Sol Oil Water Sd CEC I pH Pm Pf t Elf Chlorides Calcium CommentsComments ft lb/gal sec: cp ~o,~l. mi mid,leg F 32's % % % O/o mge/hg : ppm ppm 03103/99 15853 11.5 48! 21 27 6/10 4.8 0.0 2 14.0 0.0 86.0 0.0 5.0 ! 9.8 0.30 .2/.8 32000 40 I 03104/99 15853 10.7 43 20 15 319 3.6 0.0 2 12.0 5.0 83~0 0.3 22.5 :'8.0 0.00 0/1.2 1000 140 ' 03105/99 15853 11.4 54 20 30 7/13 3.0 0.0 2 14.0 1.0 85.0 0.0 '5.0 8.6 1'0.30 .2/.8 :30000 160 03/06/99 ~ 15881 11.5. 56 14 23 5/11 4.6 0.0 2 11.4 1.0 86.0 0.0 5.0 10.00.40 .21.6 31000 160 ' 03107199 16485" 12.0 59 20 42 18125 4.4 0.0 2j 14.8 "3.0 81.0 0.3 7.5 8.e j'0.30 .1/.6 24000 160 03108/99 I 16645 J 12.3. 61 18 39 13/25 4.5 14.0 2 i 18.0 4.0 '78.0 0.3 7.5 8.8 0.30 .1/1.2 27000 160 03/09199 ! 16890 12.4'56 26 31 8/20 3.5 9.6 2 17.5 3.5 7810 0.3 10.0 9.8 "0.50i .21.9 24000 i 120 03110/99 J 17239 12.5 ! 63 30 43 10128 3.0 8.0 2 i 17.6I 4.0 77.0 0.3 10.0 8.9 ~ 0.30I .1/.8 31000 I 120 03/11/99 ~ 17364 13.2 ' 5'9 24 43 12/30 3.2 8.6 2 20.5 J 3.5 74.5 0.3 10.0 ' 9.0 "0.30 ! .111.2 '33000 J 90 J 03112/99 17364 13.3 68 29 43 10/22 3.5 9.0 2 "22.0 ~ 3,5 7415 0.3 10.0' i 9.4' 0.40 .2/1.0 32000 ! 80 J 03/13/9§"' 17550 13.5 63 30 27 11/25 3.0" 9.4 2 24.0 J 3.0 73.0 013 10.0 ' 9.3 ..... 0.30 ~ .2/1.2 35000 J 60 J 03/14/99 18324 13.'/" 64 37 37 13/25 3.0 9.4 2 24.0 j 3.5 7215 0.3 10.0', 9.0 0.30 ' .2/1.0 34000 ! 80 I 03115/99 18740 14.0 73 30 30 10/25 3.0 9.0 2 26.0 4.0 "7b.O 0.3 10.0 i 8.9 0.20 .10/1.0 34000 80 I 03/16/99 18740 14.0 68 43 22 11/24 3.0 9.0 2 25.01 4.0 71.0 0.3 10.0 '§.0 0.20 1.11.2 35000 i 80 ' I 03117199 ' 18740 14.0 72 40 34 12/24' 3.0 9.2 . 2 25.0 : 4.0 71.0 0.3 10.0'~ 9.2 "0.20 ' .1/1.2 ' 35000 80 03/18/99 18740 14.0 74 42 33 12/22 ~ 3.0 9.0 2 25.0 4.0' 71.0 0.3 10.0' 8.9 0.20' 0.110.2 '35000 80 lJ 03i19/99 18740 14.0173 41 32 12123 3.0 9.2 2 25.0 4.0 71,0 0.3 10'.0 8.6 0.10 .1/.25 34000 so (J3120/99 18740 14.0 "70 34 35 10/27 ~ 2.8 9.2' 2 25.0 2.0 '7:~.0 '0.3 10.0 9.0 0.20 .111.0 34000 80 03121199 18740 '14.0"175 35 38 12/33 3.2 9.5 2 '25.0 '4.0 71.0 0.3 11.0 8.9 '0.15 '.1/1.2" 24000 80 03122/99' 18740 14.0"75" 35 35 13/27 3.3 9.6 2 25.0 '3.0 72.0 0.3 11~0 8.8 0.15 .05/1.2 32000 80 03123/99 18740 14.0 71 35 34 14/28 3.4 9.7 2 25.0 '3.0 J 72.0 0.3 11.0 8.6 ' 0.15 .111 28000 80 ' 03124199 18740 14.5 65 "37 28 10128 3.0 9.0 2 27.0 3.0 I 70.0 0.3' il.0 ...... 9.2 .... 0.20' .1/1.8 "34000 80 (J3125/99 18835 14.7 66 37 33 13/30 3.0 9.2 2 26.0 3.0 ' 71.0 0.3' 1i.0' 8.9 "0.15 .111.5 32000" 80 ' 03126/99 18940 14.7 70 33" 35 12/29 3.0 8.8 2 2717 3.0' 69.3 0.3 11.0 8.8 0.15 '.111.5 ' 32000 80 03/27/99 19400 14.8" 70 38 35 15/36 3.0 8.0 2 29.0 3.0 ~ 68.0 0.3 10.5 8.6 0~15' '.1/1.4 ' "30000 80 '(~3i28/99 19400 !4.8 74' '37 38 .!..3133.. 3.0 8.4 2 27.8" . '3.0 69.2 0.3 1'0,5 8.6 0.10 .'1511.~t 29000 ... J~l~!lll~llilllllltlll~ll~lllll~l~i ~lJlJ~llllll~ll~lll~llll~ll I~l~Jlillll~j~ll IIl~l~l~J~l I~llllll~lll~J I~lllll[llllll~l[I iI~IU~IllIIIII~ilIIIIIIIIliI~IIIIlll IIIIillIItlIltlBIII~iEII' li~llllltlllllllllllllll!ll~lJilllil~Jllll JlilllllllllJlll~llll Illfllllllllll~ll~llJl[lll Illrll~lllilllJllliltl~ll IIIIil~llllllllli~lllLIIl~tl IJ~l~lllllltli~llll] IIl~J~l~lllililllla~ IElllta~lll~ Jaa~lll~lJl~lEIIlll I~l~lJlllJBl~l~lJ~lltllJ~lltll~lt~l~lllliall II~I~II~I~i~III[IIE~II~IJ~IEII~I~II~ Illi~ali~lJlf~l~l~ i~E~lllJ,~l~lJftl~JlJlll~ /kNADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 2 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.0 2 100.00 0.20 70.6 3 200.00 0.15 139.3 4 300.00 0.24 135.6 5 400.00 0.26 210.8 6 500.00 0.21 196.8 7 600.00 0.31 162.8 8 700.00 0.46 144.3 9 800.00 0.56 146.9 10 900.00 0.41 133.0 11 1000.00 0.42 134.0 12 1100.00 0.52 134.0 13 1200.00 0.61 142.7 14 1300.00 0.74 148.1 15 1400.00 0.89 158.6 16 1500.00 0.96 159.6 17 1600.00 0.89 156.1 18 1700.00 0.35 218.6 19 1800.00 0.49 287.4 20 1900.00 1.04 310.9 21 2000.00 2.46 341.7 22 2100.00 3.90 351.0 23 2200.00 6.42 352.0 24 2300.00 8.98 352.6 25 2400.00 11.69 350.5 26 2500.00 14.04 351.5 27 2550.00 15.24 351.8 28 2600.00 16.37 352.3 29 2650.00 17.67 352.4 30 2700.00 18.89 352.2 0.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 50.00 50.0O 50.00 50.00 TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 0.00 0.00 0.00 100.00 0.03 0.06 200.00 -0.04 0.02 300.00 -0.32 -0.23 400.00 -0.67 -0.58 500.00 -1.01 -0.95 600.00 -1.44 -1.38 699.99 -2.07 -1.97 799.99 -2.87 -2.70 899.99 -3.59 -3.35 999.98 -4.16 -3.85 1099.98 -4.81 -4.42 1199.98 -5.64 -5.16 1299.97 -6.70 -6.13 1399.96 -8.05 -7.40 1499.94 -9.62 -8.91 1599.93 -11.19 -10.41 1699.93 -12.15 -11.36 1799.92 -12.17 -11.47 1899.92 -11.29 -10.74 1999.87 -8.49 -8.11 2099.71 -2.98 -2.72 2199.30 6.02 6.18 2298.39 19.41 19.46 2396.76 37.35 37.19 2494.24 59.61 59.19 2542.62 72.25 71.69 2590.72 85.86 85.18 2638.53 100.50 99.68 2686.01 116.18 115.22 0.00 0.16 0.41 0.65 0.68 0.51 0.53 0.85 1.35 1.88 2.40 2.99 3.64 4.31 4.93 5.51 6.11 6.24 5.64 4.55 3.19 1.98 0.67 -1.11 -3.79 -7.26 -9.09 -10.97 -12.92 -15.02 0.00 0.00 0.00 TIP 0.17 70.60 0.20 MWD M 0.41 87.69 0.20 MWD M 0.69 109.75 0.09 M~D M 0.89 130.43 0.31 MWD M -- 1.07 151.80 0.08 MWD M 1.48 158.83 0.18 MWD M 2.14 156.64 0.19 MWD M 3.02 153.44 0.10 MWD M 3.84 150.74 0.19 MWD M 4.54 148.02 0.01 MWD M 5.34 145.89 0.10 MWD M 6.32 144.77 0.12 MWD M 7.49 144.91 0.14 MWD M 8.90 146.33 0.21 MWD M 10.48 148.28 0.07 MWD M 12.07 149.56 0.09 MWD M 12.96 151.22 0.79 MWD M 12.78 153.81 0.49 MWD M 11.67 157 . 07 0.62 MWD M 8.72 158.56 1.65 MWD M 3.36 143.90 1.52 MWD M 6.22 6.18 2.52 MWD M 19.49 356.72 2.56 MWD M 37.39 354.18 2.74 MWD M 59.63 353.01 2.36 MWD M 72.26 352.77 2.40 MWD M 85.88 352.66 2.28 MWD M 100.51 352.61 2.60 MWD ~ 116.20 352.57 2.44 MWD M (c)1999 Anadrill IDEAL ID5_0C_03R] ~tNADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 31 2750.00 20,53 352.2 32 2800.00 22,10 352.0 33 2850.00 23.26 352.0 34 2900.00 24.27 352.4 35 2950.00 25.16 352.6 26-Mar-99 20:10:34 36 3000.00 26.50 352.7 37 3050.00 27.45 352.5 38 3100.00 29.27 351.9 39 3150.00 30.72 351.5 40 3200.00 32.08 351.1 Course TVD Vertical Displ Displ length depth section +N/S- +E/W- (ft) (ft) (ft) (ft) (ft) 50.00 2733.08 133.04 131.93 -17.31 50.00 2779.66 151.22 149.93 -19.81 50.00 2825.79 170.49 169.02 -22.49 50.00 2871.55 190.64 188.98 -25.23 50.00 2916.97 211.54 209.71 -27.95 .00 2961.97 233.32 231.31 -30.76 .00 3006.53 256.00 253.80 -33.70 .00 3050.53 279.75 277.33 -36.93 .00 3093.83 304.74 302.06 -40.54 .00 3136.51 330.79 327.81 -44.48 41 3250.00 32.88 351.2 42 3300.00 34.23 351.4 43 3350.00 35.23 351.6 44 3400.00 36.45 351.6 45 3450.00 37.41 351.8 50 50 5O 5O 5O .00 3178.69 357.64 354.34 -48.61 .00 3220.35 385.28 381.66 -52.79 .00 3261.45 413.76 409.83 -57.00 .00 3301.98 443.04 438.80 -61.28 .00 3341.95 473.08 468.52 -65.61 46 3500.00 38.62 352.1 47 3550.00 39.36 352.4 48 3600.00 40.36 352.4 49 3650.00 41.53 352.6 50 3700.00 42.72 352.8 50 50 50 50 50 51 3750.00 44.36 353.0 52 3800.00 46.14 353.2 53 3850.00 47.30 353.7 54 3900.00 47.97 354.3 55 3950.00 47.82 355.1 50.00 3381.34 503.87 499.01 -69.92 50.00 3420.20 535.33 530.18 -74.16 50.00 3458.58 567.37 561.95 -78.40 50.00 3496.35 600.13 594.43 -82.68 50.00 3533.43 633.67 627.70 -86.94 56 4000.00 48.11 355.4 57 4050.00 47.76 356.2 58 4100.00 48.61 356.3 59 4150.00 48.03 356.7 60 4200.00 48.05 357.0 50.00 3569.67 668.10 661.88 -91.20 50.00 3604.87 703.59 697.12 -95.49 50.00 3639.15 739.98 733.28 -99.67 50.00 3672.84 776.89 770.02 -103.53 50.00 3706.37 813.93 806.96 -106.96 3739.85 850.99 843.97 -110.04 3773.35 888.01 880.99 -112.76 3806.68 925.15 918.17 -115.19 3839.93 962.35 955.45 -117.47 3873.36 999.38 992.57 -119.52 50.00 50.00 50.00 50.00 50.00 Page 3 of 10 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 133. 151. 170. 190. 211. 06 352.52 3.28 MWD M 23 352.47 3,14 MWD M 51 352.42 2.32 MWD M 66 352.40 2.05 MWD M 57 352.41 1.79 MWD M 233. 256. 279. 304. 330. 35 352.43 2.68 MWD M 03 352.44 1.90 MWD M 78 352.42 3.68 MWD M 77 352.36 2.93 MWD M 82 352.27 2.75 MWD M 357. 385. 413. 443. 473. 66 352.19 1.60 MWD M -- 30 352.13 2.71 MWD M 78 352.08 2.01 MWD M 05 352.05 2.44 MWD M 10 352.03 1.93 MWD M 503. 535. 567. 600. 633. 89 352.02 2.45 MWD M 35 352.04 1,53 MWD M 39 352.06 2.00 MWD M 16 352.08 2.35 MWD M 69 352.11 2.40 MWD M 668. 703. 740. 776. 814. 13 352.16 3.29 MWD M 63 352.20 3.56 MWD M 03 352.26 2.48 MWD M 95 352.34 1.61 MWD M 02 352.45 1.22 MWD M 851. 888. 925. 962. 999. 11 352.57 0.73 MWD M 17 352.71 1.38 MWD M 37 352.85 1.71 MWD M 64 352.99 1.30 MWD_~ 74 353.13 0.45 MWD M (c)1999 Anadrill IDEAL ID5 0C 03R] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 61 4250,00 48.34 356.9 62 4300.00 50.13 356.7 63 4350.00 51.53 356.6 64 4400.00 53.45 356.6 65 4450.00 54.85 356.4 Course length (ft) 50.00 50.00 50.00 50.00 50.00 66 4500.00 56.86 356.2 67 4550.00 58.68 355.6 68 4600.00 60.54 354.6 69 4650.00 60.99 353.5 70 4700.00 60.91 353.3 50.00 50.00 50.00 50.00 50.00 71 4750.00 61.36 353.3 72 4800.00 61.38 353.2 73 4850.00 60.96 351.7 74 4900.00 60.61 351.0 75 4950.00 60.60 350.9 50 50 50 50 50 .00 .00 .00 .00 .00 76 5000.00 61.11 350.9 77 5050.00 61.22 351.0 78 5100.00 61.71 351.0 79 5150.00 61.90 351.0 80 5200.00 62.58 351.1 50.00 50.00 50.00 50.00 50.00 81 5250.00 62.57 351.1 82 5300.00 62.54 351.3 83 5350.00 61.85 351.3 84 5400.00 61.73 351.2 85 5450.00 61.43 351.2 50.00 50.00 50.00 50.00 50.00 86 5500.00 60.95 351.1 87 5550.00 60.56 351.1 88 5600.00 60.31 351.2 89 5650.00 59.97 351.4 90 5700.00 59.28 351.5 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 3906.69 3939.34 3970.92 4001.36 4030.64 4058.71 4085.37 4110.67 4135.09 4159.36 4183.50 4207.46 4231.57 4255.98 4280.52 4304.87 4328.98 4352.87 4376.49 4399.78 4422.81 4445.85 4469.18 4492.81 4516.61 4540.70 4565.13 4589.80 4614.70 4639.98 26-Mar-99 20:10:34 Vertical Displ section +N/S- (ft) (ft) 1036.49 1029.79 1074.20 1067.60 1112.81 1106.29 1152.32 1145.89 1192.70 1186.34 1233.93 1227.63 1276.11 1269.81 1319.16 1312.78 1362.75 1356.18 1406.43 1399.60 1450.20 1443.09 1494.07 1486.67 1537.87 1530.09 1581.50 1573.23 1625.06 1616.25 1668.73 1659.37 1712.53 1702.63 1756.45 1746.01 1800.52 1789.54 1844.76 1833.25 1889.14 1877. 1933.51 1920. 1977.74 1964. 2021.80 2008. 2065.77 2051. 2109.58 2094. 2153.21 2138. 2196.69 2181. 2240.06 2223. 2283.19 2266. Displ +E/W- (ft) -121.50 -123.61 -125.88 -128.23 -130.71 -133.38 -136.40 -140.09 -144.61 -149.64 -154.75 -159.91 -165.66 -172.22 -179.07 -185.98 -192.87 -199.74 -206.64 -213.52 Page 4 of 10 Total At DLS Srvy 'displ Azim (deg/ tool (ft) (deg) 100f) type 1036.93 353.27 0.60 MWD M 1074.73 353.40 3.59 MWD M 1113.43 353.51 2.80 MWD M 1153.04 353.61 3.84 MWD M 1193.51 353.71 2.82 MWD M 1234.85 353.80 4.03 MWD M 1277.12 353.87 3.78 MWD M 1320.24 353.91 4.10 MWD M 1363.87 353.91 2.12 MWD M 1407.57 353.90 0.38 MWD M 1451.36 1495.24 1539.03 1582.63 1626.14 1669.76 1713.52 1757.40 1801.43 1845.64 09 -220.39 1889.99 94 -227.17 1934.33 66 -233.86 1978.53 21 -240,57 2022,57 67 -247.29 2066.51 353.88 0.90 MWD M 353.86 0.18 MWD M 353.82 2.76 MWD M 353.75 1.41 MWD M 353.68 0.18 MWD M 95 -254.03 2110.30 06 -260.78 2153.90 03 -267.47 2197.37 89 -274.03 2240.71 55 -280.45 2283.83 353.61 1.02 MWD M 353.54 0.28 MWD M 353.47 0.98 MWD M 353.41 0.38 MWD M 353.36 1.37 MWD M 353.30 0.02 MWD M 353.26 0.36 MWD M 353.21 1.38 MWD M 353.17 0.30 MWD M 353.13 0.60 MWD M 353.09 0.98 MWD M 353.05 0.78 MWD M 353.01 0.53 MWD M 352.98 0.76 MWD M 352.95 1.39 MWD M Tool qual type (c)1999 Anadrill IDEAL ID5_0C_03R] ~NADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) Course length (ft) 91 5750.00 59.37 351.3 92 5800.00 58.89 351.2 93 5850.00 58.75 351.1 94 5900.00 58.09 351.0 95 5950.00 58.51 351.6 50.00 50.00 50.00 50.00 50.00 96 6000.00 58.78 350.1 97 6050.00 58.59 349.9 98 6100.00 57.93 349.6 99 6150.00 57.94 349.4 100 6200.00 58.45 349.3 50.00 50.00 50.00 50.00 50.00 101 6250.00 58.76 349.1 102 6300.00 58.78 348.9 103 6350.00 58.32 348.7 104 6400.00 58.84 349.2 105 6450.00 58.58 349.1 50.00 50.00 50.00 50.00 50.00 106 6500.00 58.71 348.8 107 6550.00 58.34 348.7 108 6600.00 58.46 348.6 109 6650.00 58.25 348.2 110 6700.00 59.17 348.2 50.00 50.00 50.00 50.00 50.00 111 6750.00 59.89 348.2 112 6800.00 59.35 348.3 113 6850.00 59.24 348.0 114 6900.00 58.45 348.0 115 6950.00 58.07 347.8 50.00 50.00 50.00 50.00 50.00 116 7000.00 57.68 347.9 117 7050.00 57.58 347.9 118 7100.00 58.66 348.6 119 7150.00 58.46 348.8 120 7200.00 57.93 348.7 50.00 50.00 50.00 50.00 50.00 TVD depth (ft) 4665.49 4691.14 4717.03 4743.21 4769.48 4795.50 4821.49 4847.79 4874.34 4900.69 4926.74 4952.66 4978.75 5004.81 5030.78 5056.80 5082.90 5109.10 5135.34 5161.30 5186.66 5211.95 5237.48 5263.34 5289.65 5316.24 5343.00 5369.41 5395.49 5421.84 26-Mar-99 20:10:34 Page 5 of 10 Vertical Displ Disp1 Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 2326.20 2309.07 2369.11 2351.49 2411.89 2393.75 2454.48 2435.82 2497.02 2477.86 2539.71 2520.01 2582.41 2562.08 2624.91 2603.92 2667.26 2645.58 2709.72 2687.34 2752.36 2729.27 2795.07 2771.24 2837.67 2813.08 2880.30 2854.96 2922.98 2896.91 2965.63 2938.81 3008.22 2980.64 3050.75 3022.38 3093.25 3064.07 3135.90 3105.89 3178.92 3148.08 3221.98 3190.31 3264.90 3232.38 3307.60 3274.24 3350.03 3315.81 3392.29 3357.21 3434.43 3398'.50 3476.82 3440.07 3519.42 3481.90 3561.86 3523.58 -286.88 2326.82 352.92 0.39 -293.41 2369.72 352.89 0.98 -300.02 2412.48 352.86 0.44 -306.69 2455.05 352.82 1.32 -313.16 2497.57 352.80 1.20 -319.98 2540.24 -327.40 2582.91 -334.97 2625.38 -342.69 2667.69 -350.54 ' 2710.11 MWD M -358.54 2752.72 -366.70 2795.39 -374.98 2837.96 -383.16 2880.55 -391.24 2923.21 352.76 2.45 MWD M 352.72 0.51 MWD M 352 . 67 1.42 MWD M 352.62 0.34 MWD M 352.57 1 . 03 MWD M -399.46 2965.84 -407.78 3008.40 -416.20 3050.90 -424.79 3093.38 -433.53 3136.01 -442 34 3179.00 -451.13 3222.05 -459.96 3264.94 -468.85 3307.63 -477.76 3350.06 352.52 0.71 MWD M 352.46 0.34 MWD M 352.41 0.98 MWD M 352.36 1.35 MWD M 352.31 0.62 MWD M 352.26 0.43 MWD M 352.21 0.76 MWD M 352.16 0.42 MWD M 352.11 0.66 MWD M 352.05 1.84 MWD M 352.00 1.44 MWD M 351.95 1.09 MWD M 351.90 0.56 MWD M 351.85 1.58 MWD M 351.80 0.83 MWD M -486.68 3392.30 351.75 0.80 -495.53 3434.44 351.70 0.20 -504.17 3476.82 351.66 2.47 -512.53 3519.42 351.63 0.53 -520.82 3561.86 351.59 1.07 MWD M (c)1999 Anadrill IDEAL ID5_0C_03R] ~NADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 6 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 7250.00 57.71 348.9 122 7300.00 59.17 350.1 123 7350.00 58.31 349.8 124 7400.00 58.37 349.5 125 7450.00 58.31 349.4 126 7500.00 58.74 349.5 127 7550.00 58.93 349.9 128 7600.00 59.93 350.5 129 7670.95 59.76 349.9 130 7767.97 59.81 349.6 131 7866.48 59.58 349.9 132 7962.18 59.03 350.2 133 8060.14 58.42 350.0 134 8157.45 58.04 349.2 135 8255.80 57.52 349.7 136 8352.85 57.18 350.8 137 8449.26 57.56 350.7 138 8545.83 56.81 351.9 139 8643.42 57.11 351.9 140 8741.74 56.61 352.7 141 8836.54 57.08 352.2 142 8933.26 57.20 353.0 143 9030.81 57.57 351.5 144 9127.49 57.85 352.1 -145 9223.77 57.60 352.3 146 9320.41 58.92 351.2 147 9417.48 58.67 351.2 148 9514.54 58.62 350.4 149 9612.23 59.90 350.7 150 9708.51 59.70 350.6 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 71.00 97.00 98.50 95.70 97.90 97.40 98.30 97.00 96.50 96.50 97.60 98.30 94.80 96.80 97.50 96.70 96.30 96.60 97.10 97.00 97.70 96.30 TVD depth (ft) 5448.47 5474.64 5500.59 5526.83 5553.07 5579.18 5605.06 5630.49 5666.15 5714.97 5764.67 5813.52 5864.35 5915.63 5968.04 6020.37 6072.41 6124.70 6177.92 6231.66 6283.50 6336.03 6388.58 6440.24 6491.66 6542.48 6592.79 6643.26 6693.20 6741.64 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3604.13 3565.09 3646.70 3606.98 3689.43 3649.06 3731.96 3690.93 3774.49 3732.77 3817.10 3774.69 3859.86 3816.79 3902.90 3859.21 3964.27 3919.70 4048.05 4002.19 4133.05 4085.87 4215.31 4166.92 4298.96 4249.35 4381.71 4330.80 4464.81 4412.55 4546.46 4493.04 4627.72 4573.26 4708.82 4653.42 4790.64 4734.42 4872.94 4815.99 4952.30 4894.67 5033.59 4975.30 5115.71 5056.67 5197.45 5137.58 5278.87 5218.25 5361.02 5299.55 5444.07 5381.62 5526.89 5463.37 5610.85 5546.19 5694.07 5628.32 -529.04 -536.80 -544.26 -551.91 -559.70 -567.51 -575.16 -582.48 -592.93 -607.85 -622.98 -637.20 -651.59 -666.53 -681.76 -695.59 -708.65 -720.93 -732.45 -743.48 -753.91 -764.38 -775.46 -787.12 -798.17 -809.96 -822.67 -835.98 -849.84 -863.36 Total At DLS Srvy Tool 'displ Azim (deg/ tool qual (ft) (deg) 100f) type type 3604.13 351.56 0.56 MWD M 3646.71 351.54 3.56 MWD M 3689.43 351.52 1.79 MWD M 3731.97 351.50 0.52 MWD M 3774.50 351.47 0.21 MWD M 3817.12 351.45 0.88 MWD M 3859.88 351.43 0.78 MWD M 3902.92 351.42 2.25 MWD M 3964.30 351.40 0.77 MWD M 4048.08 351.36 0.27 MWD M 4133.09 351.33 0.35 4215.36 351.31 0.63 4299.02 351.28 0.65 4381.79 351.25 0.80 4464.91 351.22 0.68 MWD M 4546.57 351.20 1.02 MWD M 4627.83 351.19 0.40 MWD 4708.93 351.19 1.30 MWD 4790.74 351.21 0.31 MWD 4873.04 351.22 0.85 MWD 4952.39 351.24 0.66 MWD 5033.67 351.27 0.71 MWD 5115.78 351.28 1.35 MWD M 5197.53 351.29 0.60 MWD M 5278.94 351.30 0.31 MWD M 351.31 1.67 MWD M 351.31 0.26 MWD M 351.30 0.79 MWD M 351.29 1.36 MWD_~ 351.28 0.23 MWD M 5361.08 5444.13 5526.96 5610.93 5694.15 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis (c)1999 Anadrill IDEAL ID5 0C 03R] ~NADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 7 of 10 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- 'displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 151 9806.70 59.45 350.5 98.20 6791.37 5778.73 5711.85 -877.26 5778.82 351.27 0.27 MWD M - 152 9904.90 59.20 351.9 98.20 6841.47 5863.19 5795.31 -890.19 5863.28 351.27 1.25 MWD M - 153 10002.89 58.85 350.1 98.00 6891.91 5947.20 5878.29 -903.33 5947.30 351.26 1.61 MWD M - 154 10101,18 59.77 349.6 98.30 6942.08 6031.69 5961.50 -918.23 6031.80 351.24 1.03 MWD M - 155 10199.80 59.51 351.2 98.60 6991.92 6116.75 6045.38 -932.42 6116.87 351.23 1.42 MWD M - 156 10295.49 59.27 348.5 95.70 7040.65 6199.06 6126.45 -946.93 6199.20 351.21 2.44 MWD M - 157 10392.36 59.03 348,6 96.90 7090,34 6282.13 6207.98 -963.44 6282.30 351.18 0.26 MWD--M - 158 10489.45 60.05 348.8 97.10 7139,57 6365.72 6290.04 -979.91 6365.91 351.15 1.05 MWD M - 159 10586.88 59.90 349.0 97.40 7188,30 6449.96 6372.78 -996.22 6450.18 351.12 0.31 MWD M - 160 10638.76 59.31 348.3 51.90 7214,56 6494.66 6416.67 -1005.03 6494.90 351.10 1.63 MWD M - 161 10781.31 59.25 348.3 142.50 7287,36 6616.96 6536.63 -1029.87 6617.26 351.05 0.04 MWD M - 162 10877.68 60.43 347.4 96.40 7335,79 6700.13 6618.11 -1047.42 6700.48 351.01 1.47 MWD M - 163 10974.67 60.22 347,8 97.00 7383,81 6784.21 6700.42 -1065.51 6784.61 350.96 0.42 MWD M - 164 11071.61 59.99 348.2 96.90 7432,11 6868.05 6782.59 -1082.98 6868.51 350.93 0.43 MWD M - 165 11169.48 60.99 349.1 97.90 7480.33 6953.13 6866.12 -1099.74 6953.64 350.90 1.30 MWD M - 166 11268.41 60.72 347.9 98.90 7528,50 7039.38 6950.76 -1116.96 7039.94 350.87 1.09 MWD M - 167 11366.91 60.90 349.3 98.50 7576.54 7125.25 7035.06 -1133.96 7125.86 350.84 1.25 MWD 6-axis 168 11461.88 61.80 350.0 95.00 7622.09 7208.57 7117.07 -1148.93 7209.21 350.83 1.15 MWD 6-axis 169 11559.05 61.86 349.7 97.20 7667,98 7294.22 7201.41 -1164.03 7294.88 350.82 0.28 MWD 6-axis 170 11657.48 62.02 350.1 98.40 7714.27 7381.02 7286.90 -1179.26 7381.71 350.81 0.39 MWD 6-axis 171 11753.94 62.92 351.5 96.40 7758.82 7466.49 7371,28 -1192.92 7467.19 350.81 1.59 MWD 6-axis 172 11850.88 63.09 351.1 97.00 7802.85 7552.92 7456.72 -1206.00 7553.61 350.81 0.41 MWD 6-axis 173 11947.05 63.44 350.9 96.10 7846.09 7638.74 7541.49 -1219.42 7639.44 350.82 0.41 MWD 6-axis 174 12043.88 63.40 351.6 96.90 7889.44 7725.40 7627.14 -1232.61 7726.10 350.82 0.65 MWD 6-axis 175 12140.66 64.15 352.5 96.80 7932.22 7812.23 7713.14 -1244.62 7812.91 350.83 1.14 MWD 6-axis 176 12238.00 63.95 352.8 97.30 7974.80 7899.70 7799.91 -1255.81 7900.36 350.85 0.35 MWD 6-axis 177 12335.03 63.51 352.7 97.00 8017.73 7986.67 7886.19 -1266.79 7987.29 350.87 0.46 MWD 6-axis 178 12432.29 63.42 352.4 97.30 8061.20 8073.71 7972.51 -1278.07 8074.30 350.89 0.29 MWD 6-axis 179 12528.98 63.49 352.8 96.70 8104.41 8160.20 8058.29 -1289.21 8160.77 350.91 0.38 MWD 6-axis 180 12625.72 63.34 352.5 96.70 8147.69 8246.66 8144.06 -1300.28 8247.21 350.93 0.32 MWD 6-axis (c)1999 Anadrill IDEAL ID5 0C 03R] ;kNADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 181 12722.77 62.95 352.6 182 12816.95 62.77 352.2 183 12915.06 62.72 352.6 184 13013.48 62.28 352.4 185 13110.45 62.15 352.2 Course length (ft) 97.10 94.20 98,10 98.40 96.90 186 13206.83 61.58 352.6 187 13303.58 61.35 352.4 188 13400.30 60.91 352.2 189 13496.65 60.15 350.8 190 13592.08 60.60 349.4 96.40 96.80 96.70 96.30 95.50 191 13688.50 60.47 347.8 192 13784.86 60.11 346.0 193 13881.97 60.73 344.4 194 13979.45 60.91 342.7 195 14076.05 60.94 342.8 96.40 96.40 97.10 97.50 96.50 196 14175.34 60.90 342.8 197 14271.27 61.30 343.3 198 14369.04 61.09 342.0 199 14465.67 60.72 343.0 200 14562.40 60.65 343.0 99.30 96.00 97.70 96.70 96.70 201 14659.86 60.73 341.7 202 14756.32 60.92 342.9 203 14853.22 61.11 342.6 204 14950.18 61.01 342.7 205 15047.64 61.20 342.7 97.50 96.40 96.90 97.00 97.40 206 15145.60 61.27 342.7 207 15242.90 61.18 342.5 208 15339.97 60.98 343.0 209 15436.98 61.15 342.9 210 15533.78 61.11 342.6 98.00 97.30 97.10 97.00 96.80 TVD depth (ft) 8191.55 8234.52 8279.45 8324.88 8370.06 8415.51 8461.75 8508.44 8555.82 8603.03 8650.45 8698.23 8746.17 8793.71 8840.60 8888.86 8935.26 8982.33 9029.36 9076.70 9124.43 9171.43 9218.38 9265.32 9312.38 9359.54 9406.38 9453.34 9500.27 9547.01 26-Mar-99 20:10:34 Vertical section (ft) 8333.27 8417.09 8504.29 8591.56 8677.29 Page 8 of 10 Displ Displ Total At DLS Srvy Tool +N/S- +E/W- 'displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) 100f) type type 8762.29 8847.32 8931.99 9015.83 9098.81 8229.96 -1311.51 8313.05 -1322.59 8399.49 -1334.13 8486.03 -1345.52 8570.98 -1357.01 9182.63 9266.07 9349.98 9434.27 9517.61 8655.24 -1368.25 8739.56 -1379.35 8823.47 -1390.70 8906.39 -1403.08 8988.17 -1417.36 9603.37 9686.48 9771.05 9854.49 9937.86 9070.44 -1433.95 9151.98 -1452.92 9233.62 -1474.49 9315.26 -1498.60 9395.80 -1523.61 9478.71 -1549.27 9559.10 -1573.77 9640.81 -1599.30 9721.40 -1624.71 9802.03 -1649.36 10021.77 9883.04 -1675.14 10104.83 9963.23 -1700.73 10188.59 10044.18 -1725.87 10272.45 10125.20 -1751.18 10356.70 10206.62 -1776.54 10441.57 10288.64 -1802.08 10525.81 10370.02-1827.59 10609.79 10451.19 -1852.79 10693.72 10532.35 -1877.68 10777.48 10613.31 -1902.82 8333.80 350.95 0.41 8417.60 350.96 0.42 8504.78 350.97 0.37 8592.04 350.99 0.48 8677.74 351.00 0.23 8762.72 351.02 0.70 8847.74 351.03 0.30 8932.40 351.04 0.49 9016.23 351.05 1.49 9099.23 351.04 1.36 MWD MWD MWD MWD MWD l',4'W D MWD MWD MWD MWD 9183.09 351.02 1.45 MWD 9266.59 350.98 1.66 MWD 9350.61 350.93 1.57 MWD 9435.03 350.86 1.53 MWD 9518.54 350.79 0.10 MWD 9604.48 350.72 0.04 9687.78 350.65 0.62 9772.57 350.58 1.19 9856.23 350.51 0.98 9939.83 350.45 0.07 lvlWD MWD MWD MWD MWD 10024.00 350.38 1.17 MWD 10107.34 350.31 1.10 MWD 10191.38 350.25 0.33 MWD 10275.52 350.19 0.14 MWD 10360.08 350.13 0.20 MWD 350.07 0.07 MWD 350.01 0.20 MWD 349.95 0.50 MWD 349.89 0.20 MW~ 349.84 0.27 MWD 10445.27 10529.84 10614.15 10698.42 10782.53 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis (c)1999'Anadrill IDEAL ID5 0C 03R] ~NADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 9 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total depth section +N/S- +E/W- 'displ (ft) (ft) (ft) (ft) (ft) At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 211 15630.72 61.16 212 15727.11 61.02 213 15748.75 61.11 214 15868.40 61.51 215 15960.60 62.12 342.8 96.90 9593.78 10861.32 10694.33 -1928.06 10866.74 349.78 0.19 MWD 6-axis 342.6 96.40 9640~.39 10944.69 10774.90 -1953.15 10950.49 349.73 0.23 MWD 6-axis 342.6 21.70 9650.89 10963.45 10793.02 -1958.83 10969.33 349.71 0.41 MWD 6-axis 342.7 119.60 9708.30 11067.09 10893.16 -1990.12 11073.46 349.65 0.34 MWD M - 343.0 92.20 9751.85 11147.42 10970.82 -2014.08 11154.16 349.60 0,72 MWD 6-axis 216 16054.69 62.04 217 16151.46 61.65 218 16241.79 61.69 219 16332.89 61.43 220 16425.86 61.16 342.8 94.10 9795.91 11229.61 11050.29 -2038.53 11236.75 349.55 0.21 342.5 96.80 9841.59 11313.92 11131.75 -2063.98 11321.48 349.50 0.49 342.6 90.30 9884.44 11392.42 11207.58 -2087.81 11400.38 349.45 0.11 342.5 91.10 9927.83 11471.53 11284.00 -2111.83 11479.91 349.40 0.30 343.6 93.00 9972.49 11552.19 11362.02 -2135.62 11560.99 349.35 1.08 MWD 6-axis MWD 6-axi s MWD 6-axis MWD 6-axi s MWD 6-axi s 221 16523.13 60.69 222 16619.65 59.79 223 16713.72 57.38 224 16807.99 54.07 225 16903.64 51.28 343.2 97.20 10019.73 11636.28 11443.43 -2159.88 11645.48 349.31 0.60 342.1 96.50 10067.63 11719.03 11523.39 -2184.86 11728.69 349.26 1.36 342.9 94.10 10116.67 11798.32 11599.97 -2209.02 11808.43 349.22 2.66 344.2 94.30 10169.78 11875.46 11674.69 -2231.09 11885.96 349.18 3.69 343.4 95.60 10227.74 11950.77 11747.69 -2252.29 11961.65 349.15 2.99 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 226 16992.20 47.41 227 17088.10 43.61 228 17184.99 39.64 229 17286.80 36.58 230 17380.18 34.74 343.7 88.60 10285.45 12017.31 11812.14 -2271.33 12028.53 349.12 4.38 344.7 95.90 10352.64 12085.14 11877.95 -2289.97 12096.68 349.09 4.03 345.3 96.90 10425.06 12149.07 11940.10 -2306.64 12160.86 349.07 4.12 345.0 101.80 10505.15 12211.49 12000.83 -2322.73 12223.54 349.05 3.01 344.6 93.40 10581.03 12265.56 12053.37 -2337.00 12277.84 349.03 1.99 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 231 17474.29 34.43 232 17563.47 34.24 233 17658.60 33.78 234 17753.48 33.04 235 17847.66 32.10 344.3 94.10 10658.51 12318.56 12104.83 -2351.32 12331.08 349.01 0.38 343.8 89.20 10732.16 12368.44 12153.20 -2365.15 12381.21 348.99 0.38 343.5 95.10 10810.99 12421.12 12204.25 -2380.12 12434.17 348.96 0.51 342.7 94.90 10890.21 12472.80 12254.24 -2395.31 12486.15 348.94 0,91 341.3 94.20 10969.60 12522.80 12302.47 -2410.97 12536.49 348.91 1.28 MWD 6-axis MWD 6-axi s MWD 6-axis MWD 6-axis MWD 6-axi s 236 17941.01 31.59 237 18034.46 30.82 238 18129.13 29.92 239 18222.83 29.04 240 18317.14 28.28 340.9 93.30 11048.85 12571.20 12349.04 -2426.91 12585.26 348.88 0.59 340.0 93.50 11128.83 12618.73 12394.69 -2443.12 12633.18 348.85 0.96 340.0 94.60 11210.44 12665.58 12439.64 -2459.48 12680.44 348.82 0.95 338.9 93.70 11292.01 12710.67 12482.82 -2475.66 12725.94 348.78 1.10 339.1 94.30 11374.76 12754.80 12525.04 -2491.87 12770.51 348.75 0.81 MWD 6-axis MWD 6-axi s MWD 6-axis MW~ 6-axis MWD 6-axis (c) 1999 Anadrill IDEAL ID5_0C_03R] ~NADRILL SCHLUMBERGER Survey Report 26-Mar-99 20:10:34 Page 10 of 10 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 241 18404.34 27.41 242 18501.51 26.44 243 18597.26 25.68 244 18631.51 25.22 245 18688.26 24.67 TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) Displ Total At DLS Srvy Tool +E/W- 'displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 337.8 87.20 11451.86 12794.47 12562.92 -2506.82 12810.59 348.72 1.22 337.2 97.20 11538.52 12837.16 12603.58 -2523.66 12853.76 348.68 1.04 336.1 95.80 11624.58 12877.82 12642.22 -2540.33 12894.93 348.64 0.94 336.6 34.20 11655.47 12892.00 12655.69 -2546.23 12909.29 348.62 1.48 336.7 56.80 11706.97 12915.14 12677.68 -2555.73 12932.72 348.60 0.97 MWD 6-axis MWD 6-axi s MWD 6-axis MWD 6-axis MWD 6-axis 246 18783.05 23.45 247 18876.08 21.11 248 18969.20 19.07 249 19062.77 18.31 250 19156.07 17.55 336.1 94.80 11793.53 12952.44 12713.10 -2571.19 12970.50 348.57 1.31 335.7 93.00 11879.58 12986.39 12745.28 -2585.58 13004.90 348.53 2.52 334.3 93.10 11967.01 13017.04 12774,27 -2599.08 13036.00 348.50 2.25 333.1 93,60 12055.68 13045.58 12801.16 -2612.36 13065.00 348.47 0.91 332.5 93.30 12144.44 13072.77 12826.71 -2625.49 13092.65 348.43 0.84 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 251 19246.95 16.53 252 19296.00 16.07 331.7 90.90 12231.35 13097,88 12850,25 -2637.95 13118.22 348.40 1.15 332.0 49.00 12278.38 13110.83 12862.38 -2644.44 13131.40 348.38 0.95 MWD 6-axis MWD 6-axis inal survey projected to total depth for well 253 19400.00 15.00 332.0 104.00 12378.58 13137.07 12886,97 -2657.51 13158.13 348.35 1.03 MWD M (c) 1999 Anadrill IDEAL ID5_0C_03R] SHOW REPORTS This section of the report contains copies of show evaluation reports for Red Dog No. 1. These reports are based on chromatograph evaluations of gases normally retrieved fzom mud samples injected into Sperry-Sun's Steam Still apparatus; consequently, interpretations made on each report reflect this procedure.. Show reports are not always included in the well report analysis because of restricted information requirements placed on exploration wells. They do offer some insight of fluid content on potential producing zones of good permeability; however, they are often inadequate on tight zones or when mud-gas samples are taken while coting. Please refer to the attachment regarding SPE-AIME, B.O. Pixler referencing hydrocarbon ratio evaluations. ~AMMARAY AU~RA~ ~A$ F.I.D. RHRLS~$IS TOTAL GAS IN AlE HrCp Hatch = IX10] C~LC+CL¥.g8~ qTZ.lSz CHT~ LITH.Tk ~R~ N~T.18~ PALE SHOW REPORTS This section of the report contains copies of show evaluation reports for Red Dog No. 1. These reports are based on chromatograph evaluations of gases normally retrieved ~om mud samples injected into Sperry-Sun's Steam Still apparatus; consequently, interpretations made on each report reflect this procedure.. Show reports are not always included in the well report analysis because of restricted information requirements placed on exploration wells. They do offer some insight of fluid content on potential producing zones of good permeability; however, they are often inadequate on tight zones or when mud-gas samples are taken while coting. Please refer to the attachment regarding SPE-AIME, B.O. Pixler referencing hydrocarbon ratio evaluations. Show Report .~_/ 1 ~-dJD LOGGING Depth Interval 16845 to 16885 DRILLIN~ =~RVIC~ TrueVert. Depth 10196 to 10217 Prepared by D. Wilson Operator B P Exploration Delivered to J. Siok Well Name RED DOG # 1 Date 3/11/99 Time 6:00 Location North Slope Alaska ~ ZONE PRODUCTION [] ~ [~] OIL ~] WATER D NON-PRODU~ HYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 16845 ft GAS 324 unit CHLOR. 24 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C1 20,800 - 690 = 20,110 CliO2 = 24 C2 970 - 124 ---- 846 Cl/C3 = 41 C3 690 - 197 = 493 C~/C4 = 72 C4 467 - 189 = 278 C~/Cs = 251 Cs ' 198 - 118 = 80 PRODUCTION ANALYSIS r~l GAS r-]OIL r'~ WA~ [-~ NON-PROD. DEPTH 16851 ft GAS 649 unit CHLOR. 24k Cl FLOWLINE-SUCTION = SHOW ppm ppm 25,000- 690 = 24,310 C2 1,280 - 124 = 1,156 C3 940 - 197 = 743 C4 637 - 189 = 448 Cs 268 - 118 = 150 HYDROCARBON RATIOS Cl/C2 -- 21 CllC3 = 33 CliO4 = 54 C~/Cs = 162 PRODUCTION ANALYSIS [~GAS [~] OIL [-'~ WATER r'~ NON-PROD. LITHOLOGY SANDSTONE-PREDOMINATELY UNCONSOLIDATED, MILKY, OPAQUE TO TRANSLUCENT,CLEAR, VERY FINE-FINE GRAIN, ANGULAR TO SUBROUND, WELL SORTED, OCCASIONALLY POORLY CEMENTED - LIGHT GRAY, SUBANGULAR TO SUBROUND, WITH CLAY CEMENT, CARBONACEOUS / ASPHALTIC MATERIAL, VERY FRIABLE. SHOW EVALUATION IPINPOINT ORANGE FLUORESCENCE, TRACE FAINT-SLOW YELLOW CUT AND RESIDUAL CUT FLUORESCENCE. STEAM STILL CHROMATOGRAPHIRATIO ANALYSIS INDICATES ZONE PRODUCES GAS OR OIL WITH HIGH GOR. REMARKS IMWD RESISTIVITY READINGS IN THIS ZONE HAD A MAXIMUM OF 12-13 OHM-M2/M FROM DATA PROVIDED BY ANADRILL SCHLUMBERGER. GOOD GAS SHOW. OVERALL SHOW QUALITY IS FAIR FOR OIL. 1,000 100 10 1X~O I00 10 HYDROCARBON RATIOS Cl/C2 Cl/C3 C1/C4 Cl/C5 HYDROCARBON RATIOS Cl/C2 Cl/C3 C1/C4 Cl/C5 · ~.~UD LOGGING Depth Interval 17300 to 17340 13 R I L L I I~1G 6 E Iq V I C E · True Vert. Depth 10515 to 10547 Prepared by D. Wilson Operator B P Exploration Delivered to J. Siok Well Name RED DOG # 1 Date 3/15/99 Time 12:00 Location North Slope Alaska ~, ZONE PRODUCTION I-I GAS [-~ OIL r~ WATER r-~ NON-PRODUCT[VE HYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 17300 ft GAS 55 unit CHLOR. 24 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C1 2,420- 142 = 2,278 Cl/C2 = 11 C2 230 - 23 = 207 Cl/C3 = 7 C3 382 - 46 = 336 O1/O4 = 6 C4 444 - 43 = 401 Cl/Cs = 11 C5 ' 249 - 44 = 205 PRODUCTION ~IGAs E]OIL [~] WATER r-I NON-PROD. ANALYSIS DEPTH 17320 ft GAS 58 unit CHLOR. 31 k ppm ppm RATIOS Cl 4,200- 690 = 3,510 C1/C2 = 11 C2 435 - 124 = 311 C~lC3 = 8 C3 6{~5 - 197 = 468 Cl/C4 = 6 C4 735 - 189 = 546 C~/Cs = 13 Cs 388 - 118 = 270 PRODUCTION ANALYSIS E]GAS [--] OIL r~ WATER r"~ NON-PROD. LITHOLOGY SANDSTONE-CLEAR TO OPAQUE, GRAY, VERY FINE TO FINE GRAINED, SUBANGULAR, MODERATELY SORTED, 85% UNCONSOLIDATED, 15% CEMENTED WITH CALCITE, 80% QUARTZ, 20% LITHICS AND CHERT, INCREASED CARBONACEOUS MATERIAL, CLAY MATRIX IN PART. SHOW EVALUATION INO FLUORESCENCE OBSERVED. STEAM STILL - CHROMATOGRAPH RATIO ANALYSIS INDICATES THAT THIS INTERVAL MAY BE WET. REMARKS IMWD RESISTIVITY READINGS IN THIS ZONE HAD A MAXIMUM OF 11 OHM-M2/M FROM DATA PROVIDED BY ANADRILL SCHLUMBERGER. OIL SHOW QUALITY FOR THIS ZONE IS VERY POOR. 1,000 100 10 10 HYDROCARBON RATIOS c1/c2 Cl/03 Cl/04 C1/05 HYDROCARBON RATIOS Cl/C2 C1/C3 C1/04 C1/05 '~iUD LOGGING rlRILLIklG GGPlVICGG Operator B P Exploration Well Name RED DOG # 1 Location North Slope Alaska ZONE PRODUC'rlON [-I GAS Show Report Depth Interval True Vert. Depth Prepared by Delivered to Date r-] OIL r"] WATER 17515 to 17600 10691 to 10760 w. Hermanson J. Siok 3/15/99 Time 12:00 r~l NON-PRODUCTIVE HYDRCXT. AR~S CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 17529 ft GAS 985 unit CHLOR. 32 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C1 32,400- 1,640 = 30,760 Cl/C2 = 13 C2 2,720 - 266 = 2,454 Cl/C3 -- 17 C3 2,260 - 465 = 1,795 Cl/C4 = 19 C4 2,160 - 498 = 1,662 Cl/Cs = 25 Cs ' 1,465 - 243 = 1,222 PRODUCTION [--~ GAS r'~ OIL D WATER r'~ NON-PROD. ANALYSIS DEPTH 17560 ft GAS 1600 unit CHLOR. 32 k Cl FLOWLINE-SUCTION = SHOW ppm ppm 29,600- 1,640 = 27,960 C2 2,680 - 266 = 2,414 C3 2,360 - 465 = 1,895 C4 2,135 - 498 = 1,637 C5 1,375 - 243 = 1,132 HYDROCARBON RATIOS Cl/C2 = 12 Cl/C3 -- 15 Cl/C4 = 17 Cl/C5 = 25 PRODUCTION ANALYSIS ~GAS ['~ OIL [~ WATER [--]NON-PROD. LITHOLOGY SANDSTONE-CLEAR TO OPAQUE, LIGHT GRAY, VERY FINE TO FINE GRAINED, GRADING TO SLITY, SUBANGULAR TO SUBROUND, MODERATELY TO OCCASIONALLY WELL SORTED, 95% UNCONSOLIDATED, 5% CEMENTED WITH CALCITE AND CLAY, 95% QUARTZ, 5% LITHICS, TRACE CARBONACEOUS MATERIAL. SHOW EVALUATION 30% PALE YELLOW GOLD FLUORESCENCE, SLOW STREAMING CREAM CUT. STEAM STILL CHROMATOGRAPH RATIO ANALYSIS INDICATES THAT ZONE CONTAINS OIL. REMARKS IMWD RESISTIVITY READINGS IN THIS ZONE HAD A MAXIMUM OF 8 - 90HM-M2/M. ALTHOUGH INTERVAL CONTAINED HIGH BACKGROUND GAS, LOW RESISTIVITY READINGS AND POOR GAMMA RAY RESPONSE INDICATE LOW POROSITY. O..VE~RALL OIL SHOW QUALITY IS POOR. 1,000 100 10 HYDROCARBON RATIOS Cl/C2 C1/C3 Cl/C4 Cl/C5 NONi'ROD;[JCTIVE / ~~~_ HYDROCARBON RATIOS C1/C2 C 1/C3 C1/C4 Cl/C,5 NONPRODUCT~'E ~ sp~lr~.v,.sur,~ . ShowReport -~" 4 WlUD LOGGING Depth interval 17625 to 17700 13 R I L L I N G = 6 Iq V I r- 6 6 True Vert. Depth 10782 to 10844 Prepared by D. Wilson / W. Hermanson Operator B P Exploration Delivered to J. Siok Well Name RED DOG # 1 Date 3/15/99 Time 12:00 Location North Slope Alaska - ZONE PRODUCTION [-I GAS [~ OIL [--i WATER r~ NON-PRODUCTzvE HYDROCARBONS CONTACT DEPTH Gas/Oil ft GasNVater ft OilNVater ft DEPTH 17650 ft GAS 938 unit CHLOR. 32 k ........ "--' ' ........ .... ppm ppm RATIOS Cl 23,600- 2,060 = 21,540 Cl/C2 = 13 C2 1,860 - 242 = 1,618 C~/C3 = 18 C3 1,450 - 282 = 1,168 C~/C4 = 37 04 939 - 357 = 582 C~/Cs = 567 C5 ' 318 - 280 = 38 PRODUCTION ANALYSIS E~GAS DOIL r']WATER r~l NON-PROD. DEPTH 17685 ft GAS 1300 unit CHLOR. 32 k ........ ....... .... ppm ppm RATIOS Cl 71,500- 2,060 = 69,440 C~/C2 = 13 C2 5,400 - 242 = 5,158 C~1C3 = 19 C3 3,960 - 282 = 3,678 C~/C4 = 32 C4 2,505 - 357 = 2,148 C~/Cs = 112 C5 899 - 280 = 619 PRODUCTION ANALYSIS r'~] GAS Iii]OIL F'IWATER E] NON-PROD. LITHOLOGY SANDSTONE-CLEAR TO OPAQUE, LIGHT GRAY, VERY FINE TO FINE GRAINED, GRADING TO SLITY, SUBANGULAR TO SUBROUND, MODERATELY TO OCCASIONALLY WELL SORTED, 95% UNCONSOLIDATED, 5% CEMENTED WITH CALCITE AND CLAY, 95% QUARTZ, 5% LITHICS, TRACE CARBONACEOUS MATERIAL. INTERVAL WAS PRIMARILY LOGGED AS SILTSTONE. SHOW EVALUATION 30% PALE YELLOW GOLD FLUORESCENCE, SLOW STREAMING CREAM CUT. STEAM STILL - CHROMATOGRAPH RATIO ANALYSIS INDICATES ZONE TO CONTAIN OIL & GAS. STEEP SLOPE INDICATES TIGHT ZONE. REMARKS IMWD RESISTIVITY READINGS IN THIS ZONE HAD A MAXIMUM OF 7 - 80HM-M2/M. ALTHOUGH INTERVAL CONTAINED HIGH BACKGROUND GAS READINGS, LOW RESISTIVITY READINGS AND POOR GAMMA RAY RESPONSE INDICATE LOW POROSITY. OVERALL OIL SHOW QUALITY IS POOR FOR TH!S !N .TE,,RVAL. 1,000 lO0 10 10 HYDROCARBON RATIOS Cl/C2 Cl/C3 Cl/C4 Cl/C5 HYDROCARBON RATIOS Cl/C2 Cl/C3 C1/C4 Cl/C5 NON PRODUCTI~'E GA~ Oil_ Show Report '~--" 5 '~UD LOGGING Depth Interval 17790 to 17910 DRILLING =GRVICE5 True ~/efL Depth 10920 to 11025 Prepared by W. Hermanson Operator B P Exploration Delivered to J. Siok Well Name RED DOG # 1 Date 3/15/99 Time 12:00 Location Norl~ Slope Alaska ~ ZONE PRODUCTION [-! GAS r-I OIL [-I WATER, [] NON-PRODUCTZVE HYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ff DEPTH 17820 ft GAS 1100 unit CHLOR. 32 k FLO~Mr~ll~;l~_-~i~ = ~ ~3~:~3~.t~3~ C~ 16,600- 2,060 = 14,540 Cl/C2 "' 8 C2 1,980 - 242 = 1,738 C~/C3 = 8 C3 2,160 - 282 = 1,878 C~/C4 -- 10 C4 1,835 - 357 = 1,478 Cl/C5 -- 26 Cs ' 841 - 280 = 561 PRODUCTION ANALYSIS DGAS I'~1 OIL [:]WATER I-'! NON-PROD. DEPTH 17900 ft GAS 1250 unit CHLOR. 32 k ........ ....... ..... ppm ppm RATIOS C1 29,400- 2,060 = 27,340 Cl/C2 ---- 12 C2 2,540 - 242 = 2,298 Cl/C3 = 13 C3 2,400 - 282 = 2,118 C~/C4 = 20 C4 1,730 - 357 = 1,373 C~1C5 = 72 C5 662 - 280 = 382 PRODUCTION ANALYSIS OGAS F~IoIL E] WATER` [--~ NON-PR`OD. LITHOLOGY SANDSTONE-LIGHT TO VERY LIGHT GRAY, EXTRA FINE TO VERY FINE GRAINED, FINE GRAINED IN PART, ANGULAR, MODERATELY SORTED, ~tOSTLY UNCONSOLIDATED IN SILSTONE MATRIX, VERY FRIABLE IN ~ART, LITHIC, TUFFACEOUS, OCCASIONAL CARBONACEOUS SPECKS AND LAMINATIONS,GRADING TO SILTSTONE. INTERVAL IS PRIMARILY SILTSONE. SHOW EVALUATION 20% PALE YELLOW GOLD FLUORESCENCE, POOR YELLOW-WHITE CRUSH CUT. STEAM STILL CHROMATOGRAPH RATIO ANALYSIS INDICATES THAT ZONE CONTAINS OIL. REMARKS IMWD RESISTIVITY READINGS IN THIS ZONE HAD A MAXIMUM OF 10 OHM-M2/M - AVERAGING ABOUT 6. ALTHOUGH INTERVAL CONTAINED HIGH BACKGROUND GAS, LOW RESISTIVITY AND POOR GAMMA RAY RESPONSE INDICATE POOR POROSITY. OVERALL OIL SHOW QUALITY IS VERY POOR. lO0 10 10 HYDROCARBON RATIOS C1/C2 C11C3 C1/C4 Cl/C5 HYDROCARBON RATIOS Cl/C2 C1/C3 Ct/C4 C 1/C5 PIXLER's PREMISES for LOGGING SYSTEMS SHOW EVALUATIONS Formation Evaluation Hydrocarbon Ratios B. O. Pixler, SPE-AIME, Baroid Div. National Lead Co. by Analysis of Introduction Mud logging was first offered commercially in Aug., 1939. This logging method quickly gained favor among many operators because the type of fluid in the formation could be determined within minutes after the formation was drilled. The presence and magni- tude of the methane show was and is the most im- portant factor in mud log interpretation. However this magnitude in some instances was improperly understood, and as a consequence some operators still do not use mud logging, even though the early technique frequently made the difference between a successful well and an abandoned hole. Both the "hot wire" log of gas combustibles in the sample and the percent-of-gas log obtained with the conventional gas trap and the gas chromato~aph indicate only that the reservoir in question contains hydrocarbons. These methods do not necessarily indicate the quantitative amounts of the various hydrocarbons in the mud. The addition of a new Steam Still-Reflux gas sam- pling system to gas chromato~aphy enables accurate determination of the composition of the mud gas sample. A knowledge of gas composition makes it possible to establish the relationship of methane to the heavier hydrocarbon shows. An awareness of this relationship led to a new, additional mud log inter- pretative technique that permits relating the quanti- tative amounts of methane (C~), ethane (C_~), pro- pane (Ca), butane (C0, and pentane (C~) to in-place reservoir fluid content. A long-accepted premise is that as formations are drilled, the drilling mud filtrate partially flushes the formation fluid ahead of the bit. It was generally thought that the formations were flushed to an irre- ducible minimum m generally considered to be about 30 percent of in-place fluid. Experience in mud log- ging, however, has shown that this rarely happens. This partial flushing does not prevent mud logging from successfully determining productive or non- productive formations. Experienced logging engi- neers, in possession of quantitative gas analyses, make interpretations that take into account the flushing that results in rocks of various permeabilities, the effect of overbalanced mud weight and the effect of initial filtrate loss. Method Ordinarily, when formation cuttings are drilled they retain much of the formation pore fluid. This fluid is released to the mud column as the cuttings travel up the annulus. Most of the formation fluid in the cut- tings will be "produced" into the drilling mud during the top 500 ft of hole travel. Conventionally, a mud sample is diverted to a mechanically operated gas trap to obtain a sample of the gas in the mud. The efS- ciency of this trap is from 15 to 70 percent, depending upon the gel strength of the mud, the amount of mud flowing through the trap and the rotation speed of the trap impeller. The magnitude of the conventional The ratio o/ methane to the heavier hydrocarbon components ~ ethane, propane, butane, and pentane ~ is indicative of gas, oil and water productive potential. The Steam Still-Reflux Unit, used in conjunction with mud logs and gas chromatographs ¥ields a quantitative analysis from which this ratio can be plotted. gas show is, therefore, quanutauve only to the air-gas sample obtained. The sample is accurately analyzed Dy the gas chromatograph; but, because the sample furnished by the conventional gas trap represents only a fraction of the gas present in the mud, and because that fraction is not representative of the total gases in the mud, the results are still only qualitative. When the Steam Still-Reflux Unit is used to obtain the gas sample, the gas sample will represent almost 100 percent of the hydrocarbon fractions C~ through C, that were in the mud sample. This enables the chromatograph analysis to be related quantitatively to the mud, and the readings to be reported as parts per million of each hydrocarbon vapor (C~ through C~) to mud volume. Because the cuttings from a particular formation "'produce" the gas they contain into the drilling mud, it was reasonable to assume that this same formation, if completed, would produce gases of a similar com- position. This assumption led to a comparison of ppm Logs of hydrocarbon vapors with similar data from producing wells. Plots were made of the ratio of methane to each of the heavier hydrocarbons from many analyses of wellhead samples. These plots were compared with plots, made from ppm Logs, of gas in mud. Both groups of plots showed definite patterns between (1) the magnitude of the ratios of methane to each of the heavier hydrocarbons, and (2) the slope of the lines of the plotted ratios. These, in mm, indicate productive potential and reservoir permeability. The Steam Still-Reflux Unit consists of a small steam boiler, mud-injection port, mud-steam mixing chamber, Reflux-Condensing Unit and a gas-extrac- tion port. Five ml of mud are injected into the purged mud-steam mixing chamber. The mud is rolled with 2,000 to 4,000 volumes of steam. The hydrocarbons (C, through C.,) extracted from the mud are collected at the Reflux.~..ondensing Unit, withdrawn with a syringe, diluted to the standard chromatograph sam- ple size and injected into the chromatograph for analysis. The Reflux-Condensing Unit removes only the lighter paraffin series hydrocarbons from the mud sample tested. For example, if the mud contains diesel oil, the more complex hydrocarbons- Ct and above --condense and drop back into the mud-steam mix- lng chamber. Therefore, regardless of whether the fluid phase of the mud is oil or water, the gas sample analyze~l contains only the light fractions through and the analysis is representative of the formation gas. The full importance of determining formation gas composition has not always been apparent. At first it was observed that if the magnitude of butane in the mud was greater than the magnitude of either propane or ethane, the zone in question would pro- duce water and hydrocarbons. Later, the ratios of methane to each of the heavier hydrocarbon com- ponents were plotted on semilog paper. Hydrocarbon ratio plots obtained from ppm Logs and available data from wellhead gas sample analyses were com- pared. The comparison of the plots from ppm Logs and wellhead gas analysis data showed a striking cor- relation. The correlation demonstrated that ppm Logs made with Steam Still-Reflux samples could be in- terpreted in terms of in-place formation content. The magnitude of the methane-to-ethane ratio de- termines if the reservoir contains gas or oil or if it is nonproductive. The slope of the line of the ratio plot of C~/C_~, C~/C,, Cx/C,, and C~/Cs indicates whether the reservoir will produce hydrocarbons or hydro- carbons and water. Positive line slopes indicate pro- duction; negative slopes indicate water-bearing for- mations. An undersaturated reservoir may show a negative slope, but such occurrences are rare. The ratio plots may not be definitive for low permeability zones, but unusually steep plots indicate tight zones. J i 3oo I J,_ 400 , ~ 2o0 I /l~'"~ 00! 80} ! ~C~ C~ ~C~ ~C~ C= C~ C, C~ HYDROCARBON RATIOS MISSISSIPPIAN OIL RESERVOIR (~) SILURIAN GAS-CONDENSATE RESERVOIR (~ 0RDOVICIAN GAS-CON DENSATE RESERVOIR LOWER ORD0VlCIAN GAS AND WATER Fig. l~Hydrocarbon ratio plots obtained from wellhead sample analyses data, limestone reservoirs, Rocky Mountain area. 20O Gas-con~lensate. Frio Sar~. Hiclalgo County,Texas, analysis from wellhead sample. N. LJndsey. 11,00O' oil reser~mr, analysis from ~(x:lucing well sample. State tract 49 No. 1 well. Nueces County, Texas. 12.690' section, analysis from gas show on ~rn Log. 6 ~" c., c, c... HYDROCARBON RATIOS Fig. 2~Hydrocarbon ratio plots, productive reservoirs, South Texas. ,O~ RNAi OF PFTR©i Fl \I ~frCN"<(31 A ratio of C,/C: between 2 and 15 indicates oil. A ratio of C./C... between 15 and 65 indicates gas. The lower the C,/C_. ratio, the richer the gas or the lower the oil gravity. If the ratio of C,/C: is below about 2 or above about 65 the zone is nonproductive. Field Examples Fig. I shows average hydrocarbon ratio plots from limestone reservoirs in the Rocky Mountain area. Plot 1 is derived from analyses of gases from Mis- sissippian oil-producing reservoirs. The C,/C_, ratio is 3.5. The slope of the line is positive and not steep. Plot 2 was obtained from analyses of gases from wells producing gas-condensate from the Silurian. The C:/C.~ ratio is 12; the line slope is again positive and not steep. Plot 3 is from gas-condensate wells pro- ducing from the Ordovician. The C,/C: ratio is 15 and, again, the slope of the line is not steep; all three plots show slopes favorable for production. Plot 4 shows ratios obtained from an analysis of gas from the Lower Ordovician, which produced gas and water. The plot shows a negative slope of the section from the CdC, ratio to the C,/C, ratio. Many tests have verified the fact that if a ratio plot shows a negative slope, the zone in question is water-bearing. Fig. 2 shows plotted hydrocarbon ratios for pro- ductive reservoirs in South Texas. Plot 1 was made from an analysis of a wellhead sample of gas- condensate produced from a Frio sand, Hidalgo County. The production is rich in liquid hydrocar- bons as indicated by the low C:/C: ratio. Plot 2 is from an analysis of a wellhead gas sample from an l l,000-ft oil reservoir, North Lindsey field. The pentane was not reported, but the low C~/C= ratio indicates oil production. Plot 3 was obtained from a gas show at 12,690 ft on the ppm Log of the State Tract 49 No. 1 Well, Nueces County, Tex. Formation tests resulted in gas production. Experience shows that if the C~/C: ratio is above 65 the zone is too tight for commercial production. Fig. 3 shows the ratio plots obtained from ppm Logs on Texas Gulf Coast wells that were nonproductive in the zones of interest. Plot 1 is from the ppm Log of the R. A. Tally No. 1 Well, Victoria County, Tex. The C,/C: ratio was 470. The zone was tested ex- tensively but it was a low permeability reservoir that could not be commercially completed. Plots 2 and 3 are from the State Tract 49 No. 1 Well, Nueces County, Tex. Plot 2 was from a sand encountered at about 8,060 ft. The relatively high ratios of C~/C2, C,/C3, C~/C,, and C~/C~ indicated that the zone was nonproductive because of the low permeability. This was subsequently verified by testing. Plot 3 was ob- tained from a sand at 9,130 ft. The negative slope of the ratio plot, C~/C_, to C~/Ca, indicated that the zone was water-bearing. Subsequent formation tests showed water and non-commercial amounts of gas. Plot 4 was obtained from the ppm Log of the Kovar No. 1 Well, Victoria County, Tex. The sand encoun- tered from which the plot was made is at 10,120 ft. The gas show appeared to be good, but a negative slope of the C~/Ca ratio to the C~/C4 ratio was posi- tive identification of a water-bearing formation. Evaluation Technique It is apparent that with this evaluation system, poten- tial production can be accurately predicted. The only significant time lapse between penetration of the formation and evaluation of its productive possibili- ties is the time required to pump the mud from the bottom of the hole to the surface and analyze it by the Steam Still-Reflux and Chromatograph method. Fig. 4 shows the evaluation technique, which may be described as follows. First, record the net increase of each gas com- ponent over the background gas; next, plot the ratios 4000 3000 2000 ...... · 1000 - 800: 600' 400 .... 200 !00 --- z.::.- =--.~=-_-_-.- - 80 --_-7 -- - 6o~~ 40 30-- 20 10-- 8-- 6-- 4 3--- R. A. TALLY No. 1 WELL, VICTORIA COUNTY, TEXAS STATE TRACT 49 No. 1 WELL. NUECES COUNTY. TEXAS DEPTH 806O STATE TRACT 49 No. 1 WELL. NUECES COUNTY. TEXAS DEPTH 9i30' A. KOVAR No. i 'NELL. VICTORIA COUNTY. TEXAS DEPTH 10120' C. C. C '" ~.,. C: C, C, HYDROCARBON Fig. 3--Hydrocarbon ratio plots, nonproductive reservoirs, South Texas--analyses from gas shows on ppm Logs. I I %.' I~ 1 tit',ti 200 NONPRODUCTIVE 100 -." 60 40 --GAS 30 20 .... (~) Use only gas increase over : background. (~) Plot ratios on lines indicated. I~) Evaluate section for probable producbon as indicated by the plotted curve within the following limits: (a) Productive dry. gas zones may show only C~ but abnormally high C~ only shows are usually md~cabve of salt water. r" , (b) II the ,.,:~C~ ratio is Iow in the oil sec:;on and the C~/C, ratio ~s h~gh m the gas sechon the zone is probably nonproductive. (c) I1 any ratio (C,/C~ excected d oil ~s used in the mud) is lower than a preceding ratio the zone ~s probably nonproductive. For example. ~f r, r" ,..,~, s less than C,/C~ the zone ;s probably wet. (d) The rahos may not be dehmt~ve for Iow i:>ermeabd~ty zones, however steep rabo plots may ~nd~cate ttght zones. --OIL 3 2 NONPRODUCTIVE C ~. C. C, · ~ · HYDRCCARBON RATIOS Fig. 4,--ppm Log and report form for evaluation of show. C,/C:, C,/C,, C,/C,, C,/C-. on the ratio lines as indicated. 'then evaluate, within the following limits, the section in question for probable production as indicated by the plotted curve: 1. Productive dry gas zones may show only C,, but abnormally high shows of C, only are usually indicative of salt water. 2. If the C,/C: ratio is Iow in the oil section and the C,/C, ratio is high in the gas section the zone is probably nonproductive. 3. If any ratio (C,/C, excepted if oil is used in the mud) is lower than a preceding ratio, the zone is probably nonproductive. For example, if C,./C4 is less than C,/C::, the zone is probably water-bearing. 4. The ratios may not be definitive for low perme- ability zones; however, steep ratio plots may indicate tight zones. Application The ppm Log is only one of many tools that are ordinarily used for formation evaluation. But in many instances, the ppm Log has furnished the vital infor- mation necessary to make the final decision on a well. One well drilled in inland waters of Louisiana had what appeared"~.--~i' the ppm Log to be a good sand body, but the ppm Log showed only a nominal in- crease in gas. After the sand was penetrated and the well deepened, hole trouble was encountered. No other information of interest was available on the sand. The cost of the side-tracking to investigate the sand was sizable. Tight hole conditions and the low magnitude of the gas show indicated that the sand had good permeability and that possibly formation hydrocarbons had been flushed ahead of the bit. A plot of the hydrocarbon ratios indicated oil produc- tion. Therefore, at considerable expense, the sand was investigated and a new oil field was found. An interesting well recently drilled in St. Martin Parish, La., was the No. i St. Martin Bank and Trust located on the southeast flank of the Anse La Butte Dome. A good sand encountered at about 8,000 ft showed oil, but the negative slope of the ratio plot indicated that the sand was water-bearing. The well was deepened to approximately 9,600 ft. One of the partners, a successful independent with a talent for finding oil by "feel" and by prudent use of the latest technology, decided that the formations in which the well was being drilled were tilted to almost vertical. ppm LOG DR C~ 75 50 25 IOM HYDROCARBON RATIOS C.~_~ C, C~ C,, PLOT m m C2 C3 C4 Cs 1 26 62 78 155 2 8.6 14 59 118 3 5.6 7.4 46 106 4 6.8 9.1 56 130 5 5.4 11 7O 193 6 4.5 15 54 254 C~ C....z.~ C.j..~ C._z.~ c, 60' 40 30' 20-- 10 -- 8 6 4 t 3FO!L" 2!i i NONPRODUCTIVE , Fig. 5~ppm Log and hydrocarbon ratio plots, No. 1 St. Martin Bank and Trust Well, St. Martin Parish, La. · ., ~{~,I'RN-\I OF PFTR(DI Fi'X.I TFCHNOI.OG'~' On his recommendaion the well was plugged back to about 7,000 ft and sidetracked. The sand that was drilled at 8,000 ft in the first hole was encountered in the directional hole at approximately 7,400 ft and the entire sand was hydrocarbon saturated. The ppm Log and the ratio plots from the sand in the sidetrack hole are shown in Fig. 5. Table 1 shows the mud gas components related to percent of total gas. In actual practice the ppm gas shows obtained from the ppm Log are not converted to percent of total gas; but note the general decrease in percent methane in the lower section of the sand compared with that in the upper section. The magnitude of the gas show in the straight hole and in the sidetrack hole was significant. An accurate determination, how- ever, of the composition of the gas in both cases led to correct conclusions on the potential productivity of the sand at the different depths in each hole. Note that the ratio Plot 1 at the top of the sand indicates a gas cap. As shown in Table 1, the gas was 93.1 percent methane. Subsequent plots indicated that production would be oil. In each of these cases the C~/C.. ratio was less than 9. The lowest ratio, 4.5, is shown in Plot 6, which was made from the show at TABLE 1--MUD GAS COMPONENTS, PERCENT OF TOTAL GAS Depth (ft) C, C: Cs C, C: 7,460 93.1 3.6 1.5 1.2 0.6 7,475 82.4 9.6 5.9 1.4 0.7 7,485 74.4 13.3 i0.0 1.6 0.7 7,490 78.0 11.4 8.6 1.4 0.6 7,500 77.0 -14.3 7.2 1.1 0.4 7,515 76.1 17.1 5.1 1.4 0.3 the bottom of the sand. Another example of the application of the ppm Log is No. 1 State Tract 198 Well, Aransas County, Tex. Many sands were encountered showing the presence of hydrocarbons. The logging crew sub- mitted more than 60 ratio plots to the operator during the drilling of the well. In almost all instances subse- quent information verified the logging engineers' pre- dictions of probable productivity based on the ratio plots. Fig. 6 shows a section of the ppm Log and the ratio plots for this well. The gas composition relating the percent of each gas component to the total gas is shown in Table 2. Gas condensate production is indi- 10100 -- 10200 10300 10400 10500 10600 113130 ppm LOG DR C~ 100 1OM HYDROCARBON RATIOS C~ C~ C~ C~ PLOT C2 C3 C4 Cz 1 18 71 84 230 2 20 61 92 102 3 19.5 78 233 310 4 16 93 232 Cr~ 5 19.3 58 115 185 Fig. 6~ppm Log and hydrocarbon ratio plots, No. I State Tract 198 Well, Aransas County, Tex. TABLE 2--MUD GAS COMI~ITION, PERCENT OF TOTAL GAS Depth (ft) C, C.: C, C, C, 10,110 92.0 5.2 1.3 1.1 0.4 10,115 92.0 4.6 1.5 1.0 0.9 10,450 93.3 4.8 1.2 0.4 0.3 10,520 92.8 5.8 1.0 0.4 0.0 11,305 92.3 4.8 1.6 0.8 0.5 cated by the ppm Log and ratio plots as shown. The zones are tight marine deposits--especially the 10,520-ft zone. Plot 4 has the steepest line slope; pentane was not present. The slope of Plot 3 is steep. Plots 2 and 5 show more favorable (less steep) line slopes. The electric log and subsequent formation tests made of each zone indicated probable produc- tion. The well was completed as a gas condensate producer in the 11,300-ft section, which is the section plotted as No. 5. Conclusions Only qualitative shows of hydrocarbons in the mud can be derived from conventional mud logs. If chromatography is used, only a general indication of in-place gas composition is obtainable. Such hydro- carbon shows may be reported as units of gas or percent hydrocarbons or parts per million of gas in the ak-gas mixture tested. Only the presence in rela- tive amounts, not the actual quantity, of hydrocar- bons in mud i~-~-adicated, and other supplemental information may be necessary to evaluate the forma- tion in terms of potential productivity. However, if the composition of the gas sample obtained from the mud is representative of the in-place formation gas, then the gas analysis is accurate. The use of the Steam Still-Reflux Unit makes possible a report of forma- tion gas composition on the ppm Log. Meaningful ratio plots of gas composition can then be made. Even though many factors affect the amount of reservoir fluid released to the drilling mud, reservoir potential productive capabilities can be determined by a study of the ratio of methane to each of the heavier hydro- carbon components. The hydrocarbon ratio plot is a unique technique and provides the operator with new information for evaluating productive possibilities of exploratory wells. Computer programs involving percent gas in mud (ppm Log) and gas composition are being used in special cases to determine reservoir potential produc- tion. The use of computers in mud log interpretation, although new, will contribute significantly towards a better application of the data shown on the ppm Log. J-~T Original manuscript received in Society of Petroleum Engineers office Aug. 5. :1968. Revised manuscript received March 5, 1969. Paper ($PE 2254) was presented at SPE 43rd Annual Fell Meeting held in Houston, Tax., Sept. 29-Oct. 2, 1968. <~ Copyright 1969 American Institute of Mining, Metallurgical, and Petroleum Engi. na~m, [nc. ge e GUIDEI.INES FOR USING PPM RATIO PLOTS TO EVALUATE ItY~ROCARBON SHOWS ('REVISED 9/27/89 TO COVER "ME~ ONLY" SHOWS) A show that has only methane or primarily methane CAN be indicative of a productive zone. Many wells in the Gulf of Mexico produce only methane or methane and saltwater. (The commercial productivity of a GAS/SALTWATER well is based on the relative proportions of gas versus saltwater saturations determined by resistivity measurements.) a) Fill out a SHOW REPORT in a zone that meets the requirements of a show based on the definition even if it contains methane only. b) State in the LOGGER'S OPINION that this is a "methane only" show. -. c) Also state that C1 only CAN be indicative of dry-gas production BUT usually has saltwater associated with it. After making the ppm plot and observing for a neeative slor~e, checking for a chloride increase (by titration or conductivity) OR observing a resistivity decrease on an MWD log, appropriately "X" the GAS or GAS and WATER indication in the ZONE PRODUC-WION ANALYSIS paragraph on page 1, including the depth of the water contact if detectable and the footage of the show. C1/C'2 between 2 and 15 indicates GEL. You should see some fluorescence in the mud or cuttings but not necessarily. a) Values in the range of 2 - 4 indicate low gravity oil (10 - 15 on the APl gravity comparison scale.) A Iow gravity oil can have a bronze, brown or dull orange fluorescence and be very dark brown to black in color. b) Values in the range of 4 - 8 indicate medium gravity oil (15 - 35 on the APl gravity comparison scale.) A medium gravity oil will have a cream to bright yellow fluorescence and be light to medium brown in color. c) Values in the range of 8 - I5 indicate high gravity oil (35+ on the APT gravity comparison scale.) A high gravity oil will have bright blue to blue-white fluorescence and be clear in color. SEE NOTE BELOW. C1/CTM_ ratios in the 15 to 65 range indicate GAS. Any fluorescence associated with a GAS zone indicates the presence of condensate. SEE NOTE BELOW. a) Values in the 15 - 20 range indicates gas rich in heavies, C4 and C5 ppms, and would most likely be associated with condensate. Values in the 20 - 50 range indicates gas rich in mid ranged hydrocarbons, C2 and C.3 ppms. 3~ NOTE: e c) Values in the 50 - 65 range indicates gas rich in the lighter fraction, C1 C1/C2 ratios in the I0 - 20 range can indicate the presence of CONDENSATE or DISTILLATE. Indications would be the presence of bright yellow or blue white fluorescence OR cut. (Condensate is a hydrocarbon that is a GAS under the temperatures and pressures of the reservoir but "condenses" to a LIQUID when it reaches the surface. It would compare to gasoline in appearance and physical characteristics and was in fact called "drip gas" in the early oilfield. C1/C2 ratios less than 2 and greater than 65 indicate NON-PRODUCIBLE HYDROCARBONS. a) A hydrocarbon with a value less than 2 indicates an OIL with a gravity so low (the oil is very thick) that it can't be produced. b) A hydrocarbon with a value greater than 65 indicates a light GAS, mostly C1, but the Iow permeability nature of the formation makes it non- producible. The slope of the line of all plotted ratios indicates if the zone will produce hydrocarbons only OR hydrocarbons and water. Line slope also provides some indication as to the formation permeability. a) An all rmsitive slope, up and to the right, indicate HYDROCARBONS ONLY. b) If ~anv~ of the line segments have a ne=ative slor~e, down and to the right, HYDROCARBONS AND SALTWATER is indicated. Obviously, the mud chlorides SHOULD increase but not necessarily. c) A steep line slope indicates reduced permeability AND the steeper the slope, the lower the permeability. Steep is a relative term BUT the dashed lines separating the GAS, OIL and NON-PRODUCIBLE areas of the graph are there for comparison. OIL plots whose line slope is somewhat steetoer than the MIDDLE dashed line indicate low perme, abilitv. OIL plots whose line slope is equal to or less than the MIDDLE dashed line indicate good permeability. GAS plots whose line slope is ~somewhat steer~er than the TOP dashed line indicate Iow germeabilitv. GAS plots whose line slope is et]ual to or less than the TOP dashed line indicate good permeability. TIME DISTRIBUTION -ALLOCATION NOTES I. Trip time includes: 1. Making up kelly. 2. Filling pipe. 3. Pulling - standing back pipe. II. 1. 2. 3. III. Rig 1. 2. IV. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Drilling time includes: Drilling on bottom. Making connections. MWD directional surveys. Services includes: Slip and Cut Line Lube Rig Other includes: Safety Meetings Logging with MWD Unload MWD Rig up Schlumberger Rig up Cement Lines and Equipment Mix Mud Run Leak Off Test Test Casing Make up BHA Miscellaneous Down Time .sperry-sun DRILLING SERVICES ADT Mornin.(i Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 1 RED DOG NO. 1 Date: 1/26/§9 5:00 NORTH SLOPE, ALASKA Depth 245 MD 245 TVD Footage: ... 135 NABORS 28E Rig Activity: DRILLING Report For: MASKELL/LOCKWOO Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) 3 4 NA NA H2S (ppm) degree F Survey Data Lithology 100% CONGLOMERATE Sample Depth 200 Ddll Rate (fi/hO 45 Tdp Chlorides Corrected "D" Exp. 0.75 Lag Down Pipe Shale Density (gm/cc) Lag Off Bottom EWR (res) Pore Pressure LCD Casing psi psi MUD Time Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 0:00 SPUD 8.80 30O 30/50 35/50 10.00 10.0 0.0 0.80 .15/.20 500 20O 0/96.5/3.5 7215/7215 ;it No. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB 8.0/16 PPg PPg NA Bottom Hole Open Hole psi NA ppg psi ppg psi ppg ____ psi --__ ppg BIT 1 3.0 135 55 15.0 ~umpe 1 FB-' Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) Bit HP (hhp) HP Ratio / HP/in2 3 6X12 6Xl 2 4.406 Length (fl) 235 ANNULAR DATA Volume (bbls/ft) 0.3539 Velocity (fi/min) Crit-Vel (fi/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/fl) Disp (bbls/ft) Length (ft) Weight (lbs/fi) DC 5.0000 2.2760 0.0t77 0.0065 235 140.0 DATA Drill Stdng HWDP 5" DP 5.0000 8.0000 3.0000 2.8750 0.0087 0.0080 0.0155 0.0541 150.0 REMARKS COND 20.0000 18.0O0O Casing ADT Representative DOUG WILSON sperry-sun DRILLING SERVICES ADT Mornin.cl Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 2 RED DOG NO. 1 Date: 1/27/99 5:00 NORTH SLOPE, ALASKA Depth 101 9 Footage: .. 774 NABORS 28E Rig Activity: TIH Report For: MASKELL/LOCKWOOD Background Connection Tdp Flowline Temp Pore Pressure LCD Avg Max Gas Gas (units) (units) 1-2 4 H2S (ppm) NA NA 62 degree F NA Casing psi psi NA PPg PPg Survey Data Lithology Sample Depth Tdp Chloddee Lag Down Pipe Lag Off Bottom DEG .49 AZIM 159 MD 926.24' TVD 926.24' 60% GRAVEL, 20% SAND, 20% CLAY 1000' Ddll Rate (fi/hr) Corrected I'D" Exp. 106 STROKES Shale Density (gm/cc) 2189 STROKES EWR (res) 0.83 FORMATION PRESSURE DATA Bottom Hole psi 8.4 psi PPg PPg Open Hole psi psi PPg PPg 'ime Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost DP/CSG DP/OH DC/OH SPUD 8.90 269 28/55 45/65 9.00 10.0/2 0.70 .10/.25 800 8O · 1195.6/4.3 6254/18670 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/fl RPM WOB 14.7 9O9 62.0 NA 130 10-20 Length (fi) 669 241 ANNULAR DATA Volume (bbls/ft) 0.7320 0.2194 0.1865 Pumps I 3 Size (inches) 6.5X12 6.5Xl 2 Capacity (gal/stk) 4.910 4.910 Pump Rate (stks/min) 100 100 Flow Rate (gal/min) 400 400 Pressure (psi) 1000 PD Surf/DS (psi) 0/647 Ann / Bit (psi) 9/329 Jet Velocity (ff./sec) 203 Jet Impact (lbs) 750 Bit HP (hhp) 154 HP Ratio / HP/in2 0.80 Velocity (ff./min) 677 # 88 102 Cdt-Vel (ft/min) Ann-Vol (bbls) 31 145 45 OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ff) Length (fi) Weight (lbs/fi) DC 8.0000 # # 2.8750 # 0.0080 # 0.0541 241 # 145.0 Ddll Stdng HWDP 5" DP 5.5(X)0 # 5.5000 3.25O0 4.7800 0.0102 0.0222 0.0193 0.0074 779 61.5 21.9 PIPE DATA COND 20.0000 28.0000 REMARKS AND RECOMMENDATION Casing ~resentative DOUG WILSON sperry-sun DRILLING SERVICES ADT Mornin_~ Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 3 RED DOG NO. 1 Date: 1/28/99 0500 NORTH SLOPE, ALASKA Depth 1537 MD 1537 TVI Footage: _. 518 NABORS 28E Rig Activity: RIG MAINTENA Report For: MASKELL/LOCKWOOD Background Connection Trip Flowfine Temp Avg Max Gas Gas (units) (units) 3-5 5 NA H2S (ppm) NA 67 degree F Pore Pressure ECD Casing psi psi NA PPg PPg ime Type Weight In Funnel Vis. !PV/YP Gels pH Filt/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost SPUD 9.70 320 29/71 48/80 8.90 9.8/2 0.10 .10/.25 700 100 .1/91/8.9 O. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB DP/CSG DP/OH HW/OH DC/OH Length (fi) 109 473 714 241 Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 1.09 AZIM 154.7 MD 1440.3' TVD 1440.3' 50% GRAVEL, 20% SAND, 20% CLAY, 10% LIGNITE/COAL 1500 Ddll Rate (fi/hr) Corrected "D" Exp. 203 Shale Density (gm/cc) 3772 EWR (res) FORMATION PRESSURE DATA 775 Bottom Hole psi 9.0 psi PPg PPg Open Hole psi psi PPg 1 2JSC GTO9D 16" 16" 1.~ 197.0 1427.0 55.0 NA 18.5 Pumps 1 1 3 Size (inches) 6X12 6Xl 2 Capacity (gal/stk) 4.406 4.406 Pump Rate (stks/min) 95 ~ Flow Rate (gal/min) 403 403 Pressure (psi) ~ PD Surf/DS (psi) 01647 Ann / Bit (psi) 9/329 Jet Velocity (f'dsec) 203 Jet Impact (lbs) 750 Bit HP (hhp) 154 HP Ratio/HP/in2 0.80 DATA Volume (bbls/ff) 0.7320 0.2194 0.2194 0.1865 Velocity (ff/min) 67 88 88 103 Cdt-Vel (ft/min) 626 5,90 590 614 Ann-Vol (bbls) 31.0 103.0 155.0 45.0 Drill Stdng DC HWDP 5" DP OD (inches) 8.0000 5.5000 5.5(X)0 ID (inches) 2.8750 3.2500 4.7800 'Cap (bbls/ft) 0.0080 0.0102 0.0222 Disp (bbls/ff) 0.0541 0.0191 0.0074 Length (fi) 241 714 779 Weight (lbs/fi) 145.0 61.5 21.9 PIPE COND 30.0000 28.00(30 110 REMARKS AND RECOMMENDATION Casing ADT Representative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin¢l Rel~ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 4 RED DOG NO. 1 Date: 1/29/99 0500 NORTH SLOPE, ALASKA Depth 2888 MD 2863 TVD Footage: .. 1351 NABORS 28E Rig Activity: DRILL Report For: MASKELL/LOCKWOOD Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) 18 50 H2S (ppm) NA NA 66 degree F )ore Pressure ECD Casing psi NA ppg psi ppg rime Type Weight In Funnel Vis. PV/YP Gels)H -'ilt/Cake APl HTHP Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost SPUD 9.80 295 27/45 43/70 8.5 9.8/2 . 0.10 .1/.3 700 .1/91/8.9 ¸o. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ft/hr Grade Cost/ff RPM WOB Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 19.35 AZIM 352.9 MD 2705.6' 'I-VD 2690.6. 10% GRAVEL, 70% SAND, 20% CLAY, TR% LIGNITE/COAL 2800 Drill Rate (fi/hr) 37 Corrected "D" Exp. 0.53 511 Shale Density (gm/cc) 6880 EWE (res) FORMATION PRESSURE DATA 1459 Bottom Hole psi 9.0 psi Ppg Ppg Open Hole psi PPg Ppg 1 2JSC 1.264 1537.0 26.0 1427.0 55.0 GTO9D 1.402 13.7 1351.0 99.0 NA 54 55.0 18.5 25.0 'umps 1 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) Bit HP (hhp) HP Ratio / HP/in2 3 6X12 6Xl 2 O/891 34/296 184 749 139 .7 DP/CSG DP/OH HW/OH DC/OH Length (fi) 109 1816 714 241 Volume (bbls~ff) 0.7320 0.2194 0.2194 0.1865 Velocity (fi/min) 67 87 87 103 Crit-Vel (fi/min) 619 607 Ann-Vol (bbls) 31.0 395 155.0 45.0 OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ff) Length (fi) Weight (lbs/fi) DC 8.0000 2.8750 0.0080 0.0541 241 145.0 Ddll String HWDP 5.5000 3.2500 0.0102 0.0191 714 61.5 5" DP 5.5000 4.7800 0.0222 0.0074 1898 21.9 COND 30.0000 28.0000 110 Casing Representative DON WALTERS sperry-sun DRILLING SERVICES ADT Morninq Report Avg Max Gas Gas (units) (units) )ackground 30 86 Connection NA Trip NA 73 Flowline Temp 67 degree F DEPTH 3155 3478 Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 5 RED DOG # 1 Date: 1130/99 0400 NORTH SLOPE, ALASKA Depth 3673'MD/3515'TVD Footage: ._, 785 NABORS 28E Rig Activity: DRILL 851034 Report For: MASKELL/LOCKWOOD LOGGING DATA Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 38.57 AZIM 353 MD 3481.4' TVD 3365.36' 10% GRAVEL, 70% SAND, 20% CLAY 3550 Drill Rate (fi/hr) Corrected "D" Exp. 680 Shale Density (gm/cc) 8742 EWR (res) 1.42 Casing Pore Pressure ECD psi psi line Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost SPUD 9.60 259 20/50 8.00 8.0~2 0.10 .1/.3 1200 .1/92.4/7.4 NA ~o. Type IADC Code S~ze Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost Jif RPM WOB PPg PPg 1755 1828 Bottom Hole Open Hole p~ 9.0 p~ psi psi 10.0 ppg psi 1 2JSC 1.264 1537.0 26.0 1427.0 55.0 2 'umps 1 GTO9D 16" 2136.0 86.1 NA 54 18.5 25.0 Size (inches) 6X12 6X12 Capacity (gal/stk) 4.'~i~"- Pump Rate (stks/min) 110 Flow Rate (gal/min) 465 Pressure (psi) 1-'--8'8'8'8'8'8'8'~ PD Surf/DS (psi) 0/1107 Ann / Bit (psi) 27/364 Jet Velocity (fi/sec) 206 Jet Impact (lbs) 921 Bit HP (hhp) 191 HP Ratio / HP/in2 1.0 Ppg Ppg DP/CSG DP/OH HW/OH DC/OH Length (fi) 109 714 241 Volume (bbls/ft) 0.7320 0.2194 0.2194 0.1865 Velocity (fi/min) Crit-Vel (ft/min) Ann-Vol (bbls) 75 496 31.0 98 451 569.0 98 451 155.0 115 472 45.0 Ddll Stdng DC 5.5"HWDP OD (inches) 8.000 5.500 ID (inches) 2.875 3.250 Cap (bbls/ft) 0.0080 0.0102 Disp (bbls/ft) 0.0541 0.0191 Length (ft) 241 714 Weight (lbs/fi) 145.0 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 2718 21.9 COND 30.00 28.00 110 Casing SURF INT LINER 3resentative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.(I Re~3ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.' 6 RED DOG # 1 Date: 1/31/99 4:00 NORTH SLOPE, ALASKA Depth 4158'MD/3843'TVD Footage: f, 485 NABORS 28E Rig Activity: TRIP 851034 Report For: MASKELL/LOCKWOOD Background Connection Trip Flowline Temp Avg Max ~ Gas Gas DEPTH (units) (units) 35 57 3850 NA NA 67 degree F Pore Pressure ECD Casing psi psi NA 'ime Type Weight In Funnel Vis. PV/YP Gels pH FittJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost SPUD 9.80 30O 29/63 29/65 8.50 8.4/2 0.10 .15/.30 1400 80 .1/91/8.8 No. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 48.0 AZIM 356.7 MD 4060.3' 'I'VD 3778.87' 10% GRAVEL, 90% SAND 41 50 Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) PPg PPg FORMATION PRESSUI 1798 1978 Bottom Hole psi 9.0 psi 9.9 PPg PPg Open Hole psi psi PPg PPg 2 2JSC GT09D 3 MSDSSH 1.402 4158.0 29.8 16" 16" 1.320 2621.0 88.0 49 26.0 'umps 1 Size (inches) Capac~y (gal/etk) Pump Rate (stks/min) Flow Rate (gal/mJn) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) Bit HP (hhp) HP Ratio / HP/in2 6Xl 2 6X12 DP/CSG DP/OH HWIOH DC/OH Length (ft) 109 3O94 714 24t Volume (bbls/ff) 0.7320 0.2194 0.2194 0.1865 Velocity (ft/min) Crit-Vel (ft/mJn) Ann-Vol (bbls) Drill Stdng DC 5.5"HWDP 5.5" DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ff) 0.0080 0.0102 0.0222 Disp (bbls/ft) 0.0541 0.0191 0.0074 Length (ft) 241 714 3203 Weight (lbs/fi) 145.0 61.5 21.9 COND 30.00 28.00 110 Casing SURF INT LINER Representative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin~q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 7 RED DOG # 1 Date: 2/1/9g 4:00 NORTH SLOPE, ALASKA Depth 5303'MD/4448'TVD Footage: ~. 1145 NABORS 28E Rig Activity: SHORT TRIP 851034 Report For: MASKELL/LOCKWOOD Avg Max Gas Gas DEPTH (units) (units) Background 45 81 4158 Connection 41 4050 Tdp NA :lowline Temp 71 degree F Pore Pressure ECD Casing psi psi NA ime Type Weight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost SPUD 10.10 28O 45/65 8.50 8.0/2 . 0.10 o15/.30 1400 .1/89.3/10.5 ~it No. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9AZlM 350.9 MD 5134.5' TVD z!369.~ 60% GRAVEL, 30% SAND, 10% CLAY 5300 Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) 104 PPg PPg DATA 2081 Bottom Hole Open Hole psi 9.0 pPg psi psi 10.2 pPg psi PPg PPg 2 2JSC GTOgD 3 'umps 1 MSDSSH 16" 16" 1.402 1.320 4158.0 5303.0 29.8 11.0 2621.0 1144.0 88.0 104.0 26.0 104 Size (inches) Capacity (gal/atk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) Bit HP (hhp) HP Ratio / HP/in2 6X12 6X12 4.'~0~-- ~ DP/CSG DP/OH HW/OH DC/OH Length (fi) 4239 714 241 Volume (bbls/ft) 0.7320 0.2194 0.2194 0.1865 Velocity (fi/min) C~-Vel (fi/min) Ann-Vol (bbls) Ddll Stdng DATA DC 5.5"HWDP 5.E' DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ft) 0.0080 0.0102 0.0222 Disp (bbls/ff) 0.0541 0.0191 0.0074 Length (fi) 241 714 4348 Weight (Ibs/ft) 145.0 61.5 21.9 REMARKS Casing COND SURF INT LINER 30.00 28.00 110 Representative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.q Rel~ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 8 RED DOG # 1 Date: 2/2/99 0400 NORTH SLOPE, ALASKA Depth 5303'MD/4448'TVD Footage: ~. 0 NABORS 28E Rig Activity: 13 3/8 csg 851034 Report For: MASKELL/LOCKWOOD Background Connection Trip Flowline Temp Avg Max Gas Gas DEPTH (units) (units) na na degree F Pore Pressure ECD Casing psi psi ime Type Weight In Funnel Vis. PV/YP Gels pH i Filt/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost SPUD 10.10 300 32/61 38/72 8.00 8.0/2 0.00 .05/.25 1400 100 · 1/89.1/10.7 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade CostJfl RPM WOB DP/CSG DP/OH HW/OH DC/OH PPg PPg Length (fi) 109 Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9 AZIM 350.9 MD 5134.5' TVD 4,.~9.9' 60% GRAVEL, 30% SAND, 10% CLAY Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) FORM/ 2 2JSC GT09D DATA 2081 Bottom Hole psi 9.0 psi 10.2 PPg PPg Open Hole psi psi PPg PPg 4239 714 241 1.402 4158.0 3 MSDSSH 2621.0 88.0 16" 5303.0 29.8 11.0 1144.0 104.0 49 26.0 104 Sumps I Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / B~t (psi) Jet Velocity (fi/sec) Jet Impact (lbs) Bit HP (hhp) HP Ratio / HP/in2 6X12 6X12 4.406 4.406 IDL--'~' DATA Volume (bbls/ff) 0.7320 0.2194 0.2194 0.1865 Velocity (fi/min) Cdt-Vel (fi/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls#t) Length (fi) Weight (lbs/fi) DC 8.000 2.875 0.0080 0.0541 241 145.0 Ddll Stdng 5.5"HWDP 5.500 3.250 0.0102 0.0191 714 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 4348 21.9 COND 30.00 28.00 110 SURF 13 318 12.415 0.1497 0.0241 68.0 Casing INT LINER DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig' Job No,: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851 034 Report For: 9 2/3/99 0400 5303'MD/4448'TVD 0 CHG OUT MUD LOCKWOOD/POLYA Background Connection Trip Flowtine Temp Avg Max ~ Gas Gas DEPTH (units) (units) na na degree F Survey Data Litholegy Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9 AZIM 350.9 MD 5134.5' 'i'VD 4369.9' 60% GRAVEL, 30% SAND, 10% CLAY 5300 Drill Rate (E/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) Pore Pressure ECD 2081 Casing psi psi 9.0 me Type Weight In Funnel Vis. PV/YP Gels :ilt/Cake APl HTHP =m P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost WATER Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ft/hr Grade CostJff RPM WOB PPg PPg 2081 Bottom Hole Open Hole psi g.0 pPg psi psi pPg psi 2 2JSC GT09D 16" 1.402 4158.0 29.8 2621.0 88.0 49 26.0 3 ~ps 1 MSDSSH Size (inches) 16" Capacity (gal/stk) 1.320 Pump Rate (stks/min) 5303.0 Flow Rate (gal/min) 11.0 Pressure (psi) 1144.0 PD Surf / DS (psi) 104.0 . Ann / Bit (psi) Jet Velocity (E/sec) Jet Impact (lbs) 104 Bit HP (hhp) 48.0 HP Ratio / HP/in2 PPg PPg 6X12 6X12 4.'~-- 4.406 IDLE DP/CSG DP/OH HW/OH DC/OH Length (It) 109 4239 714 241 Volume (bbls/ft) Velocity (ff/min) 0.7320 0.2194 0.2194 0.1865 Crit-Vel (ft/min) Ann-Vol (bbls) Ddll Stdng DC 5.5"HWDP 5.5" DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ft) 0.0080 0.0102 0.0222 Disp (bbls/ff) 0.0541 0.0191 0.0074 Length (ft) 241 714 4348 Weight (lbs/fi) 145.0 61.5 21.9 COND 30.00 28.00 110 170.0 SURF 13 318 12.415 0.1497 0.0241 5302 68.0 Casing INT LINER )resentative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.~ ReDort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No..' RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: # Report For: 10 2/4/99 0400 5303'MD/4448'TVD _ 0 NIPPLE UP LOCKWOOD/POLYA Background Connection Trip Flowline Temp Pore Pressure ECD Avg Max Gas Gas (units) (units) na DEPTH na degree F 2081 Casing psi psi 9.0 PPg PPg Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9 AZIM 350.9 MD 5134.5' TVD 4369.9' 60% GRAVEL, 30% SAND, 10% CLAY 5,.'.'.'.'.'.'.'.'.~Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) PRESSURE DATA 2061 Bottom Hole Open Hole psi 9.0 pPg psi psi pPg psi PPg ime Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost WATER Oo Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/It RPM WOB 2JSC GT09D 3 ~umps I 1 MSDSSH Size (inches) 6X12 6X12 Capacity (gal/stk) 4.406 4.---.-.-.-.-.-.-.-.~ Pump Rate (stks/min) ~ Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (It/sec) Jet Impact (lbs) Bit HP (hhp) HP Ratio / HP/in2 16" 16" 1.402 4158.0 29.8 2621.0 88.0 1.320 5303.0 11.0 1144.0 104.0 4t5.0 DP/CSG DP/OH HW/OH DC/OH Length (fi) Volume (bbls/ft) Velocity (ft/min) Cdt-Vel (ft/min) 109 0.7320 4239 714 241 0.2194 0.2194 0.1865 Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (lbs/fi) 9.4 DC 8,000 2.875 0.0080 0.0541 241 145.0 Ddll Stdng 5.5"HWDP 5.500 3.250 0.0102 0.0191 714 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 4348 21.9 AND COND 30.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5302 68.0 Casing INT LINER DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: # Report For: 11 2/5/99 0400 5303'MD/4448'TVD 0 NU/PICK UP PIPE LOCKWOOD/POLYA Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) na na DEPTH Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9 AZlM 350.9 MD 5134.5' 'i'VD 43~.9' t~6' GRAVI~L, 30~ SAND, IO~ CLAY 5300 Ddll Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) Casing Pore Pressure 2081 psi ECD '~ psi 2081 Bottom Hole Open Hole p~ 9.0 ppg psi psi ppg psi Io. 3 Type LSND Type MSDSSH Weight In 8.70 IADC Code Funnel Vis. 68 Size ~ 6" ' PV/YP "13r32 Jets Gels 12/14 Depth Out pH 9.50 , Rot. Hrs. Filt/Cake APl 9.0/2 Footage HTHP Avg fi/hr Pm 0.70 Grade Pf/lVlf .3/.7 Cost/ft Chlorides (ppm) 200 RPM 55/130 Calcium (ppm) 80 WOB 1OF~ Oil/Water/Solids 0~97/3 Daily/Cum. Cost 4 umps MX1 12.25 1.320 0.994 53G3.O 11.0 1144.0 104.0 Size (inches) capac~ (g~stk) Pump Rate (stks/min) Flow Rate (galknin) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet ~mpact (~bs) Bit HP (hhp) HP Ratio / HP/in2 6Xl 2 6X12 4.'~3~- ~ DP/CSG DP/OH HW/OH DC/OH Length (ft) 109 4239 714 241 Volume (bbls/ft) 0.7320 0.2194 0.2194 0.1865 Velocity (f~min) Cdt-Vel (ft/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (ft) Weight (Ibs/ft) DC 8.000 2.875 0.0(~80 0.0541 184 145.0 Ddll String 5.5"HWDP 5.500 3.250 0.0102 0.0191 712 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 4407 21.9 COND ~.~ ~.~ 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5302 68.0 Casing INT LINER 9.4 800 sperry-sun DRILLING SERVICES ADT Morninl~ Report Customer: Well: Area: Lease: Rig' Job No.: BP EXPLORATION Report No.: RED DOG # t Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 12 2/6/99 0400 5303'MD/4448'TVD - 0 BOP'S LOCKWOOD/POLYA Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) na DEPTH na na degree F Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 61 .gAZIM 350.9 MD 5134.5' TVD 434~.9' 60% GRAVEL, 30% SAND, 10% CLAY 53O0 Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) Pore Pressure ECD 2081 Casing psi 9.0 PPg 2061 Bottom Hole Open Hole ps~ 9.0 pPg p~ psi pPg psi PPg PPg me Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 8.70 12/14 9.0/2 0.70 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB 3 MSDSSH 16" 1.320 5303.0 11.0 1144.0 104.0 4 umps Size (inches) 6X12 6X12 12.25 Capac~y (gal/stk) 4~ '~--.-.-.-.-.-.-.-.-~ 0.994 Pump Rate (stks/rnin) ~ Flow Rate (galknin) Pressure (ps~ PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I, I DP/CSG 'DP/OH HW/OH DC/OH Length (fi) 109 4239 714 241 Volume (bbls/ft) 0.7320 O.2194 0.2194 0.1865 Velocity (ft/min) Crit-Vel (ff/min) Ann-Vol (bbb) OD (inches) ID (inches) Cap (bbls/ft) i Disp (bbls/ft) i Length (fi) Weight (lbs/fi) DC 8.000 2.875 0.0060 0.0541 184 145.O Drill String 5.5"HWDP 5.500 3.250 0.0102 O.~91 712 61.5 5.5" DP 5.500 4.780 0.0222 0.(3074 4407 21.9 COND SURF 30.00 133/8 28.00 12.415 O. 1497 0.0241 110 5,302 170.0 68.0 Casing INT LINER 9.4 sperry-sun DRILLING SERVICES ADT Mornin.¢l Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 13 2/7/99 0400 5303'MD/4448'TVD 0 TEST CASING LOCKWOOD/POLYA Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) na DEPTH na na degree F Casing Pore Pressure 2081 psi ECD ' psi 9.0 line Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 8.70 13/32 12/14 9.50 9.0/2 0.70 .3/.7 O/97/3 Oo Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9AZIM 350.9 MD 5134.5' TVD 4369.9' 60% GRAVEL, 30% SAND, 10% CLAY 5300 Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) PPg PRESSURE 2081 Bottom Hole psi 9.0 psi Open Hole pPg psi pPg ppg psi ppg 3 MSDSSH 16" 4 MX1 1.320 0.994 5303.0 11.0 1144.0 104.0 55/130 10/50 ~umps 1 I Size (inches) Capacity (gaVstk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (ffJsec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/]n2 6X12 4.'~-- I I 6X12 DP/CSG DP/OH HW/OH DC/OH Length (fi) 109 4239 714 241 Volume (bbls/ft) 0.7320 0.2194 0.2194 0.1865 Velocity (ft/min) Cdt-Vel (ft/min) Ann-Vol (bbls) Ddll String DC 5.E'HWDP 5.5" DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ft) 0.0080 0.0102 0.0222 Disp (bbls/ft) 0.0541 0.0191 0.0074 Length (fi) 184 712 4407 Weight (lbs/fi) 145.0 61.5 21.9 COND ~.~ 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5302 68.0 Casing INT LINER 9.4 800 )resentative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin~ Reoort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 14 2/8/99 0400 5303'MD/4448'TVD 0 ... TEST CASING LOCKWOOD/POLYA Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) na DEPTH na na degree F Casing Pore Pressure 2081 psi LCD ' psi 9.0 Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom PPg PPg DEG 61 .gAZIM 350.9 MD 5134.5' TVD 4369.9' 60% GRAVEL, 30% SAND, 10% CLAY 5303 Ddll Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) 2081 DATA Bottom Hole Open Hole psi 9.0 pPg psi psi pPg psi me No. 3 4 Type LS N D Type MSDSSH MX1 Weight In 8,70 IADC Code Funnel Vis. 68 Size 16" 12.25 PV/YP 13/32 Jets 1.320 0.994 Gels 12/14 Depth Out 5303.0 pH 9.50 Rot. Hrs. 11.0 Filt/Cake APl 9.0/2 Footage 1144.0 HTHP Avg fi/hr 104.0 Pm 0.70 Grade Pf/Mf .3/.7 Cost/ft Chlorides (ppm) 200 RPM 55/130 ~ Calcium (ppm) 80 WOB 10/50 I Oil/Water/Solids 0/97/3 Daily/Cum. Cost PPg PPg 'umps 1 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Ve~oc~ (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I 6Xl 2 6Xl 2 4.'~-- ~ I I DP/CSG DP/OH HW/OH DC/OH Length (fi) 109 4239 714 241 Volume (bbls/ff) 0.7320 0.2194 0.2194 0.1865 Velocity (ft/min) Cdt-Vel (ft/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (ft) Weight (lbs/fi) DC 8.000 2.875 0.0080 0.0541 184 145.0 DMII Stdng 5.5"HWDP 5.500 3.250 0.0102 0.0191 712 61.5 5.5'' DP 5.500 4.780 0.0222 0.0074 44O7 21.9 COND ~.~ 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5302 68.0 Casing INT LINER 9.4 DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.(I Rel3ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 15 2/9/99 0400 5303'MD/4448'TVD 0 TEST CASING/BOP'S LOCKWOOD/POLYA Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) na DEPTH na na degree F Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61 .gAZIM 350.9 MD 5134.5' TVD 60% GRAVEL, 30% SAND, 10% CLAY 5.300 Ddll Rate (ftJhr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) Casing Pore Pressure 2081 psi ECD ' psi 9.0 ime Type Weight In Funnel V~s. PV/YP Gels pH FiltJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppi) Oil/Water/Solids Daily/Cum. Cost LSND 8.70 4O 6/16 6/8 9.5 9.9/2 0.90 .4/.8 200 80 0/96.5/3.5 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ftJhr Grade Cost/ff RPM WOB PPg PPg 2081 Bottom Hole Open Hole psi 9.0 ppg psi psi ppg psi 3 MSDSSH 4 ps 1 MX1 16" 12.25 1.320 0.994 53~.0 11.0 1144.0 104.0 55/130 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/rain) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 PPg PPg I 6X12 6X12 4~ ~ I I IDLE DP/CSG DP/OH HW/OH DC/OH Length (fi) 109 4239 714 241 Volume (bbls/ft) 0.7320 0.2194 0.2194 0.1865 Veloc~/(fi/rain) Crit-Vel (ft/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (ft) Weight (lbs/fi) DC 8.000 2.875 0.0060 0.0541 184 145.0 Drill String 5.E'HWDP 5.500 3.250 0.0102 0.0191 712 61.5 5.5" DP 5,500 4.780 0.0222 0.0074 4407 21.9 COND ~0.00 28.00 110 170.0 SURF 133/8 12.415 0.1z~)7 0.0241 53O2 68.0 Casing INT LINER 9.4 DON WALTERS sperry-sun DRILLING SERVICES ADT Morninq Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 16 2/10/99 0400 5303'MD/4448'TVD ~. 0 TRIP LOCKWOOD/POLYA Background Connection Trip Flowfine Temp Avg Max Gas Gas (units) (units) na na na degr~ F DEPTH Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9AZIM 350.9 MD5134.5' TVD 60% GRAVEL, 30% SAND, 10% CLAY 5300 Ddll Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) Pressure 2081 Casing psi psi 9.0 PPg PPg 2081 Bottom Hole Open Hole psi 9.0 pPg psi psi pPg psi PPg PPg Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 8.80 62 16/25 11/14 10.7 8.8/2 1.30 .6/1.1 300 80 0/96.5/3.5 0. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ft/hr Grade Cost/ff RPM WOB 3 MSDSSH 4 'umps 1 MX1 1E' 12.25 1.320 0.994 5303.0 11.0 1144.0 104.0 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I 6X12 6X12 4.'~- ~ I I DP/CSG DP/OH HWIOH DC/OH Length (fi) 109 4239 714 241 Volume (bbls~) 0.7320 0.2194 0.2194 0.1865 Velocity (ft/min) Crit-Vel (fi/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (fi) Weight (lbs/fi) DC 8.000 2.875 0.0080 0.0541 184 145.0 Drill Stdng 5.5"HWDP 5.500 3.250 0.0102 0.0191 712 61.5 5.E' DP 5.500 4.78O 0.0222 0.0074 4407 21.9 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5302 68.0 Casing INT LINER 9.4 DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 17 2/11/99 0400 5303'MD/4448'TVD 0 TRIP LOCKWOOD/POLYA Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) na DEPTH na na degree F Casing =ore Pressure 2081 psi ECD ' psi 9.0 Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm PfRVIf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 8.80 62 16r25 11/14 10.7 8.8/2 1.30 .6/1.1 3OO 8O 0/96.5/3.5 Type IADC Code S~ze Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB DP/CSG DP/OH HW/OH DC/OH PPg PPg Length (ft) 109 Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEC-, 61.9AZlM 350.9 MD 5134.5' TVD 4369.9' 60% GRAVEL, 30% SAND, 10% CLAY 5,300 Drill Rate (rUhr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) 4239 714 241 FORMATION PRESSURE DATA 2081 Bottom Hole psi 9.0 psi PPg PPg Open Hole psi ppg psi ppg 3 MSDSSH 16' 1.320 5303.0 11.0 1144.0 104.0 55/130 10F-aO 4 'umps 1 MX1 Size (inches) 12.25 Capacity (gal/stk) 0.994 Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) Iait HP (hhp) IHP Ratio / HP/in2 6X12 I I I 6X12 ANI Volume (bbls/ff) 0.7320 0.2194 0.2194 0.1865 Velocity (fi/min) Cdt-Vel (fi/min) Ann-Vol (bbls) Ddll Stdng DC 5.E'HWDP 5.9' DP OD (inches) 8.0(30 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ff) 0.0060 0.0102 0.0222 Disp (bbls/ff) 0.0541 0.0191 0.0074 Length (ft) 184 712 4407 Weight (lbs/fi) 145.0 61.5 21.9 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 9.4 800 Representative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 18 2/12/99 0:00 5303'MD/4448'TVD 0 DRII~L CEMENT LOCKWOOD/POLYA Backgmund Connection Trip Flowtine Temp Pore Pressure ECD Avg Max Gas Gas (units) (units) na DEPTH na na degree F 2081 Casing psi psi 9.0 P~ PPg Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.9AZIM 350.9 MD 5134.5' TVD 4369.9' 60% GRAVEL, 30% SAND, 10% CLAY 5,..-.-.-.-.-.-.-.-~0 Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) IATION 2081 Bottom Hole Open Hole psi 9.0 ppg psi psi ppg psi Ppg Ppg ime Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm P f/Mr Chlorides (ppi) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 8.8 65 15/26 11114 10.6 8.9/2 1.20 .6/1.1 300 60 0/96.5/3.5 !o. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB 3 MSDSSH 4 Amps 1 MX1 16" 12.25 1.320 1 AgO 5303.0 11.0 1144.0 104.0 55/130 I Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 6X12 4~ I I -I 6X12 DP/CSG DP/OH HW/CGS HW/OH DC/CGS DC/OH Length (ft) ,~:~52 523 Volume (bbls/ff) 0.11~5 0.1:205 0.0889 Velocity (ft/min) Crit-Vel (fi/min) Ann-Vol (bbls) 544.0 Ddll Stdng DC 5.5"HWDP OD (inches) 8.000 5.500 ID (inches) 2.875 3.250 Cap (bbls/ff) 0.(3080 0.0102 Disp (bbls/ff) 0.0541 0.0191 Length (ft) 228 523 Weight (lbs/fi) 145.0 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 4552 21.9 COND ~.~ ~.~ 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 9.4 803 3resentative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.~ Rer~ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 19 2/13/99 0300 6233'MD/4887'TVD ,-. 930 DRILL AHEAD LOCKWOOD/POLYA Background Connection Trip Flowline Temp Pore Pressure ECD ime Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost DP/CSG DP/OH HW/OH DC/OH Avg Max ~ Gas Gas DEPTH (units) (units) 110 307 6120 66 degree F Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pips Lag Off Bottom Casing 2081 psi 9.0 ppg 2081 2130 psi 9.2 ppg 2366 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB LSND 8.9 55 18/29 12/16 12.4 9.0 2.80 .9/1.3 35O 40 0/96.0/4 DEG 58.02 AZIM 349.9 MD 6114.52' TVD 4857.32' 60% SAND, 40% CLAY 6050 Ddll Rate (fi/hr) Corrected "D" Exp. 1256 stks Shale Density (gm/cc) 7272 stks EWR (res) 182 1.49 DATA Bottom Hole Opsn Hole psi 9.0 ppg psi psi 9.2 ppg psi PPg PPg 3 MSDSSH 16" 12.25 1.320 1 AgO 5303.0 11.0 5.1 1144.0 930.0 104.0 182.0 55/130 I 71 10F~0 I 24.0 DATA 4 'umps 1 Size (inches) 6X12 6X12 Capacity (gal/stk) 4.406 4T'.-.-.-.-.-.-~ Pump Rate (stks/min) ~ ~ Flow Rate (gal/min) ~ Pressure (psi) 1---4'4'4'4'4'4'4'~ PD Surf/DS (psi) 0/1005 Ann / Bit (psi) 54/418 Jet Velocity (fi/sec) 229 Jet Impact (lbs) 896 I Bit HP (hhp) 207 HP Ratio / HP/in2 28.6 I I Length (fi) Volume (bbls/ft) Velocity (fi/min) Crit-Vel (fi/min) Ann-Vol (bbls) 5301 0.1195 t6~ 3~ 633.0 182 551 227 0.1194 173 340 0.1107 173 340 0.0084 253 384 18.0 61.0 19.0 LINER OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (ft) Weight (lbs/fi) DC 8.000 2.875 0.0080 0.0641 228 145.0 Ddll String 5.E'HWDP 5.500 3.250 0.0102 0.0191 523 81.5 5.5" DP 5.500 4.780 0.0222 0.0074 5482 21.9 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT )resentative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.cl Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.' RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 20 2/14/99 0300 7553MD/5611TVD 1320 DRILL AHEAD LOCKWOOD/POLYA Background Connection Trip Flowline Temp Avg Max {~ Gas Gas DEPTH (units) (units) 35 489 6600 55 7261 425 6774 83 degree F -'CD Pressure Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom ime Type Weight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids i Daily/Cum. Cost FORMATION DP/CSG DP/OH HW/OH DC/OH Casing 2081 psi 9.0 ppg 2625 , 2266 psi 9.7 ppg 2859 3 MSDSSH L S N D Type 9.3 IADC Code 63 Size 14.24 Jets 10/17 Depth Out 10.6 Rot. Hrs. 5.2 Footage Avg fi/hr 0.40 Grade .2/.4 Cost/ff 600 RPM 60 WOB 0/96/4 DEG 58.6 AZIM 349.0 MD 7476.4' TVD 5571.1' 80% SAND, 20% CLAY 7450 Ddll Rate (fi/hr) Corrected "D" Exp. 1548 stks Shale Density (gm/cc) 8811 stks EWR (res) DATA Boffom Hole Open Hole psi 9.0 ppg psi psi 9.8 ppg psi 4 'umps 1 MX1 Ppg Ppg 16" 12.25 1.320 1.190 5303.0 11.0 13.2 1144.0 2250.0 104.0 170.0 55/130 I 113 10Fo0 I 36.0 ANf Length (fi) 5301 1499 523 227 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psO Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 6X12 4.~'- I I I 6X12 4.406 110 1696 0/1255 67/473 239 1014 244 2.1 Volume (bbls/ff) 0.1195 0.1194 O.1107 0.0084 Velocity (ft/min) 175 181 181 264 Cdt-Vel (ft/min) 354 329 329 371 Ann-Vol (bbls) 633.0 173.0 61.0 19.0 OD (inches) ID (inches) Cap (bbls#t) Disp (bbls/ft) Length (fi) Weight (lbs/fi) DC 8.000 2.875 0.00843 0.0541 228 145.0 Drill Stdng 5.5"HWDP 5.500 3.250 0.0102 0.0191 523 61.5 5.E' DP 5.500 4.780 0.0222 0.0074 6602 21.9 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 9.4 DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.~ Rel~ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 21 2/15/99 0300 8724/6222 _1171 DRILL AHEAD LOCKWOOD/POLYA Avg Max Gas Gas (units) (units) Background 52 125 Connection 0 0 Trip Flowline Temp 70 degree F DEPTH 8040 Casing Pore Pressure 2081 psi ECD , 2220 psi 9.0 9.6 Ime Weight In Funnel Vis. iPV/YP !Gels APl HTHP Pm Pf/1VIf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 9.3 63 19/29 11/17 9 4.8/2 0.03 .1/.2 8O0 100 1/93/6 O. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade CosUft RPM WOB Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 57.1 AZlM 351.9 MD 8643.4' TVD 6178.3' 30% SAND, 10% CLAY, 60% GRAVEL 8600 Ddll Rate (ff./ho Corrected "D" Exp. 1812 stks Shale Density (gm/cc) 10197 stks EWR (res) PPg PPg FORMATION PRESSURE DATA Bottom Hole 2911 psi 9.0 3138 psi 9.7 PPg PPg Open Hole psi psi PPg PPg 3 MSDSSH 4 MX1 1.320 1.190 5303.0 11.0 20.1 1144.0 3421.0 104.0 1 70.0 10,50 41.0 'umps I Size (inches) Capacity (gal/stk) Pump Rate (stksknin) Flow Rate (gal/min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I 6X12 6Xl 2 4.'~E~-~ I I 0/1524 91~11 248 1096 274 2.3 DP/CSG DP/OH HW/OH DC/OH Length (fi) 5301 2673 523 227 Volume (bbls/ft) 0.1195 0.1194 0.1107 Velocity (fi/min) 182 188 188 274 Crit-Vel (ft/min) 387 361 361 Ann-Vol (bbls) 633.0 309.0 61.0 19.0 Ddll Stdng DC 5.E'HWDP 5.E' DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ff) 0.0080 0.0102 0.0222 Disp (bbls/ft) 0.0541 0.0191 0.0074 Length (ft) 228 523 7973 Weight (lbs/fi) 145.0 61.5 21.9 9.4 800 COND 30.03 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5,301 68.0 Casing INT LINER )resentative DON WALTERS sperry-sun DRILLING SERVICES ADT Morninq Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 22 2/16/99 O3OO 9010/6375 _ 286 TEST BOP MASKELL/POLYA Avg Max Gas Gas (units) (units) Background 50 80 Connection 0 0 Trip NA Flowline Temp 75 degree F DEPTH 8725 Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 57.2 AZIM 353.O MD 8933.2' TVD 6336' 60% CLAY, 30% SAND, 10% GRAVEL 9010 Ddll Rate (fi/hr) NA Corrected "D" Exp. 1866 Shale Density (gm/cc) 10600 EWR (res) 140 1.06 NA Casing Pore Pressure 2081 psi ECD , 2220 psi 9.0 9.6 ime Type Weight In Funnel Vis. PV/YP Gels pH Flit/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 9.3 63 20/28 12/28 8.6 4.5/2 0.2 .11.2 60 1/93/6 0. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB PPg PPg 3216 Bottom Hole Open Hole psi 9.0 pPg psi psi 9.7 pPg psi 3 4 MSDSSH MX1 16" 12.25 1.320 1.1gO 5303.0 9010.0 11.0 23.0 1144.0 3707.0 104.0 161.0 58.0 55/130 85/110 10,50 40/50 'umps I I Size (inches) 6X12 6X12 Capacity (gal/stk) 4.'"~J~ 4.-~.'.'.'.'.'.'.'~ Pump Rate (stks/min) ~ ~ Flow Rate (gal/min) ~ Pressure (psi) ~ PD Surf/DS (psi) 100/1320 Ann / Bit (psi) 90 / 390 Jet Velocity (f'dsec) 216 Jet Impact (lbs) 832 tBit HP (hhp) 180 HP Ratio / HP/in2 20 / 1.5 _IN2 PPg I I DP/CSG DP/OH HW/OH DC/OH Length (fi) 5301 523 227 Volume (bbls/ft) Velocity (ft/min) Crit-Vel (ft/min) Ann-Vol (bbls) 0.1195 158 39O 633.0 0.1194 164 364 353.0 0.1107 1 64 364 61.0 O.0084 239 412 19.0 Drill Stdng DC 5.5"HWDP 5.E' DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ff) 0.0080 0.0102 0.0222 Disp (bbls/ff) 0.(3541 0.0191 0.0074 Length (fi) 228 523 8259 Weight (Ibs/ft) 145.0 61.5 21.9 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 9.5 800 )resentative JOHN PATTON sperry-sun DRILLING SERVICES ADT Mornin_cl Report Customer: Welt: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 23 2/17/99 0300 9010/6375 0 TRIP IN HOLE MASKELL/POLYA Avg Max Gas Gas (units) (units) Background 25 43 Connection 0 0 Trip NA Flowline Temp 60 degree F DEPTH 9010 Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 57.2 AZIM 353.0 MD 8,933.2' TVD 6336' 60% CLAY, 30% SAND, 10% GRAVEL 9010 Drill Rate (fi/hr) NA Corrected "D" Exp. 1866 Shale Density (gm/cc) 10(~:30 EWR (res) 140 1.06 NA Pore Pressure ECD Casing psi psi 9.0 9.8 ime Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 9.6 61 18/28 13/26 8.6 4.4/2 0.2 .1/.2 800 8O 1/92/7 !O. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB PPg PPg Bottom Hole Open Hole psi 9.0 ppg psi pPg psi 9.8 pPg psi pPg 5 S73 HPX- PDC ON MOTOR 12.3 4 'umps 1 MX1 ON MOTOR 12.25 1.32 TFA 1.1gO 9010.0 23.0 3707.0 161.0 58.0 85/110 40/5O Size (inches) Capacity (gaVstk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I I I 6X12 6Xt 2 4.'~J0-- ~ 75/665 5O/210 156 500 80 21 / 0.7_1N2 ClRC ~ SHOE DP/CSG DP/OH HW/OH DC/OH Length (fi) Volume (bbls/ft) 0.1195 0.1194 0.1107 0.0084 Velocity (fi/min) 127 183 Cdt-Vel (fi/min) 3~0 364 364 412 Ann-Vol (bbls) Drill Stdng DC 5.5"HWDP 5.5" DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ff) 0.0080 0.0102 0.0222 Disp (bbls/ff) 0.0541 0.0191 0.0074 Length (ft) 256 243 8511 Weight (lbs/fi) 145.0 61.5 21.9 COND ~.~ ~.~ 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 9.6 800 )resentative JOHN PATTON sperry-sun DRILLING SERVICES ADT Morninq Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 24 2/18/99 0300 10214 / 7000 .. 1204 TRIP IN HOLE MASKELL/POLYA Background Connection Trip Flowline Temp Avg Max {~ Gas Gas DEPTH (units) (units) 65 87 10020 NONE 0 92 9010 90 degree F Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 59.2 AZlM 353.0 MD 9904.9' 'I'VD 6841.5' 50% CLAY, 40% SAND + GRAVEL, 10% SILSTONE 1050 Ddll Rate (fi/hr) NA Corrected "D" Exp. 2135 Shale Density (gm/cc) 11900 EWR (res) 175 0.73 NA Casing Pore Pressure 2081 psi 9.0 ppg ECD 2312 psi 10.0 ppg ime Type Weight In Funnel Vis. PV/YP Gels :ilt/Cake APl HTHP =m Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND Type 9.7 IADC Code 56 Size 17/25 Jets 7/30 Depth Out 8.8 Rot. Hrs. 3.8 2/32 Footage Avg fi/hr 0.2 Grade .15/.5 Cost/ff 800 RPM 80 WOB Bottom Hole Open Hole psi 9.0 ppg psi psi 10.0 ppg psi 5 873 HPX- PD¢ ON MOTOR 12.3 1.32 TFA 8.4 1204.0 143.0 NA $97 110+85 15-20 4 ~umps 1 ON MOTOR Size (inches) 6X12 6X12 12.25 Capac~ (gal/stk) 4.'~J~- 1.190 Pump Rate (stks/rnin) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf / DS (psi) 100 / 1765 161.0 Ann / Bit (psi) 90 / 445 45VVTAE3/8RGBHA Jet Velocity (fi/sec) 226 58.0 Jet Impact (lbs) 1055 851110 IBit HP (hhp) 240 ~)/50 IHP Ratio/HP/in2 181/2.0_1N2 PPg PPg I I DP/CSG DP/OH HWIOH DC/OH Length (ft) Volume (bbls/ft) Velocity (~min) Cdt-Vel (ft/min) Ann-Vol (bbls) 5301 0.1195 184 345 633.0 4414 243 256 0.1194 190 320 O. 1107 190 320 0.0840 265 360 515.0 27.0 21.0 LINER OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (ft) Weight (lbs/fi) 9.7 DC 8.000 2.875 0.0080 0.0541 256 1~5.0 Ddll Stdng 5.E'HWDP 5.500 3.250 0.0102 0.0191 243 61.5 5.5" DP 5.500 4.78O 0.0222 0.0074 9715 21.9 COND SURF 30.00 133/8 28.00 12.415 0.1497 0.0241 110 {~301 170.0 68.0 Casing INT sperry-sun DRILLING SERVICES ADT Mornin.cl Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 25 2/19/99 0300 11284 / 7536 .. 1070 MASKELL/POLYA Avg Max Gas Gas DEPTH (units) (units) Background 150 218 11280 Connection NONE 0 Tdp 158 STG 10019 Flowtine Temp 83 degree F Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG ED. 1 AZIM 349.9 MD 11169.5' TVD 7480.1' 60% CLAY, 40% SAND, TR GRAVEL 11280 Drill Rate (ftJhr) NA Corrected "D" Exp. 2385 Shale Density (gm/cc) 13200 EWR (res) 2OO 0.70 NA Casing Pore Pressure 2061 psi 9.0 ppg ECD ' 2312 psi 10.0 ppg MUD Bottom Hole 3526 psi 9.0 ppg 3919 psi 10.0 ppg DATA me Bit 5 Type LSND Type S73 HPX - PDC Weight In 9.7 IADC Code ON MOTOR Funnel Vis. 57 Size 12.25 PV/YP 17/24 Jets 1.32 TFA Gels 10/15 Depth Out pH 8.6 Rot. Hrs. 16.1 Filt/Cake APl 4,2 2/32 Footage 2274.0 HTH P Avg fi/hr 141.0 Pm 0.1 Grade NA Pf/Mf .10/.55 Cost/ft $76 Chlorides (ppm) 800 RPM 115 + 85 Calcium (ppm) 80 WOB 15 - 20 Oil/Water/Solids 3/~8~ Daily/Cum. Cost 4 Pumps I 12P100 MX1 ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.190 Pump Rate (stks/min) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf / DS (psi) 161.0 Ann / Bit (ps0 45WTAE3/SRGBHA Jet Velocity (ftJsec) 58.0 Jet Impact (lbs) 85/110 IBit HP (hhp) i I HP Ratio / HP/in2 DATA Open Hole psi psi 6X12 6X12 4.230 4.~J3- 110 110 100/1760 226 1055 240 181 / 2.0_1N2 ! I Ppg Ppg Length (ft) Volume (bbls/ff) Velocity (ft/min) Cdt-Vel (ft/min) Ann-Vol (bbls) DP/CSG 5301 0.1195 184 345 633.0 DP/OH 5484 0. t 194 190 320 675.0 HW/O H 243 O. 1107 190 320 27.0 DC/OH 256 O.08AO 265 360 21.0 Drill String Casing DC 5.5"HWDP 5.E' DP OD (inches) 8.000 5.500 5.500 30.00 13 3/8 ID (inches) 2.875 3.250 4.780 28.00 12.415 Cap (bbls/ff) 0.(3060 0.0102 0.0222 0.1497 Disp (bbls/ft) 0.0541 0.0191 0.0074 0.0241 Length (ft) 256 243 10785 110 5301 Weight (lbs/fi) 145.0 61.5 21.9 1 70.0 68.0 COND SURF INT LINER 9.7 900 DRILL TO 11284. PUMP LOW + HIGH VIS SWEEP. PULL OUT OF HOLE TO CASING TOP DRIVE. REFERENCE TEST LWD. RUN IN THE HOLE. TAG BOTTOM. DRILLING AT 03:00. HOLE IS IN GOOD SHAPE. sperry-sun DRILLING SERVICES ADT Mornin~ Rer~ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.' RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 26 2/20/99 0300 13030 / 8331 .1746 MASKELL/POLYA Background Connection Trip Flowline Temp Avg Max {~ Gas Gas DEPTH (units) (units) 200 450 11810 NONE 0 425 STG 11284 90 degree F Casing Pore Pressure 2012 psi 8.7 ppg ECD ' ~ psi 10.1 ppg ime Type LSND Type Weight In 9.8 IADC Code Funnel Vis. 56 Size PV/YP 15/21 Jets Gels 8/12 Depth Out pH 8.5 Rot. Hrs. FiltJCake APl 3.5 12 Footage HTHP Avg fi/hr Pm 0.1 Grade Pf/Mf .10/.6 Cost/ft Chlorides (ppm) 700 RPM Calcium (ppm) 60 WOB Oil/Water/Solids 3.,?V86.5/10 Daily/Cum. Cost Survey Data DEG 62.77 AZIM 352.2 MD 12816.95' TVD 8234.5' Lithology 50% CLAY- 50% SAND Sample Depth 13000 Ddll Rate (fi/hr) Trip Chlorides NA Corrected "D" Exp. Lag Down Pipe 2745 Shale Density (gm/cc) Lag Off Bottom 15200 EWR (res) 140 0.88 NA DATA Bottom Hole Open Hole 3899 psi 9.0 ppg psi 4375 psi 10.1 ppg psi Ppg 5 873 HPX- PDC ON MOTOR 12.25 1.32 TFA 29.6 4020.0 136.0 NA 115+85 15o20 4 Pumps 1 MX1 ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.190 Pump Rate (stks/min) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf / DS (psi) 161.0 Ann / Bit (psi) 45WTAE3/8RGBHA Jet Velocity (fi/sec) 58.0 Jet Impact (lbs) 85/110 Iait HP (hhp) 40/50 IHP Ratio/HP/in2 6X12 4.~b'- I I I 6X12 100 / 2050 100/450 226 1070 245 17% / 2.1 _IN2 DP/CSG DP/OH HW/OH DC/OH Length (fi) Volume (bbls/ft) Velocity (fi/min) Cdt-Vel (fi/min) Ann-Vol (bbls) 5301 0.1195 184 345 633.0 7230 0.1194 190 320 8~0.0 243 0.1107 190 320 27.0 256 0.0840 265 360 21.0 OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ff) Length (fi) Weight (lbs/fi) 9.7 DC 8.000 2.875 0.0080 0.0541 256 145.0 Ddll Stdng 5.5"HWDP 5.500 3.250 0.0102 0.0191 243 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 12531 21.9 AND COND 30.00 28.00 110 1 70.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER JOHN PATTON sperry-sun DRILLING SERVICES ADT Mornin.cl Rel3ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 27 2/21/99 0300 13853 / 8732 .. 823 DRILLING MASKELL / POLYA Avg Max ~ Gas Gas DEPTH (units) (units) Background 150 196 13490 Connection NONE 0 Trip 510 STG 13030 Flowline Temp 90 degree F Casing Pore Pressure 2012 psi 8.7 ppg ECD 2335 psi 10.1 ppg Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 60.15 AZIM 350.8 MD 13~)6.65' TVD 8555.8' 70% CLAY - 10% SAND - 2096 SILTSTONE 13700 Ddll Rate (fi/hr) NA Corrected "D" Exp. 2950 Shale Density (gm/cc) 16300 EWR (res) 140 0.91 NA DATA 4631 Bottom Hole Open Hole psi 9.0 ppg psi psi 10.2 ppg psi PPg PPg ime o. Type LSND Type Weight In 9.9 IADC Code Funnel Vis. 59 Size PV/YP 20/28 Jets Gels 8/12 Depth Out 8.5 Rot. Hrs. APl 3.2 / 2 Footage HTHP 9.2 Avg f'dhr 0.1 Grade Pf/Mf .14/.5 Cost/ff Chlorides (ppm) 700 RPM Calcium (ppm) 60 WOB Oil/Water/Solids 3.5/86.2/10.3 Daily/Cum. Cost 5 S73 HPX- PD£ ON MOTOR 12.25 1.32 TFA 39.9 4843.0 121.0 NA 110+85 15.0 4 umps 1 I ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.190 Pump Rate (stks/min) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf/DS (psi) 161.0 Ann / Bit (psi) 45WTAE3/8RGBHA Jet Velocity (fi/sec) 58.0 Jet Impact (lbs) 85 / 110 lait HP (hhp) 40/50 IHP Ratio / HP/in2 I I 6X12 6X12 4~ ~ 100/2110 140/450 226 1070 245 16% / 2.1 _IN2 DP/CSG DP/OH HW/OH DC/OH Length (fi) Volume (bbls/ft) Velocity (fi/min) Crit-Vel (fi/min) Ann-Vol (bbls) 5,301 0.1195 184 365 633.0 8053 0.1194 190 3AO S02.0 243 0.1107 lg0 340 27.0 ~ 0.0840 265 380 21.0 )D (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (ft) Weight (lbs/fi) DC 8.000 2.875 0.0060 0.0541 256 145.0 Drill Stdng 5.E'HWDP 5.500 3.250 0.0102 0.0191 243 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 13353 21.9 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 9.8 )N sperry-sun DRILLING SERVICES ADT Mornin~ Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 28 2/22/99 0300 14969 / 9274 .1117 DRILLING MASKELL / POLYA Background Connection Trip Flowline Temp Avg Max {~ Gas Gas DEPTH (units) (units) TRACE 0 483 STG 14289 92 degree F Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 60.92 AZlM 342.9 MD 14756.3' 'I'VD 9171.4' 10% CLAY - 30% SAND - 60% SILTSTONE 14800 Drill Rate (fi/hr) NA Corrected "D" Exp. 3160 Shale Density (gm/cc) 17500 EWR (res) 65 0.99 NA Casing Pore Pressure 2012 psi 8.7 ppg LCD ' 2497 psi 10,8 ppg Type LSND Type Weight In 10.5 IADC Code Funnel Vis. 58 Size PV/YP 28/24 Jets Gels 10/18 Depth Out pH 8.7 Rot. Hrs. Filt/Cake APl 3.0 / 2 Footage HTHP 9.8 Avg fi/hr Pm 0.2 Grade Pf/Mf .11.6 Cost/ft Chlorides (ppm) 700 RPM Calcium (ppm) 60 WOB Oil/Water/Solids 3.5/86.2J10.3 Daily/Cum. Cost 52O8 Bottom Hole Open Hole psi 9.6 ppg psi psi 10.8 ppg psi 5 S73 HPX - PDC ON MOTOR 12.25 1.32 TFA 51.0 5959.0 117.0 NA 110+85 15.0 4 umps 1 MX1 ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.190 Pump Rate (stks/min) ' 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Sud / DS (psi) 161.0 Ann / Bit (psi) z~-WTAE~RGBHA Jet Veloc~y (fi/sec) 58.0 Jet Impact (lbs) 851110 IBit HP (hhp) 4O/50 IHP Ratio / HP/~n2 I 6X12 6X12 4."~Jb- ~ I ! 32OO 100 / 2495 125/480 226 1140 26O 15% / 2.2 _IN2 DP/CSG DP/OH HW/OH DC/OH Length (fi) Volume (bbls/ff) Velocity (ft/min) Crit-Vel (fi/min) Ann-Vol (bbls) 5301 0.1195 184 310 ' 633.0 9169 243 256 0.1194 190 285 1145.0 0.1107 190 285 27.0 0.0840 265 335 21.0 OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (fi) Weight (lbs/fi) DC 8.000 2.875 0.0(360 0.0541 256 145.0 Ddll String 5.5"HWDP 5.500 3.250 0.0102 0.0191 243 61.5 5.5" DP 5.500 4.780 0.0222 0.0074 14470 21.9 COND 30.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 10.4 sperry-sun DRILLING SERVICES ADT Morninq Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 29 2/23/99 0300 15862 / 9705 .. 893 SHORT TRIP MASKELL / POLYA Background Connection Tdp Flowline Temp A~ Mm ~ Gas Gas DEPTH (un,s) (un,s) 165 213 15585 NONE 0 483 STG 14289 104 degree F Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZlM 342.6 MD 15727.1' TVD 9640.4' 10% CLAY - 30% SAND - 60% SlLTSTONE 15860 Drill Rate (fi/hr) NA Corrected "D" Exp. 3385 Shale Densk'y (gm/cc) 19200 EWR (res) 110 0.95 NA Casing Pore Pressure 2012 psi 8.7 ppg ECD ' 2613 psi 11.3 ppg Type Weight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11 54 26/30 9/16 8.6 3.312 9.4 0.15 .1/.6 700 60 3.0/81.9/1 5.1 [o. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB Bottom Hole Open Hole i:~ 9.9 ppg psi psi 11.3 ppg psi 5 S73 HPX- PD¢ ON MOTOR 12.25 1.32 TFA 60.5 6853.0 113.0 NA $70 115+85 15-20 4 'umps 1 MX1 ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.190 Pump Rate (stksknin) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf / DS (psi) 161.0 Ann / Bit (psi) 45VVTAE3/8RGBHA Jet Velocity (fi/sec) 58.0 Jet Impact (lbs) ss / 11o Iait HP (hhp) 40 / 50 I HP Ratio / HP/in2 PPg 6X12 4.'~jO- I I I 6X12 100 12960 140/500 226 1165 270 13% / 2.2 _IN2 DP/CSG DP/OH HW/OH DC/OH Length (fi) Volume (bbls/ft) Velocity (ft/min) Cdt-Vel (fi/min) Ann-Vol (bbls) 5301 0.1195 184 310 633.0 1OO62 243 256 0.1194 190 285 0.1107 190 285 0.0840 265 335 1250.0 27.0 21.0 LINER ;)D (inches) ID (inch,es)" Cap (bbls/ft) Disp (bblS/ft) Length (ft) Weight (lbs/fi) DC 2.875 0.0060 0.0541 256 145.O Drill String 5.E'HWDP 5.5(30 3.250 0.0102 0.0191 243 61.5 5.E' DP 5.500 4.780 0.0222 0.0074 15363 21.9 COND 30.00 28.1D0 110 170.0 SURF 133/8 12.415 0.1497 O.0241 5301 68.0 Casing INT 10.6 )N sperry-sun DRILLING SERVICES ADT Mornin~ Rel~ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 30 2/24/99 0200 15862 / 9705 ~. 0 SHORT TRIP MASKELL / POLYA Avg Max ~ Gas Gas DEPTH (units) (units) Background 20 - 40 165 15862 Connection NONE 0 Tdp 293 STG 1 5862 Flowline Temp 85 degree F Casing Pore Pressure 2012 psi 8.7 ppg LCD 2613 psi 11.3 ppg me lit No. Type LSND Type Weight In 11 IADC Code Funnel Vis. 54 Size PV/YP 26/30 Jets Gels 9/16 Depth Out pH 8.6 Rot. Hrs. F/It/Cake APl 3.3 / 2 Footage HTHP 9.4 Avg ftJhr Pm 0.15 Grade Pf/Mf .11.6 Cost/ft Chlorides (ppm) 700 RPM Calcium (ppm) 60 WOB O il/Water/S olids 3.0/81.9/15.1 Daily/Cum. Cost Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag OFF Bottom DEG 61 .O2 AZIM 342.6 MD 15727.1' TVD 9640.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15860 Ddll Rate (fi/hr) NA Corrected "D" Exp. 3385 Shale Density (gm/cc) 19200 EWR (res) 110 0.95 NA FORMATION DATA Bottom Hole psi 9.9 ppg psi 11.3 ppg 5 S73 HPX - PD¢ ON MOTOR 12.25 1.32 TFA 60.5 6853.0 113.0 NA $70 115+85 15-20 4 Pumps 1 MX1 ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.1~0 Pump Rate (stks/min) 9010.0 Flow Rate (gal/m/n) 23.0 Pressure (psi) 3707.0 PD Surf/DS (psi) t61.0 Ann / Bit (psi) 45VVTAE3/8RGBHA Jet Velocity (fi/sec) 58.0 Jet Impact (lbs) 85/110 IBit HP (hhp) 40/50 IHP Ratio/HP/in2 Open Hole psi psi HYDRAULIC Ppg Ppg 12P160 2 12P1 I I 6X12 6X12 4.233 ~-.230 100 100 2300 100 / 2960 95/420 2O6 995 206 18% / 1.7_1N2 at 9550' DP/CSG DP/OH HW/OH DC/OH Length (ft) Volume (bbls/ff) Velocity (fi/m/n) Cdt-Vel (ftJmin) Ann-Vol (bbls) 5.301 0.1195 168 310 633.0 Ddll String DC 5.E'HWDP 5.5" DP OD (inches) 8.000 5.500 5.500 ID (inches) 2.875 3.250 4.780 Cap (bbls/ff) 0.0060 0.0102 0.0222 Disp (bbls/ft) 0.0541 0.0191 0.0074. Length (ft) 256 243 15363 Weight (lbs/fi) 145.0 61.5 21.9 O. 1194 174 285 1250.0 O. 1107 173 285 27.0 0.08AO 241 335 21.0 PIPE DATA COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1~)7 0.0241 5301 68.0 Casing INT LINER 10.6 900 POOH. BUILD/ADD FRESH MUD. RIH STAGING IN Representative JOHN PATTON sperry-sun DRILLING SERVICES ADT Mornin_q Rel3ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 31 2/25/99 0200 15862 / 9705 0 WORK ON T. DRV MASKELL / POLYA Background Connection Trip Flowline Temp Avg Max (~ Gas Gas DEPTH (units) (units) 20 - 40 154-CBU 12480 NONE 0 562 STG 15862 95 degree F Casing Pore Pressure 2012 psi ECD ' 2613 psi 8.7 11.3 ime Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11 52 Z3/23 8/10 8.7 3.2/2 8.8 0.25 .11.55 8O0 60 3.5/80.5/16 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost#t RPM WOB DPICSG DP/OH HWIOH DC/OH PPg Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61 .O2 AZlM 342.6 MD 15727.1' 'I'VD 9640.4' ~Oe/o CLAY - 30% SAND - 60% SlLTSTONE 15860 Ddll Rate (fi/hr) NA Corrected "D" Exp. 3385 Shale Density (gm/cc) 19200 EWR (res) DATA Bottom Hole Open Hole 4996 psi 9.9 ppg psi 5702 psi 11.3 ppg psi 110 0.95 NA 5 873 HPX - ON MOTOR 1.32 TFA 60.5 6853.0 113.0 NA 115+85 15-20 4 'umps 1 MX1 I PPg PPg ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.190 Pump Rate (stks/min) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf / DS (psi) 161.0 Ann / Bit (psg 45WTAE3/SRGBHA Jet Velocity (fi/sec) 58.0 Jet Impact (lbs) 85/110 IBit HP (hhp) 40 150 J HP Ratio / HP/in2 6X12 6X12 4~ 4.230 I I 100 / 2960 95/420 206 995 206 18% 11.7_1N2 at 9550' DATA Length (fi:) Volume (bbls/ff) Velocity (fi:/min) Cdt-Vel (fi:/min) Ann-Vol (bbls) 5301 0. t195 168 310 633.0 1OO62 243 256 0.1194 174 285 1250.0 O. 1107 1 73 285 27.0 0.0840 241 335 21.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi:) Weight (~bs/ft) 10.6 DC 8.000 2.875 0.0080 0.0541 256 145.0 Ddll Stdng 5.5"HWDP 5.500 3.2'33 0.O102 0.0191 243 61.5 5.E' DP 5.500 4.780 0.0222 0.0074 15363 21.9 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER sperry-sun DRILLING SERVICES ADT Mornin_q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 32 2/26/99 0200 15862 / 9705 .. 0 RUN 9 5/8" CASING MASKELL / miller Avg Max Gas Gas (units) (units) Background 0-5 Connection NONE 0 Tdp :lowline Temp 95 degree F DEPTH Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZlM 342.6 MD 15727.1' TVD 9640.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15860 Ddll Rate (E/hr) NA Corrected "D" Exp. 11372 ID-CSG Shale Density (gm/cc) 8946 ANN-CSG EWR (res) NA Casing Pore Pressure 2012 psi 8.7 ppg ECD 2613 psi 11.3 ppg Ime iTYPe iWeight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND Type 11 IADC Code 50 Size 22/21 Jets 6/10 Depth Out 8.6 Rot. Hrs. 3.4/2 Footage 9 Avg E/hr 0.2 Grade .11,4 Cost/ft 600 RPM 60 WOB 3.5/81.5/1 5 53.SCSG/CSG 53.5CSG/OH 47CSG/OH Bottom Hole Open Hole psi 9.9 ppg psi psi 11.3 ppg psi 5 S73 HPX- PD( ON MOTOR 12.25 1.32 TFA 60.5 6853.0 113.0 NA $70 115+85 15-20 ANNULAR DATA 4 ~umps 1 MX1 ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.190 Pump Rate (stks/min) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf / DS (psi) 161.0 Ann / Bit (psi) zlSWTAE3/SRGBHA Jet Veloc~/(E/sec) 58.0 Jet Impact (lbs) 85/110 IBit HP (hhp) 40150 IHP Ratio / HP/in2 Length (~) 5301 1272 9289 Volume (bbls/ft) Velocity (E/min) 0.0597 PPg PPg I 6X12 6X12 4.'-'~b-- 4.230 I I 100 100 847 100/2960 95/420 206 206 18% i 1.7 _IN2 Cdt-Vel (E/min) Ann-Vol (bbls) 315.0 71.0 516.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (Ibs/ft) Ddll Stdng 47~CSG 9.625 8.681 0.0732 0.0168 9289 47.0 53.5#-CSG 9,625 8,537 0.0708 0.0192 53.5 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1z197 0.0241 5301 68.0 Casing INT LINER 10.6 CASING, ADJUST TOP DP, V, RUN CASING. DOUG WILSON sperry-sun DRILLING SERVICES ADT Mornin_~ Re~3ort Customer: Well: Area: Lease: Rig' Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 33 2/27/99 0200 15862 / 9705 0 .. RUN 9 5/8" CASING MASKELL/MILLER Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) 0-14 27 NONE 0 DEPTH 95 degree F Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZIM 342.6 MD 15727.1' TVD 9640.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15860 Drill Rate (fi/hr) NA Corrected "D" Exp. 11372 I D-CSG Shale Density (gm/cc) 8946 ANN-CSG EWR (res) NA Casing Pore Pressure 2012 . psi ECD 2613 psi 8.7 11.3 Time Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11 45 18117 4/8 8.5 3.2/2 9 0.1 .1~.5 700 60 3.5/81.5/15 ~it No. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB PPg PPg 57O2 Bottom Hole Open Hole psi 9.9 pPg psi psi 11.3 pPg psi 5 S73 HPX- PD¢ ON MOTOR 12.25 1.32 TFA 60.5 6853.0 113.0 NA $70 115+85 15-20 4 Pumps 1 2 ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1 AgO Pump Rate (stks/min) 9010.0 Flow Rate (gal/min) 23.0 Pressure (psi) 3707.0 PD Surf/DS (psi) 161.0 Ann I Bit (psi) 45WTAE3~SRGBHA Jet Velocity (fi/sec) 58,0 Jet Impact (lbs) 85 / 110 IBit HP (hhp) 40/50 IHP Ratio / HP/in2 6X12 6X12 100 1'~' PPg PPg 1 100 / 2960 95/420 206 995 206 18% / 1.7 _IN2 53.5CSG/CSG 53.5CSG/OH 47CSG/OH Length (fi) 5301 1272 9289 Volume (bbls/ff) Velocity (ft/min) 0.(~397 Crit-Vel (ft/min) Ann-Vol (bbls) 315.0 71.0 516.0 LINER OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (ft) Weight (lbs/fi) Drill String 47~-CSG 9.625 8.681 0.0732 0.01 68 9289 47.0 53.5#-CSG 9.625 8.537 0.0708 0.0192 6573 53.5 COND ~.~ ~.~ 110 1~.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT 10.6 )resentative DOUG WILSON sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 34 2/28/99 0200 15853 / 9700 CIRC 9 5/8" CASING MASKELL/MILLER round Connection Tdp i Flowline Temp Avg Max ~ Gas Gas DEPTH (units) (units) 200 429 15852 NONE 0 95 degree F Casing Pore Pressure 2012 psi ECD ' 2613 psi 8.7 11.3 me Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11 51 24/'23 8110 8.6 3.6/2 9.8 0.1 .1~.5 700 60 3.5/81.4/15.1 lit No. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade CostJff RPM WOB 53.SCSG/CSG 53.SCSG/OH 47CSG/OH PPg PPg 5 S73 HPX- PDC ON MOTOR 12.25 1.32 TFA 60.5 6853.0 113.0 NA $70 115+85 15-20 Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZIM 342.6 MD 15727.1' TVD 9640.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15850 Drill Rate (fi/hr) NA Corrected "D" Exp. 11372 ID-CSG Shale Density (gm/cc) 89,46 ANN-CSG EWR (res) NA Length (ft) 5301 DATA 5702 Bottom Hole Open Hole psi 9.9 pPg psi psi 11.3 pPg psi PPg PPg 1272 9289 4 Pumps 1 MX1 ON MOTOR Size (inches) 12.25 Capac'Ry (gal/stk) 1.190 Pump Rate (stks/min) 9010.0 Flow Rate (gal/m/n) 23.0 Pressure (psi) 3707.0 PD Surf / DS (PSQ 161.0 Ann / Bit (psi) 45VVTAE3/8RGBHA Jet Velocity (fi/sec) 58.0 Jet Impact (lbs) ~5 / 11o Iait HP (hhp) zlO/50 ]HP Ratio/HP/in2 I 6X12 6X12 12P160 I I 2300 100 / 2960 95 / 420 206 995 206 18% / 1.7 _IN2 DATA Volume (bbls/ft) Velocity (ft/min) 0.0597 Cdt-Vel (ft/min) Ann-Vol (bbls) 315.0 71.0 516.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/Tt) Length (it) Weight (Ibs/ft) Ddll String 47~CSG 9.625 8.681 0.0732 0.0168 9289 47.0 53.~CSG 9.625 8.537 0.0708 0.0192 6573 53.5 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT LINER 10.6 DOUG WILSON sperry-sun DRILLING SERVICES, ADT Mornin_cl Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 35 3/1/99 0200 15853 / 9700 NIPPLE UP MASKELL/MILLER Background Connection Trip Flowline Temp Avg Max ~ Gas Gas DEPTH (units) (units) 110 249 15852 NONE 0 95 degree F Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEC 61.02 AZIM 342.6 MD 15727.1' 'I'VD 9640.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15850 Drill Rate (fi/hr) NA Corrected "D" Exp. 11372 ID-CSG Shale Density (gm/cc) 8946 ANN-CSG EWR (res) NA Casing Pore Pressure 2012 psi ECD ' 2613 psi 8.7 11.3 ime Type Weight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11 50 22/20 7/9 8.6 3.5/2 9.8 0.1 .1/.55 8O0 80 3.5/81.4/15,1 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg ft/hr Grade Cost/ff RPM WOB PPg 57O2 Bottom Hole Open Hole psi 9.9 ppg psi psi 11.3 ppg psi 5 umps I 1 S73HPX-PDC ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.320 Pump Rate (stks/min) 15853.0 Flow Rate (gal/min) 60.5 Pressure (psi) 6844.0 PD Surf / DS (psi) 113.0 Ann / Bit (psi) NA Jet Velocity (fi/sec) 70.0 Jet Impact (lbs) 115~85 Iait HP (hhp) 15-20 IHP Ratio / HP/in2 PPg PPg 6X12 1'0~' I I I 6X12 Length (fi) Volume (bbls/ft) Velocity (fi/min) Crit-Vel (fi/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (Ibs/ft) Drill String Casing COND SURF INT LINER 30.00 13 3/8 95/8" 28.00 12.415 8.622 0.1497 0.0722 0.0241 0.0178 110 5301 15852 170.0 68.0 47~E~3.5 10.6 900 sperry-sun DRILLING SERVICES ADT Mornin_q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.:' RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 36 3/2/99 0200 15853 / 9700 RIH MASKELL/MILLER Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) 0 DEPTH degree F Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZlM 342.6 MD 15727.1' TVD 9640.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15850 Drill Rate (fi/hr) NA Corrected "D" Exp. Shale Density (gm/cc) EWR (res) NA Casing Pore Pressure 2012 psi ECD 2613 psi 8.7 11.3 ime Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11 50 22/20 7/9 8.6 3.5/2 9.8 0.1 .1/.55 800 80 3.5/81.4/15.1 Oo Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade CosUff RPM WOB PPg PPg 57O2 Bottom Hole Open Hole psi 9.9 pPg psi ppg psi 11.3 ppg psi ppg 5 ~umps 1 S73HPX-PDC ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.320 Pump Rate (stkshnin) 15853.0 Flow Rate (gal/min) 60.5 Pressure (psi) 6844.0 PD Surf / DS (psi) 113.0 Ann / Bit (psi) NA Jet Velocity (fi/sec) 70.0 Jet Impact (lbs) 115.e5 Iait HP (hhp) 15-20 IHP Ratio ! HPfin2 I I I 6X12 6X12 4~ ~ Length (fi) Volume (bbls/ff) Velocity (ftJmin) Crit-Vel (fi/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (lbs/fi) 10.6 Drill String Casing COND 30.00 28.00 110 170.0 SURF INT LINER 133/8 9,5/8" 12.415 8.622 O. 1497 0.0722 0.0241 0.0178 5301 15852 68.0 47/53.5 DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin~ Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 37 3/3/99 O2OO 15853 1 9700 BOP'S MASKELL/MILLER Background Connection Tdp Flowtine Temp Avg Max Gas Gas (units) (units) 0 degree F Casing Porn Pressure 2012 psi ECD ' 2613 psi me Type Weight In Funnel Vis. PV/YP Gels pH Flit/Cake APl Pm HTHP Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11.5 48 21/27 6/10 9.8 4.8/2 0 0.3 .2/.8 32(X30 ,~0 0/86.0/14 DEPTH Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZIM 342.6 MD 15727.1' TVD 96AO.4' 10% CLAY- 30% SAND -60% SlLTSTONE 15850 Drill Rate (fi/hr) NA Corrected "D" Exp. Shale Density (gm/cc) EWR (res) NA 8.7 11.3 PPg PPg FORMATION DATA Bottom Hole Open Hole 4996 psi 9.9 pPg psi pPg 5702 psi 11.3 pPg psi pPg ~o. Type IADC Code Size Jets Depth Out Rot. Hm. Footage Avg fi/hr Grade Cost/ft RPM WOB 5 ~umps 1 S73HPX-PDC ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.320 Pump Rate (stks/min) 15853.0 Flow Rate (gal/min) 60.5 Pressure (psi) 6844.0 PD Surf/DS (ps~ 113.0 Ann / Bit (ps~ NA Jet Velocity (fi/sec) 70.0 Jet Impact (lbs) 115.~ Iait HP (hhp) 15-20 IHP Ratio / HP/in2 I I I 6X12 6X12 4.-'~b'- 4.230 Length (ft) Volume (bbls/ft) Velocity (ft/min) Cdt-Vel (ftJmin) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (ft) Weight (lbs/fi) Ddll String Casing COND SURF INT 30.00 133/8 9 5/8" 28.00 12.415 8.622 O. 1497 0.0722 0.0241 0.0178 110 5301 15852 170.0 68.0 47~53.5 LINER 10.6 900 sperry-sun DRILLING SERVICES ADT Mornin_q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 38 3/4/99 02OO 15853 / 9700 W/O TOP DRIVE LOCKWOOD/MILLER Background Connection Trip Flowline Temp Pore Pressure ECD Avg Max Gas Gas (units) (units) 0 DEPTH degree F Casing 2012 psi 8.7 ppg 2613 psi 11.3 ppg Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZIM 342.6 MD 15727.1' TVD g6zlO.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15850 Ddll Rate (ft/hr) NA Corrected "D" Exp. Shale Density (gm/cc) EWR (res) NA FORMATION PRESSURE DATA Bottom Hole 4996 psi 9.9 ppg 5702 psi 11.3 ppg Open Hole psi ppg ime Type Weight In Funnel Vis. PV/YP Gels pH Fiit/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 10.7 48 20/15 3/9 8 3.6/2 0 0 0/1.2 1000 140 .5/83/12 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB 5 lumps 1 S73HPX-PDC ON MOTOR Size (inches) 12.25 Capacity (gal/stk) 1.320 Pump Rate (stks/min) 15853.0 Flow Rate (gal/min) 60.5 Pressure (psi) 6844.0 PD Surf/DS (psi) 113.0 Ann / Bit (psi) NA Jet Velocity (fi/sec) 70.0 Jet Impact (lbs) 11s+ IBitHP (hhp) 15-20 IHP Ratio / HP/in2 I I I 6X12 6Xl 2 4.'~3b-- ~ Length (ft) Volume (bbls/ff) Velocity (fi/min) Cdt-Vel (fi/min) Ann-Vol (bbls) 3D (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) ~Length (ft) Weight (lbs/fi) Drill String COND 20.(~ 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT 8.622 0.0722 0.0178 15852 47P~3.5 LINER 10.6 sperry-sun DRILLING SERVICES ADT MornJnq Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOC= # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 39 3/5/99 0200 15853 / 9700 - 0 PICK UP PIPE LOCKWOOD/MILLER Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) 0 DEPTH degree F Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG G1.02 AZIM 342.6 MD 15727.1' TVD 9640.4' 10% CLAY - 30% SAND - 60% SILTSTONE 15850 Drill Rate (fi/hr) NA Corrected "D" Exp. Shale Density (gm/cc) EWR (res) NA Pore Pressure 3912 psi LCD ' 2613 psi 8.7 11.3 ime Type Weight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm P f/Mr Chlorides (ppm] Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost LSND 11.4 54 20/30 7113 8.6 3/2 0 0.3 .2/.8 30000 160 1/85/14 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/E RPM WOB 5 S73HPX-PDC 7 1 DS7OFNPV-PDC 12.3 8.50 1.320 1.035 15853.0 60.5 6844.0 113.0 NA $70 115+85 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impac~ (lbs) IBit HP (hhp) HP Ratio / HP/in2 I I I 6X12 8X12 DATA Length (fi) Volume (bbls/ft) Velocity (fi/min) Crit-Vel (fi/min) Ann-Vol (bbls) OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (Ibs/ft) 10.6 Ddll Stdng COND 30.00 28.00 110 170.0 SURF 133~8 12.415 0.1497 0.Q241 5301 68.0 Casing INT LINER 8.622 0.0722 0.0178 15852 47,53.5 )resentative DON WALTERS sperry-sun DRILLING SERVICES ADT Mornin.q Re~)ort Background Connection Tdp Flowline Temp Avg Max (~ Gas Gas DEPTH (units) (units) 40 115 15870 NA NONE degree F Casing Pore Pressure 4995 psi 9.9 ppg ECD ' 6155 psi 12.2 ppg Time Type Weight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost ~it No. KCL POLY Type 11.5 IADC Code 56 Size 14/23 Jets 5/11 Depth Out 10 Rot. Hrs. 4.6 2/32 Footage 0 Avg fi/hr 0.4 Grade .2/.6 Cost/ft 31000 RPM 160 WOB 1/86/11.4 DP/CSG DP/HOLE DC/CSG DC/HOLE Customer: BP EXPLORATION Report No.: 40 Well' RED DOG # 1 Date: 3/6/99 0300 Area: NORTH SLOPE, ALASKA Depth 15873 / 9710 Lease: Footage: .. 20 Rig' NABORS 28E Rig Activity: DRILLAHEAD Job No.' 851034 Report For: LOCKWOOD/MILLi LOGGING DATA Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 61.02 AZIM 342.6 MD 15'727.1' TVD 9640.4' 30% CLAY - 70% SILTSTONE - ABNDT CEMENT 15870 Ddll Rate (ft/hr) 160 NA Corrected "D" Exp. 0.55 2725 Shale Density (gm/cc) NA 7400 EWR (res) FORMATION PRESSURE DATA Bottom Hole 4996 psi 9.9 6160 psi 12.2 Ppg Ppg 5 873HPX-PDC 7 DS70FNPV-PDC ON MOTOR ON MOTOR 12.25 8.50 1.320 1.035 15853.0 60.5 0.1 6844.0 20.0 113.0 200.0 NA $70 115+85 55+150 15-20 5-10 ANNULAR DATA Pumps I Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 Open Hole psi psi HYDRAULIC ~ 2 I 6X12 6X12 4.230 4.230 12P160 Ppg 156 467 75 9% / t .3 IN2 Length (ft) Volume (bbls/ff) Velocity (fi/min) Cdt-Vel (ftJmin) Ann-Vol (bbls) 15653 0.0478 250 345 748.0 - 0.0460 197 0.0278 439 ,400 5.5 23 0.0260 474 400 0.6 OD (inches) ID (inches) Cap (bbls/fi) Disp (bbls/ft) Length (fi) Weight (lbs/fi) 11.4 DP 5.000 4.276 0.01 78 0.0076 15167 19.5 DATA Ddll Stdng Casing HWDP DC COND SURF INT LINER 5.000 6.750 30.00 13 3/8 9 5t8" 3.030 2.875 28.00 12.415 8.622 0.0087 0.0080 0.1497 0.0722 0.0181 0.0364 0.0241 0.01 78 486 220 110 5301 15850 50.0 100.0 1 70.0 68.0 47F~3.5 REMARKS AND RECOMMENDATION MUD. DRILL FORMATION TO 15873. CIRCULATE AND DISPLACE HOLE WITH FRESH KCL MUD ~ 11.4 PPG. CONTINUE DRILLING. ADT Representative JOHN PATTON sperry-sun DRILLING SERVICES ADT Mornin,cl Rel~ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 41 3/0'~/99 0300 16591 / 10050 718 · SLIDING LOCKWOOD/MILLER Background Connection Trip Flowline Temp Pore Pressure LCD Avg Max ~ Gas Gas DEPTH (units) (units) 85 161 165,.'.'~ NA NONE 100 degree F Casing 4995 psi 9.9 ppg 6758 psi 13.4 ppg Survey Data DEG 61.02 AZIM 342.6 MD 15727.1' TVD 9640.4' Lithology 20% CLAY - 80% SILTSTONE DRLG / SLIDE Sample Depth 16500 Ddll Rate (fi/nO 85/15 Trip Chlorides NA Corrected "D" Exp. 0.92 Lag Down Pipe 2860 Shale Density (gm/cc) NA Lag Off Bottom 7850 EWR (res) PRESSURE DATA Bottom Hole Open Hole 5487 psi 10.5 ppg psi ppg 7003 psi 13.4 ppg psi ppg [me Weight In Funnel Vis. PV/YP Gels pH Fiit/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost DP/CSG DP/HOLE DC/HOLE KCL POLY 12.0 59 20/42 18/25 8.8 4.42/32 0 0.3 .1/.6 24OO0 160 3/81/14.8 ~it No. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB 5 S73HPX-PDC ON MOTOR ON MOTOR 12.25 8.50 1.320 1.035 15853.0 60.5 14.1 6844.0 738.0 113.0 52.3 NA $70 115+85 110+205 15-20 10-15 ANNULAR DATA 7 umps I 12Pli DS70FNPV-PDC I I I Size (inches) 6X12 6X12 Capacity (gal/stk) 4.230 4.230 Pump Rate (stks./min) ~ ~ Flow Rate (gai/min) ~ Pressure (psi) 3600 PD Surf / DS (psi) 75 / 2520 Ann / Bit (psi) 735 / 270 Jet Velocity (ftJsec) 158 Jet Impact (lbs) 500 I Bit HP (hhp) 80 HP Ratio / HP/in2 7% / 1.4 IN2 Length (ft) Volume (bbls/ft) Velocity (ffJmin) Crit-Vel (ftJmin) Ann-Vol (bbls) 15850 0.0478 2Sa ~0 758.0 521 0.0460 265 455 220 0.0260 481 500 20,0 6.0 LINER DATA Drill String Casing DP HWDP DC COND SURF INT OD (inches) 5.000 5.000 6.750 30.00 13 3/8 9 5/8" ID (inches) 4.276 3.000 2.875 28.00 12.415 8.622 Cap (bbls/ft) 0.0178 0.0067 0.0080 0.1 zl97 0.0722 Disp (bbls/ft) 0.0076 0.0181 0.0364 0.0241 0.0178 Length (It) 15885 486 220 110 5301 15850 Weight (lbs/fi) 19.5 50.0 1(30.0 1 70.0 68.0 47/53.5 11.4 500 MARKS AND OF SONIC AND RESISTIVITY DATA. GAS DATA IS NOT CONCLUSIVE WITH CURRENT OVERBALANCE. PORE PRESSURE ADT Representative JOHN PATTON sperry-sun DRILLING SERVICES ADT Morninq Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.- 42 RED DOG # 1 Date: 3/08/99 0300 NORTH SLOPE, ALASKA Depth 16645 / 10080 Footage: 54 NABORS 28E Rig Activity: TRIP IN 851034 Report For: LOCKWOOD/MILLER Background :Connection Trip ! Flowtine Temp Avg Max ~ Gas Gas DEPTH (units) (units) 0 193 16640 NONE NA 100 degree F Casing Pore Pressure 4995 psi ECD , 6758 psi 9.9 13.4 PPg Time Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 11:13 KCL POLY 12.3 61 18/39 13/25 8.8 4.0 2/32 14 0.3 .1/1.2 270O0 4/78/18 tit No. Type IADC Code S~ze Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB Survey Data DEG 61.1 6 AZIM 34G.6 MD 16425.86' TVD 9972.49' Lithology 20% CLAY - 80% SILTSTONE DRLG / SLIDE Sample Depth 16600 Drill Rate (fi/hr) 115 / 8 Trip Chlorides NA Corrected "D" Exp. 0.89 Lag Down Pipe 2870 Shale Density (gm/cc) NA Lag Off Bottom '7900 EWR (res) 4.50 BIT #7 FORMATION PRESSURE DATA Bottom Hole Open Hole 5504 psi 10.5 pPg psi pPg 7024 psi 13.4 pPg psi pPg MX1 ON MOTOR 12.25 0.995 7 Pumps I ~ 2 DS70FNPV-PDC I ON MOTOR Size (inches) 6X12 6X12 8.50 Capacity (gal/stk) 4.'~JO 4.230 1.035 Pump Rate (stks/min) 60 60 16645.0 Flow Rate (gal/min) 14.9 Pressure (psi) 972.0 PD Surf / DS (psi) 53.2 Ann / Bit (psi) Jet Velocity (fi/sec) 255.0 Jet Impact (lbs) 110+205 IBit HP (hhp) 10-20 IHP Ratio / HP/]n2 510 75/2520 735 / 270 158 7% / 1.4 IN2 BIT #7 DP/CSG DP/HOLE DC/HOLE Length (fi) Volume (bbls/ft) Veloc~ (ff/min) Crit-Vel (ftJmin) Ann-Vol (bbls) 18880 0.047'8 253 z~50 758.0 581 0.0460 265 z155 214 0.0260 481 500 37.0 6.0 LINER OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (Ibs/ft) PIPE DATA Drill Stdng Casing DP HWDP DC COND SURF INT 5.000 5.000 6.750 30.00 13 3/8 9 5/8" 4.276 3.000 2.875 28.00 12.415 8.b'22 0.0178 0.0087 0.0080 O. 1497 0.0722 0.0076 0.0181 0.0364 0.0241 0.01 78 15945 486 214 110 5301 15850 19,5 50.0 100.0 170.0 68.0 47F~3.5 11.5 500 )H. CHANGE OUT BIT, BHA, MWD TOOLS. SERVICE TOP DRIVE. RUN IN HOLE FILLING PIPE EVERY 35 STANDS. ADT Representative JOHN PATTON sperry-sun DRILLING SERVICES ADT Mornin.(i Re~3ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 43 RED DOG # 1 Date: 3/09/99 0300 NORTH SLOPE, ALASKA Depth 16972 / 1 0265 Footage: -. 327 NABORS 28E Rig Activity: DRILLING 851034 Report For: LOCKWOOD/MILLER Background Connection Trip Flowline Temp Pore Pressure ECD Avg Max ~_. Gas Gas DEPTH (units) (units) NONE-SEE NOTE~. BOTTOM 100 degree F Casing 4995 psi 9.9 ppg 6810 psi 13.5 ppg Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG54.O7AZIM 344.2 MD 1~37.39' TVD 10169.78' 50% SILTSTONE - 50% SANDSTONE DRLG / SLIDE 16900 Drill Rate (ffJhr) 30 / 20 NA Corrected "D" Exp. 1.58 2930 Shale Density (gm/cc) NA 7950 EWR (res) 4.50 DATA 7206 Bottom Hole Open Hole psi 11.0 ppg psi ppg psi 13.5 ppg psi ppg ime 23:01 Type KCL POLY Type Weight In 12.4 IADC Code Funnel Vis. 56 Size PV/YP 26/31 Jets Gels 8/20 Depth Out pH 9.8 Rot. Hrs. FiltJCake APl 3.5 2/32 Footage HTHP 9.6 Avg fi/hr Pm 0.5 Grade Pf/Mf .2/.9 Cost/ft Chlorides (ppm) 240(30 RPM Calcium (ppm) 1 20 WOB Oil/Water/Solids 3.5/78/17.5 Daily/Cum. Cost 8 MX1 ON MOTOR 12.25 0.995 13.8 327.0 23.4 $515 1(30+135 7 1 DS70FNPV-PDC ON MOTOR Size (inches) 8.50 Capacity (gal/stk) 1.035 Pump Rate (stks/min) 16645.0 Flow Rate (gal/min) 14.9 Pressure (psi) 972.0 PD Surf/DS (psi) 53.2 Ann / Bit (psi) Jet Velocity (fi/sec) 255.0 Jet Impact (lbs) 110+205 IBit HP (hhp) 10-20 IHP Ratio / HP/in2 I 6X12 6X12 4.230 4.230 75/2780 6OO/320 I I 170 570 97 8% / 1.7 IN2 DP/CSG DP/HOLE DC/HOLE ANNULAR DATA Length (fi) Volume (bbls/ft) Velocity (ft/min) Crit-Vel (ffJmin) Ann-Vol (bbls) 15850 0.0478 261 370 758.0 908 214 0.0460 272 375 52.0 0.0260 495 465 6.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ff) Length (fi) Weight (Ibs/ft) DP 5.000 4.276 0.0178 0.0076 16272 19.5 Drill String HWDP 5.000 3.000 0.0087 0.0181 486 50.0 DC 6.750 2.875 0.0080 0.0364 214 100.0 Casing COND SURF INT 30.00 133/8 95/8" 28.00 12.415 8.622 O. 1497 0.0722 0.0241 0.0178 110 5301 15850 1 70.0 68.0 47~o3.5 LINER 11.5 JOHN PATTON CURRENT ESTIMATED PORE PRESSURE = 11.0 PPG sperry-sun DRILLING SERVICES ADT Mornin.(I Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 44 RED DOG # 1 Date: 3/10/99 0300 NORTH SLOPE, ALASKA Depth 17315 / 10517 Footage: , 343 NABORS 28E Rig Activity: DRILLING 851034 Report For: LOCKWOOD/MILLER Background Connection Trip Flowtine Temp Avg Max {~ Gas Gas DEPTH (units) (units) 80 585 17202 585 NOTE ~ BOTTOM 295 16645 110 degree F Casing Pore Pressure 4995 psi 9.9 ECD 7062 psi 14.0 LOGGING Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pips Lag Off Bottom DEG 43.61 AZlM 344.7 MD 117(~8.1' TVD 10352.64' 60% SILTSTONE - 20% CLAY - 20% SAND DRLG / SLIDE 17260 Drill Rate (fi/hr) 20 / 25 NA Corrected "D" Exp. 1.68 2965 Shale Density (gm/cc) NA 8400 EWR (res) 5.50 DATA Bottom Hole ppg 65O8 ps~ 11.9 ppg 7656 psi 14.0 Ppg Ppg Opsn Hole psi psi PPg Ppg Time 23:30 No. Type KCL POLY Type Weight In 12.5 IADC Code Funnel Vis. 63 Size PV/YP 30/43 Jets Gels 10.28 Depth Out )H 8.9 Rot. Hrs. :iltJCake APl 3.0 2/32 Footage HTHP 8 Avg fi/hr 0.3 Grade ~f/Mf .1/.8 Cost/fi: Chlorides (ppm) 31000 RPM Calcium (ppm) 1 20 WOB Oil/Water/Solids 3.5F/8/17.5 Daily/Cum. Cost 8 MX1 7 DS7OFNPV-PDC ON MOTOR ON MOTOR 12.25 8.50 0.995 1.035 16645.0 30.5 14.9 670.0 972.0 22.0 53.2 $385 255.0 100 + 130 110+205 40-65 10-20 Pumps 1 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I 6X12 6X12 4.Z-JO ~ I I 520 100 / 2620 815/315 167 95 8% / 1.7 IN2 DP/CSG DP/HOLE DC/HOLE Length (fi) 15850 1251 214 Volume (bbls/ft) 0.0478 Velocity (fi/min) 270 Crit-Vel (fi/min) 450 Ann-Vol (bbls) 758.0 85.0 6.0 LINER Ddll String DP HWDP OD (inches) 5.000 5.030 ID (inches) 4.276 3.000 Cap (bbls/ft) 0.0178 Disp (bbls/ft) 0.0076 0.0181 Length (ft) 16615 486 Weight (Ibs/ft) 19.5 50.0 12.5 500 DC 6.750 2.875 0.0060 0.0364 214 100.0 PIPE COND 50.03 28.00 1t0 170.0 SURF 133f8 12.415 0.1497 0.0241 5301 68.0 Casing INT 8.622 0.0722 0.01 78 15850 47~53.5 )resentative JOHN PATTON 11.8 - 12.0 sperry-sun DRILLING SERVICES ADT Mornin.(i Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 45 3/11/99 0300 17364 / 1 O565 .-. 49 TRIP OUT LOCKWOOD/MILLER Background Connection Trip Flowline Temp Pore Pressure ECD Avg Gas (units) 427 1720 110 Max Gas (units) 103 DEPTH 17334 17~ 17364 S.TRIP degree F Casing psi psi 9.9 14.6 Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 37.6 AZIM 3,45 MD 17257.6' 'I'VD 10481.8' 30% SILTSTONE - 30% CLAYSTONE - 40% SAND 17360 Ddll Rate (fi/hr) NA Corrected "D" Exp. 2990 Shale Density (gm/cc) 8500 EWR (res) FORMATION PRES; DATA 18 1.70 NA 4.50 Bottom Hole ppg 6868 psi 12.5' ppg 8021 psi 14.6 PPg PPg Open Hole psi ppg psi ppg Time 23:30 8 7 Type KCL POLY Type MX1 DS70FNPV-PDC Weight In 13.2 IADC Code ON MOTOR ON MOTOR Funnel Vis. 59 Size 12.25 8.50 PV/YP 24/43 Jets 0.995 1.035 Gels 12/30 Depth Out 17364.0 16645.0 pH 9 Rot. Hrs. 32.7 14.9 Filt/Cake APl 3.2 2.r32 Footage 719.0 972.0 HTHP Avg ft/hr 22.0 53.2 Pm 0.3 Grade P f/Mr .111.2 Cost/ft $375 255.0 Chlorides (ppm) 33000 RPM 100 + 130 110+205 Calcium (ppm) 90 WOB 40-65 10-20 Oil/Water/Solids 3.5/74.5/'20.5 Daily/Cum. Cost DP/CSG DP/HOLE Length (it) 15850 1300 214 ANNULAR Volume (bbls/ff) 0.0478 Pumps 1 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) JBit HP (hhp) HP Ratio / HP/in2 6X12 12P1 I I 6X12 4~ 52~ 81 8% / 1.4 IN2 Velocity (fi/min) Crit-Vel (fi/min) Ann-Vol (bbls) 241 430 758.0 0.0460 252 435 0.0260 457 505 100.0 6.0 LINER DC/HOLE Ddll Stdng DP HWDP OD (inches) 5.030 5.000 ID (inches) 4.276 3.000 Cap (bbls/ft) 0.01 78 0.0087 Disp (bbls/ff) 0.0076 0.0181 Length (ft) 16664 486 Weight (lbs/fi) 19.5 50.0 13.2 500 DC 6.750 2.875 0.0380 0.0364 214 100.0 PIPE AND Casing COND SURF INT 30.03 13 3/8 95/8" 28.03 12.415 8.622 O. 1497 0.0722 0.0241 0.01 78 110 5301 15850 170.0 68.0 47/53.5 MIGRATION. RAISE PORE PRESSURE EST. 12.2- 1 'esentative JOHN PATTON -*CURRENT PORE PRESSURE EST. = 12.5 - 12.7 IN TIGHT ZONE- sperry-sun DRILLING SERVICES ADT Morning Report Customer: Well: Area: Lease: Rig: Job No,: BP EXPLORATION Report No,' RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851 034 Report For: 46 3/12/99 0300 17364 / 10565 0 YRIP IN LOCKWOOD/MILLER Background Connection Tdp Flowline Temp Avg Max ~ Gas Gas DEPTH (units) (units) · 100 O 427 17293 172O S.TRIP 17364 90 degree F Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG37.6AZIM345 MD 17257.6' TVD 10481.8' 30% SILTSTONE - 30% CLAYSTONE - 40% SAND 17360 Drill Rate (ft/hr) NA Corrected "D" Exp. 2990 Shale Density (gm/cc) 8500 EWR (res) 18 Casing Pore Pressure 4995 psi 9.9 ppg ECD ' 7364 psi 14.6 ppg me 22:30 ~it No. Type KCL POLY Type Weight In 13.3 IADC Code Funnel Vis. 68 Size PV/YP 29/43 Jets Gels 10/22 Depth Out pH 9.4 Rot. Hrs. Flit/Cake APl 3.5 2/32 Footage HTHP 9 Avg fi/hr Pm 0.4 Grade Pf/Mf .2/1.0 Cost/fi: Chlorides (ppm) 32000 RPM Calcium (ppm) 80 WOB Oil/Water/Solids 3.5/74.5/22 Daily/Cum. Cost 8021 Bottom Hole Open Hole psi 12.5 ppg psi psi 14.6 ppg psi 8 MX1 ON MOTOR 8.5 0.995 17364.0 32.7 719.0 22.0 22WTAE1/16 $375 100+130 9 ~ps 1 S-73 ENPX- PDC ON MOTOR Size (inches) 6X12 8.50 Capac~/(gal/stk) 4.'~Jb" 1.037 Pump Rate (stks/min) ~-- -- Flow Rate (gal/min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 Ppg Ppg I I I DP/CSG DP/HOLE DC/HOLE Length (ft) Volume (bbts/ft) Velocity (fi/rain) Cdt-Vel (fi:/min) Ann-Vol (bbls) 15850 0.0478 758.0 1306 100.0 6.0 LINER OD (inches) ID (inches) Cap (bbls/ft) D~p (bbls/ft) Length (fi:) Weight (lbs/fi) DP 5.000 4.276 0.01 78 0.0076 16664 19.5 Drill Stdng HWDP 5.000 3,000 0.0067 0.0181 486 50.0 DC 6.750 2.875 0.0080 0.0364 206 100.0 Casing COND SURF INT 30.00 133/8 95/8" 28.00 12.415 8.6'22 0.1497 0.0722 0.0241 0.01 78 110 5301 15850 170.0 68.0 47/53.5 13.2 JOHN PATTON sperry-sun DRILLING SERVICES ADT Mornin.(I Rel3ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 47 3/13/99 0300 17734 / 10875 370 ., DRILLING LOCKWOOD / POLYA Background Connection Tdp Flowline Temp Pore Pressure ECD Avg Max ~ Gas Gas DEPTH (units) (units) 675 1771 17691 NONE 17293 105 degree F Casing 4995 psi 9.9 ppg 7365 psi 14.6 ppg ~ ,me 21:00 o. Type KCL POLY Type Wekjht In 13.5 IADC Code Funnel Vis. 63 Size PV/YP 30/27 Jets Gels 11/25 Depth Out pH 9.4 Rot. Hrs. Filt/Cake APl 3.0 2/32 Footage HTH P 9.4 Avg fi/hr Pm 0.3 Grade Pf/Mf .2/1.2 CostJft Chlorides (ppm) 35000 RPM Calcium (ppm) 60 WOB Oil/Water/Solids 3.0/73/24 Daily/Cum. Cost Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 34.2 AZIM 344 MD 17563.5' TVD 10732.2' 50% SILTSTONE - 10% CLAYSTONE - 40% SAND 17680 Drill Rate (ft/hr) NA Corrected "D" Exp. 3120 Shale Density (gm/cc) 8800 EVVR (res) 65 0.71 NA NA DATA Bottom Hole 7352 psi 13.0 8256 psi 14.6 PPg PPg Open Hole psi PPg PPg MX1 ON MOTOR ON MOTOR 8.5 8.50 0.9~5 1.0G7 17364.0 32.7 6.8 9 S-73 ENPX- PDC 719.0 370.0 22.0 54.4 22WTAE1/16 100+130 110+235 40-65 5-10 ~umps I Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (galknin) Pressure (psi) PD Surf / DS (ps~ Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 6X12 2 6X12 12 4.140 4.140 60 61 5O0 3900 100/2910 600 / 290 155 540 85 7% - 1.5/IN2 DP/CSG DP/HOLE DC/HOLE Length (ft) Volume (bbls/ft) Velocity (ft/rnin) Cdt-Vel (fi/min) Ann-Vol (bbls) 15850 0.0478 248 330 758.0 1676 0.0480 208 0.0260 471 122.0 6.0 LINER OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ff) Length (ft) Wek~ht (ibs/ft) DP 5.000 4.276 0.0178 0.0076 170~ 19.5 Ddll String HWDP 5.000 3.000 0.0067 0.0181 486 50.0 DC 6.750 2.875 0.0(380 0.0364 208 100.0 Casing COND SURF INT 30.00 133/8 95/8" 28.00 12.415 8.622 0.1497 0.0722 0.0241 0.0178 110 5301 15850 170.0 68.0 47/53.5 13.5 Representative JOHN PATTON 12.8 - 1 THROUGH TARGET INTERVAL. sperry-sun DRILLING SERVICES ADT Mornin.¢l Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 48 3114199 0300 18542 / 11567 808 .. DRILLING LOCKWOOD / POLYA Background Connection Trip Flowline Temp Avg Max Gas Gas DEPTH (units) (units) 175 1536 17874 268 - (+50) 18236 6265 17364 110 degree F Survey Data Lithology 100% SILTSTONE Sample Depth 18480 Trip Chlorides NA Lag Down Pipe 3265 Lag Off Bottom 9'250 DEG 27.4AZIM338 MD 18404.3" TVD 11451.8' Drill Rate (fi/hr) Corrected "D" Exp. Shale Density (gm/cc) EWR (res) 50 0.78 NA NA Pore Pressure ECD me Type Weight In Funnel Vis. PV/YP Gels pH FiE/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost DP/CSG DP/HOLE DC/HOLE Casing ~ psi 9.9 7616 psi 15.1 23:03 KCL POLY 13.7 64 37/37 13/25 9.4 3.0 2/32 9.4 0.3 .2/1.0 34(3O0 8O 3.5/72.5/24 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB Bottom Hole ppg 8120 p~ 13.5 ppg ppg 9062 psi 15.1 ppg Open Hole psi psi Ppg PPg MX1 9 Pumps S-73 ENPX - PDC ON MOTOR ON MOTOR 8.5 8.50 0.995 1.037 17364.0 32.7 719.0 23.3 1178.0 22.0 50.6 22WTAE1116 $375 215.0 103+130 110+235 40-65 5-10 ANNULAR DATA Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/rain) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 HYDRAU I 6X12 6X12 4.'T-~-- 4.140 12P160 I I 7% - 1.5/1N2 Length (fi) Volume (bbls/ft) Velocity (fi/min) Cdt-Vel (fi/min) Ann-Vol (bbls) 15850 0.0478 248 400 758.0 2484 0.0460 208 0.0260 471 400 510 164.0 6.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (lbs/fi) DP 5.030 4.276 0.01 78 0.0376 17848 19.5 Drill String HWDP 5.000 3.000 0.0067 0.0181 486 50.0 DC 6.750 2.875 0.0080 0.0364 208 100.0 DATA COND 30.00 28.03 110 170.0 SURF 133/8 12.41 5 0.1497 0.0241 5301 68.0 Casing INT 8.622 0.0722 0.01 78 15850 47F~3.5 LINER 14.0 GAS sperry-sun DRILLING SERVICES ADT Mornin~ Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 49 RED DOG # 1 Date: 3/15/99 0300 NORTH SLOPE, ALASKA Depth 1 8740 / 11 750 Footage: . 198 NABORS 28E Rig Activity: TRIP OUT 851034 Report For: LOCKWOOD / POLYA Avg Max ~ Gas Gas DEPTH (units) (units) Background 70 842 Connection NONE Trip 515 18740 Flowfine Temp 110 degree F Survey Data Uthology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 25.7AZIM 337 ~ MD 18631 .E TVD 11655.E 90% SILTSTONE - 10% SANDSTONE 18740 Drill Rate (ft/hr) 70 NA Corrected "D" Exp. 0.80 3305 Shale Density (gm/cc) NA 9400 EWR (res) NA Casing Pore Pressure 4995 psi 9.9 ECD · 7768 psi 15.3 ppg 8250 ppg 9348 Bottom Hole Open Hole psi 13.5 ppg psi psi 15.3 ppg psi PPg PPg Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 22:52 KCL POLY Type 14.0 IADC Code 73 Size 30/30 Jets 13/25 Depth Out 9.4 Rot. Hrs. 3.0 2/32 Footage 9.4 Avg fi/hr 0.3 Grade .2/1.0 Cost/ft 34000 RPM 80 WOB 3.5/72.5/24 MX1 9 'umps 1 S-73 ENPX- PDC ON MOTOR ON MOTOR 8.5 8.50 0.995 1.037 17364.0 32.7 18740.0 26.3 719.0 1376.0 22.0 52.3 22WTAE1/16 $375 215.0 100+130 110+235 40-65 13.0 Size (inches) Capac~7 (gaVstk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (ps~ PDSurf / DS (psi) Ann I Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 6X12 4.~--40- I I I 6X12 4.140 100/3095 700/305 155 55O 85 7% - 1.5/1N2 DPICSG DP/HOLE DC/HOLE Length (ft) Volume (bbls/ff) 15850 0.0478 2682 0.0460 208 0.0260 Velocity (ft/min) 245 461 Cdt-Vel (ff/min) 345 245 Ann-Vol (bbls) 758.0 173.0 6.0 LINER OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi) Weight (lbs/fi) DP 5.000 4.276 0.01 78 0.0076 18046 19.5 Ddll String HWDP 5.000 3.030 0.0067 0.0181 486 50.0 DC 6.750 2.875 0.0380 0.0364 208 100.0 COND ~.~ 26.~ 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT 95/8" 8.622 0.0722 0.01 78 15850 47/53.5 14.0 LOGS. sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig' Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851 034 Report For: 50 3/16/§9 0300 18740 / 11750 .~ 0 E-LOG LOCKWOOD / POLYA Background Connection Tdp Flowline Temp Avg Max {~ Gas Gas DEPTH 0 0 NONE 515 18740 85 degree F C~ Pore Pressure 4995 psi ECD , 7768 psi ime Type Weight In Funnel Vis. PV/YP Gels pH Flit/Cake APl HTHP Pm P f/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 21:30 KCL POLY 14.0 68 43/22 111'24 9.0 3.0 2/32 9.0 0.2 .1/1.2 35O(30 4.0/71/25 DP/CSG DP/HOLE DC/HOLE 9.9 ppg 15.3 ppg Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/R RPM WOB Survey Data Lithology Samp~ Dep~ Trip CDio,'k~s Lag Down Pipe Lag Off Bottom DEG 25.7 AZIM 337 ~_,MD 18631.5' TVD 11655.5' 90% SILTSTONE - 10% SANDSTONE 1~740 Dr~ Rate [ft/hr) NA Corrected "D" Exp. 3305 Shale Dens~y (gm/cc) 9400 EWR (res) DATA 70 0.8O NA NA 9348 psi 15.3 ppg psi 6 9 'umps 1 MX1 S-73 ENPX - PDC J ON MOTOR ON MOTOR Size (inches) 6X12 6X12 8.5 8.50 Capacity (gal/stk) 4.1--~-- 4.140 0.995 1.037 Pump Rate (stks/min) 17364.0 18740.0 Ftow Rate (gat/m~n) 32.7 26.3 Pressure (psi) ~l'rc ~ 719.0 1376.0 PD Surf / DS (psi) 22.0 52.3 Ann / Bit (psi) 22WTAE1/16 00ERAXINOTD Jet Veloc~ (ffJsec) ,I~375 215.0 Jet Impact (lbs) 100 + 130 110 + 235 [Bit HP (hhp) 40.65 13.0 IHP Ratio I HP~n2 Ppg Ppg ANNULAR I I Length (fi) Volume (bbls/ft) Velocity (ft/min) Crit-Vel (ft/min) 15850 0.0478 345 2682 0.0460 245 2O8 0.0260 46O Ann-Vol (bbls) 758.0 173.0 6.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (ft) Weight (lbs/fi) 14.0 OP 5OOO 4.276 0.01 78 0.0076 18046 19.5 Drill String ~NOP 5O0O 3.0[]0 0.0067 0.0181 486 50.0 6_75D 2.875 o.oa6o 0.0364 2O8 100.0 30.03 28.00 110 170.0 Casing 133/8 95/8" 12.415 8.622 0.1497 0.0722 0.0241 0.01 78 5301 15850 68.0 47,53.5 JOHN PATTON sperry-sun DRILLING SERVICES ADT Morninq Rel3ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 51 3/17/99 0300 1874O / 11750 0 ., WIPER TRIP LOCKWOOD / POLYA Avg Max {~ Gas Gas DEPTH (units) (units) Background 50 210 SHOE Connection NONE Tdp NA 18740 Flowline Temp 85 degree F Casing Pore Pressure 4995 psi 9.9 ppg LCD ' 7616 psi 15.1 ppg Time 21:30 Type KCL POLY Type Weight In 14.0 IADC Code Funnel Vis. 72 Size PV/YP 40/34 Jets Gels 12/24 Depth Out pH 9.2 Rot. Hrs. Fiit/Cake APl 3.0 2/32 Footage HTHP 9.2 Avg ftJhr Pm 0.2 Grade Pf/Mf .1/1.2 Cost/It Chlorides (ppm) 35000 RPM Calcium (ppm) 80 WOB Oil/Water/Solids 4.0/71/25 Daily/Cum. Cost DP/CSG DP/HOLE DC/HOLE Length (fi:) 1585O 106 Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEC=, 25.7 AZIM 337 ~_, MD 18631.5' TVD 11655.5' 90% SILTSTONE - 10% SANDSTONE 18740 Ddll Rate (fi/hr) NA Corrected "D" Exp. 3305 Shale Density (gm/cc) 9400 EWR (res) 70 0.80 NA NA FORMATION PRESSURE DATA Bottom Hole 82¢-----------------~) psi 13.5 9226 psi 15.1 PPg PPg Open Hole psi ppg psi ppg 10 MXC1 8.5 0.997 WIPER TRIP g Pumps 1 S-73 ENPX- PDC ON MOTOR Size (inches) 8.50 Capacity (gal/stk) 1.037 Pump Rate (stks/min) 18740.0 Flow Rate (gal/min) 26.3 Pressure (psi) 1376.0 PD Surf/DS (psi) 52.3 Ann I Bit (psi) 00ERAXINOTD Jet Velocity (fi:/sec) 215.0 Jet Impact (lbs) 110+235 IBit HP (hhp). 13.0 IHP Ratio / HP/in2 12P160 6X12 4.140 4.140 2 121 I I I 6X12 515 100 /2230 625/3,~ 166 100 10% - 1.8/in2 ANNULAR DATA Volume (bbls/ff) 0.O478 Velocity (ft/min) 256 Cdt-Vel (ft/min) ,40O 510 Ann-Vol (bbls) 758.0 6.0 LINER OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (fi:) Weight (lbs/fi) 14.0 DP 5.000 4.276 0.0178 0.0076 18148 19.5 Ddll Stdng HWDP 5.000 3.0:30 0.0087 0.0181 486 50.0 DC 6.750 2.875 0.0060 0.0364 106 100.0 PIPE DATA Casing COND SURF INT RECOMM 30.00 133/8 95/8" 28.00 12.415 8.622 O. 1 z197 0.0722 0.0241 0.0178 110 5301 15850 170.0 68.0 47Fo3.5 tit FOR WIPER RUN. CURRENTLY sperry-sun DRILLING SERVICES ADT Mornin.cl Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 52 3/18/99 0300 18740 / 11750 -' 0 TRIP OUT MASKELL / POLYA Avg Max (~ Gas Gas DEPTH (units) (units) Background 50 Connection NONE Trip 1581 18740 Flowline Temp 85 degree F Casing Pore Pressure 4995 psi 9.9 ppg ECD , 7616 psi 15.1 ppg Time 16:00 o. Type KC L POLY Type Weight In 14.0 IADC Code Funnel Vis. 74 Size PV/YP 42/33 Jets Gels 12/22 Depth Out pH 8.9 Rot. Hrs. Filt/Cake APl 2.0 ?_/32 Footage HTHP 8.9 Avg fi/hr Pm 0.2 Grade Pr/Mr .111.2 Cost/ft Chlorides (ppm) 36000 RPM Calcium (ppm) 80 WOB Oil/Water/Solids 4.0/71/25 Daily/Cum. Cost DP/CSG DP/HOLE DC/HOLE Length (fi) 1585O 106 Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 25.7AZIM 337 {~ MD 18631.5' TVD 11655.5' 90% SILTSTONE - 10% SANDSTONE 18740 Ddll Rate (fi/hr) NA Corrected "D" Exp. 3305 Shale Density (gm/cc) 9400 EWR (res) NA NA FORMATION PRESSURE Bottom Hole 8250 psi 13.5 9226 psi 15.1 Ppg Ppg Open Hole psi psi Ppg Ppg 10 MXC1 9 S-73ENPX-PDC ON MOTOR 8.5 8.50 0.997 1.037 18740.0 26.3 WIPER 1376.0 TRIP 52.3 OOERAXINOTD 215.0 110+235 13.0 'umps 1 I Size (inches) 6X12 6X12 Capacity (gal/stk) 4.140 4.140 Pump Rate (stks/min) ~ ~ Flow Rate (gal/min) ~ Pressure (psi) ~ PD Surf/DS (psi) 100 /2230 Ann / Bit (psi) 625 / 345 Jet Velocity (ffJsec) 16~ Jet Impact (lbs) 6'20 tBit HP (hhp) 100 HP Ratio / HP/in2 10% - 1.8An2 I I DATA Volume (bbls/ft) 0.0478 Velocity (ft/min) 248 Cdt-Vel (ft/min) 4OO Ann-Vol (bbls) 758.0 448 510 6.0 OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (fi) Weight (lbs/fi) DP 5.000 4.276 0.0178 0.0076 18148 19.5 DMII Stdng HWDP 5.000 3.000 0.0087 0.0181 486 50.0 DC 6.750 2.875 0.0060 0.0364 106 100.0 PIPE COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT 8.6'22 0.0722 0.01 78 15850 47,53.5 LINER 14.0 sperry-sun DRILLING SERVICES ADT Mornin.~ Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 53 3/19/99 0300 1874O / 1175O RIH - DP LOG TOOLS MASKELL / POLYA Avg Max ~ Gas Gas DEPTH (units) (units) Background 30 Connection NONE Trip NA 18740 iFIowline Temp 85 degree F Pore Pressure LCD Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom Casing ,~)95 psi 9.9 ppg 8250 7616 psi 15.1 ppg 9226 DEG 25.7AZIM 337 ~;~ MD 18631.5' TVD 11655.5' 90% SILTSTONE - 10% SANDSTONE 18740 Drill Rate (fi/hr) NA Corrected "O" Exp. 3305 Shale Density (gm/cc) 9400 EWR (res) NA NA DATA Bottom Hole Open Hole psi 13.5 ppg psi psi 15.1 ppg psi PPg Ppg Time 16:00 Type KCL POLY Type Weight In 14.0 IADC Code Funnel Vis. 73 Size PV/YP 41/32 Jets Gels 12/23 Depth Out pH 8.6 Rot. Hrs. FiE/Cake APl 2,9 2/32 Footage HTHP 8.6 Avg fi/hr Pm 0.1 Grade Pr/Mr ,1/.25 Cost/ft Chlorides (ppm) 34000 RPM Calcium (ppm) 80 WOB Oil/Water/Solids 4.0/71/25 Daily/Cum. Cost DP/CSG DP/HOLE 10 MXC1 ON MOTOR 8.5 8.50 0.997 1.0G7 18740.0 18740.0 26.3 9 'umps 1 S-73 ENPX- PDC WIPER 1376.0 TRIP 52.3 00ERAXlNOTD 215.0 110+235 13.0 DATA Length (ft) Volume (bbis/ff) 0.0478 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (galknin) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velcc[ty (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 Velocity (ft/min) 6X12 4.'~-~-'- I I I 6X12 4.140 2514(30 75/- Cdt-Vel (ft/min) 400 Ann-Vol (bbls) 758.0 DC/HOLE OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (ft) Weight (Ibs/ft) DP 5.000 4.276 0.01 78 0.0076 18148 19.5 Drill String HWDP DC 5.000 6.750 3.000 2.875 0.0067 0.0080 0.0181 0.0364 50.0 100.0 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1~97 0.0241 5301 68.0 Casing INT 8.622 0.0722 0.0178 15850 47F~3.5 LINER 14.0 sperry-sun DRILLING SERVICES ADT Mornin.q Report Background Connection Trip Flowline Temp Avg Max Gas Gas (units) (units) 30 115 NONE NA 78 DEPTH degree F 18740 Pore Pressure LCD 4995 , 7616 Casing psi psi 9.9 15.1 ime Type Weight In Funnel Vis. PV/YP Gels pH Flit/Cake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) OilNVater/Solids Daily/Cum. Cost 16:00 KCL POLY 14.0 7O 10/27 9.0 2.8 2r32 8.6 o.1 .1/.25 34ooo 8o 4.o/'71/25 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Costflt RPM WOB DP/CSG DP/HOLE DC/HOLE Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 54 3/20/99 0300 18740/11750 CIRCULATE M^SKELL / POLYA LOGGING DATA Survey Data DEG 25.7 AZIM 337 ~_, MD 18631.5. 'i'VD 11655.5' Lithology 90% SILTSTONE - 10% SANDSTONE Sample Depth 18740 Drill Rate (fi/hr) Trip Chlorides NA Corrected "D" Exp. Lag Down Pipe 3305 Shale Density (gm/cc) Lag Off Bottom 9400 EWR (res) NA NA PPg PPg FORMATION PRESSURE DATA Bottom Hole Open Hole 8250 psi 13.5 pPg psi 9226 psi 15.1 pPg psi PPg PPg 10 MXC1 9 umps I 1 S-73 ENPX- PDC ON MOTOR 8.5 8.50 0.997 1.037 18740.0 18740.0 26.3 WIPER 1376.0 TRIP 52.3 00ERAXINOTD 215.0 110+235 13.0 ANNULAR DATA Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) Iait HP (hhp) HP Ratio / HP/in2 I 6X12 6X12 I I 4.140 4.140 40 167 50/440 285/- Length (It) 15850 Volume (bbls/ft) 0.0478 Velocity (fi/min) Crit-Vel (fi/min) 4O0 Ann-Vol (bbls) 758.0 OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (fi) Weight (lbs/fi) 14.0 DP 5.000 4.276 0.0178 0.0076 18148 19.5 Drill Stdng HWDP DC 5.000 6.750 3.000 2.875 0.0087 0.0060 0.0181 0.0364 50.0 1 00.0 PIPE COND 3(::).00 28.00 110 170.0 AND SURF 133/8 12.415 0.1497 0.0241 5301 68.0 WEIGHT BACK TO SPECK. MAX GAS = Casing INT 95/8" 8.622 0.0722 0.0178 15850 47F~3.5 LINER sperry-sun DRILLING SERVICES ADT Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 55 3/21/§9 03OO 18740 / 11750 _ 0 RIH -LOG ON DP MASKELL / POLYA Background Connection Tdp Flowline Temp Avg Max Gas Gas (units) (units) DEPTH NONE NA 85 18740 degree F Casing Pore Pressure 4995 psi 9.9 ppg LCD , 7314 psi 14.5 ppg me Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm Pr/Mr Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 9:30 KCL POLY 14.0 75 35~J8 0.4 8.9 3.2 2/32 9.5 0.15 0.111.2 24000 4.0/71/25 Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/fi: RPM WOB Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG 25.7 AZIM 337 ~ MD 18631.5' 'I-VD 11655.9 90% SILTSTONE - 10% SANDSTONE 18740 Drill Rate (fi/hr) NA Corrected "D" Exp. 3850 Shale Density (gm/cc) 10600 EWR (res) NA NA DATA Bottom Hole 8250 psi 13.5 8860 psi 14.5 Open Hole ppg psi ppg ppg psi ppg 10 MXCl 9 S-73 ENPX- PDC ON MOTOR 8.5 8.50 0.997 1.037 18740.0 18740.0 26.3 WIPER 1376.0 TRIP 52.3 00ERAXINOTD 215.0 110+235 13.0 umps I Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I I I 5.5X12 5.5X12 3.'~-- 3.630 DP/CSG DP/HOLE DC/HOLE Length (fi:) 15850 Volume (bbls/ft) 0.0478 Velocity (fi/min) 79 Crit-Vel (fi/min) ,400 Ann-Vol (bbls) 758.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (ft) Weight (lbs/fi) DP 5.000 4.276 0.0178 0.0076 18148 19.5 Ddll Stdng HWDP DC 5.000 6.750 3.000 2.875 0.0067 0.0(380 0.0181 0.0364 50.0 100.0 PIPE COND Casing SURF INT 30.00 133/8 95/8" 28.00 12.415 8.622 0.1 ~197 0.0722 0.0241 0.01 78 110 5301 15850 170.0 68.0 47F33.5 LINER 14.0 500 RUN IN HOLE FOR PIPE Representative JOHN PATTON sperry-sun DRILLING SERVICES ADT Morninq Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 56 3/22/99 O3OO 18740 / 11750 -- 0 POOH MASKELL / POLYA Background Connection Trip Flowtine Temp Avg Max ~ Gas Gas DEPTH (units) (units) 15-20 34 NONE NA 18740 85 degree F Casing Pore Pressure 4995 psi 9.9 ppg ECD ' 7314 psi 14.5 ppg ime 9:30 Type KCL POLY Type Weight In 14.0 IADC Code Funnel Vis. 75 Size PV/YP 35/38 Jets Gels 0.4 Depth Out pH 8.9 Rot. Hrs. FiltJCake APl 3.2 2/32 Footage HTHP 9.5 Avg fi/hr Pm 0.15 Grade P f/Mr 0.1/1.2 Cost/ft Chlorides (ppm) 24000 RPM Calcium (ppm) 80 WOB Oil/Water/Solids 4,0/71/25 Daily/Cum. Cost DP/CSG DP/HOLE DC/HOLE Length (fi) 158..'.'.'.'.'.'.'.'50 Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 25.7AZIM 337 ~ MD 18631.5. TVD 11655.5' 18740 Drill Rate (fi/hO NA Corrected "D" Exp. 3875 Shale Density (gm/cc) 10600 EWR (res) NA NA FORMATION PRESSURE DATA Bottom Hole 825O psi 13.5 8860 psi 14.5 Ppg Ppg Open Hole psi psi Ppg Ppg 10 MXC1 9 S-73 ENPX- PDC ON MOTOR 8.5 8.50 0.997 1.037 18740.0 18740.0 26.3 WIPER 1376.0 TRIP 52.3 OOERAXINOTD 215.0 110+235 13.0 'umps 1 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 5.5X12 3.510 1 5.5X12 3.510 I I 50/525 325/- ANNULAR DATA Volume (bbls/ft) 0.0478 Velocity (ft/min) Crit-Vel (fi/min) 400 Ann-Vol (bbls) 758.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ft) Length (ft) Weight (lbs/fi) 14.0 DP 5.000 4.276 0.01 78 0.0076 18148 19.5 Drill Stdng HWDP DC 5.000 6.750 3.000 2.875 0.0067 0.0080 0.0181 0.0364 50.0 100.0 AND COND ~.~ 26.~ 110 1~.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT 95/8" 8.622 0.0722 0.0178 15850 47/53.5 LINER JOHN PATTON sperry-sun DRILLING SERVICES ADT Mornin~ Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 57 3/23/99 0300 18740 / 11750 ~ 0 TRIP IN MASKELL / POLYA Background Connection Trip Flowline Temp Avg Max {~ Gas Gas DEPTH (units) (units) 25 62 'NONE NA 18740 80 degree F Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEG25.7AZIM337 ~MD 18631.5' TVD 11655.5' 18740 Drill Rate (fi/hr) NA Corrected "D" Exp. 3875 Shale Density (gm/cc) 10600 EWR (res) NA NA Casing Pore Pressure 4995 psi ECD ' 7314 psi 9.9 14.5 ime Type Weight In Funnel Vis. PV/YP Gels pH FiltJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 5:00 KCL POLY 14.0 71 35/34 14/'28 8.6 3.42/32 9.7 0.15 0.1/1.0 28000 3.0/72/25 O. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB 8250 Bottom Hole psi 13.5 p~ 14.5 Open Hole ppg PPQ ppg psi ppQ S-73 ENPX 9 S-73ENPX-PDC ON MOTOR ON MOTOR 8.5 8.50 1.968 1.037 18740.0 26.3 1376.O 52.3 00ERAXINOTD 215.O 110+235 13.0 umps Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/rain) Pressure (psi) PD Surf / DS (psi) Ann / Bit (psi) Jet Veloc~ (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio / HP/in2 I 5.5X12 5.5X12 3.'STO- 3.510 I I 491 100/ 315/80 8O 280 25 3% - .4/IN2 AT 7800' DP/CSG DP/HOLE DC/HOLE Length (ft) 76O0 Volume (bbls/ft) 0.0478 Velocity (fi/min) 244 418 Cdt-Vet (ft/min) Ann-Vol (bbls) 758.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbts/fi) Length (ft) Weight (Ibs/ft) DP 5.000 4.276 0.0178 0.0076 18148 19.5 DMII String HWDP 5.000 3.0(30 0.0087 0.O181 486 50.0 DC 6.750 2.875 0.0080 0.0364 400.0 COND 30.00 28.00 110 170.0 SURF 133/8 12.415 0.1497 0.O241 5301 68.0 Casing INT 95/8" 8.622 0.0722 O.01 78 15850 47/53.5 LINER 14.5 sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 58 3/24/99 0300 18740 / 11750 0 CIRCULATING MASKELL / POLYA Background Connection Trip -'lowline Temp Avg Max Gas Gas DEPTH (units) (units) 40 NONE 1263 18740 90 degree F Survey Data L~,.~/ Sample Depth Trip Chlorides Lag Down Pipe Lag Off Bottom DEC 25.7AZIM 337 ~ MD 18631.5' TVD 11655.5' 18740 Ddll Rate (fi/hO NA Corrected "D" Exp. 3935 Shale Density (gm/cc) 10950 EWR (res) NA NA Pore Pressure ECD Casing 4995 psi 9.9 78aa p~ 15.6 me Type Weight In Funnel Vis. PV/YP Gels pH Filt/Cake APl HTHP Pm ;Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 23:00 KCL POLY 14.5 65 37/28 10/28 9.0 3.0 2/32 9.2 0.2 0.111.8 340O0 3.0/70r27 O. Type IADC Code Size Jets Depth Out Rd. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB Bottom Hole ppg 8250 psi 13.5 ppg 9531 p~ 15.6 Open Hole ppg psi ppg ppg psi ppg 11 S-73 ENPX 9 ~73ENPX-PDC ON MOTOR ON MOTOR 8.5 8.50 1.988 1.037 18740.0 26.3 1376.O 52.3 00ERAXINOTD 215.0 110+235 13.0 'umps I Size (inches) 5.5X12 5.5X12 Capacity (gal/stk) 3.'5'"['0- ~ Pump Rate (stks/min) ~ ---~ Flow Rate (gal/min) ~ Pressure (psi) ~ PD Surf/DS (psi) 100/3185 Ann / Bit (psi) 630 / 85 Jet Velocity (fi/sec) 80 Jet Impact (lbs) 298 lair HP (hhp) 25 HP Ratio / HP/in2 2% - .4/IN2 I I DP/CSG DP/HOLE DC/HOLE Length (fi) Volume (bbls/ft) Velocity (ft/min) Cdt-Vel (ff/min) Ann-Vol (bbls) 1585O 0.O478 446 330 758.0 2685 0.0460 257 335 174.0 205 0.0260 456 440 6.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbls/ff) Length (ft) Weight (lbs/fi) DP 5.000 4.276 0.0178 0.0076 18148 19.5 DfillS~ng HWDP 5.000 3.000 0.0087 0.0181 486 50.0 DC 6.750 2.875 0.0060 0.0364 205 100.0 Casing COND SURF INT 30.00 133/8 95/8" 28.00 12.415 8.622 0.1497 0.0722 0.0241 O.01 78 110 5301 15850 170.0 68.0 47/53.5 LINER 14.5 sperry-sun DRILLING SERVICES, ADT Mornin~ Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 59 3~25~99 0300 18940 / 11937 200 ,-~ TRIPPING MASKELL / POLYA Background Connection Trip Flowline Temp Avg Gas (units) NONE 100 Max Gas (units) DEPTH 18792 18740 Survey Data DEG 23. 45 AZ I M 336 ~_.MD 18783' 'l-VD 11793.5' Lithology 100% SILTSTONE Sample Depth 18940 Drill Rate (fi/hr) Tdp Chlorides NA Corrected "D" Exp. Lag Down Pipe 3955 Shale Density (gm/cc) Lag Off Bottom 11100 EWR (res) 21 1.21 , 3.00 NA Pore Pressure 4995 ECD ' 8020 Ca~ng 9.9 15.6 ime Weight In 'Funnel Vis. ,PV/YP Gels )H Ike APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) OilNVaterlSolids Daily/Cum. Cost 23:00 KCL POLY 14.7 66 37/33 13/30 8.9 3.0 2/32 9.2 1.5 .111.5 32000 80 3.0/71/26 O. Type IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/ff RPM WOB PPg Bottom Hole Open Hole 8690 psi 14.0 ppg psi ~e7o p~ 15.9 ppg p~ 11 8-i~ ENPX 9 Pumps 1 S-73 ENPX- PDC ON MOTOR ON MOTOR 8.5 8.50 1.988 1.037 18940.0 18740.0 5.3 26.3 200.0 1376.0 37.7 52.3 00ERAXINOTD 215.0 110+230 110+235 12-15 13.0 Size (inches) Capacity (gal/stk) Pump Rate (stks/min) Flow Rate (gal/rain) Preesum (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (ffJsec) Jet Impact (lbs) IBit HP (hhp) HP Ratio I HP/in2 PPg PPg ! 5.5X12 5.5X12 I I 10013580 740 180 78 29O 25 2% - .4/IN2 DP/CSG DP/HOLE DC/HOLE Length (fi) 1585O Volume (bbls/ff) 0.0478 Velocity (ft/min) 241 252 Cdt-Vel (ft/min) 370 370 471 Ann-Vol (bbls) 758.0 183.0 6.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bbts/ft) Length (ft) Weight (lbs/fi) DP 5.000 4.276 0.01 78 0.0076 18249 19.5 Ddll String HWDP 5.000 3.000 0.0087 0.0181 486 50.0 DC 2.875 0.0060 0.0364 205 100.0 COND ~.~ 26.~ 110 170.0 SURF 133/8 12.415 0.1497 0.0241 5301 68.0 Casing INT 95/8" 8.622 0.0722 0.0178 15850 47/53.5 LINER 14.7 sperry-sun DRILLING SERVICES ADT Mornin.(I Rel)ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: 60 RED DOG # 1 Date: 3/26/99 0300 NORTH SLOPE, ALASKA Depth 18997 / 11990 Footage: _. 57 NABORS 28E Rig Activity: DRILLING 851034 Report For: M^SKELL / POLYA Background Connection Trip Flowline Temp Avg Max {~ Gas Gas DEPTH (units) (units) 100 185 18950 NONE , 85 degree F Survey Data DEG 23.45 AZIM 336 {~ MD 18783' TVD 11793.5' Lithology 100% SILTST~)NE Sample Depth 18940 Drill Rate (fi/hr) 20 Trip Chlorides NA Corrected "D" Exp. 0.88 Lag Down Pipe 3995 Shale Density (gm/cc) 3.00 Lag Off Bottom 11100 EWR (res) ' NA Pore Pressure ECD Casing 4995 psi 9.9 ppg 8020 psi 15.9 ppg Ime Weight In ~Funnel Vis. iPV/YP Gels pH FiltJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids Daily/Cum. Cost 16:00 KCL POLY 14.7 12/29 8.9 3.0 2/32 9.2 1.5 .1/1.5 3.0/69.3/27.7 O. IADC Code Size Jets Depth Out Rot. Hrs. Footage Avg fi/hr Grade Cost/it RPM WOB Bottom Hole Open Hole 87'23 psi 14.0 ppg psi 9913 psi 15.g ppg psi 11 S-73 ENPX ON MOTOR 8.5 1.968 18940.0 5.3 200.0 37.7 NA 110+230 12-15 12 (RR ffi;t) umps 1 S-73 ENPX - PDC ON MOTOR Size (inches) 8.50 Capacity (gal/stk) 1.968 Pump Rate (stks/min) Flow Rate (gal/min) 1.8 Pressure (psi) 57.0 PD Surf / DS (psi) 32.0 Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) 90 + 200 Iait HP (hhp) 8-12 IHP Ratio / HP/in2 Ppg Ppg , 5.5X12 5.5XI 2 3.'5'i'0- ~ I I 100/3130 700 / 70 73 250 20 2% -.3/1~12 DP/CSG DP/HOLE DC/HOLE Length (It) Volume (bbls/it) Velocity (ftJmin) Crit-Vel (ft/min) Ann-Vol (bbls) 15850 0.0478 224 365 758.0 2942 0.0460 233 365 188.0 205 0.0260 414 457 6.0 OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (fi) We~ht (~bs/it) DP 5.000 4.276 0.0178 0.0076 18306 19.5 Drill Stdng HWDP 5.000 3.003 0.0367 0.O181 486 50.0 DC 6.750 2.875 0.0080 0.0364 205 100.0 COND ~.00 110 1~ SURF 133/8 12.415 0.1497 O. O241 5301 68.0 Casing INT 95/8" 8.6"22 0.0722 0.0178 15850 47/=53.5 LINER 14.7 sperry-sun DRILLING SERVICES ADT Mornin.q Report Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 61 3/27/99 0300 19400 / 12379 ~ 403 CIRCULATING MASKELL / MILLER Background 'Connection iTrip Temp Avg Max ~ Gas Gas DEPTH (units) (units) 80 1644 19372 NONE 106 degree F Survey Data Lithology Sample Depth Tdp Chlorides Lag Down Pipe Lag Off Bottom DEG 16.07 AZIM 332 {~ MD 19296' TVD 12278.4' 70% SHALE - 20% TUFF - 10% SAND 19400 Drill Rate (fi/hr) NA Corrected "D" Exp. 4020 Shale Density (gm/cc) 11400 EWR (res) 30 0.91 ZOO NA Pore Pressure ECD Casing 4995 psi 9.9 ppg 9334 8121 psi 16.1 ppg 10428 me Type Weight In Funnel Vis. PV/YP Gels FiltJCake APl HTHP Pm Pf/Mf Chlorides (ppm) Calcium (ppm) Oil/Water/Solids 'Daily/Cum. Cost 20:00 KCL POLY 14.8 7O 38/35 15/36 8.6 3.0 2/32 8 0.15 · 1/1.4 300O0 8O 3.0/67/29 0. IADC Code Size Jets Depth o~ Rot. Hrs. Footage Avg fi/hr Grade Cost/ft RPM WOB Bottom Hole Open Hole p~ 14.5 ppg psi psi 16.2 ppg psi 11 S-73 ENPX ON MOTOR 8.5 1.988 1 .g68 18940.0 19400.0 5.3 14.5 200.0 460.0 37.7 31.7 NA NA 110+230 90+200 12-15 ~ 12 (RR ~9) Pumps 1 ~ 2 S-73 ENPX - PDC ON MOTOR Size (inches) 5.b-X12 5.b-'X12 8.50 Capacity (gal/stk) 3.'5"~0" Pump Rate (stks/min) Flow Rate (gal/min) Pressure (psi) PD Surf/DS (psi) Ann / Bit (psi) Jet Velocity (fi/sec) Jet Impact (lbs) IBit HP (hhp) HP Ratio I HP/in2 8-12 Ppg Ppg 44OO 100/3420 8OO/8O 77 287 22 2% - .4/IN2 DPICSG DP/HOLE DC/HOLE Length (ft) Volume (bbls/ft) Velocity (fi/rain) Cdt-Vel (ft/min) Ann-Vol (bbls) 15850 0.0478 238 378 758.0 0.0460 249 378 0.0250 441 481 219.0 6.0 LINER OD (inches) ID (inches) Cap (bbls/ff) Disp (bbls/ft) Length (fi) Weight (lbs/fi) 14.9 DP 5.000 4.276 0.01 78 0.0076 18709 19.5 Ddll Stdng HWDP 5.000 3.000 0.0067 0.0181 488 50.0 DC 6.750 2.875 0.0080 0.0364 COND ~.~ 28.~ 110 170.0 Casing SURF INT 133/8 95/8" 12.415 8.622 O. 1497 0.0722 0.0241 0.01 78 5301 15850 68.0 47,53.5 (1000 U. AVG) LOGGED IN SHALE. RAISE PORE sperry-sun DRILLING SERVICES ADT Mornin~ Rel)ort Customer: Well: Area: Lease: Rig: Job No.: BP EXPLORATION Report No.: RED DOG # 1 Date: NORTH SLOPE, ALASKA Depth Footage: NABORS 28E Rig Activity: 851034 Report For: 62 3/28/99 0300 19400 / 12379 0 RIH TO CEMENT MASKELL / MILLER Background Connection Tdp Flowline Temp Avg Max ~ Gas Gas DEPTH (units) (units) 70 LAST CIRC. 85 degree F Pore Pressure ECD Survey Data Lithology Sample Depth Trip Chlorides Lag Down Pipe Lag OFF Bottom Casing 4995 psi 9.9 ppg 9334 8121 psi 16.1 ppg 10428 ime 20:.00 Type KCL POLY Type Weight In 14.8 IADC Code Funnel Vis. 70 Size PV/YP 38/35 Jets Gels 15/36 Depth Out pH 8.6 Rot. Hrs. Flit/Cake APl 3.0 2/32 Footage HTHP 8 Avg fi/hr P m O. 15 Grade Pf/Mf .1/1.4 Cost Jif Chlorides (ppm) 30000 RPM Calcium (ppm) 80 WOB Oil/Water/Solids 3.0/67/29 Daily/Cum. Cost DEG 16.07AZIM 332 {~ MD 19296' TVD 12278.4' 70% SHALE - 20% TUFF - 10% SAND 19400 Drill Rate (fi/hr) NA Corrected "D" Exp. 4020 Shale Density (gm/cc) 11400 EWR (res) Bottom Hole Open Hole psi 14.5 ppg psi psi 16.2 ppg I:~ Ppg 12 (RR ~9) umps 1 12P I-'T~ 2 S-73 ENPX- PDC ! ON MOTOR Size (inches) 5.5X12 5.5X12 8.50 Capacity (gal/stk) 3.'b=~'0'- ~ 1.988 Pump Rate (stks/min) 68 T 19400.0 Flow Rate (gal/min) ~ 14.5 Pressure (PSO 460.0 PD Surf / DS (psi) 31.7 Ann / Bit (psi) NA Jet Velocity (fi/sec) 31W-rAXICTTD Jet Impact (lbs) ~o + 20o Iait HP (hhp) 8-12 IHP Ratio / HP/in2 I I 44130 100 / 3420 800/80 ~7 22 2%-.4~N2 DP/CSG DP/HOLE DC/HOLE Length (fi) 15850 Volume (bbls/ft) Velocity (ft/min) Cdt-Vel (ft/min) Ann-Vol (bbls) 0.04'78 2'38 378 758.0 0.0460 249 378 219.0 0.0260 441 481 6.0 OD (inches) ID (inches) Cap (bbls/ft) Disp (bble/ft) Length (fi) Weight (lbs/fi) 14.9 DP 5.000 4.278 0.01 78 0.0076 19.5 Ddll Stdng HWDP DC 5.000 6.750 3.000 2.875 0.0067 0.0080 0.0181 0.0364 50.0 100.O COND ~.~ 110 170.0 SURF 133~8 12.415 0.1497 0.0241 5301 68.0 Casing INT 8.622 0.0722 0.0178 15850 47/53.5 LINER Lotus cc:Mail for Steve car~r~ll Date: 4/17/99 Sender: "William E. Merry" <wem@alaska.net> To: Select List <wem@alaska.net> bcc: Steve Carroll Priority: Normal Subject: Receiving Attachments like Photos Author: "William E. Merry" <wem@alaska.net> at Internet-Mail Date: 4/17/99 9:23:25 PM Priority: Normal bcc: Steve Carroll at SSDSAK To: Select List <wem@alaska.net> at Internet-Mail Subiect: Receiving Attachments like Photos Folks -- for all who have America Online (AOL) for their e-mail service, or know somebody who does and is having trouble with being able to view attachments; I've finally learned why. A decoder needs to be downloaded from AOL and installed. It's for "MIME", (.mim file extensions). If you have a PC/IBM type computer, click on "keyword"' type in "MIME'" scroll down to the blue letter line called 'MIME Decoder VI. 3.7 Decoder PPC." If you have a MAC, there's a decoder for you too. Download it, install it, with your mouse - right click on the downloaded attachment, then left click on "decoder". You should then be able to go to the attachment in the download directory and double click on it and see it. I you have problems, call AOL's 800 number and ask for technical support ...... it's free. -- Bill Anadrill Alaska District 3940 Arctic Boulevard Anchorage, Alaska 99503-5785 Tel.: (907) 273-1700 Date: Well Name: Company: API Number: Location: Field: Rig: 30 March 1999 Red Dog # 1 BP Exploration (Alaska) Inc. 50-089-20027-00 North Slope, Alaska Wildcat Nabors 28E Anadrill Personnel Field Crew: Cell Managers: Cell Engineers: jeroen w p bosse Nathan Rose Mark St. Amour Ray Whit-mm Field Support: Alaska District Manager: D'Arcy Quinn Field Service Manager: Joey LeBlanc SERVICES PROVIDED Service Directional Survey Service (DSS) 26 Jan DWOB/DTOR (IWOB) 26 Jan Compensated Dual Resistivity (CDR) 26 Jan Annular Pressure While Drilling (PWD) 26 Jan ADN6 (used on non-consecutive runs) 17 Feb ISONIC 17 Feb Resistivity At the Bit (RAB) 03 Mar - GeoSteering (GST) 03 Mar - Service Dates 27 Mar 99 27 Mar 99 27 Mar 99 27 Mar 99 27 Mar 99 27 Mar 99 07 Mar 99 11 Mar 99 Depth Interval 120- 19400 120- 19400 120- 19400 120- 19400 9009- 19400 9009- 19400 15853- 16645 15853- 17364 OPERATING STATISTICS Total MWD Pumping Hours: 489.6 Total MWD Below Rotary Hours: 885 Total MWD Footage Drilled: ,19280 ft Total MWD Runs: 11 Total LWD Pumping Hours: Total LWD Below Rotary Hours: 489.6 885 RECEIVED APR 1 6 1999 Al Oit & 6as Co s. Commission LWD Tool CDR ISONIC ADN6 RAB GST Footage Drilled 19280 ft 10391 ft 8296 ft 792 ft 1511 ft Total Runs 11 6 4 1 2 JOB PERFORMANCE DIRECTIONAL Surveys were provided over the entire well. The final survey point was at 19296.00 ft with an inclination of 16.07 degrees and an azimuth of 332.02 degrees. The drop tendency of the final bottom hole assembly was used to extrapolate a survey inclination to total depth. This places the final bottom hole location at: Measured Depth: 194000.0 ft Latitude: North 12862.38 ft Displacement at Azimuth: 13131.40 ft at 348.38° True Vertical Depth: Departure: 12378.58 ft West 2644.44 ft FORMATION EVALUATION Surface Hole Real-time gamma ray and resistivity were used for lithology identification and correlation to pick the 13 3/8 inch casing point. Intermediate Hole Real-time gamma ray and resistivity were used for lithology identification and correlation to pick the 9 5/8 inch casing point. Additionally, ISONIC delta-T was transmitted real-time for pore pressure detection and seismic correlation. ADN6 was run in the bottom of this hole section in recorded memory mode to obtain bottom quadrant density measurements. Production Hole GST inclination, resistivity and gamma ray measurements at the bit were used for directional control and formation identification while drilling toward the potential coring point. Real-time gamma ray and resistivity were used for lithology identification and correlation. Additionally, ISONIC delta-T was transmitted real-time for pore pressure detection and seismic correlation. DRILLING MECHANICS The real-time MWD downhole weight-on-bit and downhole torque measurements were monitored by the Anadrill engineers on location to help optimize drilling parameters. The measurements were also made available real-time to the driller on the rig floor. Depth based drilling mechanics logs were provided as needed to the rig team. The logs were sent electronically to the town based drilling engineers each morning. Annular Pressure While Drilling was monitored real-time during circulation to monitor hole cleaning. Also, based on the formation leak off tests, high limits for equivalent circulating density were established which were not to be exceeded while drilling. A theoretical ECD was calculated at each connection to use as a base line value for comparison to the MWD measurement. This data was compiled and reported by the various service companies at the rig. Anadrill provided real-time time based drilling mechanics logs as needed to the rig team to help evaluate drilling practices. These logs were sent electronically to the town based drilling engineers each morning. The APWD was also recorded in downhole memory. Logs were generated after each run to help evaluate drilling practices while breaking circulation, making connections, tripping, backreaming, etc. SHOCK Shock was monitored real-time for MWD tools. No shocks were seen while drilling this well. In addition, LWD tools recorded shocks in memory. No shocks were recorded by the LWD tools during this well. WASHOUT DETECTION Washouts can be detected from MWD turbine rpm, stand pipe pressure, and total pump flow. No washouts were detected while drilling this well. LESSONS LEARNED Surface Hole The large size of the hole minimized the efforts of monitoring APWD for hole cleaning and Equivalent Circulating Density. The calculated theoretical ECD very closely matched the measured ECD for each connection. No hole problems were encountered while drilling. Intermediate Hole During the first bit run with a milltooth bit, the drilling practices did not have any significant impact on ECD. The calculated theoretical ECD very closely matched the measured ECD for each connection. Significant ECD (up to 13 ppg) spikes were observed when the hole packed off during the trip out of the hole. When backreaming out of the hole the flow rates were reduced to keep ECD spikes below the high limit established during the formation leakofftest. This was successful in eliminating pressure spikes. While drilling with the PDC bit the calculated theoretical ECD and measured ECD value started diverging as depth increased. This is most likely due to the friction factors used by the modeling program (note: the model was provided by BP Exploration (Alaska) Inc.) Drilling practices were analyzed using the recorded memory APWD data in an attempt to minimize ECD spikes in the production hole. At total depth for the hole section the MWD tool was downlinked multiple times. This is a process of varying the pump rates in a prescribed sequence to reprogram the MWD tool downhole. The downlink commands were used to change the real-time MWD data transmission rate from three (3) bits per second to six (6) and twelve (12) bits per second. Consideration should be given to using this technique in the future to reprogram the memory recording rate for LWD tools. Production Hole Monitoring ECD helped to drill the 8 ½ inch hole section especially coming out of the 9 5/8 inch casing shoe where the hole angle was relatively high. Hole cleaning was very good and no problems were encountered. The real-time and recorded memory ISONIC data was very useful for pore pressure prediction. GST Inclination at the bit closely matched MWD survey inclinations at the same depths. Inclination at the bit gave the directional drillers early response to BHA tendencies. When working with GST it is important to emphasize that the tool response for gamma.ray is correct. However, GST gamma ray may not match up to CDR gamma ray as far a absolute counts are considered. The resistivities were 'exactly' the same. At total depth the MWD signal had significantly deteriorated due primarily to the mud properties. In the future when these depths and mud weights are expected the MWD should be configured to transmit data at a slower rate to give a stronger signal. Alternately, this can also be done by downlinking to the tool downhole. This process would allow the greatest real-time data density while still maintaining a strong MWD signal to compensate for the drilling conditions as needed. Anadrill appreciates the opportunity to provide BP Exploration (Alaska) Inc. / Shared Services Drilling with MWD and LWD services. Sincerely, Joey Leblanc Field Service Manager jeroen w p bosse Field Cell Manager Attention: Subject: BP EXPLORATION, Alaska Date' 04/14/1999 Trans: 90448 Howard Okland (Alaska Oil & Gas Conservation Commission) RED DOG - FINAL DIRECTIONAL SURVEY DISTRIBUTION Enclosed are the materials listed below. If you have any questions please contact David Douglas in the BP Exploration (Alaska), Inc. Petrotechnical Data Center at (907) 564-5929. -' .,'z' Record Type Record Date Company Description Media/Quantity MWD SURVEY 03-26-1999 ANADRILL MWD DIRECTIONAL SURVEY 1 PAPER REPORT 1 ASCII DISKETTE GYRO SURVEY 02-14-1999 GYRODATA GYRO MULTISHOT SURVEY 1 PAPER REPORT INSIDE 5,5" DRILLPIPE 1 ASCII DISKETTE Please sign and return one copy of this transmittal letter. Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 Attention: Subject: BP EXPLORATION, Alaska -~-~5 ~ Date: 04/14/1999 ~\~ Trans: 90445 Howard Okland (Alaska Oil & Gas Conservation Commission) RED DOG - FINAL LOG DISTRIBUTION Enclosed are the materials listed below. If you have any questions please contact David Douglas in the BP Exploration (Alaska), Inc. Petrotechnical Data Center at (907) 564-5929. Record Type Record Date Company Description Media/Quantity OH COMPUTED 03-15-1999 SCH CMR TOTAL POROSITY (1.3 1 COLOR COPY LOG SEC WAIT 33MS CUT-OFF) (COMPOSITE PRESENTATION) OH COMPUTED 03-15-1999 SCH CMR TOTAL POROSITY (1.3 1 COLOR COPY LOG SEC WAIT 33MS CUT-OFF) OH COMPUTED 03-15-1999 SCH FMI DIPSETS & ROSE 1 COLOR COPY (1:240) LOG PLOTS (STATIC 1 COLOR COPY (1:600) NORMALIZED) OH COMPUTED 03-15-1999 SCH FMI IMAGES & DIPSETS 1 COLOR COPY (1:10) LOG (STATIC & DYNAMIC NORMALIZED) OH MWD LOG 03-27-1999 ANA COMPOSITED CDR (MD) 1 BLUEPRINT OF EACH COMPOSITED CDR (TVD) 1 SEPIA OF EACH OH MWD LOG 03-27-1999 ANA COMPOSITED ADN6 (MD) 1 BLUEPRINT OF EACH COMPOSITED ADN6 ('I-VD) 1 SEPIA OF EACH OH MWD LOG 03-27-1999 ANA COMPOSITED ISONIC (MD) 1 BLUEPRINT OF EACH COMPOSITED ISONIC (-r'VD) 1 SEPIA OF EACH OH LOG 03-19-1999 SCH ARRAY INDUCTION/GR 1 BLUEPRINT & 1 SEPIA OH LOG 03-16-1999 SCH AlT WITH DIPOLE SHEAR 1 BLUEPRINT & 1 SEPIA SONIC (MD) OH LOG 03-16-1999 SCH AlT WITH DIPOLE SHEAR 1 BLUEPRINT & 1 SEPIA SONIC (TVD) OH LOG 03-15-1999 SCH SONIC SHEAR IMAGER/NGT 1 BLUEPRINT & 1 SEPIA OH LOG 03-16-1999 SCH NATURAL GAMMA RAY 1 BLUEPRINT & 1 SEPIA OH LOG 03-19-1999 SCH CMR 1 BLUEPRINT & 1 SEPIA OH LOG 03-22-1999 SCH RFT 1 BLUEPRINT & 1 SEPIA TAPE 04-15-1999 SCH & ANA EDITED & COMPUTED DATA 1 8MM TAPE ITOTALS: Color Prints Blueprints Rolled Sepias 8 mm Edit Tape (TAR) 5 13 13 1 w/Listing Please sign and return one copy of this transmittal letter¢ . / Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA-'dlL AND GAS CONSERVATION CO~fi~llSSlON APPLICATION FOR SUNDRY APPROVAL CONFIDENTIAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: I--I Development [] ExploratOry [--I Stratigraphic []Service 4. Location of well at surface 1682' NSL, 4508' WEL, SEC. 34, T10N, R21 E, UM At top of productive interval 3174' NSL, 985' WEL, SEC. 21, T1 ON, R21 E, UM At effective depth N/A At total depth 4011' NSL, 1887 WEL, SEC. 21, T10N, R21E, UM (As Planned) 6. Datum Elevation (DF or KB) KBE = 43.10' 7. Unit or Property Name Exploration 8. Well Number Red Dog #1 9. Permit Number 98-252 10. APl Number 50-029-20027 11. Field and Pool Prudhoe Bay Field / Undefined Pt. Thomson Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 19400 feet 12379 feet feet feet Length Size 80' 20" 5262' 13-3/8" 15811' 9-5/8" Plugs (measured) Junk (measured) Cemented 260 sx Arcticset (Approx.) 547 sx PF 'E', 538 sx 'G', 1800 sx PF 'E', 200 sx PF 'C' 830 sx Class 'G' MD TVD 80' 80' 5302' 4448' 15851' 9706' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A ORIGINAL 13. Attachments [~ Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation March 28, 1999 3/26/99 Date approved 16. If proposal was verbally approved Blair Wondzell Name of approver Contact Engineer Name/Number: Gabriel Higuera, 564-5284 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge SignedFlOyd Hernande~'*~~,~2.1~/~ Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date I Approval N~-' ~),~- ~' Plug integrity Mechanical Integrity Test Subsequent f,~li~(~9~luired 10- ,/'~O ORIGINAL SIGNED' BY !>-Qg~e.~'/. ~ Commissioner Approved by order of the Commission Robe~ Form 10-403 Rev. 06/15/88 Date Submit In Triplicate ,~6~are'd rilling Well Name RED DOG #1 AFE Number AFE # 851034 Suspension Program AFE Amount $ 20.139 MM - Drill&Complete Estimated Time: March 10, 1999 Prepared By: ' .~/~ Gabriel Higuera~,~ Approved By: Floyd Hernand~z Date Chuck Mallary' k.Z)ate The PRIORITIES for this job are in the following order of importance: 1. NO ACCIDENTS- Employ Sure Training, Pre-Job Safety Meeting, & Stop 2. NO ENVIRONMENTAL IMPACTS- Alaska Cleans Seas Spill Tech On-Site and Utilize Fluid Transfer Permits. 3. ENSURE GOOD COMMUNICATION AND TEAM WORK 4. PREVENT STUCK PIPE 5. SUCCESSFULLY SUSPEND THE WELL No portion of this work is so urgent that the time cannot be taken to do it without injuring yourself or others. The following program will be carried out at the completion of drilling operations on Red Dog #1. Please contact AOGCC slope rep. prior to each stage of the suspension program as they are likely want to witness at least some of the operation as well as verifying the condition of the site prior to final suspension. Abandoning The Reservoir Interval. Cement Plug #1 According to the AOGCC regs, the uncased portions can be abandoned by the displacement method. A continuous cement plug must be spaced to extend upward from 50' below the base to 100' above the top of all hydrocarbon- bearing strata. The plug will consist of 15.8 ppg, Premium cement. 1. After drilling to TD, ensure that the hole is cleaned based on PWD and drilling parameter trend lines. POOH. , RIH with open ended drillpipe to TD. Condition the mud and hole until optimal conditions are achieved. FIowrates during conditioning should mimic flowrates anticipated while pumping cement 3. Rig up to pump 1st stage of Cement Plug #1. Note: Cement Plug #1 will consist of 4 cement pumping stages. Each stage will be 1000' long, except for the last stage which will be 850' long. Note: Actual volumes in the openhole should be based on the openhole caliper log. 4. Pressure test surface lines. , Spot 1st stage balanced cement plug (15.8 ppg Premium) from TD (19,400' MD) to 18,400' MD. Displace at the maximum rate (limited by ECD constraints) to improve gelled mud removal: Note: Reference Recommended Practices for "Setting a Kick-off or Abandonment Plug in Openhole". 6. POOH to estimated TOC @ 18,400' MD. 7. Circulate hole clean the long way. 8. Prepare for 2® stage of Cement Plug #1. , Spot 2nd stage balanced cement plug (15.8 ppg Premium) from 18,400' MD to 17,400' MD. Displace at the maximum rate (limited by ECD constraints) to improve gelled mud removal: Note: Reference Recommended Practices for "Setting a Kick-off or Abandonment Plug in ©penhole". 10. POOH to estimated TOC @ 17,400' MD. 11. Circulate hole clean the long way. 12. Prepare for 3rd stage of Cement Plug #1. 13. Spot 3rd stage balanced cement plug (15.8 ppg Premium) from 17,400' MD to 16,400' MD. Displace at the maximum rate (limited by ECD constraints) to improve gelled mud removal: Note: Reference Recommended Practices for "Setting a Kick-off or Abandonment Plug in Openhole" 14. POOH to estimated TOC @ 16,400' MD. 15. Circulate hole clean the long way. 16. Prepare for 4th (last) stage of Cement Plug #1. 17. Spot 4th stage balanced cement plug (15.8 ppg Premium) from 16,400' MD to 15,550' MD. Displace at the maximum rate (limited by ECD constraints) to improve gelled mud removal: Note: Reference Recommended Practices for "Setting a Kick-off or Abandonment Plug in Openhole". 18. POOH to 15,250' MD. 19. Circulate hole clean the long way. 2O. POOH Setting 9-5/8" EZSV & Cement Plug #2 AOGCC regs do not require an EZSV above Cement Plug #1, but the EZSV is being placed for pressure integrity insurance for future P&A operations or re- entry. The AOGCC does require a location tag on all required cement plugs. 21. Pickup 8-1/2" bit and scraper. 22. RIH to TOC @ 15,550' MD and tag to comply with AOGCC regs. 23. Circulate hole clean and POOH. 24. Pickup 9-5/8" EZSV. RIH and set on top of Cement Plug #1. 25. Sting out of EZSV and spot a 100' balanced 15.8 ppg Premium cement plug (Cement Plug #2) 26. POOH slowly to 300' above estimated TOC (15,150' MD) 27. Reverse circulate the hole clean with 15.0 ppg mud system. Abandonment Mud The AOGCC regs require that intervals below and betwen plugs must be filled with a fluid of a density that equals or exceeds the fluid density used to drill that interval. A 11.0 ppg mud or heavier should be left throughout the wellbore. 28. POOH to 2200' MD while laying down 5" drillpipe. 29. Pressure test 9-5/8" casing to 2500 psi for 10 minutes. 30. Spot a diesel plug from 2200' MD to 300' MD. Note: The diesel plug will be placed across the permafrost to avoid any freezing of the fluid which has the potential for bursting the 9-5/8" casing. 31. POOH. Suspension Plug. Cement Plug #3. The AOGCC regs requires a bridge plug to be set between 200' and 300' below the casing head and capped with 100 linear feet of cement. A 9-5/8" EZSV will be set @ 300' MD and cement plug #3 will be balanced from 200' MD to 300' MD inside the 9-5/8" casing. 32. RIH with 9-5/8" EZSV and set at 300' MD. 33. Sting out of EZSV and spot a 100' balanced 15.6 ppg Permafrost C cement plug (Cement Plug #3) from 300' MD to 200' MD. 34. POOH slowly to surface. Abandoning the 9-5/8" x 13-3/8" Annulus. Cement Plug #4 The AOGCC regs require that all annular space in communication with openhole and extending to the surface must be plugged with sufficient cement to effectively seal the annular space in a manner satisfactory to the commission. The 9-5/8" x 13-3/8" casing annulus will be abandoned by downsqueezing 2900' of 15.8 ppg Premium cement followed by 2400' of 12.0 ppg Permafrost E cement. 35. While waiting on cement (plug #3), rig up to 9-5/8" x 13-3/8"annulus and down squeeze 2900' of 15.8 ppg Premium cement followed by 2400' of 12.0 ppg Permafrost E cement. 36. After allowing sufficient time for cement plug #4 to set, pressure test plug #4 to 500 psi above the injection pressure seen while displacing the cement plug for 10 minutes. 37. Pickup 5" drillpipe and tag cement plug #3. 38. Spot diesel plug from top of cement plug #3 to surface. 39. POOH and lay down drillpipe. 40. Pickup 1 joint of 4-1/2" 12.6# L-80 NSCT tubing and FMC tubing hanger. 41. RIH and land hanger. 42. Nipple down BOPE. 43. Nipple up adapter flange and tree. Note: Tree should consist of 2 master valves, 1 swab valve with tree cap & gauge, 2 wing valves with blind flanges. 44. Install cellar cover and well sign. NOTE: The following information must be on the well sign: BP Exploration Red Dog #1 1682' NSL, 4508' WEL Section 34, T1 ON, R21E Umiat Meridian RED EXPLORATION PROPOSED SUSPENSION SCHEMATIC Diesel surface to 200' MD/TVD) Cement Plug #3 (200' MD to 300' MDFFVD) Diesel (300' to 2200' MD/TVD) Cement Plug #4 (9-5/8" by 13-3/8" annulus) Permafrost E (surface to 2400' MD) Premium (2400' to 5302' MD) (2400' to 4447' TVD) H-40, BTC @ 80' MD (80' TVD) 13-3/8" ES Cementer @ 2133' MD (2133'TVD) 9-5/8" EZSV @ 300' MD (300' TVD) 13-3/8" 68# L-80, BTC @ 5302' MD (4447' TVD) Crossover, 9-5/8" 53.5# P-110, SLHC @ 6686' MD (5156' TVD) -- 15.0 ppg KCL Polymer Drilling Mu( (2200' MD to 15,450' MD) (2200' TVD to 9506' TVD) Estimated Top of Cement behind the 9-5/8" Casing @ 13,950' MD (8780' TVD) Cement Plug 15,450' MD- 15,550' MD) (9506' TVD- 9554' TVD) EZSV @ 15,550' MD (9554' TVD) Cement Plug #1 (15,550' MD to 19,400' MD) (9554' TVD to 12,371' TVD) 9-5/8" 47# P-110, SLHC @ 15,850' MD (9699' TVD) Possible Oil & Gas Bearing Zones from 16,840' MD to 19,250' MD ~ 15.8 ppg Premium Cement 5.6 ppg Permafrost "C" Cement ~12.0 ppg Permafrost "E" Cement 8-1/2" Openhole TD @ 19,400' MD (12,371' TVD) 15.0 ppg KCL Polymer Drilling Mud Diesel ~ Cement In Place Prior to Abandonment RED #1 EXPLORATION PROPOSED SUSPENSION SCHEMATIC Cement Plug #5 ~MD to 300' MD) Cement Plug #4 (9-5/8" by 13-3/8" annulus) Cement Plug #3 (9-5/8" by 13-3/8" annulus) 20" 91.5# H~40, BTC @ 80' MD 13-3/8" ES Cementer @ 2133' MD 9-5/8" Bridge Plug @ 300' MD 13-3/8" 68# L-80, BTC @ 5302' MD 9-5/8" 53.5# P-110, SLHC @ 6686' MD Estimated Top of Cement behind the 9-5/8" Casing @ 13,950' MD Cement Plug #2 (15,450' - 15.550') 9-5/8" EZSV @ 15,550' MD 9-5/8" 47# P-110, SLHC @ 15,850' MD Cement Plug #1 (15,550' MD to 19,420' MD) Possible Oil & Gas Bearing Zones from 16,840' MD to 19,250' MD 5,8 ppg Premium Cement 5.6 ppg Permafrost "C" Cement 2.0 ppg Permafrost "E" Cement 8-1/2" Openhole TD @ -19,420' MD 15.0 ppg KCL Polymer Drilling Mud Diesel Cement In Place Prior to Abandonment ,i [::)"l::t I I..1.- I N ~ SEFIVi i:: E S Contact No. Red Dog #1 #14 To: State of Alaska AK Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99502 Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Co~e~s: From: Washed. & .Dried BP Exploration (Alaska) Inc. Red Dog #1 North Slope, Alaska API #50-089-20027-00 Shipment Includes: Process Depth Start Process Date Start 18220 / 18240 03/29/99 Process Depth End Process Date End 18580 / 18600 03/29/99 Total Number of Samples Included in this Shipment 19 Shipment Number SA-08-044 Comments 20' samples 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)273-3500 · Fax (907)273-3535 A Halliburton Industries, Inc. Company Contact No. Red Dog # 1 #lA To~ State of Alaska AK Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99502 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: From: ~gashed & Dried BP Exploration (Alaska) Inc. Red Dog #1 North Slope, Alaska API #50-089-20027-00 Shipment Includes: Process Depth Start 17840 / 17860 Process Date Start 03/29/99 Process Depth End Process Date End Total Number of Samples Included in this Shipment 19 Shipment Number SA-08-044 Comments 20' samples 18200 / 18220 03/29/99 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)273-3500 · Fax (907)273-3535 A Halliburton Industries, Inc. Company 198-252-0 RED DOG Roll #1: Start: Stop Roll #2: MD 19400 ~TVD 12379 ~Completion Date: 1 50- 089-20027-00 Start Stop ~7~/99 Completed Status: SUSP BP EXPLORATION (ALASKA) ~C Current: T Name Interval D 9120 ~"~"~'~ BP 14500-18740 L ADN-MD '-/'~- FINAL 9009~19400 . L ADN-TVD- FINAL 6370-12378 . L CDR-MD/-' FINAL 110-19400 Sent Received T/C/D OH 4/16/99 OH 4/14/99 4/16/99 OH 4/14/99 4/16/99 OH 4/14/99 4/16/99 L CDR-TVD Z..--~- FINAL 110-12378 OH 4/14/99 4/16/99 L CMR J'~ FINAL L CMR-TOTL POROSISg/'~FFINAL L CMR-TOTL POROSlY F~ ..AL.. L COMBO GAS SHOW t~NFINAL L COMBO MUD-MD ~""~'FINAL n COMBO MUD-TVD ~q"'2 L DIP ROSE PLOTS /_,,,FINAL n DIP ROSE PLOTS C'"Ff~AL L ENG LG-MD~ FINAL L FMI & DIP b'"/'- FINAL L ISONIC-MD t'""//' FINAL 16970-18734 OH 5 BL(C) 16670-18686 {) Cie/C, ~ ,'4 ~*~/Fq- f~'/'?dI~c3 ~5 K ~ BL(C) 16670-18686 P~V/C~/l~l~ 5 SPERRY 15850-19400 ~.%/~9-(g~ OH 2 SPERRY 110-19400 kp~v-r-'[?~" SPE~Y 110-12379 ~-~ ¢' 'Z'*''' OH 2 BE(C) 16612-18426 ~ OH 2 BE(C) 16612-18426 j~ ~ OH 1 SPE~Y 110-19400 ~~d/,~ OH 2 BL(C) 16612-18426 OH 1 9009-19400 OH 4/14/99 4/16/99 4/14/99 4/16/99 4/14/99 4/16/99 5/19/99 5/20/99 5/19/99 5/20/99 5/19/99 5/20/99 4/14/99 4/16/99 4/14/99 4/16/99 5/19/99 5/20/99 4/14/99 4/16/99 4/14/99 4/16/99 L ISONIC-TVD --~'-' FINAL L NGR '-~"~' FINAL L PEX-AIT/DSSI-MD 13'~INAL L PEX-AIT/DS SI-TVD Z-'"~FFINAL L PEX-AIT/GR ~ FINAL L RFT/~~'~ FINAL L ~GT FINAL R SRVY RPT/' R SSTVE (2.-'''''~- R WELL SUMRY RPT/-""~F~AL SPERRY 0-19400 S 1001 'J' W/D 15450-18600 S WASH/DRY #1001 ~'"'-~- WASHED/DRIED 0-15450 T 9047~- 1 SCHLUM ~ 6370-12378 15970-18530 15974-18577 9755-11620 15866-18734 15866-17344 14547-18530 SCHLUM 0-19400 GYRODATA DRLPIPE 0-7600. OH 4/14/99 4/16/99 OH 5 4/14/99 4/16/99 OH 4/14/99 4/16/99 OH 4/14/99 4/16/99 OH 5 4/14/99 4/16/99 OH 4/14/99 4/16/99 OH 5 4/14/99 4/16/99 OH 4/14/99 4/16/99 OH 4/14/99 4/16/99 OH 5/19/99 5/20/99 OH 4/6/99 4/6/99 OH 3/4/99 3/4/99 OH 4/27/99 5/20/99 Wednesday, March 28, 2001 Page 1 of 1 Contact No. Red Dog #1 #14 To: From: State of Alaska AK Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99502 Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: From: Washed & Dried BP Exploration (Alaska) Inc. Red Dog #1 North Slope, Alaska API #50-089-20027-00 Shipment Includes: Process Depth Start 17480 / 17500 Process Date Start 03/24/99 Process Depth End Process Date End Total Number of Samples Included in this Shipment 18 Shipment Number SA-08-044 Comments 20' samples 17820/17840 03/27/99 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)273-3500 · Fax (907)273-3535 A Halliburton Industries, Inc. Company 0 !:! I I--I--i I~1 i~ SEI~VICI~S Contact No. Red Dog #1 #f4 To~ State of Alaska AK Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99502 Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: From: Washed & Dried BP Exploration (Alaska) Inc. Red Dog #1 North Slope, Alaska API #50-089-20027-00 Shipment Includes: Process Depth Start 17100/17120 Process Date Start 03/24/99 Process Depth End Process Date End Total Number of Samples Included in this Shipment 19 Shipment Number SA-08-044 Comments 20' samples 17460/17480 03/27/99 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)273-3500 · Fax (907)273-3535 A Halliburton Industries, Inc. Company D'I=~ I I--I--I N I~ , Contact No. Red Dog # 1 # 1:4 To~ State of Alaska AK Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99502 Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: From: Washed & Dried BP Exploration (Alaska) Inc. Red Dog #1 North Slope, Alaska AP1 #50-089-20027-00 Shipment Includes: Process Depth Start 16450 / 16500 Process Date Start 03/23/99 Process Depth End Process Date End Total Number of Samples Included in this Shipment 16 Shipment Number SA-08-044 Comments 50' SAMPLES 16450/17000 17O8O/171OO 03/26/99 20' SAMPLES 17000 / 17100 5631 Silverado Way, Unit {3, Anchorage AK 99518-1654 · (907)273-3500 · Fax (907)273-3535 A Halliburton Industries, Inc. Company OF:Il CI--I N [3 S I:: I:lV I C I:: S Contact No. Red Dog #1 #1~4 To: State of Alaska AK Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99502 Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: From: Washed & Dried BP Exploration (Alaska) Inc. Red Dog #1 North Slope, Alaska API #50-089-20027-00 Shipment Includes: Process Depth Start 15450/15500 Process Depth End 16400 / 16450 Process Date Start 03/22/99 Process Date End 03/25/99 Total Number of Samples Included in this Shipment 21 Shipment Number SA-08-044 Comments 50' samples 12' SAMPLE 15850/15862 38' SAMPLE 15862 / 15900 5631 Silverado Way, Unit G, Anchorage AK 99518-1654 · (907)273-3500 · Fax (907)273-3535 A Halliburton Industries, Inc. Company WAYBILL Mail Invoices To: Sperry-Sun Drilling Services Date Shipped: MTO # 5631 Silverado Way, Suite G Time Shipped: Anchorage, AK 9951~ ~ TO I (F_...~ I (delete non-applicable) T~T~. I FROM (delete non-applicable) Sperry-Sun Drilling Services Shipped from: .5~_~"/c2/4/'~-"// /~/~&¢'~/"~/~'~' STATE of A~S~ AK OIL & GAS CONSERVATION COMM. 5631 Silverado Way, ~G ~00~ ~cuPINE DRIVE ANCHO~GE, AK 99~2 Anchorage, AK 99518-1654 ,~N: HeWeD OK~ND CARRIER & WAYBILL ~: CLIENT & JOB 8: SPECIAL INSTRUCTIONS/COMMENTS: R~SON FOR SHIPMENT I~M NO. Q~ PART 8 SERIAL 8 DESCRIP~ON 4 5 9 10 11 12 13 14 . 15 16 17 ~OTfi: S~[Cl~k GO~D~IORS (indg~o applicablo) A~achod Ship.rs Declaration ~ 1. Innor ~acka~es in Itom(s) comp~ with prescd~d Sp~ications Iistod on 2. Innor ~acka~s in Itom(s) comp~ with proscribod S~gations for "Flammablo Solids Dan~orous G~ds" S~ A~achod Ship.rs Doclaration 3. Innor P~ka~s in Itom(s) comp~ with proscdbod S~c~ations for "~adioacti~o Matodals ~an~erous Goods" ~ ~achod Ship.rs Doclaration Vohiclo Must Dis~a~ ~di~cfivo ~lacards d .rv[ces nlhng BP EXPLORATION (ALASKA) FAX # (907) 564-5193 FAX COVER SHEET TO: COMPANY: LOCATION: Blair Wondzell AOGCC Anchorage FAX #: 276-7542 FROM: LOCATION: PAGES TO FOLLOW: Terrie Hubble · SHARED SERVICES DRILLING ANCHORAGE, ALASKA PHONE #: 564-4628 5 DATE: 03-22-99 COMMENTS: CONFIDENTIAL Red Dog #1 IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER: (907) 564-4628 A a. sk. eare.d .rv!ces nll ng To: From: Subject: Blair Wondzell Date: 3/22/99 Floyd Hernandez Sundry Notice to Drill Deeper on the Red Dog #1 Exploration Well Following your verbal approval last Friday, 3/19/99, for drilling deeper on the Red Dog #1 exploration well, I have attached the required Sundry Notice application. I have also attached an outline of the plan forward, as well as a risk assessment for drilling to the top of the Shale Wall. Should you have any questions, please feel free to contact me at 564-5960. STATE OF ALASKA APPLICATION FOR SUNDRY APPROVAL :1. Ty~ of Request: ~Abandon ~8uspend ~ Plugging ~me E~ension ~ Perorate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance []Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well []Stimulate Name of Operator BP Exploration (Alaska) Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1682' NSL, 4508' WEL, SEC. 34, T10N, R21E, UM At top of productive Interval 3174' NSL, 985' WEL, SEC. 21, T10N, R21E, UM At effective depth N/A At total depth 3819' NSL, 1792 WEL, SEC. 21, T10N, R21E, UM [] Other (As Planned) 5. Type of well: [] Development [] Exploratory I~ Stratigraphic ~,J Service 6. Datum Elevation (DF or KB) KBE = 43.10' 71 Unit or Property Name Exploration 8. Well Number Red Dog #1 9. Permit Number 98-252 10, APl Number 50-029-20027 11. Field and Pool Prudhoe Bay Field / Undefined Pt. Thomson Pool 12, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 18740 feet 11754 feet feet feet Length Size Structural Conductor 80' 20" Surface 5262' 13-3/8" Intermediate 15811' 9-5/8" Production Liner Plugs (measured) Junk (measured) Cemented MD TVD 260 sx Arcticset (Approx.) 80' 80' 547 sx PF 'E', 588 sx 'G', 1800 sx PF 'E', 200 sx PF 'C' 5302' 4448' 830 sx Class 'G' 15851' 9706' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A ORIGINAL 13. Attachments [] Description summary of proposal [] Detaited operations program [] BOP sketch 14. Estimated date for commencing operation March 19, 1999 16. If proposal was verbally approved Blair Wondzell ~ Name of approver Cenfacf Engineer Name/Number: Gabriel Higuera, 564-5284 3/19/99 Date approv_ed 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 584-4625 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed · Floyd Hernande Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative m~y witness Plug integrity __ BOP Test / Location clearance Mechanical Integrity Test __ Approved by. order of the Commission :cfm 10-403 Rev. 06/15/88 J Approval No: ~ Subsequent form required 10- ORIGINAL SIGNEDBY Robert N. Chdste.-.son Commissioner Returned - Date Submit In Triplicate CONFIDENTIAL PROCEDURE - DRILLING DEEPER TARGETS IN 8-1/2' HOLE , , . . . . t Run in hole with 8-1/2" S73HEPX used bit (S/N JR6916), XP Straight Motor and CDR - SONIC - DIR MWD - ADN (the ADN should be in recorded mode). At least one D1 drill must be performed prior to continue drilling ahead. RIH to 9-5/8" casing shoe (stage in as required). Circulate and condition mud until properties have stabilized (mud viscosity, mud weight). Continue RIH to bottom. Circulate and condition mud. Pump high density/high fiber sweep prior to trip to the shoe. POOH to 9-5/8" casing shoe. Break circulation prior to perform Pressure Integrity Test. Close the annular BOP and perform a Pressure Integrity Test up to 17.0 ppg. Perform the integrity test following the procedures described in the Drilling Dossier for LOT to minimize any potential hole problems. It is important to be aware that the result of this test is critical in determining the maximum mud weight to use while drilling the deeper targets. NOTE: If pressure integrity is less than 16,5 ~pg, inform the SDE immediately. RIH back to bottom and circulate. See attached Mud Recommendations document from Baroid. Drill ahead based on the following mud weight schedule: DEEPER TARGETS MD (ft) ~ (ft) TVDSS(ft) Min. MW I TOP KODIAK 18761 11773 11730 14.5 TOP KILLIAN 19208 ' 12193 12150 15.0 TOP SHALE WALL 19312 12293 12250 15.0 WELL TD 19416 12393 12350 15.0 If additional mud weight increase is required based on estimated pore pressure verified by pressure detection tools (CDR and Sonic; background, connection, and trip gas trends; cuttings characteristics), be aware that at least 1.5 .~.~_q window has to be maintained between the MW CONFIDENTIAL and the PIT value. Confirm this assumption with your actual ECD (from PWD). Drill ahead to +/- 100 ft MD into the Shale Wall to +/-19,416 ft to get GR or RES through Top Shale Wall (12,250 ft TVDSS) and log 50 ft MD. The onsite geologist with the assistance of the town personnel will assist in the calling TD. No directional work is required. The directional plan shows the expected tendency of the rotary assembly that we will run, If tendency is different than expected, no action is required. Short trip as necessary. Keep a close monitoring on ECD with PWD, since the ECD will be very close to the integrity level of the welibore. NOTE: If pump pressure will become a limiting factor, reduction in the flow rate should not go below 420 gpm (minimum to clean the hole). If so, more frequent wiper trips to the shoe are required to clean tangent section inside the casing. NOTE: Ensure that ditch magnets are rigged up to enable the monitoring of casing wear. . At TD, circulate and ensure hole is clean based on lhe PWD and drilling parameter trend lines. ,, Based on further conversations with Partners and after analizing the information from drilling these deeper targets, decision will be taken with regard either running liner or suspend the well. Program to follow. CONFIDENTIAL 9,9 ppg formation below shoe: 2570 psi (AP) 2,7 ppg forma on at top Red Dog: 1260 psi (AP Mud to be in excellent cend~llon (Rheoiogy) Maximum pore pressure to be 14,5 ppg Close monitoflng of PWD data (Hole cleaning-ROP) Integrity Test pass at least 17.0 PPG F.~IW. Ru~ minimum bit pressure drop (needed for tools t~ work) Lay down "pressure drop" lools MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman DATE: March 3, 1999 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor ~f~olr~ a9wlccgf.doc FROM: John H Spaulding,~,~ SUBJECT: Petroleum InspectOr BOPE Test Nabors 28E Red Dog #1 Wildcat PTD 98-252 March 2, 1999' I traveled this date to witness the BOPE Test on Nabors 28E, located at the Red Dog #1 exploration site. The AOGCC BOPE Test Report is attached for reference. no failures were obse__rved. The test went As noted on the inspection report,,~ well and the rig was found to be in excellent condition. All areas around the rig were clean and orderly with good access. The BOPE Test was to 9000 psi on the components, thus the somewhat longer time for testing. SUMMARY' I witnessed the successful BOPE Test on, Nabors 28E, Red Dog #1, 0 failures, 6 hours. Attachment:agwlccgf.xls Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Alaska Inc. Operator: BPX Alaska Well Name: Red Dog #1 Casing Size: 9 5/8" Set @ Test: Initial Weekly X DATE: 3/3/99 Rig No. 28E PTD # 98-252 Rig Ph.# 659-1201 Rep.: Dick Maskell Rig Rep.: Chris Page Location: Sec. 34 T. 1ON R. 21E Meridian Umiat Other MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quart. Location Gen,: ok Well Sign ok Upper Kelly/IBOP 1 Housekeeping: ok (Gen) Drl. Rig ok Lower Kelly/IBOP 1 PTD On Location yes Hazard Sec. yes Ball Type 1 Standing Order Posted yes Inside BOP I Test Pressure P/F 250/9, 000 P 250/9,000 250/9,000 250/9,000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F '1 250/3500 D 250/9,000 250/9, 000 250/9,000 250/9,000 250/9,000 250/9,000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 17 250/9, 000 P 42 250/9, 000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 1,525 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 28 sec. Trip Tank ok ok System Pressure Attained 2 minutes 31 sec. Pit Level Indicators ok ok Blind Switch Covers: Master: x' Remote: x Flow Indicator ok ok Nitgn. Btl's: 8 Bottles 2 2000'avg. Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok Number of Failures: 0 ,Test Time: 6.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to tl'le AOOCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: Grig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev.12/94) a9wlccgf, xls A .. .ka eare.d ry[ces nll ng To: Bob Crandall Date: 2/24/99 From: Subject: Floyd Hernandez Red Dog #1 Bottomhole Location Revision 'Attached is the new proposed bottomhole location for the Red Dog #1 exploration well. The new proposed bottomhole location will move 652' to the west of the permitted bottomhole location. The proposed location is still within the same Section, Township, and Range of the permitted location. Listed below are legal descriptions for both the permitted bottomhole location and the new proposed bottomhole location: Permitted Bottomhole Location: 3671 FSL, 1058' FEL, Sec 21, T10N, R21E New Proposed Bottomhole Location: 3670' FSL, 1710 FEL, Sec 21, T10N, R21E The new location is being proposed due to better directional control than anticipated and for optimal intersection of reservoir targets. Should you have any questions, please feel free to contact me at 564-5960. CC. R. Skillern J. Sick G. Higuera D. Cocking 02/24/99 09:37 VAX 907 504 5193 111' EXPLORATION ~* AO(;CC [~003 BP EXPLORATION (ALASKA) INC. PTAC 98/99 EXPLORATION AND APPRAISAL WELL PROPOSED WELL BORE LOCATION MAP DATE: February 1999 SCALE: SHEET: = 2,000 Feet I of 1 o×13953_299.dgn AmaBr£11 ~chl~mbe ~Ser Alaska Discrict Anchorage, AK WeLl ......... : Re~ ~ ~1 (P16A} Field ........ : ?r~dho~ Bay, Pt ThomI)son Umita ........ : F~RT ~al ~scription X,-Coord Ta~et ....... : 35~3 FSL ~659 ~ S21 TION R2LE ~ 399430.00 3 Y-Coord 5914227.39 5922814-54 5926805.78 ID3~TIF[CA~ION D~P~H A~LE ,C~RV'~ l/lO0 131.1.0.45 L3SO0.OO . . L3600.00 · :- ' L3700.00 :::, 13~O0.O0 L3900.00 62.15 3~2.20 8370.07 8326.L2 62.~5 352.20 ~370.07 61-99 3~1.20 84~2.0~ 8368,07 61.6~ 34~-96 8506_43 8756.46 61.52 3~7.~4 S$54.00 ~SLO.O~ 9D20-52 61,L4 ~44.45 8697.95 8654.00 9282-50 61,03 ~%3.31 $7~6_~1 9~02.36 9369-~ END l/L00 CUR~B 13919,59 61o01 343.09 $755'.80 8711.85 9386-19 P~loared ..... : 20 Feb L999 Vert sect a~-: 35~.59 KB elevations.: 43,95 ft ~snetic DcI~: ~25-815 (~) Scale Factor.: 0.99991099 Comv~r~ence__: -0.g~424437 ANADRi£L AKA-DPC APPROVED FEB 2 0 1999 INITIA "' 857f.00 ~ 1357.2T W 400~9.32 5922~%-54 857A,OD N L~57.~T W 400&79.3~ 59228~-5~ ~0OL <T~ 8909.%3 N 1416.6e W 400424,26 592~L53-37 98'L 1,00 ggg&.6l N 1436,03 W 40fl406.03 5923239,30 98L 1.BO 9164.64 N 2479.69 W {00364,57 5923409.66 97L 1.00 9~4e.~ ~ lS04,00 W 400341.37 $923494-05 96L 1. Od 9265,L3 N 1508,95 ~ 400336.~3 5923510-52 ~S 1.O0 (A~ad~ill (c) 99 RDIPI6A 3.2C 2:24 PM P] 'Zl i'rl t r~ Red o<.' EDI~TIF~C~TION TOP MBK ~0 TOP CA~Tq/I~ CURWE ~1~00 20 Feb 1999 P~~e 2 DIRSCTYON AZ I M~TF. k¢307.~0 6L.Ol 243.09 19514,13 61-02 343.09 ~54f$.08 61.01 343.09 16152.34 6L.03 343.09 16~0.00 60.06 343.09 ~63~0.00 58.06 343.~9 [fi357,94 5fi.90 343.89 [6400.0~ $6.~6 343,D~ £6500-00 $4.06 343.39 16600.00 S2.0fi 343.09 = _-- TVD SUB-S~A D~PART 8943.95 B~OO.O0 9722.0~ 9043.95 9aO0,O0 9500,52 950~.00 9456.05 Z0714.53 9837.94 5~93.99 11317.72 COORDINATES-FRO~ ALASKA Zone 3 9590.02 N 1607.72 W 4002a2.09 9762.69 N 1~60.22 W 400191.~$ 592~00~.~5 __ FAC~ lO0 ~4S O - 09 O. OD O .00 0.00 2.00 . 2.0C- 2.00 2-00 2.00 2,00 10550.15 N 1899-63 W 3~9962.71 5924800,3B I[$ 1113F.67 N 2077.04 W 399792-91 S925386.~1 LS 11173.37 ~ 2089.11 W 299781,~6 592S425.96 LS ~912.g0 9~68.g5 L24%5.5~ 11255.42 N 2114.05 ~ 399757,4~ 5925505.~2 L~ 994~-95 9900.00 L1¢9%.~9 11302-16 N 222~.26 ~ 399~43.B8 5925555.23 L~ 9967.k8 5923.23 11526.5~ 11335.71 ~ 2138.46 W 399734.[2 5~25588.91 bS 10~24.46 998~.51 [16,07.~4 11414.13 ~ 2162-31 ~ 399711.3~ 5915667-63 b~ 10084-56 1004e.61 [165fi.6~ 1/490.59 ~ 21~5.55 W 3~9~89.05 5525~4.3~ ~S L6700.00 $0-06 343.09 16909.00 4S.06 343.09 16900.00 46.06 3~3.09 E7O00.O0 44.06 ~a3.09 17100.00 42.06 343.09 10~47.41 L01~3.46 ~2~65,60 11565.00 E 220~,~7 W 399667.~0 592S~19-0~ hS 2.GO 10281~06 1~237.11 [l~LO.70 ELIOT.30 N 2251.44 ~0351.70 10307.75 L1980.70 1~77~.02 N 2272,02 ~042&~7~ ~fl380.~1 12048.21 ~840.~3 N 2291.~8 17200.00 40,06 343,09 17300.00 38.06 343,09 17400.00 36.06 ]43.39 1750G.00 ~4,96 343.D9 17505_4~ ~3,95 343.09 2050~-~q /~456.22 12113,L7 ~05~9.B2 ~0533.87 12175,4B 10~Q.62 ~06~3.~7 107~9.47 i~695,52 i2291,~8 10743.9~ ~0?0ff.00 12294,57 1~903.17 N 231~.99 W 399569.G0 5926156.52 LS 2.00 ~9~3.45 N 2329.31 W 399551-~6 592621.9,02 18 2.00 1202~.10 N 2146.~4 W ~995Z~.6S 5926276.69 L$ 2-00 1207%.05 N 236B.5§ W ~99518.69 5926332,05 I~ 2.00 .j 1760C,00 ~2.06 343.99 17700,00 50,06 343.09 17~00.~0 2S.06 343,09 17853.67 26.~8 343.09 17900.0B ~fi.06 343.09 18000,00 24.06 1BZOU.00 22.06 343.09 L8200.00 20.86 343.09 (Anadr±ll (c)99 EDTP16A 3,2C 2;24 PM ~) 10823,28 LO77g.33 k2345.82 10908.9~ ~086{.99 12395,64 10996.3~ 10952.40 L2&44.$7 11043.95 11000.00 L24~5,40 11175.99 1~132,04 L2531.74 112~8.00 11224.05 /2570,g7 L13-,ql . 3 2 11317,37 12606,00 1212~.24 1,4 2379,42 W 399503-$1 592~3~{,~3 5S 2,00 12177.59 ~ 2394.42 W 399489-15 5926433.97 LS 2.09 12224.06 N 2408,55 W 399475.6~ 5926480.6! L$ 2.00 E2247.78 ~ 2415.76 W 399468~~2 5926504,43 ~ 2-00 ~2267.57 N 2421,78 W 399462.96 592652~.30 LS 2,00 1230g. G9 N 2434.09 1234A.$,~ 1'4 2~45.49 rd' 399440.27 5926602..58 Lg 2.00 12379-93 N 2455,9~ W 399430.27 5926637,08 LS 2.00 ANADRIL[ AKA-DPC APPROVED irES 0 1999 PROPOSED STAT/O~ MEASIIRB~ INCLN 2/109 ~XD-O3 18532.7e 20.08 TOP KODIAK TOP KIhLT AN 1BT13.&L 343.09 343.09 343,09 343.09 I~ERTICAL-DBPTIiS SECTION C00RDIAIATES-FROM A3_,ASKA Zone 3 TOOL DL/ 'F913 SlgB-SEA D~PART WELLIiF_,AD X y L1363.95 31320.00 12606.95 12380.85 N 2456.21 ~ 39F430.00 $92~638.00 BS 2.00 11393.95 11350.08 12617.75 123~1.30 ~ 2i5~.39 ~ 39942~.96 A926648,49 HS 0.00 11673.9~ 11630.0~ 12718-54 12488.~0 } 248~,04 # 399398,59 592674~.3~ 31843.95 31B00.0~ L?.779.74 12548.~0 ~ 2507,03 W 399361.36 5~26-g05-78 0.00 3t3.09 11843.95 11800-00 32073,9S 12030.00 12493,95 12450-00 ~2593.9~ 12550.00 12779.74 ' 1254~.00 N 250?.03 W 399381.36 5926805-78 O.00 '1'1 m I ,'Al~adrii1 (c199 ROtPL6A 3.2C 2:24 PM P} ANADRILL AKA-DPC APPROX./ED 1999 U FEB-20-1999 16:~ FROM C ]RILL SCHLUMBERGER TO 5645i9] P.06 L .... SHARED SERVICES DNiLLI-N'G I ~ , --, Red Bog #J (P16A) ' VERTICAL SECTION VIEW ii ................ Section at'. 35~ ~NADRLL A~A-DPC TVD Scale.' ~ ~nch ~ B00 f~et ~ ~ "~'~ ' '-~ Drawn · 20 F~b ]999 Fg~ g 0 !99~. _. ,. , ....... Anadrj ]] ~chJumb~rger INIT1AL . '~ M~r~r IdentificatiOn ffi BKB ~ECTN - INCLN .... A) ~UR~ 1/100 ~0 8370 8677 6~, Bi Tie-Jrt ~M~0 8370 8677 . C) END ~/i00 CURVE ~9~0 87~6 9~ ! D) 9-5/8" CSG PT 41> ]5455 ~00 ]0715 I E) CURVE 2/tO0 ~Gl~ 9838 11318 51,01 ~ ,, F) E~ ~/100 CURV~ 18~0~ ]~64 ~2607 ~O,0O ~ ' 6) T~T 18803 1t364 ~2607 ~0.00 I ........ i' H) 7" LINER PT <11) ¢871~ ~1844 :atso ' ~ I) ID 18714 1~B44 ~780 20.00 ,' I "i" i ' ----"' ....... , ~ : "T~ ~ ~-~oT '~1 ~ ', I ..... [ ....... { '-' , ................ , .... ~,--,, ,,.., .~ ......... ~mr~om- m.~¢ .............................. k .......... ~ ........... ~ ........... ....... . ...... .... 8400 8800 gg'00 9600 t0000 10400 10800 1 ~200 t t600 l~000 J~400 1~800 13200 FEB-20-1999 16:55 FROM f )RILL SCHLUMBERGER TO 5645193 P, 07 SHARED · , ! ~arken Identification ~ N/S E~ A) CURVE I/lO0 t3i10 8571~N 1357 B) T~e-in 13110 857t 1357 C) ENO t/t00 CURVE J3920' g265 N 1509 DJ 9-5/8" CS6 PT <1[> 15455 10550 1900 E) CURVE ~/~00 ~.~ ~. ~o~ ") 7" LINER Pf 41> t8714 t2548 N 2507 Red Dog /fl (PICA) PLAN VlE~ i i i i i iii iii i CLOSURE ..... : ~796 feet at AZinluth ~48,70 DECLINATION.: +28.8t3 (E) SCALE ....... : 1 ~nch = 800 feet DRA~IN .......: 20 Feb 1999 .SERV ~[C~ES ' BF(f'-LF"[ NG' i m ANAD~JLL A, ~,A~_DPCi " ' AF'PROV[:.D-'", .... ~,'1/~'~ ;~ .... , ....... , ! ' I , i , ...... -. , .... ~ ..... 4800 4400 4000 3600 3200 ~ ~00 ~000 t600 l~O0 800 400 0 400 800 WAYBILL Mail Invoice~ To: Sperry-Sun Drilling Services Date Shipped: ,~ -"22'- ?(~ MTO # 5631 Silverado Way, Suite G Time Shipped: Anchorage, AK 99518-1654 TO I FROM I (delete non-applicable) TO I FROM (delete non-applicable) Sperry-Sun Drilling Services Shipped from: ,)--,~-~'/x2//./~-/y' /~',~",~/~~ STATE of ALASKA - - AK OIL & GAS CONSERVATION COMM. 5631 Silverado Way, fiG 3oo4 POCUPINE DRIVE ANCHORAGE, AK 99502 Anchorage, AK 99518-1654 ATTN:HOWARDOKLANO CARRIER & WAYBILL #: CLIENT & JOB #: SPECIAL INSTRUCTIONS/COMMENTS: REASON FOR SHIPMENT · ITEM NO. QTY PART # SERIAL # DESCRIPTION 4 5 10 11_ 12 13 / 14_. ~ 16 17 /~, 2O NOTE: SPECIAL CONDITIONS (indicate applicable) 1. Inner Packages in Item(s). comply with prescribed Specifications listed on Attached Shippers Declaration 2. Inner Packages in Item(s). comply with prescribed Specifications for "Flammable Solids Dangerous Goods" See Attached Shippers Declaration '3. Inner Packages in Item(s) comply with prescribed Specifications for "Radioactive Materials Dangerous Goods" See Attached Shippers Declaration IVehicle Must Display Radioactive Placards WHITE - Recipient YELLOW - Carrier PINK - Originator GOLD - Originator 0 !:! I I--I-I N I;ic:E I~IVI CZ ~ S Contact No. Red Dog # 1 #14 To: State of Alaska AK Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99502 From: Sperry-Sun Drilling Services Attn: Steve Carroll 5631 Silverado Way, #G Anchorage, AK 99518-1654 Contents: Washed & Dried BP Exploration (Alaska) Inc. Red Dog #1 North Slope, Alaska API #50-089-20027-00 Shipment Includes: Process Depth Start Process Date Start 0 / 150 Process Depth End 1100 / 1150 02/15/99 Process Date End 02/15/99 Total Number of Samples Included in this Shipment 21 Shipment Number SA-08-017 Comments 50' samples 5631 Silverado Way, umt G, Anchorage AK 99518-1654 ' (907)273-3500 · Fax (907)273-3535 A Halliburton Industries, Inc. Company MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~ DATE: February 9, 1999 Chairman THRU: Blair Wondzell, .~'J).~ FILE NO: P. I. Supervisor FROM: Lawrence M WadeCr'-- SUBJECT: Petroleum Inspector .a9wgbigf. DOC BOP Test Nabors 28E Red Dog #1 PTD 98-252 February 5,1999: ! caught the plane to Badami at 6 PM. On arriving it was found that the rig was having problems getting a casing integrity test. They had cemented their 13 3/8' casing and were doing a pressure test. They had a leak and ran an RTTS tool to find it. It was not the diverter port as was suspected so they picked up a bit and drilled to within 20' of the shoe. The RTTS was then ran in and the leak was then determined to be at the shoe. In the meantime ! flew back to Deadhorse on Sunday afternoon and then flew back to Badami on Monday at noon The BOP test started at 11:30 PM. Everything was tested to 5000 psi except for the hyril. It was the only thing that failed. It was changed out in 6 hrs, tested and passed. The location and rig looked orderly and clean. Due to the recent rig layoffs there are many core people new to this rig working in new jobs. Things will probably get a lot more cohesive in a short time. SUMMARY: I witnessed a BOP test on Nabors 28E, 4.5 hours, 1 failure. Attachments: a9wgbigfe.xls cc; NON-CONFIDENTIAL · STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION' Drlg: X Workover:~ Drlg Contractor: Nabors Rig No. Operator: ARCO, Murphy, Fina, Chevron Well Name: Red Dog #I Casing Size: 13 3/8" Set @ 5,302 Test: Initial X Weekly Other DATE: 28E PTD# 98-252 Rig Ph.# Rep.: Paul Lockwood 2/9/99 Rig Rep.: Leonard Schiller Location: Sec. 34 T. 1ON R. 21E Meddian Umiat Test Pressures 250/5000 Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location X Standing Order Posted X Well Sign X Drl. Rig X Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 250/5000 250/5000 250/5000 250/5000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/3500 F I 250/5000 P f 250/5000 P I 250/5000 P f 250/5000 P 2 250/5000 P 1 250/5000 P 250/5000 MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 1 Hydraulic Chokes I Test Pressure 250/5000 32 250/5000 P/F P P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,900 I 1,500 minutes 26 sec. 2 minutes 33 sec. X Remote: X 2050-2150-2100-210 2050-2100-2100-1900 Psig. Number of Failures: '/ ,Test Time: 5.0 Hours. Number of valves tested f8 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Annular preventer failed pressure test. Element replaced and passed pressure test. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev. 12/94) agwgbigf, xis TONY KNO WLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION January, 5, 1999 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Floyd Hcmandez Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Red Dog # 1 BP Exploration (Alaska) Inc. Permit No: 98-252 Sur. Loc. 1682'NSL, 4508%VEL, Sec. 34, T10N, R21E, UM Btmhole Loc. 3671'NSL, 1058%VEL, Sec. 21, T10N, R21E, UM Dear Mr. Hcmandez: Enclosed is the approved application for permit to drill thc above referenced well. Thc permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A xveekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for thc Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and an5' CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sin ~ // Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlfFEnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Consen'ation w/o encl. STATE OF ALASKA ALASKA ~.-¢~.' AND GAS CONSERVATION COM,_~_~SSlON CONFIDENTIAL 20 AAC 25,005 REVISED la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI I'q Service [] Development Gas [] Single Zone [] Multiple Zone 2. ~ame o:[ Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 35' Prudhoe Bay Field / Undefined 3. Address 6. Property Designation Pt. Thomson Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL377013 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1682' NSL, 4508' WEL, SEC. 34, T10N, R21 E, UM Exploration At top of productive interval 8. Well Number Number 2S100302630-277 3174' NSL, 985' WEL, SEC. 21, T10N, R21E, UM Red Dog #1 At total depth 9. Approximate spud date Amount $200,000.00 3671' NSL, 1058 WEL, SEC. 21, T10N, R21E, UM ~ 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL377012, 1609'I No Close Approach 2560 19518' MD / 12740' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 2000' MD Maximum Hole Angle 59.65° Maximum surface 8994 psig, At total depth (TVD) 12740'/10268 psig 18. Casing Program Specifications Setting Depth Siz9 Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 BTC 80' 40' 40' 120' 120' 260 sx Arctic Set (Approx.) 16" 13-3/8" 68# L-80 BTC 5460' 40' 40' 5500' 4508' 1585 sx PF 'E', 1570 sx 'G' 12-1/4" 9-5/8" 53.5# P-110 ILHC 6000' 40' 40' 6040' 4786' 354 sx Class 'G' 12-1/4" 9-5/8" 47# P-110 ILHC 10906' 5040' 4786' 16946' 10595' 8-1/2" 7" 32# P-110 NSCC 2499' 16796' 10477' 19295' 12745' 395 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ProductionORIGINAL .... Liner i~ ! - ,--,, .. Perforation depth: measured true vertical 20. Attachments ["' Filing Fee 'El Pro"'perty Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [~ Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Gabriel Higuera, 564-5284 Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd Hernandez~~ L~.,.~ ,./~tlo' Senior Drilling Engineer Date l~'-(/z//'~ ~ Commission Use Only Permit Number I APl Number Approval Date See cover letter _,/O?- 2,~Z--~I 50-<:~ o~'~--~ .2-, (:~<:~ ~_..~ /--'-._~'~ ~ for other requirements Conditions of Approval: Samples Required J~'~Yes [] No Mud Log Required J~Yes []No Hydrogen Sulfide Measures []Yes 1~No Directional Survey Required 'j~]Yes I-]No Required Working Pressure for BOPE 1'-12K; []3K; 1--14K; 1--15K; [~10K; []15K Other: ORIGINAL SIGNED BY by order of Approved By Robert N. Chdstenson Commissioner the commission Date/'----._:2 Form 10-401 Rev. 12-01-85 Submit In Triplicate RED DOG #1 BOPE PRESSURE TESTING PROCEDURE Surface Hole: Hydril MSP 21-1/4", 2M diverter system on 20" conductor pipe · On installation, system shall be function tested. Intermediate Hole: 13-5/8", 10M BOP system on 13-3/8" casing Initial installation: Annular 3,500 Pipe rams 10,000 Blind rams 10,000 Pipe rams 10,000 Choke manifold and choke & kill lines 10,000 Kelly cocks 5,000 Standpipe manifold 5,000 3si 3si 3si 3si 3si 3si While drilling 12-1/4" hole: Annular 3,500psi Pipe rams 5,500psi Blind rams 5,500psi Pipe rams 5,500psi Choke manifold and choke & kill lines 5,500psi Kelly cocks 5,000psi Standpipe manifold 5,000psi Production Hole: 13-5/8", 10M BOP system on 13-3/8" casing Annular Pipe rams Blind rams Pipe rams Choke manifold and choke & kill lines Kelly cocks Standpipe manifold 3,500~si 9,000~si 9,000~si 9,000~si 9,000 ~si 5,000 ~si 5,000)si Well Testing with Rig: 13-5/8", 10M BOP system on 13-3/8" casing Annular 3,500psi Pipe rams 9,000psi Blind rams 9,000psi Pipe rams 9,000psi Choke manifiold and choke & kill lines 9,000psi Kelly cocks 5,000psi Standpipe manifold 5,000psi The 9,000 psi pressure test represents the maximum surface pressure anticipated during Red Dog #1 testing operations, RFT data obtained available prior to DST operations should be used to review the pressure testing requirements and amend if necessary. Full BOP test will be conducted prior to each DST. Page 1 Red Dog gl Exploration Well Hazards & Contingencies Surface Hole Section: (16" hole size & 13-3/8" casing) · No shallow gas expected, but be prepared just in case. · Loss circulation in the surface hole is not expected. Intermediate Hole Section: (12-1/4" hole size & 9-5/8" casing) Abnormal pressure is expected in the intermediate hole section. The pressure transition zone is expected to rise from normal pressure (9.0 ppg EMW) at approximately 7000' TVD to 12.5 ppg EMW at the target Red Dog Sands (10,680' TVD). · No H2S or CO2 are expected in this hole section. · No faults are expected to be crossed. No loss circulation is expected in the intermediate hole. Hazards of loss circulation will be managed by proper techniques to maintain low ECD (i.e. Utilization of the Pressure While Drilling logging tool). Production Hole Section: (8-1/2" hole size & 7" liner) The pore pressure in the target sands (Red Dog Sands) should be approximately 12.5 ppg to 13.0 ppg. The secondary targets (Kodiak & Killian Sands) may have pore pressure up to 14.5 ppg EMW. The current TD of the well is the top of the Shale Wall which may have pore pressures up to 15.5 ppg at 12,640' TVD. · No H2S or CO2 are expected in this hole section. · No faults are expected to be crossed. Loss circulation in the production hole section may occur. The PWD tool will be used to manage ECD while drilling and reaming. Losses may also occur while drilling the secondary target sands (Kodiak & Killian) which may require 2.0 ppg to 3.0 ppg EMW above the pore pressure of the main target (Red Dog). _: David W. Johnston, Chairman/Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 December 11, 1998 Via Fax# (907) 276-7542 Re~ Red Dog #1 Drilling Unit NE/4 of Section 21, Township 10 North, Range 21 East, Umiat Meridian Beaufort Sea, Alaska Dear Commissioner Johnston: /'Jast(a Ojj & Gas Coii~. We the undersigned, BP Exploration (Alaska) Inc., ARCO Alaska, Inc., Murphy Exploration & Production Company, Petrofina Delaware Incorporated and Chevron U.S.A. Inc., hereinafter referred to as "the Parties", have drilling and participating rights in the above referenced drilling unit; further we are the sole parties having such rights in the lands immediately adjoining referenced drilling unit. As participating parties in the drilling of the Red Dog #1 Well, the Parties have heretofore entered into certain agreements which determine the rights of the Parties to share in the potential costs, liabilities and production that may be attributed to all operations, including but not limited to, drilling, completing and plugging of the Red Dog #1 well and drilling unit. Pursuant to Alaska Statue AS 31.05.100 (c), the Parties have agreed to pool their respective interests within the above referenced drilling unit in those percentages determined by the aforementioned agreements among the Parties. By execution of this letter the Parties hereby affirm, confirm, acknowledge and agree, that their respective interests, within the above referenced drilling unit, have been voluntarily pooled pursuant to Alaska Statue AS 31.05.100. Time being of the essence in the signing and delivery of this pooling letter to the Commission, it has been prepared and distributed among the Parties by electronic means for reproduction, counterpart execution and delivery to the Commission. Therefore, it is requested that that you recognize that the various copies of it which may be submitted to you are identical in content, although they may vary in appearance and accept them as a single document upon execution of such counterpart copies by all Parties. BP Exploration (Alaska)Inc. By: Chevron U.S.A. Inc. By: Date: Date: Title: Title: Page 2 Red Dog #1 Drilling Unit December 11, 1998 ARCO Alaska, Inc. By: Title: Date: Petr fin .Delaware I. ncorporated Title: ~ V Date: I Z '-' //--~-- ~ Murphy Exploration & Production Company By: Title: Date: D[~ 2~ ~998 · j ~...hared ~ ,,4~ervices ~.~1~.~. ~rilling COMPANY: FAX: PHONE: Number of attachments not including fax cover: Red Dog #1 Exploration Well Hazards & Contingencies Surface Hole Section: (16" hole size & 13-3/8" casing) Existing wells within the area do not show any shallow gas near the surface (<2000). The nearest wells located approximately 3.5 miles to the southeast (East Mikkelsen # 1), 4 miles to the east (Pt Thomson #4), and 6 miles to the northwest (Challenge Island #1) showed no signs of gas near the surface. Seismic analysis indicates shallow gas is unlikely to be encountered. Other regional offset data also confirms a very low probability of encountering any shallow gas or abnormal pressures in the 16" hole section.. Even though we do not expected any problems, SSD will discuss the potential for encountering shallow gas during the pre-spud meeting and also have all gas detection systems in place prior to spudding the well. Diverter system will be installed prior to spudding the well. See Shallow Gas Awareness Plan attached to Permit to Drill application. · Loss circulation in the surface hole is not expected. Listed below are critical drilling issues that have been highlighted for the surface hole section: 1. Permafrost washout 2. Hole cleaning in the kickoff section and high angle section. 3. Low solids gravity buildup 4. Seepage losses while drilling or making wiper trips 5.. Wall cake thickness across highly permeable sand bodies 6. Avoid cuttings overloading in solids control equipment by reducing flow rate and increasing the viscosity of the fluid system 7. Control dogleg severity in the buildup section 8. Surface casing shoe depth is critical for good leak-off test and kick tolerance in 12-1/4" hole section 9. Cement to surface (will use 2-stage cement procedure) Intermediate Hole Section: (12-1/4" hole size & 9-5/8" casing) Abnormal pressure is expected in the intermediate hole section. The pressure transition zone is expected to rise from normal pressure (9.0 ppg EMW) at approximately 7000' TVD to 12.5 ppg EMW at the target Red Dog Sands (10,680' TVD). Resistivity and D exponent trends line plots will be the primary tools for pore pressure determination. Offset wells resistivity plots will be available on-site for comparative purposes. Mud weight will be increased in line with estimated pore pressure with the intent of drilling with a safe overbalance of 200 psi (approx. 0.4 ppgEMW at 9,852'TVD). There have been no indications of H2S or CO2 on nearby wells and none are expected on Red Dog #1. No faults are expected to be crossed. No loss circulation is expected in the intermediate hole. Both Challenge Island and East Mikkelson #1 experienced no losses in the intermediate hole section. Hazards of loss circulation will be managed by proper techniques to maintain low ECD (i.e. Utilization of the Pressure While Drilling logging tool). Listed below are some critical drilling issues that have been highlighted for this hole section: 1. Keep mud as clean as possible down to the top of the transition zone 2. Minimize steering in tangent section to reduce hole tortuousity 3. Increase dilution rate to reduce Iow gravity solids 4. High hole angle cleaning in long tangent section 5. Reduce torque and drag with lubricant additions, hole cleaning practices, and reduced tortuousity Production Hole Section: (8.1/2" hole size & 7" liner) The pore pressure in the target sands (Red Dog Sands) should be approximately 12.5 ppg to 13.0 ppg. The secondary targets (Kodiak & ICillian Sands) may have pore pressure up to 14.5 ppg EMW, The current TD of the well is the top of the Shale Wall which may have pore pressures up to 15.5 ppg at 12,640' TVD. Resistivity and D exponent trends line plots will be the primary tools for pore pressure determination. A LWD sonic tool will be mn in this hole section which will be used to determine pore pressure. Offset wells resistivity and sonic plots will be available on-site for comparative purposes. Mud weight will be increased in line with estimated pore pressure with the intent of drilling with a safe overbalance of 200 psi (approx. 0.3 ppgEMW at 12,640'TVD). No H2S or CO2 are expected in this hole section. No faults are expected to be crossed. Loss circulation in the production hole section may occur. The PWD tool will be used to manage ECD while drilling and reaming. Losses may also occur while ch'illing the secondary target sands (Kodiak & Killian) which may require 2.0 ppg to 3.0 ppg EMW above the pore pressure of the main target (Red Dog). Challenge Island #1 experienced massive losses while drilling the Pt Thomson sands which caused a well control incident. Total depth for the Red Dog well is above the Pt Thomson sands. Listed below are some critical drilling issues that have been highlighted for this hole section: 1. Be aware of ECD while drilling or reaming 2. Losses while increase mud weight (drilling secondary targets) 3. Low gravity solids buildup 4. Tight PVT monitoring for gas influx while drilling and tripping 5. Keep monitoring the connection, trip, and background gas for trends indicating any abnormal pressure 6. Torque and drag reduction 7. Coring operations 2 ] 998 , PRESSURE TESTING PROCEDURE All pressure testing will be carried out in compliance with the SSD Drilling Policy Version 2.0, AOGCC slope representatives to be notified of pressure testing operations 24 hours in advance if possible and given the option to witness the pressure testing. I . Pressure testing operations 1.1 Personnel safety No personnel are to be in vicinity of equipment or lines being subjected to test pressures, The SSD Representative must be satisfied, prior to commencement of pressure testing operations, that clear communication exists between all personnel Involved in the operation, 1.2 Testing procedure All BOP equipment tests will include a Iow pressure test of 250 psi before proceeding with the full pressure test. A satisfactory pressure test is represented by the test pressure held for 5 minutes after the pressure is established. Casing will be pressure tested for 30 minutes before drill-out as per AOGCC Regs. 2. Well Control Equipment 2.1 On installation of Hydril MSP 21-1/4", 2M diverter system on 20" conductor pipe, system shall be function tested. 2.2 On installation of 13-5/8", 10M BOP system on 13-3/8" casing: Annular Pipe rams Blind rams Pipe rams Choke manifold and choke & kill lines Kelly cocks Standpipe manifold 3,500psi 10,O00psi 10,000psi 10,O00psi 10,000psi 5,000psi 5,000psi Page 1 This test represents the maximum anticipated surface pressure to which the BOP would be potentially subjected during the course of operations at Red Dog #1. A test to these pressures is being conducted at this stage to enable any BOP problems to be identified, ensuring that time is available to repair and/or order new equipment before a test to 10,000 psi is essential for continuance of operations, It is imperative that the side-arm outlet beneath the test plug is open (and confirmed as such) during pressure testing operations. Burst rating of the 13-3/8", 68#, BTC is 5020psi. 2.3 While drilling 12-1/4" hole: Annular Pipe rams Blind rams Pipe rams Choke manifold and choke & kill lines Kelly cocks Standpipe manifold 3,500psi 5,500psi 5,500psi 5,500psi 5,500psi 5,000psi 5,000psi Above tests to be carried out every 7 days. The 5500 psi pressure test represents the maximum surface pressure. anticipated (5418 psi) while drilling the 12-1/4" hole section, tt assumes gas to surface, with formation pressure 12.5 ppg at 9,852 ft. 2.4 After running 9-5/8" casing and while drilling 8-1/2" hole. Annular Pipe rams Blind rams Pipe rams Choke manifold and choke & kill lines Kelly cocks Standpipe manifold 3,500psi 9,000psi 9,000psi 9,000psi 9,000psi 5,000psi 5,000psi Above tests to be carried out every 7 days. The 9000 psi pressure test represents the maximum surface pressure anticipated (8994 psi) while drilling the 8-1/2" hole section. It assumes gas to surface, with formation pressure 15.5 ppg at 12,740 ft. Page 2 2.5 After running 7" casing, prior to conducting DST. Annular Pipe rams Blind rams Pipe rams Choke manifiold and choke & kill lines Kelly cocks Standpipe manifold 3,500ps~ 9,000ps~ 9,000psi 9,000ps~ 9,000ps~ 5,000ps~ 5,000psi The 9,000 psi pressure test represents the maximum surface pressure anticipated during Red Dog #1 testing operations, RFT data obtained available prior to DST operations should be used to review the pressure testing requirements and amend if necessary. Full BOP test will be conducted prior to each DST. Page 3 RED DOG #1 Shut in Procedures SURFACE HOLE (21-1/4' 2,000# Hydril BOP/Diverter) 'SSD procedures will be followed to minimize any potential for a shallow gas kick. Sufficient hydrostatic column will always be maintained while drilling the well and the correct tripping procedures' will be followed while tripping in and out of the hole. If a shallow gas kick is .taken prior to setting surface casing, the gas kick will not be shut- in, but diverted through the diverter system. As mentioned above, there is considered to be a very Iow chance of enc6untering shallow gas. We have no high resolution seismic due to the proximity of the shore line, but we do have offset well information. The Point Thomson #4, East Mikkelsen #1 and Challenge Island #1 wells, did not drill any gas bearing formation in the surface hole. INTERMEDIATE-PRODUCTION HOLE (13-5/8' 10,000#.Hydril BOP Stack) According with BP Well Control Manual and SSD procedures, a well kick will be shut in and controlled at the BOP stack on hole sections below the surface casing. The "Fast Shut-in" is the preferred method of Shutting in a well. This method ensures that the well is safely shut in and the influx volume is minimised. The smaller the volume of influx, the lower will be the pressures in the wellbore and at surface throughout the kick control process. The first action when a primary indication of a kick (pit gain or increase in flowrate) is seen is to shut the well in. 'In order to implement the fast shut-in, the equipment should be set up as follows: · The remote operated choke closed and isolated by a high pressure valve inmediately upstream. (Ensure that the choke pressure can be monitored in this position). · One remote operated chokeline valve closed. (HCR valve). In the event that the well is flowing: 1- Open choke line valve(s) 2- Close annular preventer 3- Check that well is shut in 4- Record DP and CSG pressures 5- Notify Company Representantive 6- Proceed as directed It is the responsibility of the Drilling Supervisor to ensure that the Contractor is made aware of the procedures that should be initiated in the event of a well kick. Anchoraoe, AK 99603 {gO7) 2~3-~700 Fao( ~61-8537 DIRECTIOI4ALWEL5 PLAIT for SHARED SEI{~ICES DRILLING ~elf ......... : Red Dcg tl (Pl2A) Field ........ : Prud/loe Bay. PC Thompson Con~utat£o=..: Hinimu~ Curvature Units ........ : F~HT Surface La~..: 70.~751{102 ~ Sur~ac% bong.: 146.79Lt2574 W E~DCATZON~: - M.,ASI~ 2one: Legal Oe~cr~pt~on X-Coor~ Surface ...... : 1682 FSL 4507 FHL $34 T10N R21E UM 401725.0G Target ....... : 5174 FSL 985 FEA S21 T10~ RP1EUM %00100280 R~ .......... ~ ~671 FSL I058 FZL S21 TiO~ RlTE~ 400033.~1 Prepared ..... : 17 Dec 1998 Vert sect az.: 251.59 ~gnetlc Dcln: +28.82~ Scale Convergence.,: -0, ?4424410 Y-Comrd ' :';"' ' ; .... .; [ 5926300 ........................ ..'i.:.T.~. ...................... !~TATI Olg t~EASLFRHD iMCLI{ 13II~CT$ON VI~RT [CAL - D~i~TI{S IDENT~ ~ICATi ON DSPTH ANGLE A~ II~FOTH TVD SUB - SEA D8PART ~;ELLa{EAI~ X ~ PkCE ~ 0-00 O.OO 0.00 0.00 -44.80 KOP SUII./) 1/LO0 2000.00 0~00 35R,59 2000.00 1955.20 ~UILD I.S/L00 2~00.60 1.00 351,59 2099.99 2055.1~ BUILD 2.$/~00 2300.00 ~.SO 351.59 2299.75 2254.95 0,00 0.il0 N 0.00 0.00 N 0.00 0.87 0.86 N 0-t3 ~ 40LOad.R8 591~27.86 3.9] 3.B8 N 0.59 W 40~72%.48 5914~30,89 ~0.~3 9_92 8L O.OO gL o.oo 8L 1.oo ~L 1.50 8L 2.00 2400.00 7.00 36[.59 2399,24 2354.44 20.05 2500.00 LO.GO 351.59 2498,13 2453.33 34-g3 2600.00 tr.00 351.59 2596.3i 2551.31 54.76 2700.00 16.00 351.59 ~692.92 2648.12 79.~0 2800,~0 19.00 351.59 ~7~.28 2743~8 109.$7 2.93 W 401722.33 $9L414~.87 its 2.50 5,09 W 4~172~.35 59L&261.51 8~ 3.00 8,0L W 401717.70 59L4281.2~ 11.67 W 401714.36 59L4306.08 ~$ 3.00 L6,07 W 401~10,35 5914335.S~ EF 3.00 2900,OO 22,00 351,S9 288L.94 2837-14 30~0,00 25.00 351,59 2973.63 2920.83 ~&3.32 N 2t.19 W 40L705.68 5g143~0.~? HS 3.00 382.77 N 27.02 ~ &01700.36 591441G,0B HH 3,00 (Aaadrill (c)gS RDIPI2 3.2C ~:05 [~%! P) U i'1] I STATION ~ASURJBD IMCLN £DE~'TTIF[CATEON DEPTH 33Q0.00 25.00 3200.00 ~3Q0.00 3~_00 3400-00 37-00 ~500-00 40.80 DJR~CTION Sr~RTICAL-DEPTHS ANGL~ AZIMUTH TVD SHB-SSA 351.59 351.59 351.5'9 351.59 306~.11 ~Q18.31 3150.[4 33QS.34 3~34.47 31B9.67 3315,85 327i.07 3394.12 ~349.3~ 22~.37 332.33 390,~9 4~2,f4 COORDfAtATES-~RG~ ALASF. A Z<)~e 5 TO0~ DL/ : 2~5.6~ N 40.75 W 40%655.84 5914503.09 HS 3.00 ]2B.7~ N 4B.~l H 40~G80.67 5914556.33 ~ 3.00 386.19 N 5~-10 ~ 401672.93 591~613,87 HS B.00 44~.7~ ~ 66.2~ ~ 40166{.63 5914675.55 81 3,00 3600.00 ~3_00 3200.00 46.00 3BQO.OO 49.00 3900.00 51.00 4000.00 55.00 3S~.59 351.59 351.59 351.59 3~9,0k 3~24.21 518.~9 35~O.33 3495-53 588.9~ 3607.~8 ]563.0S 662.~g 3671.4~ 3626.68 739.S~ 3730,95 3686.15 820.22 513-51 N 75.89 ~ 401655.79 $91~741.21 ~ 3.00 $B2.6{ N $6.14 W ~0~6%6.%4 59~810.66 [q-S 655.57 N ~6.92 W ~0L$~,6L 591~583.7t I-IS 3.00 731.89 ~ 10B.21 W 401626.32 591~960.17 ~ 3.00 END 3/100 ~UIL0 TOP ~31,83 5~.96 4331,83 58.96 14102,~ 58,96 1~5B~,33 58.96 3~1.59 37B6.14 ~7%1.34 903.60 35'1.59 3802.79 3757.99 930.?~ 351.59 3905.93 3861~13 [70~.O9 351.59 S9~4,80 8900.0D 9~73.29 351.59 9194.80 9150.00 98gR.~ 893.88 N 132.1~ ~ 401604,4~ 5915122.{5 [-~ 3-00 9~0.73 N 1~6,13 ~ &O1B00.B$ 5915149.3~ ~ 3.00 1090.2~ N 161.19 W 401578.00 5915~19.~4 ~ 0.00 9782.2~ N L446.29 ~ 400406,02 ~92~026.3~ ~ Q.O0 DROP 2/100 15980.58 58.96 15~00,00 5B.57 15900,00 56,$7 16000,00 ~4,57 16L00,00 S2,57 35L.59 9810,17 9765.3? 10910,95 IO993.62 N_ 1595.81 W 400269,66 5925039.48 ~ O.O0 9820.24 g795.44 L0927,55 10SL0,0~ N 159B.2~ ~ 400267.4S 5925055.95 LS 2.00 9873.87 9.829.09 L/011,95 10893.53 N l$10.59 W 400256.19 5925139.57 L~ 2.00 995O.41 98~.~1 110g~.42 L0975.~2 N T~22.~S W 40024~.19 5925221.3~ LS 2.00 9989,80 994~,OO LlI~4,87 11054.7Q N 163~.~2 W 40023&.¢6 59253OL.02 LS 2.00 16200.00 50.57 16300.O0 48.57 16400-00 46.57 351.59 35t.59 351.59 351.59 351,59 351.59 351.59 10051.96 I.OflQT.L6 11253,2~ 11112.19 N 1645,87 10116.81 L0012.01 11329,3~ 11209.49 N 1657.0O 10326.74 10281.94 11543,~4 11~L9.~0 ~ l~8B.32 I0~01.55 10356.75 1k609.78 114~4.94 N 1047~.64 Z0433,84 11673,48 11547.95 N 10559.90 L0513.10 11934,44 11608.26 N 1698. O2 ~ 1707.34 ~l 1716.26 tN.. 400~24.01 5925375.64 LS 2.00 400213.86 5925454.09 LS 2.00 40020%.02 5925~27.20 LS 2.00 40019~,49 5925597.96 LS 2.00 400tB5,30 5925666.26 LS 2.00 Red, Dog ~3. (P12&I 9-$/8" CSG PT <[1> ~HD 2/L00 DRO2 DROP 2/i00 TOP RD-75 EbTD 2/1.00 DEOP TOP KO~ IAK TOP KI LLIAN .q KALE WALL TD Dec 1998 P~e 3 PROPOSED ~ELL PROFILH ~FSkSURED [~CLN DrRECTIQN ~6945.68 35,65 I7B44-13 36.65 k7100.00 34.54 i7105.2G 34.43 351.59 351.59 351.59 351.59 35L.59 TVD SUB-SEA DEPART L0594.80 10S50.O0 L1761.36 1L634.89 ~ 1720.19 ~ 400156,21 592~88~21 ~S 2.00 10594.80 lOSSO.O0 11761,36 11654.89 k~674,80 106~0.00 11818.75 11691.66 ~ ~7~.59 ~ 40014~.58 5925939.08 LS 0.00 L0724.80 1~6~0.00 ~185],81 117~6.34 N 1733.7l ~ 4~8143.90 5925973.83 LS 2,00 i?2OO.O0 32.5{ 17300_00 30.54 17~00.00 28.54 1750~_00 26.54 17533.48 351.59 10803,8G 10759.06 119~6,11 11778.08 N 351.59 ~0889.Q9 10844.29 i1958.41 11829,82 N ~749,01 W 4~0129.95 5926077.4~ LS 2.00 351.59 10976.09 10951,29 351.59 11064.76 11019.96 12053.93 119~4.B1 ~ [762.99 W 400117.21 5926172.14 LZ 2.00 351,59 11094.80 13050.Q0 12068.7~ 11938.9~ N 1765.15 W 400115.24 59~186.~0 LS ~.00 19GOO.Q0 ~4.54 17700,00 22.54 17800.00 20.54 3~1,$9 111~4.98 /1110.18 12097-0~ 351,$9 11246.66 Li201.86 12136.97 351.59 11339.67 112~4.87 351.59 11364.80 11320.00 ~1966.9~ N L769.29 W 400~11.~{ 12006.45 N 1775.13 W 400106.13 12042.76 N 17~0.Sq W 400L01,24 12051.94 N 178l.B~ W 400kO0;OO 12051.91 H 1781.86 ~ 400100,00 5926214.~6 L~ S9262~4,~3 ~S 1.afl 5926290,81 b~ 5926300.00 ~S 2.00 5926300,00 HZ X8120~75 20.00 351.5~ L1644.80 11600.00 18741.98 2O.0O 351.59 12224.80 12180.00 19082.51 2O.O~ 35L.59 %2544.80 12500.00 19188.93 2U.QO 35L.59 126(t,80 12600,00 19295.35 ~0.00 351.59 127i$.8~ 11700.00 11152.76 ~ 179~.76 W ~O0086.%1 5926¢00.59 ~S 0.00 12476.81 ~ 1844.67 12552.81 N 18~9.99 ~ 400037.86 592676~.68 HS 0.00 12548.82 N 1855.32 ~ 400033.03 5926797.75 O.O0 19295.35 10.00 351.59 1274~.$9 12700.00 12685.~3 12548.82 N 1855,3~ W 400033.01 5926797.75 0,00 (Anadri.][ (c)98 RDLP12 3.2C 4:0S Pi,{ P) ~K~> o SHARED SERVICES DRILLING . ii, , .4nod£ j ll Schlumberger' iii i i Red Dog #1 VERTICAL SECTION - !Sect ion at: 351.59 TVD Scale ' I ~nch = 2400 feat Oep Scale ' ! inch = 2400 feet ii i Lit, IlJ i (P 2A) VIEW .........~' i ' ". .... t I ur8~ll .... -".!"- ' '.. :' ~' -"":' ~'" ""' :'C- .~ - - '. .. - . .. - : ':. ...- : .. 3 _ _ ,, , 1200 " ~ ,.,,. . .. :.: ; : ,.,~.... Narker I~entificabinn MD BXB SECTN INF. L; ,.- ........ ,.:--.-,, A) 'KB 0 0 O O.O) :.:,'.. ' ~ ! 8) KOP BU]LO 1/i00 2000 ~000 0 O.O ~ =~--- - "'. :~ "..i -;:' -.... 4 ~-.. C] BUILD !.5/~00 2tOO ~lO0 ~ ~ I I ..... : ..,L.~-~ ~ o) ~U~LO e/~oo ~_~Oo ~0o ~ ~..~ ~ ............. - .... ~': E) BUILD 2.5/rOD 2_300 2300 lO 4.5 t F) 8UILD 37~00 2aO0 ~399 ~ 7.0 .... 6) ENO -WIO0 BbtlLD 4i32 ~803 931 58.9 1) DROP ~j~OO ~57B~ ~:10 ~ODt:l 58.9 ~ -,- ,. J} 9-5/I~' CSS PT <11> ~5~46 t0595 ~tT~ 35.5 ~ ~ .-.. ii. ~,~~ K} ENO ~/~00 O, OP ~69~1S ,0595 tt76~ ]5.6 {~ :" I LJ OROP ~/:~00 f71)44 [0675 t,8~9 25.5 .~!_~ N] TARGET ~~x~ 17827 13365 i2~83 20.0 ~ ~¢ P] ~O tg~g5 12745 ~2685 20.~ h~ -~ ............................................................, , 'fD~,¢[~'~ .......................................... ~_~ ..... ~ ... ~ _ ~'~-- ........ ~ ............ I [ I Sec~ ion Departure ~r~tl (c[98 ~Ol',',~"~',~ ~: ~ ~l ~i - - - .... ' ........................................... z ]> ]u 12/2'1/1998 10-44 7 ANADRILL DEC PAGE SHARED SERVICES DRILLING I I1 ' _ Marker Ident~ f~£al:ion MD N/S BUILD 2/tO0 ~300 4 N E) ,UILO ~.5/,00 2300 lO N F, 8UILO 3/100 2400 20 , 3~ G~ END 3/100 BUILD 4.~32 921 N 136 HI ~3-3/8" CSO PT <l I> 4332 ~090 N 161 g-5/8" CSG PT <11> ]8946 11635 N 1720 K) END 2/]00 DROP ~6~48 t]635 N ~720 L) DROP 2/100 ]7044 11692 N M) ENO 2/]00 OROP t7827 ~2052 N I782 O) 7" LINER PT <(I > ~9295 ~2549 N P] fO ~9~95 ]~549 N 1855 Fled Dog (P 2A) PLAN VIEW CLOSURE ' 12685 feet at Azimuth 351.59 DECLINATION' +28.826 (E) SCALE ' 1 inch : 2400 feet DRAWN ' ~7 Dec ~998 nadrY ]] Sch]umber,?r I ~! (Point) , ) ...... . .... ,.--,"-:- ; ....,. ..i.. z .. - · · ¢,· .. =-.,. .... : .... -:". ..... ~"; :ti !- I , ; . ," ..- ... ~ : : .. -: i, ~ ~ ... · "-'--r ; ""' .......... ' :?'"'"'; .... ! ! ~ '"'""" :'I ' i :: . ;;. '.. . ..... , ....... ;"..., · _ __ .. t ..... · .. I ; , -.~., ~ .....i ._ . ~,.~¢...i,. , ..... , ; 8400 7200 6000 4800 3600 2400 t200 0 ]~00 2400 3600 4800 <- WEST' EAST ~> M URPHY EXPLORATION & PRODUCTION COMPANY 131 SOUTH ROBERTSON STREET (701 12) P.O. BOX 6 1780 NEW ORLEANS, LA 70161-I780 (504) 561-28I I ~ FAX (504) 561-2837 ! December 14, 1998 0~ Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Red Dog # 1 Drilling Unit NE/4 Sec. 21-10N-21E, Umiat Meridian Beaufort Sea, Alaska Our O/A M-3741 Dear Mr. Johnston: Enclosed fred Murphy's original of the letter dated December 11, 1998, concerning pooling for referenced well. As promised in my fax of this date, I hereby submit to you Murphy's original of this letter for your file. We appreciate your willingness to accept the counterpart copies of this letter and hope that it/they will be better than would have a single copy which had been faxed around among the group's members. Very truly yours, William R. Gage, Jr., CPL Senior Landman WRG\G:LLAND\WPDATALALASKAXRED DOG\98\12 15A -- -- Enclosure CC: G. M. Shirley BP Exploration (Alaska) Inc. Attention: R. L. Skillem P. O. Box 196612 Anchorage, AK 99519-6612 David W. Johnston, Chairman/Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 December 11, 1998 Via Fax¢ (907) 276-7542 Re: Red Dog #1 Drilling Unit NE/4 of Section 21, Township 10 North, Range 21 East, Umiat Meridian Beaufort Sea, Alaska Dear Commissioner Johnston: We the undersigned, BP Exploration (Alaska) Inc., ARCO Alaska, Inc., Murphy Exploration & ProduclJon Company, Petrofina Delaware Incorporated and Chevron U.S.A. Inc., hereinafter referred to as '~the Parties", have dril ling and participating rights in the above referenced drilling unit; further we are the sole parlJes having such rights in the lan ds immediately adjoining referenced drilling unit. As participating parties in the drilling of the Red Dog #1 Well, the Parties have heretofore entered into certain agreements which determine the rights of the Parties to share in the potential costs, liabilities and produclJon that may be attribute d to all operations, including but not limited to, drilling, completing and plugging of the Red Dog #1 well and drilling unit. Pursuant to Alaska Statue AS 31.05.100 (c), the Parties have agreed to pool their respective interests within the above referenced drilling unit in those percentages determined by the aforementioned agreements among the Parties. By execution of this letter the Parties hereby affirm, confirm, acknowledge and agree, that their respective interests, within the above referenced drilling unit, have been voluntarily pooled pursuant to Alaska Statue AS 31.05.1 00. Time being of the essence in the signing and delivery of this pooling letter to the Commission, it has been prepared and distributed among the Parties by electronic means for reproduction, counterpart execution and delivery to the Commission. Therefore, it is requested that you recognize that the various copies of it which may be submitted to you are identical in content, although they may vary in appearance and accept them as a single document upon execution of such counterpart copies by all Parties. BP Exploration (Alaska)Inc. By: Title: Date: Chevron U.S.A. Inc. By:. Title: Date: Dog #1 Drilling Unit December 11, 1998 Page 2 Red ARCO Alaska, Inc. By: Title: Date: Petrofina Delaware Incorporated By:, Title: Date: Murphy~)~t~oduction Company By: Davrd M. Wood Title: Vice President Date: Dec. 14, 1998 Murphy document G:\LAND\WPDATAV~LASKA\RED_DOG\98\12_11 D.WPD ARCO Alaska, Inc. Post Office Box' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12/5 December 14, 1998 David W. Johnston, Chairman/Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3t 92 Re: Red Dog #1 Drilling Unit NE/4 of Section 21, Township 10 North, Range 21 East, Umiat Meridian Beaufort Sea, Alaska Via Fax# (907) 276-7542 Dear Commissioner Johnston: We the undersigned, BP Exploration (Alaska) Inc., ARCO Alaska, Inc., Murphy Exploration & Production Company, Petrofina Delaware Incorporated and Chevron U.S.A. Inc., hereinafter referred to as "the Parties", have drilling and participating rights in the above referenced drilling unit; further we are the sole parties having such rights in the lands immediately adjoining referenced drilling unit. As participating parties in the drilling of the Red Dog #1 Well, the Parties have heretofore entered into certain agreements which determine the rights of the Parties to share in the potential costs, liabilities and production that may be attributed to all operations, including but not limited to, drilling, completing and plugging of the Red Dog #1 well and drilling unit. Pursuant to Alaska Statue AS 31.05.100 (c), the Parties have agreed to pool their respective interests within the above referenced drilling unit in those percentages determined by the aforementioned agreements among the Parties. By execution of this letter the Parties hereby affirm, confirm, acknowledge and agree, that their respective interests, within the above referenced drilling unit, have been voluntarily pooled pursuant to Alaska Statue AS 31.05.100. Time being of the essence in the signing and delivery of this pooling letter to the Commission, it has been prepared and distributed among the Parties by electronic means for reproduction, counterpart execution and delivery to the Commission. Therefore, it is requested that that you recognize that the various copies of it which may be submitted to you are .identical in content, although they may vary in appearance and accept them as a single document upon execution of such counterpart copies by all Parties. BP Exploration (Alaska) Inc. By: Chevron U.S.A. Inc. By: Title: Title: Date: Date: AR3B 6003-93 242-2603 Red Dog #1Drilling Ur December 14, 1998 · :- Page 2 Petrofina Delaware Incorporated By: Title: Date: Murphy Exploration & Production'Company By: Title: Date: 14 '98 Oa:38PM ~P LXPLU~HI±UM HK r,zxo BP Exploration (Aleaka) Inc. 900 East Benson Boulevard P. O, Box 19{~612 Anchorage, Alaska 99519-0955 Tel. (907) $64-5446 To: COMPANY: FAX TRANSMITTAL FAX NUMBER: FROM: PHONE: FAX NUMBER: Urgent MESSAGE: 564-5132 Q FYI Please reply Confidential ~____PAGE(S) TO FOLLOW - (Not Including this "Cover Sheet") Contact Loretta Dufour at (907) 564-5446 if them are problems with this transmittal, Thank you. Rev. 08113/98. I.,JD ~ 1~ ~98 0~:38PN BP ~XP~©R~TI©~ ~K David W. Johnston, Chairman/Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 -,3192 December 11, 1998 Via Fax~ (907) 276-7542 Red Dog #1 Drilling Unit NE/4 of Section 21, Township 10 North, Range 21 East, Umiat Meridian Beaufort Sea, Alaska Dear Commissioner Johnston: We the undersigned, BP Exploration (Alaska) inc., ARCO Alaska, Inc., Murphy Exploration & Production Company, Petrofina Delaware Incorporated and Chevron U.S.A. Inc., hereinafter referred to as ~the Parties", have drilling and participating rights in the above referenced ddlling unit; further we are the sole parties having such rights in the lands immediately adjoining referenced drilling unit. As participating parties in the ddtling of the Red Dog #1 Well, the Parties have heretofore entered into certain agreements which determine the dghts of the Parties to share in the potential costs, liabilities and production that may be attributed to all operations, including but not limited to, drilling, completing and plugging of the Red Dog #1 well and ddlling unit. Pursuant to Alaska Statue AS 31.05.100 (c), the Parties have agreed to pool their respective interests within the above referenced drilling unit in those percentages determined by the aforementioned agreements among the Parties. By execution of this letter the Parties hereby affirm, confirm, acknowledge and agree, that their respective interests, within the above referenced drilling unit, have been voluntarily pooled pursuant to Alaska Statue AS 31.05.100. Time being of the e.~.sence in the signing and delivery of this pooling letter to the Commission, it has been prepared and distributed among the Parties by electronic means for reproduction, counterpart execution and delivery to the Commission. Therefore, it is requested that that you recognize that the various copies of it which may be submitted to you are identical in content, although they may vary in appearance and accept them as e single document upon execution of such counterpart copies by all Parties, Chevron U,S,A. Inc, DEC 14 '98 02:39PM BP EXPLORATION AK P.3/6 Page 2 Red Dog #1 Drilling Unit December 11, 1998 ARCO Alaska, Inc, By:_ Title:, Date: Petrofina Delaware Incorporated By:_. Title: Date:__ Murphy Exploration & Production Company Ely:__ Title:, Date:__ 'MURPHY E×plo~ation & Productia.n 'Company.- 131 Sout;h R6be'rtso~ .Strae'~ New OrleDn~, 'LA 70112 · P.: O, B~x 61780 , New Or~ans, LA FRDNTIER EXP LORAT, ION 'D~ PA RIME'N? FAX NUMBER': (504) ~6 I ''2.221 BATE FROM TEL. _D_ecember 14._1B9.8', .__ · W~ 11 i_~m. Rd_ G~e .,'~' dr~ . ..,' !50.4_)..~6 ~- ~s ~8 '_ ~ , ,. .. TO, COMPANY' FAX # · · : , ~O&GIiC " · . N,UMB~R, OF RAGES (including cover. 'sheet)~' ,, . 3'__~ " , (For 'a ret~ansmi:~sion..dua to .missing: pages':or other pr6blems,'"c~.l 1 (fi04)'$61-2,797. as ,soon as possible.) ' ' " · ' . "' , , DI'SPOSITION oF 'ORIGINAL: ,_~et,urn t~ R0o~763 , " ,, -. ; . . -. · , . , ,. ~ . Gentl~nen: :Per r~que,~ et'Mr, s,Idllern, mc1Os~'fin~t Mu~hY's r~rod~tion of ~s digit~y distributed 1~ 121l 1/gS whi~ h~ be~ ~ed on behalf of Mushy ~i~ration ~ Pro,du~On Comply', t.~ ~oaly s~d our o~l.ofthis l~er by m~l to Mr, ~o~wn .so h! ~ii have it for tM files o~ ,. , .. DEC 14 , '. DaVid W. Johnston1, Chalnna,/Commlssioher . Alaska O.it and Gas Consen~atl~n Commission . ~nO'l'Percupirm Drtw ,. Anchorage, Alaska 99501~3192 · ., , , · Re: ": , · , Red Dog #1 D~illir~§ Unit - ". NE/4 of Secl~on 21, TQwnsNp 10 North, Range 21 ~Ea~-i, Umiat Meridian Beaufort Sea, Alaska .-. · ., . . · , · .' . . Dear Commissioner Johnston: · , De=ember 11,' 1998 'V'm. Fax~ (907) :;276-7542 · - , · , . -we'.,th. Undersigned, i P.Exr l'orat an.(Alaska)"lne., ARCO tn ., Mum~Y,'~lor~oa & . ' ' ~U~n Com~ny, Pe~flna Da~m Ink.rat.'and Che~ U.S ,A. Inc.',-hemina~er referred ', ~ as .~e Pa~es", have d~l ling and pa~ipa~ng-~gh~ in the abeffe, m~emn~ed d~,lll~ un~; ~Aher' --- we are ~e ~la'pa~ ha~ su~ ~h~ · ~e an ds Imm~ia~iy adjoining refere~ ,drilling. un~.. ' ~ pa~paBng pa~ in ~e drilling of ~e Red Dog ~1 'Wall. ~a PaCes,have her~ofom entered . Into ~a~in agreeme~ ~ich determine the ~ghb af ~e Pa~ I~ share in the.pinotol cu~." · ' · I~bi~a~ and pr~u~on ~a may be. eMb~ d ~ all a~am~ns, Includ~g b~ notiimE~d.to', d~ll.a, · eompi~ng and plugging of ~e Red D~g ~1 well and driili~g unE ._ . 'Pum,uant. to Alas~ S~e AS 31:05,1.00 (c),'~e Pa~e; have agreed. ~ pool their,~pe~e Interes~ ~hin ~a above 'referenced d~lling unit in ~e percen~g~ de~ined'~ ~e .. aforemen~aned agmemen~ among the Pa~s. ' .- ,, ., .- ay e~ecNfio n of ~ le~r the Pa~as hereby affirm, ~nfi~. ackn~ledg~ a~ agme~ ~et their r~~e inte~, ~in ~e aboVe m~mnoed dfitljng,unit~.have'bea~ ~la~ pooled pu~ent"" '- . . . ~ . . . ta Alaska S~e ~ 3~ ,05.10D ....... ,, , . .... , Time being ef ~ e~en~e'ln tho signing and 'deliv~ of fflis pooling leEer'ta ~e Co'minion, ff ' ,..,- "has been prepared and distribu~d among ~e Pa~eS by' ~le~anie means ~r reprodu~an., c~unmrpa~ e~e~aan and deljve~ ~ the'Cammi~ien. Therefore,' E ~. reque~ed ~at y~- mc~nize ~at ~e vahous copies of ~ which may be .s~bm~d td you am idenfi~l In ~n~nL e~ough they may yaw in appearance a~ acceptthem as a =i~gle document upon execution of. - su~ caunm~ capias by all Pa~es. BP EzP. leratialt (Alaska) Inc. Date[__ '_ ~ ......... · .. '. Chavre~l U;~:A, I~c, .. .~y:-__ _ _ _ _ ... ~__ · Title:_ __ , Date:. " ' · · · , ,. ; · , . · · , -:-.-. , Dag #1 Drilling UnE December 11, .la98 ARCO Alaska, inc, By: _ _~. . Ti'de~ ,, _ ~ . Date:. = . i 1 Red Petrofina Delaware. Im;orporatad ByL .. _ Title: = r-- --. -- .'. Date'._ ,_ _ ,. · l~u~iOnBy: ' Company David , M. Wood _.. Title: V~ce president .___. .. '.Date'.. De_c. 1~4. · . Murphy document G:~LAND~P :)AT^~LASlG~F.D_DOGXt~8~,12..11D,WF'D BP EXPLORATION December 3, 1998 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 David W. Johnston, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Request for Exception to the Provisions of 20 AAC 25.055 - Red Dog #1 Well Dear Commissioner Johnston: BP Exploration (Alaska) Inc. hereby applies for an exception to the provisions of 20 AAC 25.055 for the drilling of Red Dog #1 Well (the Well), for which the proposed location is: 1. Surface Location: 1987' North of the South Line, 4043' West of the East Line, Section 34, Township 10 North, Range 21 East, Umiat Meridian. 2. Target Location: 1745' South of the North Line (581' South of the North Lease Line - ADL 377013), 1594' West of the East Line (7992' West of the East Lease Line - ADL 377013), Section 21, Township 10 North, Range 21 East, Umiat Meridian. 3. Total Depth Bottomhole Location: 1256' South of the North Line (93' South of the North Lease Line - ADL 377013), 1708' West of the East Line (8108' West of the East Lease Line - ADL 377013), Section 21, Township 10 North, Range 21 East, Umiat Meridian. The owners and operators of all governmental quarter sections directly and diagonally offsetting the proposed location of the Well are BP Exploration (Alaska) Inc., Chevron U.S.A. Inc., Arco Alaska, Inc. and Petrofina Delaware, Incorporated. The plat required by the regulation is attached as Exhibit 1. The verification required by the regulation is attached as Exhibit 2. A copy of the notification to the owners and operators is attached in the package and is designated as Exhibit A. If you have any questions or require additional information, please contact R. L. Skillern at 564-5567. Sincerely, ,p~~o~ion (AI~. ska) I'l~c. E. ~. Zse¢c~ky, J[.' Land Mgnager - Alaska 0il l Gas Cons. Commission Anchorage enc. DATE: SCALE: November 1998 1" = 2,000 Feet SHEET: lofl EXHIBIT 2 VERIFICATION OF APPLICATION FOR SPACING EXCEPTION RED DOG #1 WELL Floyd Hernandez, Senior Drilling Engineer for BP Exploration (Alaska) Inc., does hereby verify the following: 1. I am acquainted with the application submitted for the drilling of the Red Dog #1 Well. 2. I have reviewed the application submitted for the exception to 20 AAC 25.055 and all facts therein are tree. 3. I have reviewed the plat attached as Exhibit 1 and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this ~ day of December, 1998. Floyd Hemand~zf Senior Drilling Engineer STATE OF ALASKA THIRD JUDICIAL DISTRICT 1998. SUBSCRIBED AND SWORN TO before me this ~ ... ..~ t#lllllllllJl~" ~"'~ day of December, ~~~ y ~p~~LiC ~~~~(~R ALASKA My commission expires' I~. _Pmmmi~ ExI3ires Matc~ 12, 200O EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Mater of the ) Request of BP Exploration (Alaska) ) for an Exception to the Provisions ) of 20 AAC 25.055 - RED DOG 4/1 ) ) AFFIDAVIT OF R. L. SKILLERN STATE OF ALASKA THIRD JUDICIAL DISTRICT R. L. Skillern, being first duly sworn, upon oath, deposes and states as follows: 1. My name is R. L. Skillern. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Landman for the well operator, BP Exploration (Alaska) Inc. 3. Pursuant to 20 AAC 25.055 (b), BP Exploration (Alaska) Inc. (BP), the well operator, prepared a Notice of Request for an Exception to the Provisions of 20 AAC 25.055. A copy of this notice is attached, hereto as Exhibit A. 4. On December ~4M , 1998, pursuant to 20 AAC 25.055(b), BP sent a copy of said notice by registered mail to the last known address of each owner and operator of governmental quarter sections directly and diagonally offsetting the quarter section of the proposed location of the oil well, and has notified the appropriate departments within BP Exploration (Alaska) Inc. Attached hereto as Exhibit B is an affidavit of Mailing of Notice. Subscribed and sworn to this(~'H4 day of December, 1998. STATE OF ALASKA THIRD JUDICIAL DISTRICT R LERN The foregoing instrument was acknowledged before me this December, 1998, by R. L. Skillern. day of Notary Public, State of Alaska My Commission Expires: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 3, 1998 EXHIBIT A Chevron U.S.A. Inc. Attn: Corry Woolington 1301 McKinney Houston, Texas 77010 Petrofina Delaware, Incorporated Attn: J. Peter Tower 14950 Heathrow Forest Pkwy., Suite 300 Houston, Texas 77032 Arco Alaska, Inc. Attn: Jim Ruud 700 G Street Anchorage, Alaska 99501 Notice of Request for Exception to the Provisions of 20 AAC 25.055 Red Dog #1 Well Gentlemen: Pursuant to the requirements of 20 AAC 25.055(b), BP Exploration (Alaska) Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25.055(a)(1). Specifically, the exception location applied for will be as follows: 1. Surface Location: 1987' North of the South Line, 4043' West of the East Line, Section 34, Township 10 North, Range 21 East, Umiat Meridian. 2. Target Location: 1745' South of the North Line (581' South of the North Lease Line - ADL 377013), 1594' West of the East Line (7992' West of the East Lease Line - ADL 377013), Section 21, Township 10 North, Range 21 East, Umiat Meridian. 3. Total Depth Bottomhole Location: 1256' South of the North Line (93' South of the North Lease Line - ADL 377013), 1708' West of the East Line (8108' West of the East Lease Line - ADL 377013), Section 21, Township 10 North, Range 21 East, Umiat Meridian. A copy of the request is attached. Sincerely, E. P. Zsele,~zky, Jr. Land Mamfger - Alaska enc. EXHIBIT B TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) Request of BP Exploration (Alaska) Inc. ) for an Exception to the Provisions of ) 20 AAC 25.055 - RED DOG #1 ) ) AFFIDAVIT OF MAllING OF NOTICE STATE OF ALASKA THIRD JUDICIAL DISTRICT SS. Loretta J. Dufour, being first duly sworn, upon her oath, deposes and says: I am a citizen of the United States of America over the age of 19 years, and em~Elpyed as a administrative assistant for BP Exploration (Alaska) Inc. That on the ~-7'/-c day of December, 1998, I sent a true and correct copy of the E. P. Zseleczky, Jr. December 3, 1998 Notice of Request for Exception to the Provisions of 20 AAC 25.055 via United States Registered Mail, to: Chevron U.S.A. Inc. Attn: Corry Woolington 1301 McKinney Houston, Texas 77010 Petrofina Delaware, Incorporated Attn: J. Peter Tower 14950 Heathrow Forest Pkwy, Suite 300 Houston, Texas 77032 Arco Alaska, Inc. Attn: Jim Ruud 700 G Street Anchorage, Alaska 99501 ,/. DATED at Anchorage, Alaska, this ~{' day of December, 1998. oretta J D o AND SWORN TO before me this ~"~g/e/day of December, 1998. Notary Public, State of Alaska / / My Commission Expires: December 7th, 1998 Mr Blair Wondzell AOGCC 3001 Porcupine Drive, Anchorage, AK 99501 CONFIDENTIAL Ref.: Red Dog #1 Exploration Well Dear Sir, We expect to begin drilling operations on our Red Dog #1 exploration well sometime between December 23rd 1998 and January 15th 1999. The well is being classified "Confidential" by BPX and I would appreciate any assistance in helping to maintain confidentiality. The permit application contains the names and contact numbers for the BP Drilling staff involved with the Red Dog operation. The geological contact will be: Jerry Siok Senior Geologyst Tel: 564-5199 Siok will co-ordinate the submission of all required data at the completion of our operations. We will also be submitting a confidential summary of operations as required. Yours sincerely, Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska)lnc SUMMARY OF OPERATIONS WELL: Red Dog # 1 LOCATION: Surface: Target: T.D.: 1987' FSL 4043' FEL S34 T10N R21E UM 3535' FSL 1593' FEL S21 T10N R21E UM 4024' FSL 1708' FEL S21 T10N R21E UM ESTIMATED START: December 23, 1998 DRLG OPS DAYS TO COMPLETE: 101 days (72 days drill, core and log; 27 days testing; 2 days P&A) CONTRACTOR: NABORS 28E MAX ANGLE/AZIMUTH/KOP/BUILD/MAX DEP: 59.65 deg / 346.74 deg / 2000 ft / 3 deg/100 ft / 12942 ft Ground level elevation is 8.1' AMSL. KB to ground level elevation is 35'. Close Approach Wells - None Drlling Hazzards - 1) No H2S or CO2, 2) No Shallow Gas, 3) Abnormal Pressure* *High overpressures have been encountered in all wells drilled in the Pt. Thomson area. Expected reservoir pressure is 12.7 ppg. Maximum pressure may be up to 15.5 ppg if the wellbore tags the Shale Wall. EXPECTED PORE PRESSURES AND FRACTURE GRADIENTS: Depth ('TVDBR'F) Strata / Casin.q Point Pore pressure Fracture Gradient (ppg EMW) (ppg EMW) 0'-7000' Tertiary 9.1 14.0 7000'-9190' Tertiary 9.1-10.5 16.6 9190'-10720' Canning Fm. 10.5-12.5 17.2 10720'-11640' Brookian Fm. 12.5-13.0 17.3 11640'-12740' Kodiak-Killian-Shale Wall 13.0 --> 15.5 17.8 CASING PROGRAM: Hole Csq Wt(Ib/ft) Grade Conn Lenqth Top 30" 20" 91.5# H-40 BTC 80 40 16" 13-3/8" 68# L-80 BTC 4315 40 12-1/4" 9-5/8" 53.5# P-110 ILHC 6000 40 12-1/4" 9-5/8" 47# P-110 ILHC 10060 6040 8-1/2" 7" 32# P-110 NSCC 3568 15950 Btm ('MD) 120 4355 6040 161OO 19518 LOGGING PROGRAM: Open Hole- 16" Hole: 12-1/4" Hole 8-1/2" Hole: Cased Hole LWD (GR-RES) LWD (GR-RES) WIRE LINE: PEX · -GR (NGS) w/2 arm caliper · -Array Induction Tool/SP · -Micro Resistivity · -LDT Density · -CNLg Neutron DSI Sonic (c&s) LWD (GR-RES-DENSITY-NEUTRON-RAB-SONIC) WIRE LINE: PEX · -GR (NGS) w/2 arm caliper · -Array Induction TooI/SP · -Micro Resistivity · -LDT Density · -CNLg Neutron DSI Sonic (c&s) CMR FMI RFT Equivalent Side Wall Core VSP CBL-VDL in 7" Liner OPERATIONS CONTACT: Principal Contact: Alternate Contacts: Floyd Hernandez Gabriel Higuera Work Phone- 564-5960 Home Phone- 696-8971 Pager- 275-5856 Work Phone- 564-5284 Home Phone - 248-0118 Pager- 275-8609 Due to the confidential nature of this well, please limit communications to the above 2 people. At least one will be available at all times until the end of operations. PROPOSED DRILLING PROGRAM WELL: Red Dog #1 Ice construction from Badami to the Red Dog #1 well location is planned for Dec 6t~ through Dec 17t". Once ice construction is completed, the Nabors 28E Rig will be moved along the ice road to the Red Dog #1 location. Drilling Operations: (All depths are approximate) The ice pad will be constructed and a well cellar excavated before the rig arrives on location. The conductor hole will be pre-drilled and the 20" conductor set and cemented before the rig's arrival. Move in, rig up. Accept rig for operations. Nipple up diverter and function test same. Drill 16" hole to casing point. Full mud logging facilities will be on location from spud to TD. Run and cement 13-3/8", 68# casing to surface. Perform Wellhead Stability Treatment and Annular Isolation if no cement seen at surface on primary cement job. Install blowout prevention equipment consisting of 10,000 psi W.P. pipe rams, blind rams, and 5,000psi annular preventer. The initial BOP test of 10M equipment will be conducted to 10,000 psi; subsequent tests will be conducted to maximum surface pressure anticipated in the current hole section. Maximum anticipated possible bottomhole pressure is 10,268 psi (15.5ppg EMW) at 12,740' TVD. This information is based on offset well data and seismic-data interpretation. Maximum possible surface pressure is 8,994 psi based on a gas column to surface from 12,740' TVD. The transition from normal to abnormal pressure gradient is prognosed at approximately 6800'TVD. Formation leak-off tests will be performed 20' below the 13-3/8" and 9-5/8" casing shoes. The well will be a "S Shape" hole, Kick off depth at 2000 ft, Maximum angle 59.65 deg. 12-1/4" hole section TD will be reached at 9,852' TVD (into the transition zone). Run logs. Run 9-5/8", 47-53.5 Cf ILHC casing string to within 10' of 12-1/4" TD and cement with Class G cement. If needed, the annulus would be used for injection of waste fluids and freeze protected. Drill 8-1/2" hole to Base Red Dog. Run logs. Plug 8-1/2" open hole section back to 9-5/8" casing shoe. Drill 8-1/2" hole to Core Point. Core 180 ft and drill to TD at 1 9518 ft. Run 7" Liner. It will be fully cemented using Class G cement. The well will be completed with a 7"x4-1/2" production packer and 4-1/2" completion string with two Gas Lift Mandrels. Well Test will be conducted with the rig off location and any fluids produced from the well will be hauled to Badami facilities. Fluids and cuttings incidental to the drilling of the well will be transported to Badami (Primary Disposal Facility). As a contingency those fluids could be injected on-site, down the 13-3/8" x 9-5/8" annulus once available. The well will be suspended or abandoned as per the attached schematics. The pad will be cleaned up of any surface debris. The nearest offset well is some 3.1 miles away, hence no close approach data is included in this package. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. MUD PROGRAM' Red Dog#1 MUD SPECIFICATIONS- SURFACE HOLE Surface: Mud Weight: ppg 9.0 Funnel Viscosity sec/qt .--300 YP Ibs/100ft2 40 - 60 10 sec Gel lbs/100ft2 30 - 60 10 min Gel lbs/100ft2 60 - 80 pH - 9- 10 APl Fluid loss mi/30 min 15-25 Solids % MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to 10000' TVD: LSND Gel/Polymer System Mud Weight ppg 9.2-12.8 Yield Point Ibs/100ft2 8 - 12 Plastic Visc. 10 - 20 APl Fluid Loss mi/30 min 12 - 8 pH 9.0 - 9.5 Solids % <10 MUD SPECIFICATIONS-PRODUCTION INTERVAL: Casing point: 9.2 - 9.5 <100 20 - 40 15 - 20 20 - 30 9-10 10-15 <8 Mud Weight ppg 12.8-15.8 Yield Point lbs/100ft2 10 - 20 Plastic Viscosity 15 - 25 APl Fluid loss mi/30 min 4 - 8 pH 9.5 - 10.5 Solids % 10 - 23 Pore pressure prediction techniques and observation of hole conditions will be used to increase mud weight in line with increases in bottom hole pore pressure. Keeping a safe overbalance of +/- 200psi is planned, this equates to a mud weight approximately 0.3 ppg over pore pressure EMW at 12,640 TVD. Disposal Cuttings Handling: Cuttings should be hauled to Badami Facilities. Fluid Handling: All drilling and completion fluids are planned to be hauled to Badami Facilities. However, those can be annular injected once injection is available. Request to have Red Dog #1 well for annular pumping. Request to AOGCC for Annular Pumping Approval for Red Dog//1' 1. Approval is requested for Annular Pumping into the Red Dog #1 13-3/8" x 9-5/8" casing annulus. 2. The base of the permafrost for the Red Dog #1 well is approximately 1600' TVD. There are no known freshwater aquifers in the vicinity of the Red Dog #1 well. There are no domestic or industrial use water wells located within one mile of the project area. 3. The receiving zone to which the fluids will migrate is within the Upper Brookian Sequence in the Sagavanirktok formation. The depth of this zone is greater than 3900' TVD. Expected operating pressure while injecting is between 800 psi and 1100 psi. 4. The drilling wastes to be disposed of during the this operation can be defined as drilling mud, cement contaminated mud, rig wash fluids, waste water (from rig boiler blowdown, mud & cement rinse of associated rig equipment), and formation fluids. A maximum volume of 35,000 bbls of waste slurry with a maximum slurry density of 17 ppg will be disposed of down the Red Dog #1 annulus. 5. The 13-3/8" casing shoe will be set at 4355' MD (3918' TVD) which is below the Permafrost, below any possible freshwater aquifer, and within the Sagavanirtok Formation. 6. The burst rating (80%) for the 13-3/8" 68# L-80 BTC casing is 4016 psig while the collapse rating (80%) of the 9-5/8" 47# P-110 ILHC casing is 4240 psig. The break down pressure at the casing shoe is expected to be between 12.5 ppg to 13.0 ppg equivalent mud weight. 7. The Calculated Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 1000 psi for a 14.5 ppg fluid in this well (Assumes worst case in which 9-5/8" casing is filled with gas). MASP = 4016 psig - ((fluid density ppg - 1.9) X 0.052 X 13-3/8" Casing Shoe TVD) 8. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. 9. If the well is tested, hydrocarbon fluids may be injected back into the reservoir or down the 13-3/8" x 9-5/8" annulus. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Point Red Dog #1 0 0 Submitted for 1999 Thomson DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. CEMENT PROGRAM 13-3/8" SURFACE CASING SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: Permafrost Type 'E' 12 ppg TAIL CEMENT TYPE: Premium with 2% CaC115.8 ppg CENTRALIZER PLACEMENT: 1. Run one solid rigid centralizer per joint for the first 15 joints. CEMENT VOLUME: 1. Lead slurry from Base Permafrost to surface w/350% excess. 2. Tail slurry from TD to Base Permafrost with 50% excess + 80' float joint 9-5/8" INTERMEDIATE CASING SPACER: 70 bbls MSC4 spacer CEMENT TYPE: Premium 15.8 ppg ADDITIVES: 0.2% CFR-3+ 0.4% Halad 344 + 0.1% HR-5 OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 to 14 bpm. CENTRALIZER PLACEMENT: 1. Run one solid rigid centralizer per joint from the shoe to 1000 ft above the shoe. CEMENT VOLUME: 1. Cement up to 1000' above shoe with 30% excess on caliper volume 7" LINER SPACER: 70 bbls MSC4 spacer CEMENT TYPE: Premium 15.8 ppg ADDITIVES: 0.2% CFR-3 + 0.4% Halad 344 + 0.1% HR-5 CENTRALIZER PLACEMENT: 1. Run two turbulators per joint across the entire liner. LINER CEMENT VOLUME: 1. Open hole caliper volume+ 30% excess. 2. 150' height of cement above 7" liner hanger. 0009 I, 000~ [ 0001~ ~ 000~[ 000~ L ..................... 000 I. I. ......... L ............ ,~ ........ · ..... 0000 I, . · - ..................... '-- - 0006 0'81. O'ZI. 0'91. 0'c31. 0'~1. 0'81. O'gl. 0'1.1. 0'01. 0'6 (gad) aunssaud auod ....................... 0008 O00Z ................ 000~ 0O08 ................... O00Z~ ~ ............ 000[ 0 0'8 0'/_. (.L-I) QM. OOQ 031:1 .LV Q;I.LO;idX=1 =ll:lNSS=il:ld 31dn.l. OVl:ld QNV =II:INSS3I::Id 3ElOd RED'DOG #1 EXPLORATION'WELL CASING DIAGRAM 20" Conductor ~ 120' MD 13-3/8" CSG 68# L-80 BTC · 9-5/8" CSG 47-53.5 # P-110 ILHC · 7" LINER 32# P-110 NSCC I~ 4,355' MD- 3,918' TVD · 16,100' MD- 9,852' TVD 19,518' MD - 12,740' TVD PROPOSED CASING DESIGN FOR RED DOG #1 WELL All calculations utilized in the casing design for this well are based on parameters and guidelines set in the BP Casing Design Manual. The following table shows the minimum safety factors found during the design. Besides, one page summary for each casing string with a short description of each Icad is enclosed. Casing String Specification Interval (ft) Drift Dia. (in) Minimum Safety Factor BURST COLLAPSE AXIAL TRIAXlAL Surface Casing 13 3/8", 68.00 Ibm/ft, L-80 BTC, L-80 40-4355 12.259 Intermediate Csg 9 5/8", 47.00- 53.5 Ibm/ft, P-110 ILHC, P-110 40-16100 8.625 A Production Liner 7", 32.00 Ibm/fi, P-110 NSCC, P-110 15950-19518 6.000 A 2.30 L 1.31 2.67 F 2.29 1.48 L 1.33 1.91 1.77 2.27 B 1.24 4.41 1.76 B Conn Burst L Conn Leak F Conn Fracture A Alternate Drift I SURFACE CASING (RED DOG #1) 13-3/8" 68# L-80 BTC i LOAD DESCRIPTION DESIGN FACTOR DEPTH Critical Load in Red BP MINIMUM ~ ACTUAL BURST 1. GAS KICK 2. PRESSURE TEST 3. ANNULAR INJECTION 4. BUMP PLUG 70 bbl gas kick (12.7 ppg) while drilling at 16100 ft (TD 12-1/4" hole) with 12.8 ppg MW. Casing pressure test at 2000 psi over 9.3 ppg MW. Annular injection (11.5 ppg fluid) through 13-3/8"x9-5/8" annulus with 1500 psi. Bump plug with 1000 psi while displacing cement with 9.3 ppg MW. 1.15 2.30 4355 ft COLLAPSE '1. LOST ClRCULATION 2. CEMENTING Lost returns at 16100 ft (TD 12-1/4" hole) with 12.8 ppg MW. Mud column drops until equalize normal formation pressure (8.5 ppg pore pressure). Cementing operation, tail slurry 15 ppg and lead slurry 14.6 ppg. Displacement fluid 9.3 ppg MW. 1.00 1.31 4043 ft AXIAL LOADS 1. RUNNING IN HOLE 2. OVERPULL FORCE 3. BUMP PLUG 4. SERVICE LOADS Running casing at 5 ft/sec. 100.000 lb overpull to work pipe. Bump plug with 1000 psi while displacing cement with 9.3 ppg MW. 1.60 2.67 2000 ft I INTERMEDIATE CASING (RED DOG #1) 9-5/8" 47-53.5# P-110 ILHCI LOAD DESCRIPTION DESIGN FACTOR DEPTH Crltical Load in Red BP MINIMUM I ACTUAL BURST 1. GAS KICK 2. PRESSURE TEST 3. TUBING LEAK 4. BUMP PLUG COLLAPSE 1. LOST ClRCULATION 2. CEMENTING AXIAL LOADS 1. RUNNING IN HOLE 2. OVERPULL FORCE 3. BUMP PLUG 4. SERVICE LOADS 70 bbi gas kick (15.6 ppg) while drilling at 19750 fl (TD 8-1/2" hole) with 15.8 ppg MW. Casing pressure test at 3800 psi over 12.8 ppg MW. Near surface tubing leak, 0.15 psi/ft fluid gradient inside tubing and 8.5 ppg packer fluid. Bump plug with 1500 psi while displacing cement .with 12.8 ppg MW. 1.15 1.48 16100 ft Lost returns at 19750 ft (TD 8-1/2" hole) with 15.8 ppg MW. Mud column drops until equalize normal formation pressure (8.5 ppg pore pressure). Cementing operation, 15.8 ppg slurry, displacement fluid 12.8 ppg MW. 1.00 1.33 8018 Running casing at 5 fl/sec. 100.000 lb overpull to work pipe. Bump plug with 1500 psi while displacing cement with 12.8 ppg MW. PRESSURE TEST 1.40 1.91 2000 I PRODUCTION LINER (RED DOG #1) 7" 32# P-110 NSCC i LOAD DESCRIPTION DESIGN FACTOR DEPTH critical Load in Red BP MINIMUM I ACTUAL BURST 1. PRESSURE TEST 2. TUBING LEAK 3. BUMP PLUG Liner pressure test at 3000 psi over 15.8 ppg MW. Near surface tubing leak, 0.15 psi/ft fluid gradient inside tubing and 8.5 ppg packer fluid. Bump plug with 1500 psi while displacing cement with 15.8 ppg MW. 1.10 2.27 19518 ICOLLAPSE 1. PRODUCTION LOAD 2. CEMENTING Gas production, assuming methane (2.8 ppg) below the packer and 8.5 ppg completion fluid above it. Cementing operation, 15.8 ppg slurry, displacement fluid 15.8 ppg MW. 1.10 1.24 19518 AXIAL LOADS 1. RUNNING IN HOLE 2. OVERPULL FORCE 3. BUMP PLUG ~4. SERVICE LOADS Running casing at 5 fi/sec. 100.000 lb overpull to work pipe. Bump plug with 1500 psi while displacing cement with 15.8 ppg MW. 1.60 4.41 15800 BP EXPLORJ~i]'ION Memorandum To: Erik Davidsen ~V--~) ,,/,~/~..s Date: Walt Fulroth WN~ From: 13 Nov. 1998 Subj: Shallow Hazard Survey for Red Dog #1 well site The Red Dog #1 well is currently planned to be directionally drilled from a surface location within the SW 1/4 of Sec 34, T10N, R21E (Attachment 1). Red Dog #1 drilling will start vertical and slowly build angle along an azimuth of about N16°W to an approximate depth of 4500' tvdss (approximately 990 ms seismic two-way recording time) where 13 3/8" casing will be set. In accordance with Alaska State permitting requirements, the potential for shallow (<4500') gas sources in the vicinity of the proposed well location has been reviewed. Analysis consisted of examination of 2-D/3-D seismic data near the well site (see Attachments 2 & 3) and looking for the following effects: · anomalous high or Iow amplitude seismic reflectors · velocity pull downs or time delays along individual seismic reflectors · phase changes along otherwise continuous reflectors Unfortunately, the proximity to the coastline places the well path in an area of severe ray path distortion. In this zone, the sharp transition from a thick permafrost layer onshore to a very thin permafrost layer combined with floating ice causes the quality of the shallow seismic to deteriorate significantly. This thinning-permafrost model easily duplicates the seismic response shown in Attachment 2. If the data deterioration was caused by shallow gas, amplitude anomalies would be expected in that zone, and the reflectors at 600-1000 ms should show localized push-down. In some regions, pre-stack seismic information can determine fluid content, in the Red Dog area, the anomalous zone is too shallow to use the prestack information. Despite the data quality problem, the probability for shallow gas is very Iow for the following reasons: 1) This same character occurs along the entire North Slope within 2000 feet of the coastline as it is here. 2) The amplitude character in the onshore data is very consistent and shows no sign of shallow gas. (Attachment 3) 3) No shallow gas has been encountered in nearby wells and no other data in the immediate area show gas character. 4) In-situ gas formation is unlikely from these sediments and the sediment type (gravel) would make it very difficult to trap gas. In summary, although the occurrence of shallow gas has not been eliminated, there is nothing on our current datasets to suggest the presence of a near-surface hazard at the Red Dog #1 location. Attachments: 1) Red Dog Prospect Map 2) Seismic Dip Traverse 3d vs 2d 3) Seismic Strike Traverse from Wthom3d RED DOG #1 H2S Contingency Plan Detection Monitoring: Automatic monitors: "Sierra Monitor" visual and audio H2S alarm system Probe locations: rig floor shale shakers bell nipple cellar pump room Setting levels:Low - 10 ppm High - 20 ppm Manual: 1 -"Industrial Scientific" Model HMX271detector 2 -"Lumidor MicroMax" Model MAX 3EP H2S detectors 1 - Drager w/benzene and H2S tubes Contingency and Control: H2S treating material for the drilling mud will be Zinc Carbonate and will be on location. Detailed emergency operating procedures are in place. Detailed step by step remedial procedures during tripping, fishing, and drilling are in place. 9 - 30 minute self contained breathing apparatus on location. H2S Training: All personnel onsite have H2S training. RED DOG #1 SHALLOW GAS AWARENESS PLAN Shallow gas hazards are not expected during the drilling of the RED DOG #1 well. Even though we do not expect to encounter any shallow gas, NABORS 28E will be equipped with the following gas detection system: ¥ Rig gas sensors located at the pits, cellar, & rig floor ¥ PVTsystem ¥ Trip tank ¥ SPERRY SUN Mudlogging Unit - Specialized personnel - Total Hydrocarbon Analyzer - Gas Chromatogragh Usual SSD procedures will be followed to minimize any potential for a shallow gas kick. Sufficient hydrostatic column will always be maintained while drilling the well and the correct tripping procedures will be followed while tripping in and out of the hole. If a shallow gas kick is taken prior to setting surface casing, the gas kick will not be shut-in, but diverted through the diverter system. As mentioned above, there is considered to be a very Iow chance of encountering shallow gas. We have no high resolution seismic due to the proximity of the shore line, but we do have offset well information. The Point Thomson #4, East Mikkelsen #1 and Challenge Island #1 wells, did not drill any gas bearing formation in the surface hole. The proposed surface casing shoe depth for the RED DOG #1 well is 3,918 ft TVD. SURFACE DIVERTER PIPING .CONFIGURATION PLAN Vim BOP STACK ELEVATION 1.7,-5./8" 10.O00~ HYDRIL - 21 1/4° 20OO~ HYD~L BOP/DfV~:~ER 4' ~°o co~£c~o~ c/~ Pcuc, OYPtc~ ao~ SURFACE DIVERTER CONFIGURATION __ 16' Ft.G'D ~F..NT 2 8EO,'.'.'~ 10 Red Dog 10M Christmas tree 300' of cement on sand spacer on wireline plug 20" conductor Wireline plug in XN nipple Freeze protect diesel Gas lift mandrel 13 3/8" casing 4 1/2" tubing Kill weight mud in tubing and annulus Gas lift mandrel 9 5/8" casing Wireline plug in X nipple Wireline plug in XN nipple Propped frac ~ ~ 7" liner 20" Conductor @ 120' MD Plug #3 (42' - 200' RED DOG #1' P&A PROPOSAL All casing strings cut at 7' below ground level (42' MD) 9-5~8" Bridge Plug @ 200' MD 13-3/8" Casing @ 4,355' MD 14.5 ppg Kill Fluid G NEAT FORMULATION FOR ALL CEMENT PLUGS EXCEPT SURFACE PLUG - PERMA FROST TYPE 'C' TOP OF CEMENT PLUG @ 16000' 9-5~8" Casing @ 16,100' MD BASE OF CEMENT PLUG @ 16200' TOP OF CEMENT PLUG @ 17230' 7330' M D ~ 15.8 PPG CEMENT ~-~ 14.2 PPG MUD CEMENT IN PLACE PRIOR TO ABANDONMENT BASE OF CEMENT PLUG @ 19461' TD @ 19518' MD 19411' MD Anadrill Schlumberger Alaska District J940 Arctic Blvd, AnChorage, AK 99503 {907) 273-I700 Fax S6]-8S37 DIRECTIONAL 9ELJ~ PLAN for SHARED SERVICES DRILLING well ......... : Red Dog R1 (P6A} F£eld ........ : Prudhoe Bay Computation..: Mioimum Curvature Units ........ : FEET Surface Lat..: 70.L759V445 N Surface Long,: I46.78738994 W Legal Description Surface ...... : 1987 FSL 4043 FEL S34 TION R21E LTM Target ....... : 3535 FSL 1593 BHL .......... : 4024 FSL 1708 Prepared ..... : 24 Nov 1998 Vert sect az.: 346.74 KB elevation.: 40,00 ft Magaetic Dcln: ~26.475 Scale Pactor-: 0. Convergence..: -8.74073343 .... · ,..-~:. ,~ ..... ~,~.~ ~.- ~'~-~ ......... "-'-'D FOR NOT "' '"" LOCATIONS - ALASKA Zone: 3 X-Coord Y-Coord 40219~,00 5914s26.00 39~496.00 5~26669.08 399387.11 59271~9.29 ....... K~ ............................. o.~e .....o:oo ........... o:'o~ ......... ~;"~ ..... z¢o':'o~ ........... ~.~'~ ............ ~;'d6"~ ....... b;ao 'z '"4~f~927'd~"B~i¥~i~'i6o "l~'f' b'.'66 ..... ×o~ su~) [/sao 2000.aa o.oo 366.74 2000.00 1960.00 0.00 o.oo R 0.00 ~ ~a2t95.o0 59z6526.00 ~3~ 0.00 9U~LO L.S/ZO0 2100.00 [.O0 3~6.?~ 2099.99 2059.99 O.e? O.B5 ~ 0.20 W ~02192.B] 59~4526.85 L3~ 1.00 ~UZ~ 2ILoa 2200.00 2.SO ~.?~ 2[~9,95 ~15~.95 ~.93 3.~ ~ o.~o ~ 402~2.[5 s~[~s~.es [a~ 1.s0 nUILD ~/100 2400.00 7.00 346,74 2399,24 2359.2~ 20-05 19.51 N 4.60 W 402[88.65 59145~5,$7 ~9 2.50 2500.00 1D.00 346.~ 2498.13 245B.~3 34.83 33-90 N 7.99 W 4021S5.45 591456~.~Q ~$ 3.00 2600.00 13.00 F%6.74 2596.11 2576.[[ 54.76 53.30 N 12.5~ W ~0218X~13 5914579.~6 ~IS 3.80 27O0.00 16.00 3~6.74 2692.92 2672.72 79.80 77,~7 N 18,3X W 402195.70 5914603.89 HS 3.00 280G.00 19.00 346.74 2988.28 2747.28 109.87 [06.93 N 25,21 W 402169.18 5914633.24 HS 3.00 m 2900.O0 22.00 346,74 2881.94 ~841.94 144.88 14X.02 ~ 33-2~ W 402161,S9 591~667,42 ~S 3.00 3000.00 25.00 346,74 2973,63 2933.63 184.75 17~.82 N 42.39 W 402152.95 5914706.34 ~S 3.00 {AnadrL!l (c)gB ROLP~ S.2C 9:01 AJ,1 P) tx.) &ed Do~ ~ STAT rOl~ IDENTIFICATION END 3/100 BUILD 13-3/8" CSG PT TOP C3~IlqG DROP 2/100 PROPOSED WELL ~ROFILE 24 Nov /995 Page 2 blT, ASURED INCLN DIRECTION DEPTH .ANGLE AZIMUTH VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 3063.11 3023.11 229.37 3150. a~ ~aaO. 14 278 . 60 3234.47 3194.47 332.33 3515.$7 3275.87 398.39 3394.12 3354.12 452.6A 3100.00 28.00 346-74 3200.00 31.00 346.74 3300.00 34.00 346.74 3400.00 37.88 546.74 3500.00 40.OD 346.74 COORDINATES-PROM ALASKA Zone 3 WELLHEAD X Y 223,25 N 52.62 W 402143.27 5914749.89 271.17 N 63.92 W 402132.60 5924797.95 323.46 N 76.24 W 402120.95 5914850.39 379-98 N 89.56 W 402108.36 591.4907.07 440.56 N 103.85 W 402094.87 5914967.83 TOOL DL/ PACE NS 3.00 HS 3.D0 HS 3.00 ~S 3.00 ~ 3.00 3600.00 43.00 346.74 3700.00 46.00 346.74 3800.00 49.00 34G.74 3900.00 52.00 346.74 4000.00 55.00 346.74 3469.01 3429.0I 518.89 3540.33 3500.33 588.97 3607.85 3567.88 662.69 3671.48 3631.48 :739.85 3730.95 3690.95 820.22 $05.05 ~ 519.05 ~ 402080.50 5915032.50 HS 3.00 573.26 N 1.35.12 W 402065.31 S915[00.91 ~S 3.00 645.02 ~ 152.04 W t02049.33 5915172.87 ~S 3.00 720.11. ~ 169.74 ~ 402032.60 591524~.Z~ NS 3.00 793.34 N 138.18 W 402015.17 59L5526,64 ~S 3.00 4300.00 58.00 4155.14 59.65 346.74 4355.14 59.65 346.74 1~299.88 59.65 14794.71 5~.65 346.74 15967.52 S9-65 ~46.74 16~00,O0 59.00 346.74 ~-'-7.)16~00;00"' ST:UO ..... ~4~.7~ L6~00.00 55.00 346.74 16300.00 53.00 346.74 3786.14 3746.1~ 903.60 3814.68 3774.68 950.77 3915.73 3875.73 1123.38 8940.00 8900.00 9705.59 9L90.00 9150.00 1.01.32.63 9782.53 9742.53 1114~ .76 9799 .09 9759.09 11172.69 -~'~'~'~': ~'~ .... ~'~'Ci'.'fi'~" '£f~'~%-;'.~ ' 'i'6'~%'~':&'k' N' "i~-'~ 9907.99 9867.92 11340.40 11037.91 N 2601.78 9966.76 9926.76 11421.30 1111.6.66 N 2620.31 879.S0 N 207.31. W 401997.10 5915408.03 HS 3.00 925.41 N 218.13 W 401986.87 59154fiA.07 HS 3.00 1093.41 N 257.73 W 4039~9.45 $9/5622.S~ HS 0.00 94~6.71 N 2226.6~ W 400088.8~ 5923999.87 HS O.O0 986~.36 ~ 2324.66 W 399996.24 5924416.71 RS 0.OD 10847.~9 ~ 2556.8~ W 399776.81 59~54~4.68 L~ 0.0~ /0874,68 N 2663.25 W 399770,75 5925431.91 LS 2.00 399752.37 592551~.72 LS 2.00 399734.39 ~925595.65 LS 2.00 399716.85 ~925674.62 LS 2.00 16~O0.O0 51.00 346.74 16500.00 49.00 346.74 16600.00 {7.00 346.74 16700.00 45.00 346.74 ~6800.00 43.00 346.74 10028.31 9985.31' IL500./0 11L93.36 N 2638.39 10092.58 L0052.58 11~76.71. 11267.92 N 2655.97 10159.49 10119.49 11651.03 11340.~6 N ~673.02 10228.94 20188.94 LX722.96 LL410.27 ~ 2689.52 10300.87 10260.87 11792.43 11477.89 N 2705.46 399699.77 5925751.54 LS 2.00 399683-~6 5925526,31 LS 2.00 399667.05 5925898.86 LS 2,00 399651.~$ 5925969.05 LS 2.00 399636.39 5926036.88 LS 2.~0 .o Z ~> ~J 16900.00 41.00 346.74 17000.00 39.00 346.74 17100.00 37.00 346.74 (Anadrill (c)98 ~D1P6 3.2C 9:01 A[,] P) 10375,17 10335.17 11859.35 10451.77 ~04L1.77 L1923.63 10530.56 L0490.56 11985.20 L1543.02 N 2720.81. W 399621.89 5926102.20 LS 2.00 11605.59 ~ 2735.56 W 399607.95 5926164.9~ LS 2.00 11665.51 N 2749.68 I Red Dog %1 (P6A} STATZON TOP RD-25 TOP ~(AIN RD BASE PJ$- 03 T~P KODIAK TOP K[LLIAN SKALE ~L%LL 7 · L~NER'-PT ......... 24 Nov 1998 Page 3 PROPOSED WELL PROPILE MS~ASURED INCL~ DIRECTION VErTICAL-DEPTHS SECTION DEPT~ AI~L~ A:Z~UT~ TVD SL~-SEA DEPART %7200.00 35.00 346.74 10611.45 1057~.45 12043.9~ 17300.00 33.00 346.$4 10694.35 10654.36 12099.90 17330.48 32.39 346.74 10720.00 10680.00 12[I6.37 17400,00 31.00 346.74 10779.~4 10739.14 12152.90 %7412.65 30.75 346.7~ ~079~.00 ~0750.00 12159.39 COORDINATES-FROM ALASKA Zone.3 TOOL DL/ WELLHEAD X Y FACS 1~722.~3 N 2763.17 W 3995~1.86 5926282.43 LS 2.00 11777.16 N 2~76.00 ~ 399569.73 5926337-02 LS 2.00 11~93.19 N 2779.78 W 399566.16 5926353.09 LS 2.00 11828,74 N 2788,~6 W 399558,24 5926388.7£ LS 2.00 [~835.06 N 2789.65 W 399556.84 5926395.08 }tS 2.00 17~1~.56 30.95 346.74 10875.00 10535.00 %2209.96 11884.28 N 280~.25 W 399545.87 $926~4.45 LS O.00 176~0.0~ 28.98 346.74 1~951.69 10911.69 12254.80 11927,15 N 2811.35 W 399536,32 5926487,44 LS 2-~0 ~7700.00 26,98 346.9~ ~10~0,00 ~lOOO.00 12300.92 i~972,82 N 2822.1l W 399~26.15 5926533.2~ LS 2~00 17755.8~ 25.87 346.74 1%O~O.O0 1[050.00 L232~.79 11997.00 N ~B27.82 ~ 399520.77 S926~$7.49 LS 2.00 17800.00 24.98 3~6.74 11129.89 110S9.89 ~25~4,73 12015.46 N 2832.17 W 399516.66 5926576.00 LS 2.00 17900.00 22,95 346.9~ li221,25 11181,25 12385-37 12055.02 N 2841.49 W 3995D?.~4 5926615.67 LS 2.00 18000.00 20~98 346.~ 1l$~3.97 11~7~.97 ~2~22.81 12091.~ N 2850.08 ~ 399~99.73 592665~.~ LS 2.00 38049.[4 20.00 346,74 11360.00 11320.00 124~0.01 12108.L9 ~ 2854.03 W 399496.00 5926669,00 KS 2-00 I83~7.1% 20.00 3~6.74 1~640.00 ]1600.00 1254~.~2 I2207.3~ ~ 2877.41 W 399473.91 592676B.~ H9 0.00 ~896%.33 20.00 346.7% ~2220.00 12~80.00 ~27S3.02 124~2.86 N 2925.8~ W 399428.14 5926974.54 ~]S 0.00 ~9304.87 20.00 3A6.74 12540.D~ 12500.00 [286~.49 ~2526.22 N 29~2.56 W 399~02.$9 5927088.23 19411.2S 20,00 ................. 3~6,74 126~0.00 12600.00 12905.89 L2561,65 N 2960,9~ W 399395.00 5927123.~7~ . ,HS ....... 0.o0 .o Z {Anadrill ( c m) 9 8 RDIP6 3.2C 9:OL A~4 P) :SHARED SERVICES DtqlLLING _ I II , _~ ' . IIII I II I II 24, 9~00 .0800 n III I I ...llll I I .... III I Anadrj ]] Schlumberger ReO Dog #t (P6A) VERTICAL SECTION ViEW Bect~on at: 246.74 TVO Scale.' ~ inch : ;:400 feet Dep ScB]e.' ! ~nch = 2400 feet ; ' · I ~. '-'"~ ." :'"' ;"-",", ::i'? '"':~ ?'~.;'iq. ! :.,. ,. * 't,. ' :]:: .... .: .,.. .-.,, :,,.... ~ ~ "...~. ' ~ i i i i ii i _ i i -- z %"i' =,. .... ,: ?:.:%,--..:-I'-, Marker I[~entification ~ID BKB SECTIg INCL .; ~, i ~"'-~ A) KB § O :.:~ ~ !.. ] ..t:: ~[~:--Z--. ~. !'i.."'/.~,r~ B) KOP BUILO ~/tO0 2000 2000 0 ~ . .................. C) BUILD t.5/~00 2~00 2~00 1 i.O I" . -' ' ...... ~ "' r ~ i ' D) BUILD 2/~00 2200 2200 4 2.5 \ E) BUILD 2.5/tDO 2300 2300 ]0 4.5 F] BUIL8 3/i00 2400 23~ 20 7.0 ......... , G) END 3/100 BUILD 4155 3B15 95i 59.6 GH"~'~ H) 13-3/8" CSG Pl 4355 3916 ]123 59.8 I) DROP 2/100 ~596B 9783 11f45 59.E ~. J) 9-5/8" CASING PT 17413 ~07§0 ~215~ 30.7 -- '~ l ........... K) 7" LINER PT t95~8 1~740 ~2942 20.0 ' ' ~~ ........................ ' ,.,, . ................... i ............ '"" .... ' ........ '" '" "" '"" '~'1~' ........ 7.'1' ..... ~ ..................... ,.' ............................... --; .... ',~q:m,~ - ~,,~' F - '"'~ ............ ......... ...... i ............. i ....... ~ ......... L - ' ' ...............................t d - - - '~ U : T~P"Y.~]??~-t~¢:~3- ' '1 ..... i ............... i l~' I'aJ'get' (F:adius 4011 feel } ,.2 .............................................. : , J ............ _"~ =J ' , i' ...... .................. ..... ' j. ........... .......... ] ...... _.'__. '~_ ..... '__~-.:\--_' ...... ', ..... -----' ]' .-_.. ::::::::::::::::::::::::::::: ::::-::=:=:=:=: ::::::::::::::::::::::::::::::::::::: ' I I I t I / " · 1200 2400 3600 4800 6000 7200 8400 g§O0 loaoo t20.00 t3200 t4400 t5600 .16800 .18000 Section Departure .c: 0;:] /~ PI ............................................................ ~. Z PAGE 86 SH. ARED SERVICES DRILLING c~ ~ ~,~/~oo 2~oo ~ ~o. PLAN VIE~ 0) BUILO 2/100 8~00 4 N ~ ~1 -- , .... El BUILO 2.5/t0o 2300 ~0 N 2 w CLOSURE · ~2942 feet at Az imuEh 3, 6 74 F~ 8U~LO 3/~00 a400 20 N D ~ . Gl END 3/~00 BUILD 4t55 925 N 2~8 ~ DECLINATION.- +25.475 (E) HI 13-318" CSG PT 4355 1093 N 258 W SCALE ' ' I inch = 2000 Ceet Il DROP 2/tO0 15968 108~7 N 2557 u J) g-5/8" CASING PT 17413 a1835 N 2790 N DRAWN.~ ...... : 24 NOv ~g98 K) 7" LINER PT ~9518 ~2597 N 2969 ~ . i i ~ · ~nadril] Schlumberg~ . .~ "' ~. ,, ~ . .~. __ - " .~ Ia, ti[fla~tus_.400,~eet ) _ ?'5. :-..~ , .- j ; ~ ... ~, ~ ' "' ~ '" "f ~ ' ' ' ' '~.J 1 'x¢ : ! :: ,'"'V 7' ' .) :~" '~':"' . , .. ;. ~"..;, .~ ./ . - ': ~ ~ '-5" ~. ~'-:.. ' .. '.. ( .".'.'.:"'-..;: ~ ', ~.~' ..... { - ~..., . .... ... ..... ~., , ' ,, . .. " 1 ' : "' : " ~ ~ '~n~n ~nnn ~nnn ~0000 9000 8000 7000 6000 5000 4000 3000 2000 I000 O 1000 oo .t 43o7oI VENDOR ALASKAST z DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ~]~. 1. 9fa ¢':K09'~ 1 ........ ~- ...... .tO0, O0 !00. O0 HANDI_IN~ INoT'~ S/F ('_,,-~RI3L ~ " WI'T'HEY ,X4114 ~ _tO0 O0 100. O0 ~C~O CH~CK IN PAY~E~ ~EMS DE~RIBED ABOVE. BP EXPLORATION (ALASKA), INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CiTY BANK CLEVELAND, OHIO 56-389 412 No. H 143070 CONSOLIDATED COMMERCIAL ACCOUNT Of) 14.3070 "F o 'T ti ,e 0t~ ALASKA q" ' ,..:. lATE DEPT OF' REVENUE 30©1 PORCUP!blE DR A K 9 9 5 0 .'I, -" :31 ~ 0 DATE AMOUNT NOT VALID AFTER 120 DAYS ~ '"-W-~L~. PERMIT CHECKLIST FIELD & POOL COMPANY /~/~C) WELL NAME/~j .,~, ,,, '~// PROGRAM: exp~ dev [] redrll [] serv [] wellbore sec II ann. disposal para req,~ ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. DA.TE , 12. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well Iocaled in a defined pool .................. Well located proper distance from drilling unit boundary .... Well Iocaled proper distance from other wells .......... Sufficient acreage available in drilling uni! ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CM'[' vol adequate to tie-in long string to surf csg ........ · 18. CMf 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 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder 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 .J(D..OO~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ Y N (.~.N Q N (~N 28. Work will occur without operation shutdown ........... (~) 29. Is presence of H2S gas probable ................. Y . . . GEOLOGY 30. Perm,, can be msue, w,o hydrogen sulf, de measures ..... 31. Data presented on potential overpressure zones ....... ~' N~/ ~ ~ / ~ , / ~ /~ 32. Seismic analysis of shallow gas zones ..... ' ....... , .~ ~ N~/i~o~_J~/ ~ ..... ~.~~_Z~ ........... 33. Seabed condition su~ey (if off-shore) .......... ~,~1/~ y N _ ~ / ~ ~ ~ ~ A R D TE 34. Co~/~/ph~/or weekly progress reports ...... / ~ N .......... g pr-t <A) F. a su,aU ....... j ;, ,/;, / / APPR DATE (B) will n~t conlaminate freshwater; or cause drilling wasle.., ~N _~ lo.~udace; .~ ~ ~ _.~~ (C) will'[~t impair.~echanical integrity of the well used for disposal; ' ' i i ri'n air ec v ~ (D) wdlnoldamageproducngformatono t p r o eryfro~a ~N ........... i~-~i~ ~' .'-'~', ~=--, '~'~-' ........................ pool; and (E) will not circumvent 20 AAC 25 252 or 20 AAC 25 412 . . , ~,, · , , - ._ GEOLOGY: ENGINEERING: UIC/Annular COMMISSIO~~ Comments/Instructions: M:cheklisl ~ev 05129198 dlf'C ~n~sofli(:~fiwnf(Jian~dmr~;~, I,', l, h',l 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. -1- Red Dog #1 LIS Tape Verification Listing The following information was extracted from the enclosed EDITED WELL LOG DATA TAPE Company: Well Name: Red Dog gl FieM Name: Wildcat Borough: North Slope State: Alaska AP1 Number: 50-089-20027 Date Logged: 15-MAR-1999 Top of Logged Interval: F F 14500.(F) Bottom of Logged Interval: F F 18740.(F) TAPE FORMAT: LIS ! RECEIVED ~,,t4~ ~0 !999 bJ.~ka 0i! & Gas Cons. C0rnmiss~ Tape was created by: Schlumberger- Geo.ques_t, Alaska Interpretation anrct Computing Services OCS) Tape was created on: - Wed May 5 09:05:43 AKDT 1999 Files Included on this Tape: Logical File Name: HILTD .001 , START DEPTH STOP DEPTH 18727. 15734. Logical File Name: SNAM .002 START DEPTH STOP DEPTH 18578.5 14537. Logical File Name: SNAM .003 START DEPTH STOP DEPTH 19421.5 96.5 INCREMENT -0.5 ft INCREMENT -0.5 ft INCREMENT -0.5 ft Schlumberger GeoQuest -2- LISTING of ALL PARAMETERS, COMMENTS and LOG CURVES for FILE: List of set - TOOL, Set Name 2 NAME MNEM STAT HEIG VOLU WEIG PRES TEMP HILTD HILTD DISA-50000.(IN) -50000.(F3) -50000.(LB) -50000.(PSIA) -50000.(DEGF) AMS AMS DISA -50000.(IN) -50000.(F3) -50000.(LB) -50000.(PSIA) -50000.(DEGF) CMRT CMRT DISA-50000.(IN)-50000.(F3)-50000.(LB)-50000.(PSIA)-50000.(DEGF) List of set - OUTP, Set Name 4 NAME MNEM TUNI PUNI DESC GR GR GAPI GAPI RHGX RHGX C_-EC,3 G/C3 SP SP MV MV CFTC CFTC CPS CPS CNTC CNTC CPS CPS ECGR ECGR GAPI GAPI PXND PXND CFCF CFCF NPHI NPHI CFCF CFCF NPHI NPHI CFCF CFCF CRAT CRAT GDEV GDEV DEG DEG MRES MRES OHMM OHMM MTEM MTEM DEGF DEGF BS BS IN IN CS CS F/HR F/HR CVEL CVEL F/MN F/MN TENS TENS LBF LBF K'TIM KTIM MD MD KSDR KSDR MD MD KCMR KCMR MD MD TCMR TCMR CFCF CFCF CMFF CMFF CFCF CFCF CMRP CMRP CFCF CFCF BFV BFV CFCF CFCF T2LM T2LM MS MS T12R T12R LT2C LT2C MS MS ATRX ATRX OHMM OHMM ATRT ATRT OHMM OHMM ATD2 ATD2 IN IN ATD1 ATD1 IN IN AT90 AT90 OHMM OHMM AT60 AT60 OHMM OHMM AT30 AT30 OHMM OHMM AT20 AT20 OHMM OHMM AT10 AT10 OHMM OHMM AO90 AOgO OHMM OHMM AO60 AO60 OHMM OHMM AO30 AO30 OHMM OHMM AO20 AO20 OHMM OHMM AO10 AO10 OHMM OHMM AF90 AF90 OHMM OHMM AF60 AF60 OHMM OHMM AF30 AF30 OHMM OHMM AF20 AF20 OHMM OHMM AFl0 AFl0 OHMM OHMM HMNO HMNO OHMM OHMM HMIN HMIN OHMM OHMM PEFZ PEFZ RSOZ RSOZ IN IN RXOZ RXOZ OHMM OHMM RHOZ RHOZ G/C3 GJC,3 DPHZ DPHZ CFCF CFCF HCAL HCAL IN IN Ust of set - XNAM, Set Name 6 NAME MNEM TYPE NAME ', ~ ORIG CNUM --GR"-. GR CHANNEL GR 0 0 RHGX" RHGX CHANNEL RHGX_HILT 0 0 SP SP CHANNEL SP 0 0 CFTC CFTC CHANNEL CFTC 0 0 CNTC CNTC CHANNEL CNTC 0 0 ECGR ECGR CHANNEL ECGR 0 0 PXND-' PXND CHANNEL PXND_HILT 0 0 NPHI NPHI CHANNEL NPHI 0 0 NPHI NPHI CHANNEL I'N_PH~ 0 0 CRAT CRAT CHANNEL ']'NRA 0 0 MRES MRES CHANNEL MRES 0 0 MTEM MTEM CHANNEL MTEM 0 0 KTIM KTIM CHANNEL KTIM 0 0 KSDR KSDR CHANNEL KSDR 0 0 KCMR KCMR CHANNEL KCMR 0 0 TCMR TCMR CHANNEL TCMR O 0 CMFF CMFF CHANNEL CMFF 0 0 CMRP CMRP CHANNEL CMRP_3MS 0 0 BFV BFV CHANNEL BFV 0 0 T12R T12R CHANNEL T12R 0 0 LT2C LT2C CHANNEL LOG_T2CUTOFF 0 0 ATRX ATRX CHANNEL AHTRX 0 0 ATRT ATRT CHANNEL AHTRT 0 0 ATD2 ATD2 CHANNEL AHTD2 0 0 ATD1 A'I'D1 CHANNEL AHTD1 0 0 ATg0 AT90 CHANNEL AHT90 0 0 AT60 AT60 CHANNEL AHT60 0 0 AT30 AT30 CHANNEL AHT30 0 0 AT20 AT20 CHANNEL AHT20 0 0 AT10 AT10 CHANNEL AHT10 0 0 AO90 AO90 CHANNEL AHO90 0 0 HILTD .001 -3- AC60 AC60 CHANNEL AHO60 0 0 AC30 AC30 CHANNEL AHO30 0 0 AC20 AC20 CHANNEL AHO20 0 0 AC10 AC10 CHANNEL AHO10 0 0 AFg0 AFg0 CHANNEL AHFg0 0 0 AF60 AF60 CHANNEL AHF60 0 0 AF30 AF30 CHANNEL AHF30 0 0 AF20 AF20 CHANNEL AHF20 0 0 AFl0 AFl0 CHANNEL AHF10 0 0 List of set - CONS, Set Name 7 NAME MNEM STAT TUNI PUNI DESC VALU lA la ALLO PDAT PDAT ALLO EPD EPD ALLO LMF LMF ALLO APD APD ALLO EDF EDF ALLO EGL EGL ALLO EKB EKB ALLO 2A 2A ALLO LCP LCP ALLO MMDU MMDU ALLO TD TD ALLO E E ALLO TREF TREF ALLO DIFF DIFF Al_LO HVCS HVCS ALLO IHVC IHVC ALLO FCD FCD ALLO CD CD ALLO AMD AMD ALLO STEM STEM ALLO TWS TWS Al_LO RW RW ALLO BSAL BSAL ALLO MRT MRT ALLO MRT3 MRT3 ALLO MRT2 MRT2 ALLO MRT1 MRT1 ALLO RMFB RMFB ALLO RMB RMB ALLO MCST MCST ALLO RMCS RMCS ALLO MFST MFST ALLO RMFS RMFS ALLO MST MST ALLO RMS RMS ALI_O DFPH DFPH ALLO DFL DFL ALLO DFV DFV ALLO DFD DFD Al_LO CWEI CWEI ALLO CSIZ CSIZ ALLO BS BS ALLO MHD MHD Al_LO CTOP CTOP ALLO FLEV FLEV Al_LO CBLO CBLO ALLO CBDR CBDR ALLO BLI BLI ALLO TIJ TL! ALLO TDL TDL AM_O TDD TDD ALLO ELZ ELZ ALLO OPER OPER ALLO LCC LCC ALLO LUN LUN ALLO PVER PVER ALLO SON SON ALLO CJT CJT ALLO CASN CASN ALLO HIDE HIDE ALLO HID1 HID1 ALLO HID2 HID2 ALLO HLD HID ALLO R16 R16 ALLO R3 R3 ALLO R2 R2 ALLO R1 R1 ALLO OS5 OS5 Al_LO OS4 OS4 ALLO OS3 OS3 ALLO OS2 OS2 ALLO OS1 OS1 ALLO MCSS MCSS ALLO MFSS MFSS ALLO MSS MSS ALLO TCS TCS ALLO DCS DCS ALLO DFT DFT ALLO CASG CASG AIIO WlTN WlTN AIIO ENGI ENGI ALLO LUL LUL Al_LO TLAB TI_AB ALLO DLAB ~ ALLO FEJN RUN ALLO DATE DATE ALLO CONT CONT ALLO NATI NATi AU_O RANG RANG Al_LO TOWN TOWN ALLO SECT SEGT ALLO .lIN .lIN .lIN .lIN .lIN .lIN .lIN .lIN .lIN .lIN F F LB-1 LB-1 LBF LBF F F IN IN F F DEG DEG DEGF DEGF DEGF DEGF OHMM OHMM PPM PPM DEGF DEGF DEGF DEGF DEGF DEGF DEGF DEGF OHMM OHMM OHMM OHMM DEGF DEGF OHMM OHMM DEGF DEGF OHMM OHMM DEGF DEGF OHMM OHMM C3 C3 S S I_B/G LB/G IN IN IN IN DEG DEG F F F F F F F F F F F F F F F F BP Exploration (Alaska) Inc. Ground Level 1260.(.11N) Rotary Table 2754.(.11N) 4014.(.11N) 1260.(.11N) 41,34.(.11N) BP Exploration (Alaska) Inc. ALLOW FEET 18740.(F) 9.63E-07(LB- 1) IO00.(LBF) 1.(F) HCAL START 7.(IN) 15852.(F) 352.5(DEG) -40.(DEGF) 100.(DEGF) 1.(OHMM) 33000.(PPM) 203.(DEGF) 203.(DEGF) 203.(DEGF) 203.(DEGF) 0.04519875(OHMM) 0.07480074(OHMM) 60.(DEGF) 0.76(OHMM) 60.(DEGF) 0.142(OHMM) 60.(DEGF) 0.235(CHUM) 9. 2.S(C3) 66.(S) 14. (LB/G) 67.(LB/F) 9.625(IN) 8.5(IN) 64.15001(DEG) -999 0.(F) 15850.(F) 15852.(F) 18740.(F) 14500.(F) 18740.(F) 18740.(F) '.. 33.45(F) -999 1805 8C1-205 6109824 Primary Platform Express Combinable Magnetic resonance tool PEX-CMRT -: INCLUDE Crew:. Mike Foust/Troy Pabst/Greg Pearson Cores RFT FMI-DSI Measured Measured Mud Engineer 12:30 15-MAR-1999 Fresh Water Mud Jerry Sick. Khedher IVlellah/ Daniel Palmer Kenai - Alaska 10:28 15-MAR-1999 Orte : 15-MAR-lC99 21E 10N 21 -4- LONG LONG ALLO LATI LATI ALLO APIN APIN ALLO DMF DMF ALLO FIP FIP ALLO FL1 FL1 ALLO FL FL ALLO STAT STAT ALLO COUN COUN ALLO FN FN ALLO WN WN ALLO CN1 CN1 ALLO RLAB RLAB ALLO 3A 3A ALLO LLAB LLAB ALLO CLAB CLAB ALLO SLAB SLAB ALLO 4A 4A ALLO DO DO ALLO F F LQMS LQMS ALLO pp pP ALLO SPEE SPEE ALLO F/HR F/HR ENVI ENVI ALLO VHOL VHOL ALLO F3 F3 VCEM VCEM AIIO F3 F3 5A 5A ALLO MPOI MPOI ALLO IN IN OFFS OFFS ALLO GAPI GAPI EX]ON DCON ALLO GAIN GAIN ALLO EUCF EUCF ALLO SHIF SHIF AIIO 6A 6A ALLO F F 7A 7A ALLO IN IN 8A 8A ALLO MV MV 9A 9A ALLO 10A 10A ALLO 11A 11A ALLO 12A 12A ALLO 13A 13A ALLO F F 14A 14A ALLO IN IN 15A 15A ALLO CPS CPS 16A 16A ALLO 17A 17A ALLO 18A 18A AIIO 19A 19A ALLO 20A 20A ALLO F F 21A 21A ALLO IN IN 22A 22A ALLO CPS CPS 23A 23A ALLO 24A 24A ALLO 25A 25A ALLO 26A 26A AIIO 27A 27A ALLO F F 28A 28A ALLO IN IN 29A 29A ALLO ~ 30A 30A ALLO ' 31A 31A ALLO ~ 32A ALLO 33A 33A ALLO 34A 34A ALLO F F 35A 35A ALLO IN IN 36A 36A ALLO IN IN 37A 37A ALLO 38A 38A ALLO 39A 39A ALLO 40A 40A ALLO 41A 41A ALLO F F 42A 42A ALLO IN IN 43A 43A ALLO DEGF DEGF 44A 44A ALLO 45A 45A ALLO 46A 46A ALLO 47A 47A AIIO 48A 48A AIIO F F ORDU ORDU UNAL FEET 50-089-20027 Rotary Table Total depth: 3671' NSL, 1058' WEL Surface: 1682' NSL, 4508' WEL Alaska North Slope Wildcat Red Dog #1 RANGE TOWNSHIP SECTION BOROUGH: STATE: NO o.(~ NONE RECOMPUTE 1800(F/HR) FTB_TELEMETRY 7.142033(F3) 2.99977(F3) MEASURED_DEPTH 104.(IN) 0.(GAPI) 3. 1.063993 0.36 0. 8.666668(F) 1.(IN) 0.(MV) O. 1. 0.0625 0. 0.08333334(F) 34.(IN) -29.92664(CPS) 3. 1.150804 1. 0. 2.a33333(F) 28.(IN) -28.30965(CPS) 5. 1.074279 1. 0. 2.~(F) 2e.(IN) O. 3. 0.9652077 1. O. 2.333,.'.'.'~3(F) -71 .(IN) 0.3448029(IN) 0. 0.955115 0.000377 2. -. -5.916667(F) 70.(IN) 1.52589E-06(DEGF) 9. 1. 1. 0. 63.44667(F) List of set - XNAM, Set Name 8 NAME MNEM TYPE NAME ORIG CNUM lA lA PARAMETER 2A 2A PARAMETER 3A 3A PARAMETER 4A 4A PARAMETER 5A 5A PARAMETER 6A 6A PARAMETER 7A 7A PARAMETER 8A 8A PARAMETER 9A 9A PARAMETER 10A 10A PARAMETER 11A 11A PARAMETER 12A 12A PARAMETER 13A 13A PARAMETER 14A 14A PARAMETER 15A 15A PARAMETER 16A 16A PARAMETER 17A 17A PARAMETER 18A 18A PARAMETER 19A 19A PARAMETER 20A 20A PARAMETER 21A 21A PARAMETER 22A 22A PARAMETER 23A 23A PARAMETER 24A 24A PARAMETER COMPANY 0 0 COMPANY 0 1 TLLAB 0 0 FLSHSTRM 0 0 LOGMODE 0 0 TOOL_STRING_MEASURE_POINT_OFFSET 0 0 MPOI 0 1 OFFS 0 1 [:)CON o 1 GAIN 0 1 EUCF 0 1 SHIF 0 1 TOOL_STRING_MEASURE_POINT_OFFSET 0 1 MPOI 0 2 OFFS 0 2 DCON 0 2 GAIN 0 2 EUCF 0 2 : SHIF 0 2 TOOL_STRING_MEASURE_POINT_OFFSET 0 2 MPOI 0 3 OFFS 0 3 DCON 0 3 GAIN 0 3 -5- 25A 25A PARAMETER EUCF 0 3 26A 26A PARAMETER SHIF 0 3 27A 27A PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 3 28A 28A PARAMETER MPOI 0 4 29A 29A PARAMETER OFFS 0 4 30A 30A PARAMETER DCON 0 4 31A 31A PARAMETER GAIN 0 4 32_A 32A PARAMETER EUCF 0 4 33A 33A PARAMETER SHIF 0 4 3.4A 34A PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 4 35A 35A PARAMETER MPOI 0 5 36A 36A PARAMETER OFFS 0 5 37A 37A PARAMETER DCON 0 5 38A 38A PARAMETER GAIN 0 5 39A 39A PARAMETER EUCF 0 5 4OA 40A PARAMETER SHIF 0 5 41A 41A PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 5 42A 42A PARAMETER MPOI 0 6 43A 43A PARAMETER OFFS 0 6 4.4A 44A PARAMETER DCON 0 6 45A 45A PARAMETER GAIN 0 6 46A 46A PARAMETER EUCF 0 6 47A 47A PARAMETER SHIF 0 6 48A 48A PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 6 Cm~t: ~ EDITED DATA - FROM DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline C, rr, r~ C, nm~ C, nm~ Crr~'~: Crna~ Cmnt: Cmnt: Crrm~ ~****S,c~,l**u,rn,,,b?,r.g. er * Schlumberger Data Services Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Crm3t: Crnnt: Crmll: Crm'~ Cmra: Cmr~ Crnnt: Cm.n~ Crnnt: Cmnt: Cmn~ C, mrlt: Crnal: Crra'~ Crnn~ Crna~ C, mnl: C, ma~ Crnn~ Cmn~ Crnn~ Cmnt: Cmnt: Cmnl: Cn'm~ Crnnt: Cn'~t: Cmn~ Crnna: Crn~'~: Cmal: This data file contains primary log curves and is grouped into THREE logical files as follows: PRIMARY DEPTH LOG: 1. PLATFORM EXPRESS - Array Inductiort/LithoDensity/Compensated Neutron and CMR - Combinable Magnetic Resonance (AlT, CNL, LDT, CUR) Recorded File Name Interval Top Interval Bottom PLAY_011.dlis 15734.00(ft) 18727.00(ft) 2. DSI/FMI - Dipole Sonic NGT and Micro Imager Calipers/Deviations (no Images), 3 files spliced & depth matched Recorded File Names ~lnterval Top IntervalBottom PLAY_O63.dlis 14530.6250 15900.3965 PLAY_062.dlis 15900.3965 16949.6582 PLAY_061 .dlis 16949.6582 18570.5000 Summary of sh[/ts applied to SONIC/NGT data: Final Lo<:jged Depth Depth ft 18570.500 18578.500 17806.600 17814.820 17407.100 17413.09 17305.700 17311,449 16849.300 16855.691 14530.500 14537.000 3. LWD · CDR/CDN/RAB - tools run over selected intervals, ~ curves depth matched to the PLATFORM EXPRESS Recorded File Names Interval Top Interval Bottom example Array (ft) (ft) DlisComposlnt. dlis 79.0000 17900.1309 PEF .RAB .009 LWD_015.dlis 17900.1309 18850.4023 PEF .CDR .010 LWD_O16,dlis 18850.4023 19400.5000 PEF .CDR .015 Summary of shifts applied to LWD data: Final Logged Depth Depth 19400.500 19421.50000 17792.900 17813.98242 17693.700 17713.88672 17635.700 17653.87109 17471.600 17468.88672 17396.500 17413.36914 17325.700 17343.38867 17308.400 17324.34375 17296.400 17309.06250 17257.000 17277.61719 17233.100 17253.25586 17163.800 17175.96680 16995.000 17007.88281 16918.600 16930.37305 16842.000 16853.74805 16803.500 16817.42969 16784.900 16796.61133 15377.300 15894.84082 78.500 96.00000 -6- Cmnt: ................................................................. Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Crrmt Cmnt: Cmnt Cmnt: Cmnt: Cmnt Cmnt Cmnt: Crnnt: Cmnt C, mnt: Crnnt: Cmnt Cmnt: Cmnt Cmnt Cmnt: Cmnt: Cn'mt Cmnt Crnnt: Header Data from Primary Depth Control Log: Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: FMI-DSI, RFT, Cores, Permanent Datum: Log Measured From: Drillin~ Measured From: Elevation: K.B.: Date: Run No: Depth Driller: Depth Logger: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit Size: Type Fluid in Hole: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: T~me Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Dech Ground LevelElev: Rotary Tab 22.95 Rotary Tab 34.45 D.F.: 33.45 G.I-: 15-MAR-1999 One 18740.00 18740.00 18740.00 14500.00 9.625 @ 0.00 0.00 8.5 Fresh Water Mud 14.00 9.00 Mud Engineer 0.23 @ 60.00 0.14 @ 60.00 0.76 @ 60.00 Rge: 21E 1([50 Above Perm Datum 10.50 Visc: 66.00 Fluid Loss: 2.80 Measured Rmc: Measured 0.07 @ 203.00 12:30 10:28 203.00 1805 Location: Kenai - Al Khedher MellahJ Dani Jen'y Siok. 0.000 Cmnt Cmnt Cmnt Cm~t Croat Cmnt Cmnt Cmnt Cmnt Cmnt C~nt Cmat Cmnt Cmnt C, rnnt Cmnt Crnnt Cmnt Cmnt: Remarks: Crew: Mike F-oust/TrW Pabst/Greg Pearson REmarks from DSI Run: Remarks: DSI modes run from 18530 to 1688ff - Cress Dipole: BCR mode - Upper dipole - Lower Dipole - Compressional , DSI data missing' from 16970 to 16945 DSI modes from 16945 to 14500 - Upper dipole - Compressional Crew: Mike FousFTroy Pabst/Greg Pearson Cmnt LWD Header - taken from - CDR .017 field data Crnnt: Cmnt: trent: Crrmt: Crnnt Crn~c Cmnt: Cm. nt Cmnt Crr~t: Cmnt Cmnt Cmnt ................. Schlumberger Data Services Schlumberger * Measured Depth Log Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska Service Order #: Location: Sec: SEC. Twn: Rge: APl No: 50-089-20027- Sec: SEC. Twn: Other Services: MWD Direct, Annular Pr, Permanent Datum: Mean Sea Level Elev: 0.00 LOg Measured From: Drill Floo Drillin~l Measured From: Elevation: K.B.: 0.00 D.F.: Date: 99 Run No: 16 Depth Driller: 0.00 Depth Logger: 0.00 BTM Log Interval: 0.00 Top LOg Interval: 0.00 Casing Driller: 0.000 @ Casing Logger. Bit Size: 16. Type Fluid in Hole: Dens: 0.00 pH: 0,00 Source of Sample: Rm @ Meas Temp: 0.00 @ Rmf @ Meas Temp: 0.00 @ Rmc @ Meas Temp: 0.00 @ Source: Flmf: Rm @ BHT: 0.00 @ 'lqme Circ. Stop: Rge: , , 43.95 Above Perm Datum' 43.95 G.L: 10.50 Vi.so: Fluid Loss:. 0.00 0.00 0.00 Rmc: 0.00 Cmnt: Logger on Bottom: Cmnt: Max Rec Temp: Cmnt: Equip: Cmnt: Recorded by: Cmnt: Witnessed by: Cmnt: Magnetic Deck Cmnt: Cmnt: Cmnt: 0.~ bosse 0.0~ Location: List of set - FRAME, Set Name 61 NAME DESCRIPTION CHANNELS INDEX-TYPE I ........... [9,0,INDEX BOREHOLE-DEPTH DECREASING -60(.11N) ........................... EXTERNAL-INDEX GR RHGX SP CFTC CNTC ECGR PXND NPHI NPHI CRAT GDEV MRES MTEM BS CS CVEL TENS KTIM KSDR KCMR TCMR CMFF CMRP BFV T2LM T12R LT2C ATRX ATRT ATD2 ATD1 AT90 AT60 AT30 AT20 ATIO AO90 AO60 AO30 AO20 ~ AO10 AF90 AF60 AF30 AF20 AF 10 HMNO HMIN PEFZ RSOZ RXOZ RHOZ DPHZ HCAL 1 0(IN) -999.25 .lIN 73 \ 1 368 List of set - CHANNEL, Set Name 62 DIRECTION SPACING ENCRYPTED INDEX-MIN INDEX-MAX INDEX-STYLE INDEX ................... 73 .lIN I .... I ...... O 0 1 1 0 1 GR ................... 68 GAPI I .... I ...... O 1 1 1 AITH 0 RHGX ................... 68 G/C3 I ........ .'~[;":1'" . ..... b 1 1 1 LDT 4 SP ................... 68 MV 1 ...... ~;'"{ .... . ..... O 1 I 1 AITH 8 CFTC ................... 68 CPS 1 ........ :~":1'" . ..... 0 1 1 1 CNL 12 CNTC ................... 68 CPS I ....... ~"'~'" . ..... 0 1 I 1 CNL 16 .................. ECGR ................... 68 GAP1 I .... 1 ...... 0 1 I I AITGR 20 PXND ................... 68 CFCF 1 ....... '..-~.'"~'" : ...... 0 1 1 1 CNLLDT 24 NPHI ................... 68 CFCF 1 ..... :.".:'"~ ..... . ..... 0 1 1 CNL 28 NPHI ................... 68 CFCF I ...... ~:":~ .... . ..... 0 1 NAME PROPERTIES REPRESENTATION-CODE UNITS DIMENSION AXIS ELEMENT-UMIT SOL~.RC, E APl-CODES FILE-NUMBER SERVICE-ID SERVICE-ORDER-NUMBER OFFSET-IN-FRAME ARTIFICIAL-CHANNEL : -8- CNL CRAT ................... 68 CNL GDEV ................... 68 AITH MRES ................... 68 AMS MTEM ................... 68 AMS BS ................... 68 AMS CS ................... 68 AMS CVEL ................... 68 AMS TENS ................... 68 AMS K-rIM ................... 68 CMR KSDR ................... 68 CMR KCMR ................... 68 CMR TCMR ................... 68 CMR CMFF ................... 68 CMR CMRP ................... 68 CMR BFV ................... 68 CMR T2LM ................... 68 CMR T12R ................... 68 CMR LT2C ................... 68 CMR ATRX ................... 68 AITH ATRT ................... 68 AITH ATD2 ................... 68 AITH ATD1 ................... 68 AITH AT90 ................... 68 AITH AT60 ................... 68 AITH AT30 ................... 68 AITH AT20 ................... 68 AITH AT10 ................... 68 AITH ^090 ................... 68 AITH AO60 ................... 68 AITH AO30 ................... 68 AITH AO20 ................... 68 AITH AOIO ................... 68 AITH AF90 ................... 68 AITH ^ITH AITH 32 36 4O 44 1 DEG 1 OHMM I DEGF 1 IN 1 52 F/HR 1 56 F/MN 1 6O LBF 1 64 MD 1 MD 1 72 MD 1 76 CFCF 1 8O CFCF 1 84 CFCF 1 88 CFCF 1 92 MS 1 1 100 MS 1 104 OHMM 1 108 OHMM 1 116 IN 1 124 IN 1 132 OHMM 1 140 OHMM 1 148 OHMM 1 156 OHMM 1 164 OHMM 1 172 OHMM 1 180 OHMM 1 188 OHMM 1 196 OHMM 1 204 OHMM 1 212 OHMM 1 220 OHMM 1 228 OHMM 1 236 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 2 2 2 2 2 2 2 _ 2 2 2 2 2 2 2 2 2 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 ' 1 1 1 1 1 1 1 1 1 1 -9- AF20 ................... 68 OHMM 1 .... 1 ...... 0 1 2 2 AITH 244 AFl0 ................... 68 OHMM I ......... ~ii~":1" . ..... 0 1 2 2 AITH 252 HMNO ................... 68 OHMM I .... 1 ...... 0 1 3 3 MCFL 260 HMIN ................... 68 OHMM 1 .......... ~i~"i' . ..... 0 1 3 3 MCFL 272 PEFZ ................... 68 1 .... ~'.~'"i ...... . ..... 0 1 3 3 LDT 284 .................. RSOZ ................... 68 IN I .... 1 ...... 0 1 3 3 HILTD 296 RXOZ ................... 68 OHUU 1 .......... ~;'.~'"'i ...... 0 1 3 3 LDT 308 RHOZ ................... 68 G/C3 1 ....... ~":1 .... . ..... 0 1 3 3 LDT 320 DPHZ ................... 68 CFCF 1 ........ ~"~'" . ..... 0 1 3 3 LDT 332 HCAL ................... 68 IN 1 ..... ~'"'~ ..... . ..... 0 1 6 6 AMS 344 .................. Co~tents of Data Frame at 18727. (ft), 5707.9896 (m) INDE 2247240 GR 116,072 RHGX 4.337529 SP 0. CFTC 1117.91 CNTC 2964.222 ECGR 148.9254 PXND 302.6947 NPHI 0.2852551 NPHI 0.2892318 CRAT 2.697405 GDEV -999.25 MRES 11.95146 MTEM 203.1468 BS 8.5 CS 923.0769 CVEL -15.38462 TENS 2967. KTIM 1.902173E-O8 KSDR 0.0001046098 KCMR 0.0001046098 TCMR 0.06455061 CMFF 2.1359E-05 CMRP 0.007143869 BFV 0.06452926 T2LM 1.227314 T12R 0. LT2C 1531.191 ATD2 ATD1 AT90 AT60 AT30 AT20 AT10 AO90 AO60 AO30 AO20 AO10 AFg0 AF60 AF30 AF20 AFl0 Contents of Data Frame at 18500. (ft), 5638.8 (m) INDE 2220000 GR 93.71037 RHGX 2.972763 SP -97.125 CFTC 1005.837 CNTC 2716.697 ECGR 119.2586 PXND 0.1831091 NPHI 0.3008125 NPHI 0.2979711 CF{AT 2.787926 GDEV 26.24241 MRES 11.95146 MTEM 203.5884 BS 8.5 CS 1245.816 CVEL -20.7636 TENS 2382. KSDR 0.0001797396 KCMR 0.0001797396 CMRP 0.02095355 BFV 0.06072658 T2LM 1.816156 T12R 0. 3.779116 3.871934 . 3.571272 3.6303,33 ATD2 9.067394 9.068033 ATD1 9.067394 9.068033 AT90 3.585745 3.649964 AT60 3.691506 3.758623 AT30 3.833784 3.945813 AT20 3.92241 4.083135 AT10 3.79933 3.923174 AO90 3.633428 3.66335 AO60 3.784308 3.816169 AO30 4.00163 4.123858 AO20 4.114121 4.267876 AO10 3.930574 4.198802 AF90 3.493867 3.516695 AF60 3.62747 3.651419 AF30 3.806401 3.83443 AF20 3.79841 3.823642 AFl0 3.720279 3.741137 1.068436 1.0921 1.075236 0.88258 0.9076117 0.8850433 5.6806;2 5.733896 5.742389 0.086189 0.08157463 0.07640658 4.723351 4.749903 4.794727 KT1M 2.622914E-08 TCMR 0.06075323 CMFF 2.664601E-05 LT2C 1531.191 -]0- 2.613257 2.614141 2.615563 0.0222683 0.02173294 0.02087073 8.95537 8.984177 9.007221 9.022585 9.030266 9.030266 Contenls of Data Frame at 18000. (ft), 5486.4 (m) INDE 2160000 GR 92.01839 RHGX 2.952684 SP -28.375 CFTC 1129.555 CNTC 2917.529 ECGR 116.6097 PXND 0.1755331 NPHI 0.2759693 NPHI 0.2804734 CRAT 2.615518 GDEV 30.96033 MRES 11.95146 M'I'EM 195.9952 BS 8.5 CS 568.1479 CVEL -9.469133 TENS 2582. KTIM 0.0002629918 KSDR 0.001008932 KCMR 0.001008932 TCMR 0.08349337 CMFF 0.001898156 CMRP 0.02713555 BF-V 0.08159521 T2LM 2.278227 T12R 0. LT2C 1531.191 4.646035 4.671931 4.519869 4.51108 ATD2 8.890717 8.897654 ATD1 8.890717 8.897654 AT90 4.518997 4.503795 AT60 4.685352 4.667828 AT30 4.798873 4.800644 AT20 4.873462 4.926938 AT10 4.637983 4.683489 AO90 4.196873 4.494765 AO60 4.364964 4.685575 AO30 4.603234 4.759379 AO20 5.34289 5.118593 AO10 4.667269 4.752223 AF90 4.504013 4.493133 AF60 4.693168 4.680215 AF30 4.881099 4.865145 AF20 4.865614 4.857709 AFl0 4.661448 4.654703 2.452793 2.464005 2.343314 3.437192 3.451575 3.152857 4.967891 4.964791 4.959273 0.00307487 0.004017559 0.004017559 5.52665 5.602493 5.579799 2.612569 2.61306 2.613788 0.02268574 0.02238837 0.02,194665 8.932325 8.933477 8.943848 8.933477 8.938087- 8.947304 Contents of Data Frame at 17500. (ft), 5334. (m) INDE 2100000 GR 92.53748 RHGX 2.965149 SP -11.625 CFTC 1037.221 CNTC 2825.403 ECGR 117.5931 PXND 0.1884232 NPHI 0.2870612 NPHI 0.3017316 CRAT 2.693894 GDEV 33.9957 MRES 11.95146 MTEM 189.4467 BS 8.5 CS 514.6451 CVEL -8.577419 TENS 2232. KTIM 0.0001046119 KSDR 0.0004747419 KCMR 0.0004747419 TCMR 0.07357877 CMFF 0.0013643 CMRP 0.02303421 BFV 0.07221447 T2LM 2.012304 T12R 0. LT2C 153;I.191 4.171172 4.23785 4.362373 4.440096 ATD2 8.917316 8.917032 ATD1 8.917316 8.917032 AT90 4.361787 4.355474 AT60 4.458581 4.450387 AT30 4.439835 4.492995 AT20 4.664764 4.766816 AT10 4.197925 4.285152 AO90 3.929941 4.265869 AO60 4.037308 4.390143 AO30 4.170312 4.661823 AO20 4.946226 5.221709 AO10 4.210069 4.680017 AF90 4.23553 4.266223 AF60 4.365221 4.395141 AF30 4.519095 4.570189 AF20 4.457144 4.501543 AFl0 4.041379 4.083736 1.996223 2.055758 2.060089 2.666767 2.753423 2.708777 5.956558 5.808611 5.664029 0.001928642 0.00414646 0.00552286 -]]- 3.420649 3.495166 3.65252 2.594529 2.596141 2.599019 0.03361905 0.03264167 0.03089803 8.998581 8.992819 8.995699 8.995699 8.992819 9.001461 Contents of Data Frame at 17000. (ft), 5181.6 (m) INDE 2040000 GR 68.37979 RHGX 2.833359 SP -35.8125 CFTC 1381.633 CNTC 3532.28 ECGR 88.90848 PXND 0.1988722 NPHI 0.2576048 NPHI 0.2727919 CRAT 2.535063 GDEV 47.45858 MRES 10.92467 MTEM 183.7041 BS 8.5 CS 489.4698 CVEL -8.157831 TENS 2256. KTIM 0.3677622 KSDR 0.02955186 KCMR 0.02955186 TCMR 0.1004048 CMFF 0.03771269 CMRP 0.06659399 BFV 0.06269209 T2LM 8.526165 T12R O. LT2C 1531.191 6.077145 7.489515 8.320604 8.471678 ATD2 11.42457 9.737833 ATD1 11.391 9.737833 AT90 8.323555 8.513885 AT60 8.514914 8.706839 AT30 9.460249 9.870256 AT20 14.88662 16.34412 AT10 7.28828 8.863661 AO90 7.832572 8.254734 AO60 7.974123 8.394604 AO30 10.14736 9.380793 AO20 7.578469 9.089542 AO10 5.931208 6.831628 AF90 8.145124 8.185722 AF60 8.478292 8.515533 AF30 9.300949 9.471735 AF20 8.561131 8.822819 AFl0 5.856033 5.902076 1.185232 1.285223 1.265741 0.9249697 1.029285 1.021298 3.451005 3.426235 3.40293 0.09311257 0.08347677 0.07107301 6.604611 6.88321 7.546053 2.476954 2.474077 2.473134 0.1048764 0.1066201 0.1q71917 9.565422 9.527014 9.488607 9.468122 9.447638 9.46044 Contents of Data Frame at 16500. (ft), 5029.2 (m) INDE 1980000 GR 94.13678 RHGX 2,928667 SP -57.75 CFTC 961.5437 CNTC 2596.148 ECGR 127.1231 PXND 0,1892675 NPHI 0.2787807 NPHI 0.2891159 CRAT 2.742392 GDEV 60.49617 MRES 11.95146 MTEM 178.2434 BS 8.5 CS 1739.488 CVEL -28.99147 TENS 1929. KT1M -999,25 KSDR -999,25 KCMR -999.25 4.683305 4.600464 5.02903 4.968843 ATD2 10.27726 10.24824 ATD1 10.27726 10.24824 AT90 5.045547 4.953705 AT60 5.253596 5.15577-1 AT30 5.464759 5.318353 AT20 5.175696 5.310308 AT10 4.647503 4.539542 AO90 4.619102 3.797227 AO60 4.786683 3.91306 AO30 5.310228 4.59016 AO20 4.127743 7.362836 AO10 3.983877 4.212607 AFg0 5.040645 5.035149 AF60 5.278598 5.274561 AF30 5.490019 5.482689 AF20 5.369139 5.327386 AFl0 4.737209 4.698578 0.9526006 0.8251871 0.8128083 0.7318228 0.5993181 0.5850134 4.747403 4.827458 4.898488 0.1341571 0.1438226 0.155858 4.823261 4.929312 4.948359 2.575283 2.571594 2.5678 - 17,- 0,04528349 0,0475187 0.04981821 10.21478 10.27247 10.2747 10.27051 10.26938 10.2692 Contents of Data Frame at 16000. (ft), 4876.8 (m) INDE 1920000 GR 87.35757 RHGX 2.972631 SP -34.5625 CFTC 849.4329 CNTC 2528.521 ECGR 118.7267 PXND 0.2087033 NPHI 0.2988801 NPHI 0.3310539 CRAT 2.888148 GDEV 62.05036 MRES 10.92467 MTEM 172.9442 BS 8.5 CS 1863.497 CVEL -31.95828 TENS 1310. K'I'IM -999.25 KSDR -999.25 KCMR -999.25 4.043093 3.906186 5.105305 5.092911 ATD2 10.1855 10.18252 ATD1 10.1855 10.18252 ATg0 5.212529 4.621311 AT60 5.329181 4.707631 AT30 4.843547 4.309259 AT20 4.549511 4.186512 ATIO 4.029787 3.763526 AO90 3.89979 3.563971 AO60 3.971466 3.605077 AO30 4.539251 4.519763 AO20 4.727898 3.32306 AO10 4.180097 3.684594 AFg0 4.942001 4.827819 AF60 5.108406 4.998246 AF30 5.328592 5.289602 AF20 4.713964 4.765724 AFl0 3.979595 4.019019 0,923351 0,9268413 0.9354939 0.6832316 0.6867698 0,7000254 4,361534 4.343382 4.325854 0.1582171 0.157616 0,1515967 5.366067 5,387043 5,406229 2.567957 2.566841 2.565532 0.04972284 0.05039981 0.05119295 10.40144 10,38992 10.44753 10.40144 10.3976 10,41297 End of File HILTD .001 ~ -13- LISTING of ALL PARAMETERS, COMMENTS and LOG CURVES for FILE: List of set - OUTP, Set Name 2 NAME MNEM TUNI PUNI DESC BS ..... '.-~'""i'~---1;~ .... CGR CGR GAPI GAPI CHR2 CHR2 CHRP CHRP CHRS CHRS CS CS F/HR F/HR CVEL CVEL F/HR F/HR DEV DEV DEG DEG DT1 DT1 US/F US/F DT2 DT2 US/F US/F DT2R DT2R US/F US/F DT DT US/F US/F DT4S DT4S US/F US/F DT DT US/F US/F DTD2 DTD2 F F DTD4 DTD4 F F DTRP DTRP US/F US/F DTRS DTRS US/F US/F DTSH DTSH US/F US/F AZ AZ DEG DEG HDAR HDAR IN IN HTEN HTEN LBF IRF I'n' ITT US US MRES MRES OHMM OHMM MTEM MTEM DEGF DEGF P1AZ PIAZ DEG DEG POTA POTA % % PR PR RB1 RB1 DEG DEG GR GR GAPI GAPI SPHI SPHI CFCF CFCF TENS TENS LBF LBF THOR THOR PPM PPM TPRA TPRA TURA TURA UPRA UPRA URAN UP, AN PPM PPM VPVS VPVS C13 C13 IN IN C24 C24 IN IN List of set - XNAM, Set Name 4 NAME MNEM TYPE NAME ORIG CNUM CGR CGR CHANNEL CGR 0 0 DEV DEV CHANNEL DEVI 0 0 DT ....... D'l_._.. CHANNEL.DT4P.. 0 0 -D'r DT CHANNEL DTCO 0 ~ 0 'DTSH DTSH CHANNEL DTSM 0 0 AZ AZ CHANNEL HAZI 0 0 HTEN HTEN CHANNEL HTEN 0 0 MRES MRES CHANNEL MRES 0 0 MTEM MTEM CHANNEL MTEM 0 0 P1AZ P1AZ CHANNEL PIAZ 0 0 RB1 RB1 CHANNEL RB 0 0 GR . GR . CHANN.EL SGR 0 0 C13 C13 CHANNEL C1 0 ' 0 C24 C24 CHANNEL C2 0 0 List of set - CONS, Set Name 5 NAME MNEM STAT TUNI PUNI DESC VALU lA lA ALLO PDAT PDAT ALLO EPD EPD ALLO .lIN .lIN LMF LMF ALLO APD APD ALLO .lIN .lIN EDF EDF ALLO .lIN .lIN EGL EGL ALLO .lIN .lIN EKB EKB ALLO .lIN .lIN 2A 2A AIIO SHT SHT ALLO DEGF DEGF BHS BHS ALLO MATR MATR ALLO BHT BHT ALLO DEGF DEGF GCSE GCSE Al_LO SDFA SDFA ALLO IN IN CD CD ALLO F F STEM STEM ALLO DEGF DEGF RW RW ALLO OHMM OHMM TWS TWS ALLO DEGF DEGF BSAL BSAL ALLO PPM PPM MCST MCST ALLO DEGF DEGF RMCS RMCS ALLO OHMM OHMM MFST MFST Al_LO DEGF DEGF RMFS RMFS ALLO OHMM OHMM MST MST ALLO DEGF DEGF RMS RMS ALLO OHMM OHMM DFPH DFPH Al_LO DFL DFL ALLO C3 C3 DFV DFV Al_LO S S DFD DFD Al_LO LEFG LB/G CWEI CWEI At. LO LB/F LB/F CSIZ CSIZ ALLO IN IN BS BS ALLO IN IN MHD MHD ALLO DEG DEG BP Exploration (Alaska) Inc. Ground Level 1260.(.11N) Rotary Table 2754.(.11N) 4014.(.11N) 1260.(.11N) 4134.(.11N) BP Exploration (Alaska) Inc. 67.99998(DEGF) OPEN MME 211.9999(DEGF) BS 0.9(IN} 15850.(F) -40.(DEGF) 1.(OHMM) 100.(DEGF) 33000.(PPM) 60.(DEGF) 0.76(OHMM) 60.(DEGF) 0.142(OHMM) 60.(DEGF) 0.235(OHMM) 9. 2.8(C3) : 66.(S) 14.(LB/G) &SON) 64.15001(DEG) SNAM .002 - 14- CBDR CBDR ALLO LUN LUN ALLO TDD TDD ALLO LCC LCC ALLO PVER PVER ALLO SON SON ALLO HiDE HIDE ALLO HID1 HID1 ALLO HID2 HID2 ALLO R16 R16 ALLO OS3 OS3 ALLO OS2 OS2 ALLO OS1 OS1 ALLO MCSS MCSS ALLO MFSS MFSS ALLO MSS MSS ALLO TCS TCS ALLO DCS DCS ALLO DFT DFT Al_LO WITN WITN Al_LO ENGI ENGI ALLO LUL LUL ALLO DATE DATE Al_LO RANG RANG Al_LO TOWN TOWN ALLO SECT SECT ALLO APIN APIN ALLO DMF DMF ALLO FL1 FL1 ALLO FL FL ALLO STAT STAT ALLO FN FN ALLO WN WN ALLO VHOL VHOL ALLO VCEM VCEM ALLO ORDU ORDU UNAL F3 F3 F3 F3 FEET List of set - XNAM, Set Name 6 NAME MNEM TYPE NAME ORIG CNUM lA lA PARAMETER COMPANY 0 2A 2A PARAMETER COMPANY 0 Crnnt: 15852.(F) 1805 18740.(F) 44O 8C1-205 6109824 Formation Micro-lmager Sonic Shear Imager Natural Gamma Ray - Caliper Crew: Mike FousFTroy Pabst/Greg Pearson Cores RFT PEX-CMR Measured Measured Mud Engineer 12:30 15-MAR-1999 Fresh Water Mud Jerry Sic)k/ Jim Seccomb/... Khedher Mellah Kenai - Alaska 15-MAR-1999 21E 10N 21 50-089-20027 Kelly Bushing Total depth: 3671' NSL, 1058' WEL Surface: 1682' NSL, 4508' WEL Alaska Prudhoe Bay Red Dog #1 67.95436(F3) 21.72137(F3) Cmnt: Cmnt: EDITED DATA - FROM DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline Cmnt: Cmnt: ..... .********* Cmnt: * Schlumberger * Crnnt: .............. Cmnt: Company: Cmnt: Well: Cmnt: Field: Cmnt: County: Crnnt: State: .Crnnt: Cmnt: Schlumberger Data Services BP Exploration (Alaska) Inc. Red Dog #1 Wildcat No~h Slope Alaska Cmnt: Cmnt: This data file contains primary Icg curves and is grouped into Cmnt: THREE logical files as follows: Omni: trent: ................................................... Cmnt: PRIMARY DEPTH LOG: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: C~nnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: Crnnt: Crnnt: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: 1. PLATFORM EXPRESS - Array InductionJLithoDensity/Compensa.ted Neutron and CMR - Combinable Magnetic Resonance (ALT, CNL, LDT, CMR) Recorded File Name Interval Top Interval Bottom PLAY_011 .dlis 15734.00(ft) 18727.00(ff) 2. DSI/FMI - Dipole Sonic NGT and Micro Imager Calipers/Deviations (no Images), 3 files spliced & depth matched Recorded File Names Interval Top IntervalBottom PLAY_O63.dlis 1 4530.6250 15900.3965 PLAY_062,dlis 15900.3965 16949.6582 PLAY_061.dlis 16949.6582 18570.5000 Summary of shifts applied to SONIC/NGT data: Final Logged Depth Depth ft ft 18570.500 18578.500 17806.600 17814.820 17407.100 17413.09 17305.700 17311.449 16849.300 16855.691 14530.500 14537.000 3. LWD - CDR/CDN/RAB - tools run over selected intervals, ~ curves depth matched to the PLATFORM EXPRESS Recorded File Names Interval Top Interval Bottom example Array (ft) (ft) DlisComposlnt.dlis 79.0000 17900.1309 PEF .RAB .009 LWD_015.dlis 17900.1309 18850.4023 PEF .CDR .010 LWD_016.dlis 18850.4023 19400.5000 PEF .CDR .015 Summary of shifts applied to LWD data: Final Logged - 15 Cmnt: Depth Depth Cmnt: ft ft Cmnt: 19400.500 19421.50000 Ca~nt: 17792.900 17813.98242 Cmnt: 17693.700 17713.88672 Cmnt: 17635.700 17653.87109 C~nnt: 17471.600 17488.88672 Crnnt: 17396.500 17413.36914 Cmnt: 17325.700 17343.38867 Crnnt: 17308.400 17324.34375 Cmnt: 17296.400 17309.06250 Cmnt: 17257.000 17277.61719 Grant: 17233.100 17253.25586 Cmnt: 17163.800 17175.96680 Cmnt: 16995.000 17007.88281 Cmnt: 16918.600 16930.37305 C~nnt: 16842.000 16853.74805 Cmnt: 16803.500 16817.42969 Cmnt: 16784.900 16796.61133 Cmnt: 15877.300 15894.84082 Cmnt: 78.500 96.00000 Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: C~nnt: C~nnt: Cmnt: Cmnt: Cmnt: C~nnt: C_,~nnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: C~'nnt: Crnnt: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: C~mt: Cmnt: Cmnt: .Cmnt: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: Header Data from Primary Depth Control Log: Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Sudace: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: FMI-DSI, RFT, Cores, Permanent Datum: Ground LevelElev: Log Measured From: Rotary Tab Drilling Measured From: Rotary Tab Elevation: K.B.: 34.45 D.F.: Date: 15-MARo1999 Run No: One Depth Driller: 18740.00 Depth Logger: 18740.00 BTM Log Interval: 18740.00 Top Log Interval: 14500.00 Casing Driller: 9.625 @ Casing Logger: Bit Size: 8.5 Type Fluid in Hole: Fresh Water Mud Dens: 14.00 pH: 9.00 Source of Sample: Mud Engineer Rm @ Meas Temp: 0.23 @ Rmf @ Meas Temp: 0.14 @ Rmc @ Meas Temp: 0.76 @ Source: Rmf: ~ Measured Rm @ BHT: 0.07 @ Time Circ. Stop: 12:30 Logger on Bottom: 10:28 33.45 G.L: Rge: 21E 1(~.50 Above Perm Datum 10.50 Max Rec Temp: 203.00 Equip: 1805 Location: Recorded by: Khedher MellatV Dani Witnessed by: Jerry Siok. Magnetic Deck 0.000 Visc: 66.00 Fluid Loss: 2.80 Rmc: 203.00 Measured Cmnt: C~nnt: Cmnt: Grant: Cmnt: Cmnt: Ca~nt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: Crrmt: Remarks: Crew: Mike FoustYTroy Pabst/Greg Pearson REmarks from DSI Run: Remarks: DSI modes run from 18530 to 1688ft - Cress Dipole: BCR mode - Upper dipole - Lower Dipole - Compressional DSI data missing from 16970 to 16945 DSI modes from 16945 to 14500 - Upper dipole - Compressional Crew: Mike FoustJTroy Pabst/Greg Pearson Cmnt: C~mt: LWD Header - taken from - CDR .017 field data Cmnt: C4nnt: ................. Schlumberger Data Services C~rmt: * Schlumberger * Measured Depth LOg Cmnt: Cmrlt: ............. Cmnt: Cmnt: Company: BP Exploration (Alaska) Inc. C~mt: Well: Red Dog #1 Cmnt: F~eld: Wildcat Cmnt: County: Nabors 28E Cmnt: State: Alaska Cmnt: Service Order #: Cmnt: Location: Cmnt: Sec: SEC. Twn: Rge: Cmnt: Cmnt: APl No: 50-089-20027- Sec: SEC. Twn: Cmnt: Other Services: MWD Direct, Annular Pr, , Cmnt: Permanent Datum: Mean Sea Level Cmnt: Elev: 0.00 Crnnt: Log Measured From: Drill Floo 43.95 Rge: Above Perm Datum -]6- Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt:. Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: List Drilling Measured From: Elevation: K.B.: 0.00 D.F.: Date: 99 Run No: 16 Depth Driller: 0.00 Depth Logger: 0.00 BTM Log Interval: 0.00 Top Log Interval: 0.00 Casing Driller: 0.000 @ Casing Logger: Bit Size: 16. Type Fluid in Hole: Dens: 0.00 pH: 0.00 Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: bosse Witnessed by: Magnetic Decl: 0.000 43.95 G.L.: 10.50 Visc: 0.00 Fluid Loss: 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 Rmc: 0.00 @ 0.00 0.00 Location: 1 ........... [116,0,INDEX of set - FRAME, Set Name 64 NAME DESCRIPTION CHANNELS INDEX-TYPE BOREHOLE-DEPTH DECREASING -60.(.11N) ........................... EXTERNAL-INDEX BS CGR CHR2 CHRP CHRS CS CVEL DEV DT1 DT2 DT2R DT DT4S DT DTD2 DTD4 DTRP DTRS DTSH H DAR HTEN ITl' MRES MTEM P1AZ POTA PR RB1 GR SPHI TENS THOR TPRA UPRA URAN VPVS C13 C24 1 O{IN) -999,25 .lIN 68 \ I 184 List of set - CHANNEL, Set Name 65 DIRECTION SPACING ENCRYPTED INDEX-MIN INDEX-MAX INDEX-STYLE INDEX 68 .lIN 1 .... 1 ...... 0 0 ................... I 1 0 1 BS 68 IN I .... I ...... 0 2 ................... I 1 AUX 0 CGR 68 GAPI I ........ ~'.~'"'i" . ..... 0 2 ................... I 1 NGT 4 CHR2 68 I ....... ::::""i"' . ..... 0 2 ................... 1 1 LDM 8 CHRP 68 I ........ ::::":1'" . ..... 0 2 ................... 1 LDM 12 CHRS 68 I ........ ::::":1'" . ..... 0 2 ................... 1 1 LD M 16 CS 68 F/HR I ..... ~*':1' ..... . ..... 0 2 ................... I 1 AUX 20 .................. NAME PROPERTIES REPRESENTATION-CODE UNITS DIMENSION AXIS ELEMENT-LIMIT SOURCE APl-CODES FILE-NUMBER SERVICE-ID SERVICE-ORDER-NUMBER OFFSET-IN-FRAME ARTIFICIAL-CHANNEL -17- CVEL ................... 68 AUX DEV ................... 68 FMI DT1 ................... 68 LDM DT2 ................... 68 LDM DT2R ................... 68 LDM DT ................... 68 LDM DT4S ................... 68 LDM DT ................... 68 LDM DTD2 ................... 68 LDM DTD4 ................... 68 LDM DTRP ................... 68 LDM DTRS ................... 68 LDM DTSH ................... 68 LDM FMI HDAR ................... 68 FMI HTEN ................... 68 AUX ITl' ................... 68 LDM MRES ................... 68 AUX MTEM ................... 68 AUX P1AZ ................... 68 FMI POTA ................... 68 RB1 GR NGT PR ................... 68 LDM ................... 68 LDM NGT SPHI ................... 68 LDM TENS ................... 68 AUX THOR ................... 68 NGT TPRA ................... 68 NGT TURA ................... 68 NGT UPRA ................... 68 NGT UP, AN ................... 68 NGT VPVS ................... 68 LDM C13 ................... 68 FMI C24 ................... 68 FMI F/HR 1 .... 1 ...... 0 1 1 24 DEG 1 ....... iiii":1'"' . ..... 0 1 1 28 US/F 1 ........ ::::"i'" . ..... 0 1 1 32 US/F 1 ...... ~'"i .... . ..... 0 1 1 36 US~F I ....... ::::"T" . ..... o I 1 4o U~/f ~ ....... .:::'"i .... . ..... o I 1 US/F 1 ....... ::::"i .... . ..... 0 I 1 US/F 1 ...... ~'"i .... . ..... 0 1 1 52 F I ....... iiii";t'"' . ..... 0 1 1 56 F I ....... iiii":1'"' . ..... 0 I 1 60 USJF I ....... ~'.'"'~"' . ..... 0 1 1 64 US/F 1 ....... ::::'"'["' . ..... 0 1 1 68 US/F I ....... ::::'"'~"' . ..... 0 1 1 72 DEG I ...... ::::":1' .... . ..... 0 1 1 76 IN 1 ...... '.'.'.:'"'i .... . ..... 0 I 1 80 LBF I ....... ::::'"'i"' . ..... 0 I 1 84 US 1 ...... ::::"'~ .... · ..... 0 1 1 88 OHMM 1 ......... ::::'"~' . ..... 0 I 1 DEGF 1 ........ ::::'"'~" . ..... 0 I 1 DEG 1 .... 1 ...... 0 1 1 100 % 1 ......... ::::'"~' . ..... 0 1 1 104 1 ...... ::::'"i .... . ..... 0 1 1 108 DEG 1 ........ ::::'"~" - ....... 0 1 1 112 GAPI 1 ....... ::::""~"' . ..... 0 1 116 CFCF 1 ....... ::::'"i"' . ..... 0 1 1 120 LBF I ...... .':::"i ..... . ..... 0 I I _ 124 PPM 1 .......... ::::":1' . ..... 0 1 1 . 128 ~ ....... ::::'T" . ..... o I 1 132 1 ....... ::::'"~"' . ...... 0 1 1 136 1 ....... ::::'"i"' . ..... 0 I 1 140 PPM I ......... ::~':'"i' . ..... 0 I 1 144 ~ ....... ::::"Y' . ..... o 1 1 148 IN 1 .... ::.':"½ ....... · ..... 0 4 4 152 IN 1 ..... :::71' ..... . ..... 0 4 4 168 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 Contents of Data Frame at 18578.5 (ft), 5662.7268 (m) INDE 2E+06 BS 8.5 CGR 142.7057 CHR2 0.9560424 CHRP 0.959762 CHRS 0.7575819 CS 60.20872 DT 84.26689 DTD2 -999.25 DTD4 -999.25 DTRP 84.26689 DTRS 159.0999 DTSH 163.8125 AZ 293.655 HDAR 8.812628 HTEN 1103.171 ITT 42.13345 MRES 11.95146 MTEM 203.4334 P1AZ 59.17176 POTA 2.350697 PR 0.3200809 RB1 128.6311 GR 121.6326 SPHI 0.209653 TENS 8061. THOR 23.33692 TPRA 9.927658 TURA 46.67384 UPRA 0.2127029 UP, AN -2.537168 VPVS 1.943972 C13 C24 Contents of Data Frame at 18500. (fi). 5638.8 (m) INDE 2E+06 BS 8.5 CGR 141.4184 CHR2 0.9732476 CHRP 0.9843279 CHRS 0.9209808 CS 481.9966 DT 85.37572 DTD2 -999.25 DTD4 -999.25 DTRP 85.37572 DTRS 161.9907 DTSH 166.7502 AZ 294.126 HDAR 8.772779 HTEN 1095.229 ITT 6584.558 MRES 11.95146 MTEM 203.4334 P1AZ 62.43752 POTA 2.326184 PR 0.322363 RB1 131.6.537 GR 121.6326 SPHI 0.2150473 TENS 7942.042 THOR 23.14008 TPRA 9.94766 TURA 46.28017 UPRA 0.2149443 URAN -2.382189 VPVS 1.953135 C13 8.794798 8.794798 8.794798 8.794798 C24 8.750816 8.750816 8.750816 8.750816 Contents of Data Frame at 18000. (ft), 5486.4 (m) INDE 2E-H:)6 BS 8.5 CGR 105.9964 CHR2 0.9751638 CHRP 0.988833 CHRS 0.9561785 CS 492.9582 DT 82.3251 DTD2 -999.25 DTD4 -999.25 DTRP 82.3251 DTRS 150.4772 DTSH 157.6066 AZ 296.7984 HDAR 7.048108 HTEN 1039.116 ITT 48555.77 MRES 11.95146 MTEM 193.3722 P1AZ 46.85512 POTA 3.339998 PR 0.3123866 RB1 113.2639 GR 112.6081 SPHI 0.199856 TENS 7555.167 THOR 10.75242 TPRA 3.219209 TURA 13.54325 UPRA 0.2382745 URAN 0.7960373 VPVS 1.914439 C13 7.664129 7.604966 7.247798 6.912542 C24 7.780976 7.507052 7.249416 7.022874 Contents of Data Frame at 17500. (ft), 5334. (m) INDE 2E+06 BS 8.5 CGR 111.1007 CHR2 0.969574 CHRP 0.9772736 CHRS 0.9271564 CS 809.8567 DT 80.90456 DTD2 -999.25 DTD4 -999.25 DTRP 80.90456 DTRS 151.7007 DTSH 158.942 AZ 301.4069 HDAR 4.269489 HTEN 927.418 ITT 90032.5 MRES 11.95146 MTEM 164.5678 P1AZ 53.35772 POTA 3.556894 PR 0.3251398 RB1 116.1426 GR 119.5151 SPHI 0.1923861 TENS 7651.096 THOR 11.03874 TPRA 3.115911 TURA 10.87354 UPRA 0.2872611 URAN 1.01309 VPVS 1.964583 C13 4.265712 4.265712 4.265712 4.265712 C24 4.273271 4.273271 4.273271 4.273271 Co, tents of Data Frame at 17000. (fi). 5181.6 (m) INDE 2E+06 BS 8.5 CGR 103.667 CHR2 0.9550521 CHRP 0.987843 CHRS 0.9011376 CS 630.0194 DT 78.64.552 DTD2 -999.25 DTD4 -999.25 DTRP 78.64552 DTRS 151.2503 DTSH 155.746 AZ 301.608 HDAR 0.6740217 HTEN 925.9778 Fir 130470.7 MRES 10.92467 MTEM 179.9301 PIAZ 47.74742 POTA 4.278477 PR 0.3288728 RB1 113.6753 GR 65.51169 SPHI 0.1799651 TENS 6781.992 THOR 6.338198 TPRA 1.481415 TURA 12.6764 UPRA 0.116864 URAN -1.824678 VPVS 1.980354 C13 C24 Contents of Data Frame at 16500. (ft). 5029.2 (m) INDE 2E+06 BS 8.5 CGR 97.90842 CHR2 0.9403126 CHRP 0.9761028 CHRS 0.01563174 CS 1214.581 DT 79.64429 DTD2 -999.25 DTD4 -999.25 DTRP 79.64429 DTRS 162.599 DTSH 154.2907 AZ 301.1736 HDAR 8.075617 HTEN 1077.926 ITl' 43909.7 MRES 10.92467 MTEM 176.7793 P1AZ 49.98967 POTA 3.~4 PR 0.3172038 RB1 125.4144 GR 104.9457 SPHI 0.1855426 TENS 6880.491 THOR 8.492229 TPRA 2.500335 TURA 10.5366 UPRA 0.2513565 URAN 0.8472754 VPVS 1.937379 C13 7.984466 7.990438 7.990438 7.990438 C24 - - - 8.125328 8.21269 8.308315 8.324383 ' C<~tents of Data Frame at 16000. (ft). 4676.8 (m) -~ INDE 2E+06 BS 8.5 CGR 105.0443 CHR2 0.9513804 CHRP 0.9437423 CHRS 0.07002567 CS 1188.988 DT 79.88718 DTD2 -999.25 D'I'D4 -999.25 · -DTRP 79.88718 ' DTRS 167.4897 DTSH 143.8428 AZ 301.4733 HDAR 8.369715 HTEN 827.6384 ITT 83978.7 MRES 11.7994 MTEM 170.8313 P1AZ 43.89558 POTA 3.406269 PR 0.2767509 RB1 115.5931 GR 111.4392 SPHI 0.189858 TENS 6545.533 THOR 10.25834 - - TPRA 3.011293 TURA 13.69402 UPRA 0.2259831 URAN 0.7699348 VPVS 1.800756 C13 8.038357 8.012604 7.993393 7.990438 C24 8.876123 8.734161 8.677546 8.670858 Contents of Data Frame at 15500. (ft). 4724.4 (m) · INDE 2E+06 BS 8.5 CGR 57.16171 CHR2 0.9566674 CHRP 0.7588019 CHRS 0.9653535 CS' 1739.751 DT 54.39606 DTD2 -999.25 DTD4 -999.25 DTRP 54.39606 DTRS 78.49843 DTSH 157.1684 AZ 259.1082 HDAR 4.1099~2 HTEN 645.5466 ITT 21705.34 MRES O. MTEM 167.9141 P1AZ 353.0791 POTA 1.828621 PR 0.4319551 RB1 95.47935 GR 58.56911 SPHI -0.01842928 TENS 6318.292 THOR 5.655314 TPRA 3.10896 TURA 11.37063 UPRA 0.2734556 UP, AN 0.1694493 VPVS 2.889328 C13 4.108329 4.108329 4.108329 4.10~329 C24 4.086707 4.086707 4.086707 4.106474 Contents of Data Frame at 15000. (ft). 4572. (m) - INDE 2E+06 BS 8.5 CGR 63.58601 CHR2 0.964535 CHRP 0.9444329 CHRS 0.936185 CS 1741.429 DT 54.53638 DTD2 -999.25 DTD4 -999.25 DTRP 54.53638 DTRS 82.26659 DTSH 155.1176 AZ 67.45868 HDAR 4.097698 HTEN 635.6213 I'Fi' 49288.89 MRES 10.92467 MTEM 162.1223 P1AZ 159.4105 POTA 2.368887 PR 0.4294706 RB1 93.84012 GR 63.19082 SPHI -0.01677377 TENS 6067.312 THOR 4.942135 TPRA 2.086269 TURA 9.88427 UPRA 0.2110696 URAN -0.04758089 VPVS 2.844305 C13 4.082098 4.082098 4.082098 4.082098 C24 4.113358 4.113358 4.113358 4.113358 End of File SNAM .002 - 20 - LISTING of ALL PARAMETERS, COMMENTS and LOG CURVES for FILE: List of set - OUTP, Set Name 2 NAME MNEM TUNI PUNI DESC ATDN ATDN DB DB RA ATRD ATRU A'~rN ATUP DT GR VERD CRAT NPHI RTIM ROP5 ROBU ROBR ROBL ROBB RHOB PSRU PSRD RP PEU PER PEL PEF PEB HORD DTAB DRHU DRHR DRHO DRHL DRHB DPOR DPHU DPHR DPHL DPHI DPHB DCAL BS DTrP DTRP DTC CHTP CHRP DTCU DT CHCU CHCO RING RBIT BSAV BMAV BDAV RA OHMM OHMM ATRD OHMM OHMM ATRU OHMM OHMM Al'TN DB DB ATUP DB DB DT US/F US/F GR GAPI GAPI VERD IN IN CRAT NPHI CFCF CFCF RRM S S ROP5 F/HR F/HR ROBU GJC3 G/C3 ROBR G/C3 G/C3 ROBL G/C3 G/C3 ROBB G/C3 G/C3 RHOB G/C3 G/C3 PSRU OHMM OHMM PSRD OHMM OHMM RP OHMM OHMM PEU PER PEL PEF PEB HORD IN IN DTAB S S DRHU G/C3 G/C3 DRHR G/C3 G/C3 DRHO G/C3 G/C3 DRHL G/C3 G/C3 DRHB G/C3 GJC3 DPOR CFCF CFCF DPHU CFCF CFCF DPHR CFCF CFCF DPHL CFCF CFCF DPHI CFCF CFCF DPHB CFCF CFCF DCAL IN IN BS IN IN DTTP US/F US/F DTRP US/F US/F DTC US/F US/F CHTP CHRP DTCU US/F US/F DT US/F US/F CHCU CHCO RING OHMM OHMM RBIT OHMM OHMM BSAV OHMM OHMM BMAV OHMM OHMM BDAV OHMM OHMM List of set - XNAM, Set Name 4 NAME MNEM TYPE NAME ORIG CNUM RA RA CHANNEL ATR 0 0 A'I-fN ATTN CHANNEL AI-I'N 0 0 DT DT CHANNEL DT 0 0 GR GR CHANNEL_GFt_CDR 0 0 NPHI NPHI CHANNEL TNPH 0 0 ROBU ROBU CHANNEL ROBU 0 0 ROBR ROBR CHANNEL ROBR 0 0 ROBL ROBL CHANNEL ROBL 0 0 ROBB ROBB CHANNEL ROBB 0 0 RHOB RHOB CHANNEL RHOB 0 0 RP ' RP CHANNEL PSR O 0 PEF PEF CHANNEL PEF 0 0 PEB PEB CHANNEL PEB 0 0 DRHO DRHO CHANNEL DRHO 0 0 DRHB DRHB CHANNEL DRHB 0 0 DPOR DPOR CHANNEL DPOR 0 0 DPHI DPHI CHANNEL DPHI 0 0 DCAL DCAL CHANNEL DCAL 0 0 DT DT CHANNEL DTCO 0 0 CHCO CHCO CHANNEL CHCO 0 0 RING RING CHANNEL RING 0 0 RBIT RBIT CHANNEL RBIT 0 0 BSAV BSAV CHANNEL BSAV 0 0 BMAV BMAV CHANNEL BMAV 0 0 BDAV BDAV CHANNEL BDAV 0 0 List of set - CONS, Set Name 5 NAME MNEM STAT TUNI PUNI DESC VALU lA lA ALLO PDAT PDAT ALLO EPD EPD ALLO .lIN .lIN LMF LMF ALLO APD APD At_LO .lIN .lIN F_DF EDF ALLO .lIN .lIN EGL EGL ALLO .lIN .lIN BP Exploration (Alaska) Inc. Ground Level 1260.(.11N) Rotary Table 2754.(.11N) 4014.(.11N) 1260.(.11N) SNAM .003 EKB 2A MTO1 MF1 DLT DPLF TOTD STRN ENRN DPRF SDAT GMDC GMLD GMLH LDLS LTVD LAZM LINC LDEP GMLG LOCH LOCG TOTC TFCP DIPR MDCP TPRA AQDY JSTM DFDL RCON REFP FMFS MFD MWIN MRIN MCIN MTDH MTIN HTVD BTVD BHAN PCNT SWDT ALGO MNTH NOZA NOZ6 NOZ5 NOZ4 NOZ3 NOZ2 NOZ1 SURL SURI CALC DSCF BCOF MWGT DWBR SWBR 3A PV YP R600 R300 R3 X~DM XPNM A M 4A MDEN RTST GRAD PGRS 5A S3MG S1MG LSMG L4MG S3AL SlAL L5AL L4AL PEFO 6A 7A PEFS HSFZ CDNV 8A 9A GROF GRSC GTSF 10A ACF LAMB M~M MLTG MLWN MLA1 MIRS MLSS MLSB EKB 2A MTO1 MF1 DLT DPLF TOTD STRN ENRN DPRF SDAT GMDC GMLD GMLH LDLS LTVD LAZM LINC LDEP GMLG LOCH LOCG TOTC TFCP DIPR MDCP TPRA AQDY JSTM DFDL RCON REFP FMFS MFD MWIN MRIN MCIN MTDH MTIN HTVD BTVD BHAN PCNT SWDT ALGO MNTH NOZA NOZ6 NOZ5 NOZ4 NOZ3 NOZ2 NOZ1 SURL SURI CALC DSCF BCOF MWGT DWBR SWBR 3A PV YP R600 R300 R3 )~PDM XPNM A M 4A MDEN RTST _ GRAD PGRS 5A S3MG S1MG L5MG L4MG S3AL S 1 AL L5AL L4AL PEFO 6A 7A PEFS HSFZ CDNV 8A 9A GROF GRSC GTSF 10A AOF LAMB MLRM MLTG MLWN MLA2 MLA1 MLBS MLSS MLSB ALLO .lIN .lIN ALLO ALLO F F ALLO F F ALLO F F Al_LO F F ALLO F F ALLO ALLO ALLO ALLO ALLO DEG DEG ALLO DEG DEG ALLO ALLO D/HF D/I-IF ALLO F F ALLO DEG DEG ALLO DEG DEG ALLO F F ALLO ALLO ALLO Al_LO DEG DEG Al_LO DEG DEG ALLO DEG DEG ALLO DEG DEG ALLO DEG DEG ALLO ALLO S S A~O AIIO ALLO F F A~_O OHMM OHMM ALLO G/C3 G/C3 ALLO LB/G LB/G AIIO OHMM OHMM ALLO MM/M MM/bl ALLO DEGF DEGF ALLO DEGF DEGF ALLO F F ALLO F F A~O A~O AIIO ALLO ALLO ALLO IN2 IN2 A~O I/~ 1/32 AIIO 1/~ 1/32 AIIO I/~ 1/32 AIIO I/~ 1/32 AIIO 1/~ 1/32 AIIO I/~ 1/32 AIIO AIIO ALLO , ALLO ' ALLO ALLO LB/G LB/G AIIO ALLO ~.BF KLBF A~O PSI PSI ALLO CP CP ALLO PSi PSI ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO G/C3 G/C3 ALLO DEGF DEGF ALLO D/HF D/HF A~O AIIO AIIO AIIO AIIO AIIO AIIO A~O A~O AIIO A~O ALLO AIIO AIIO AIIO AIIO ALLO RPM RPM ALLO RPM RPM AIIO AIIO AIIO ALLO PPK PPK AIIO AIIO AIIO AIIO ALLO KLBF KLBF AIIO AIIO ALLO IN IN AIIO AIIO -2! - 4134.(.11N) BP Exploration (Alaska) Inc. 1536.(F) 110.(F) 1536.(F) 110.(F) 1536.(F) 28538904 28538904 Driller Pipe Tally 25 January 1999 28.81841 (DEG) 80.87704(DEG) 1148.688 1.028845(D/HF) 12378.58(F) 332.02(DEG) 15.(DEG) 19400.(F) 1002.671 1148.69 1002.67 28.81(DEG) 221.2(DEG) 80.88(DEG) 28.81 (DEG) 351.59(DEG) 917049600(S) 10. NO 0.(F) 1.2(OHMM) 1.(G/C3) 10.(LB/G) 100.(OHMM) IO0.(MM/M) 100.(DEGF) 80.(DEGF) 100.(F) 100.(F) 1 1 1 1 1 1 .(IN2) 1.(V32) 1 .(I/32) 1 .(V32) 1 .(I/32) 1.(I/32) 1.(I/32) 1. 1. O. 1. 1. 9.700001 (LB/G) 3. 10.(KLBF) o.(PSl) 22.(CP) 46.(PSI) 3. 2. 0. 0.625 0.375 0.6700001 2 SAND 2.65(G/C3) 32.(DEGF) 1 .(D/HI=} YES O. 4901.11 1047.78 213.88 211.71 2426.77 344.57 36.91 0.5 1.65 0.55O0001 4.5 2. 4.1 20.(RPM) 20.(RPM) 0. 1. 3 0.(PPK) 0.5808001 24.19 1. 1. 25.(KL~F) 0.15 0.15 12.2.5(IN) 15. 5. - 22 - MLLC MLLC MLUC MLUC MLFR MLFR MLTA MLTA MLSP MLSP MLST MLST XIW5 XIW5 XDW3 XDW3 ×DW2 XDW2 ×DW1 XDW1 ×IW4 XIW4 ×IW3 XIW3 XJW2 XIW2 XJW1 XlW1 DTOF DTOF DWOF DWOF 11A 11A 12A 12A 13A 13A 14A 14A 15A 15A 16A 16A 17A 17A 18A 18A 19A 19A MGDF MGDF SWP5 SWP5 SWP4 SWP4 SWP3 SWP3 SWP2 SWP2 SWP1 SWP1 P4DR P4DR P3DR P3DR P2DR P2DR PIDR P1DR DHRF DHRF PFRF PFRF PPRF PPRF RVFC RVFC P4FC P4FC P3FC P3FC P2FC P2FC PIFC PIFC P4EF P4EF P3EF P3EF P2EF P2EF PIEF P1EF P4CP P4CP P3CP P3CP P2CP P2CP P1CP P1CP TWS TWS RW RW CWEI CWEI CSIZ CSIZ BS BS HIDE HIDE HID1 HID1 HID2 HID2 OS2 OS2 OS1 OS1 ENGI ENGI RUN RUN SECT SECT LONG LONG LATI LATI A.PIN APIN STAT STAT COUN GOUN FN FN WN WN C~11 CN1 RLAB RLAB 2{3A 20A LLAB U.AB ORDU ORDU UNAL ALLO ALLO ALLO ALLO DEG DEG ALLO F F ALLO F F ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO KFLB KFLB ALLO KLBF KLBF ALLO ALLO ALLO ALLO ALLO ALLO ALLO F F ALLO ALLO PSI PSI ALLO ALLO ALLO F F ALLO F/HR F/HR ALLO F F ALLO F F ALLO ALLO ALLO ALLO ALLO R/GA R/GA ALLO GPM GPM ALLO PSI PSI ALLO ALLO ALLO ALLO ALLO ALLO % % ALLO % % ALLO % % ALLO % % ALLO BBL BBL ALLO BBL BBL ALLO BBL BBL ALLO BBL BBL ALLO DEGF DEGF ALLO OHMM OHMM ALLO LB/F LB/F ALLO IN IN ALLO~ IN IN ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO 0.1 0.1 0.4 20.(DEG) 50000.(F) O.(F) O. 0.01 0.00563 0.00563 -0.0243 -0.0246 -0.0264 -0.02 -9.(KFLB) -64.(KLBF) 13 27.45099 0.3228434 917807719 1786.119 847.3715 4272.871 (F) 9.700001 2152.77(PSI) -1 53. 10.(F) 36000.(F/HR) O. O. O. O. 0.(R/GA) 0.(GPM) 125.(PSI) 0.0770(X)01 1. 1. 1. 1. 100.(%) 100.(%) 9~.(%) 96.(%) 0.1(BBL) 0.1(BBL) 0.10491(BBL) 0.10491(BBL) 155.(DEGF) 0.15(OHMM) 0.(LB/F) 0.(IN) 16.(IN) Measured Depth Log FIELD PRINT Scales 1:600 and 1:240 Annular Pressure W~ile Drilling MWD Directional bosse 16 SEC. 34, T10N, R2.1E, UM 146.791126 W 70.1751421 N 50-089-20027-00 Alaska Nabors 28E Wildcat Red Dog #1 CDR RANGE TOWNSHIP 1682' NS[., 4508' WEL List of set - XNAM, Set NAME MNEM TYPE NAME ORIG CNUM Name 6 lA lA PARAMETER COMPANY 0 0 2A 2A PARAMETER COMPANY 0 1 3A 3A PARAMETER DPRSS 0 0 4A 4A PARAMETER MATRIX 0 0 5A 5A PARAMETER TNRA_OFF 0 0 6~ 6A PARAMETER SSENS 0 0 7A 7A PARAMETER LSENS 0 0 8A 8A PARAMETER CDN_RPM 0 0 9A gA PARAMETER ADN_RPM 0 0 IOA 10A PARAMETER RT_BSAL 0 0 11A 11A PARAMETER DZCNT 0 0 12A 12A PARAMETER DZTMP 0 0 13A 13A PARAMETER DZDLS 0 0 14A 14A PARAMETER DZTIM 0 0 15A 15A PARAMETER DZSPP 0 0 16A 16A PARAMETER DZ-rFL 0 0 17A 17A PARAMETER Dz'rvD 0 0 18A 18A PARAMETER DZMDW 0 0 19A 19A PARAMETER DZHDR 0 0 2OA 20A PARAMETER TLLAB 0 0 ~ EDITED DATA - FROM DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline Cmnl: - 23 - Cmnt: Crnnt: * Schlumberger ' Schlumberger Data Services Cmnt: Cmnt: Company: BP Exploration (Alaska) Inc. Cmnt: Well: Red Dog #1 Cmnt: Field: Wildcat Cmnt County: North Slope Cmnt: State: Alaska Cmnt: Crnnt: Cmnt: Cmnt: This dala file contains primary Icg curves and is grouped into Crnnt: THREE logical files as follows: Grant: Crnnt: .............................................. Crrmt: PRIMARY DEPTH LOG: 1. PLATFORM EXPRESS - Array InductionJLithoDensity/Compensated Neutron and CMR - Combinable Magnetic Resonance (ALT, CNL, LDT, CMR) Recorded File Name Interval Top Interval Bottom PLAY_011 .dlis 15734.00(ft) 18727.O0(ft) 2. DSI/FMI ....... - Dipole Sonic NGT and Micro Imager Calipem/Devlations (no Images), 3 files spliced & depth matched Recorded File Names Interval Top IntervalBottom PLAY_063.dlis 14530.6250 15900.39~o5 PLAY_O62.dlis 15900.3965 16949.6582 PLAY_061 .dlis 16949.6582 18570.5000 Summary of shifts applied to SONIC/NGT data: Final Logged Depth Depth 18570.500 18578.500 17806.600 17814.820 17407.100 17413.09 17305.700 17311.449 16849.300 16855.691 14530.500 14537.000 3. LWD - CDR/CDN/RAB - tools run over selected intervals, --- curves depth matched to the PLATFORM EXPRESS Recorded File Names Interval Top Interval Bottom example Array (ft) (ft) DlisComposlnt,dlis 79.0000 17900.1309 PEF .RAB LWD_015.dlis 17900.1309 18850.4023 PEF ,CDR LWD_016.dlis 18850.4023 19400.5000 PEF .CDR Summary of shifts applied t.p LWD data: Final Logged Depth Depth ft 19400.500 19421.50000 17792.900 17813.98242 17693.700 17713.88672 17635.700 17653.87109 17471.600 17488.88672 17396.500 17413.36914 17325.700 17343.38867 17308.400 17324.34375 17296.400 17309.06250 17257.000 17277.61719 17233.100 17253.25586 17163.800 17175.96680 16995.000 17007.88281 16918.600 16930.37305 16842.000 16853.74805 16803.500 16817.42969 16784.900 16796.61133 15877.300 15894.84082 78.500 96.0OO00 Header Data from Primary Depth Control LOg: Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NS[-, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: FMI-DSI, RFT, Cores, Permanent Datum: Ground LevelElev: LOg Measured From: Rotary Tab 22.95 Drilling Measured From: Rotary Tab Elevation: K.B.: 34.45 D.F.: Date: 15-MAR- 1999 Run No: One Depth Driller: 18740.00 Depth Logger: 18740.00 BTM LOg Interval: 18740.00 Top LOg Interval: 14500.00 Casing Driller: 9.625 @ 0.00 Casing Logger: 0.00 Blt Size: 8.5 Type Fluid in Hole: ~ Water Mud 33.45 G.L: .009 .010 .015 . Rge: 21E 1(~.50 Above Perm Datum 10.50 - :2,4 - Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: 'Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Decl: 14.00 Visc: 66.00 9.00 Fluid Loss: 2.80 Mud Engineer 0.23 @ 60.00 0.14 @ 60.00 0.76 @ 60.00 Measured Rmc: Measured 0.07 @ 203.00 12:30 10:28 203.00 1805 Location: Kenai - Al Khedher Mellah/ Dani Jerry Siok. 0.000 Remarks: Crew: Mike Foust/T'roy Pabst/Greg Pearson REmarks from DSI Run: Remarks: DSI modes run from 18530 to 1688ft - Cress Dipole: BCR mode - Upper dipole - Lower Dipole - Compressional DSI data missing from 16970 to 16945 DSI medes from 16945 to 14500 - Upper dipole - Compressional Crew: Mike FoustfTroy Pabst/Greg Pearson LWD Header - taken from - CDR .017 field data ................. Schlumberger Data Services * Schlumberger * Measured Depth Log Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska Service Order #: Location: Sec: SEC. Twn: Rge: APl No: 50-089-20027- Sec: SEC. Twn: Other Services: MWD Direct, Annular Pr, Permanent Datum: ~Mean Sea Level Elev: 0.00 Log Measured From: Drill FIDo Drilling Measured From: Elevabon: K.B.: 0.00 D.F.: Date: 99 Run No: 16 Depth Driller: 0.00 Depth Logger: 0.00 BTM Log Interval: 0.00 Top Log Interval: 0.00 Casing Driller: 0.000 @ Casing Logger: Bit Size: 16. Type Fluid in Hole: Dens: 0.00 pH: 0.00 Source of Sample: Rm @ Meas Temp: 0.00 @ Rmf @ Me. as Temp: 0.00 @ Rmc @ Meas Temp: 0.00 @ Source: Rmf: Rm @ BHT: 0.(30 @ Time Circ. Stop: Logger on Bottom: Max Rec Temp: 0.00 Equip: Location: Recorded by: bosse Witnessed by: Magnetic Decl: 0.000 Rge: , 43.95 Above Perm Datum 43.95 G,L: 10.50 Visc: Fluid Loss: 0.00 0.00 0.00 Rmc: 0.00 List of set - FRAME, Set Name 67 NAME DESCRIPTION CHANNELS INDEX-TYPE I ........... [47,0,INDEX DIRECTION SPACING ENCRYPTED INDEX-MIN INDEX-MAX INDEX-STYLE BOREHOLE-DEPTH DECREASING -60.(.lIN) ........................... EXTERNAL-INDEX ATDN ATRD ATRU ATTN ATUP ~ DT GR VERD CRAT NPHI RTIM - 25 - ROP5 ROBU ROBR ROBE ROBB RHOB PSRU PSRD RP PEU PER PEL PEF PEB HORD DTAB DRHU DRHR DRHO DRHL DRHB DPOR DPHU DPHR DPHL DPHI DPHB DCAL BS DTTP DTRP DTC CHTP CHRP DTCU DT CHCU CHCO RING RBIT BSAV BMAV BDAV 1 0(IN) -999.25 .lIN 68 \1 300 List of set - CHANNEL, Set Name 68 NAME PROPERTIES REPRESENTATION-CODE UNITS DIMENSION AXIS ELEMENT-LIMIT SOURCE APl-CODES FILE-NUMBER SERVICE-ID SERVICE-ORDER-NUMBER OFFSET-IN-FRAME ARTIFICIAL-CHANNEL INDEX ................... 68 .lIN I .... I ...... 0 0 1 1 0 1 ATDN ................... 68 ~ DB I .... I ...... 0 3 1 1 CDR 0 RA ................... 68 OHMM I ........ ~;[~":1'" . ..... 0 3 1 1 CDR 4 ATRD ................... 68 OHMM I ........ ~ii":1'" . ..... 0 3 1 1 CDR 8 ATRU ................... 68 OHMM I ........ ~[i":1'" . ..... 0 3 1 1 CDR 12 ATI'N ................... 68 DB 1 ..... i;i~'"~ ...... . ..... 0 3 1 1 CDR 16 ATUP ................... 68 DB I ..... ~['"~ ..... . ..... 0 3 1 1 CDR 20 DT ................... 68 USE 1 .... ii;~'"~ ...... . ..... 0 3. 1 1 ISON 24 GR ................... 68 GAPI 1 ...... ~;ii'"~ .... . ..... 0 3 I I ' ADN 28 VERD ................... 68 IN I ..... ii~i":1' ..... . ..... 0 3 1 1 ADN 32 CRAT ................... 68 I ..... [::]":1 ...... . ..... 0 3 I 1 ADN 36 NPHI ................... 68 CFCF 1 ...... ~[":1 ..... . ..... 0 3 I 1 ADN 40 RTI M ................... 68 S I ..... .';:."'~ ...... . ..... 0 3 1 1 ADN 44 ROP5 ................... 68 F/HR I ...... .'::.'"~ ..... . ..... 0 3 I 1 ADN 48 ROBU ................... 68 G/C3 1 ...... ::::'"~ .... . ..... 0 3 I 1 ADN 52 ROBR ................... 68 G/C3 I ...... ::::'"~ .... . ..... 0 3 I 1 ADN 56 ROBE ................... 68 G/C3 1 ..... ;;'~:"~ ..... . ..... 0 3 i 1 ADN 60 ROBB ................... 68 G/C3 I ...... ~":1' .... . ..... 0 3 I 1 ADN 64 RHOB ................... 68 G/C3 I ...... ~iii'"~ .... . ..... 0 3 - 26 - ADN PSRU ................... 68 CDR PSRD ................... 68 CDR RP ................... 68 CDR PEU ................... 68 ADN PER ................... 68 ADN PEL ................... 68 ADN PEF ................... 68 ADN PEB ................... 68 ADN HORD ................... 68 ADN DTAB ................... 68 ADN DRHU ................... 68 ADN DRHR ................... 68 ADN DRHO ................... 68 ADN DRHL ................... 68 ADN DRHB ................... 68 ADN DPOR ................... 68 ADN DPHU ................... 68 ADN DPHR ................... 68 ADN DPHL ................... 68 ADN DPHI ................... 68 ADN DPHB ................... 68 ADN DCAL ................... 68 ADN BS ................... 68 ADN D'I-rP ................... 68 ISON DTRP ................... 68 ISON DTC ................... 68 ISON CHTP ................... 68 ISON CHRP ................... 68 ISON DTCU ................... 68 ISON DT ................... 68 ISON CHCU ................... 68 ISON CHCO ................... 68 ISON RING ................... 68 FlAB RBIT ................... 68 RAB BSAV ................... 68 RAB 68 OHMM 1 ......... ;;;;":1" 72 OHMM I ......... ~:"i" 76 OHMM 1 ........ ~'"~'" 80 ~ ..... .'ili"i ...... 8. 1 88 .... ::"'i ...... 1 92 .... ::'"i ...... 1 ..... :2"~ ...... 1 lOO IN 1 ...... .':.':":1 ..... 104 S 1 ..... ::::":1' ..... 108 G/C3 I ...... ::::'"~ .... 112 G/C3 I ...... ::::'"~ .... 116 G/C3 I ...... ::::'"'~ .... 120 G/C3 1 ...... ::::":1 ..... 124 G/C3 1 ...... ::::":1' .... 128 CfCf I ....... 132 CFCF I ....... 136 CFCF 1 ....... 140 CFCF 1 ....... .'.'-.': "i .... 144 CFCF 1 ...... ;~.'~"i ..... 148 OFOF 1 ....... ::::":1'"' 152 156 IN I .... ::::"i ....... 160 us~ I ..... ::::"~' ..... us~= ~ ...... ::'"i .... us~f ~ ...... ::::"i ..... 1 176 ...... ::...~ .... 1 18o usfF ~ ...... ::'"~ .... US/F 1 ..... :::7"~ ..... 188 I ....... :.':."'~1 .... 192 ....... ::::-.~ .... 1 196 OHMM I ........... 2OO OHMM 1 ......... ::::'"~' 220 OHMM I .......... 240 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 5 5 5 3 3 3 3 3 3 3 3 3 3 3 3 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 ...... 0 3 1 1 ...... 0 3 1 ...... O' 3 1 ...... 0 3 1 3 3 3 3 3 3 - 27 - BMAV ................... 68 ©HMM 1 .... 1 ...... 0 3 5 5 RAB 260 BDAV ................... 68 OHMM 1 .......... ~'"i ...... 0 3 5 5 RAB 280 .................. Contents of Data Frame at 19421.5 (ft), 5919.6732 (m) INDE 2E+06 ATDN 0.934269 RA 2.526181 ATRD 2.907966 ATRU 2.221261 A'I-I'N 1.055128 ATUP 1.175987 DT 90.42448 GR 128.5068 VERD 8.534904 CRAT 0.008648625 NPHI -O.03730891 RTIM 7519.359 ROP5 25.31507 ROBU 2.59867 ROBR 2.579932 ROBL 2.599056 ROBB 2.599864 RHOB 2.586143 PSRU 2.064128 PSRD 2.093223 RP 2.078599 PEU 14.26567 PER 7.076939 PEL 12.36854 PEF 9.509218 PEB 6.366978 HORD 8.549286 DTAB 23825.2 DRHU -0.02141804 DRHR 0.008219019 DRHO -0.005059613 DRHL -0.01938901 DRHB 0.01363687 DPOR 0.02966317 DPHU 0.031109 DPHR 0.04246581 DPHL 0.03087506 DPHI 0.0387014 DPHB 0.0303858 DCAL 0.1473608 BS 8.5 DTTP -999.25 CHCO 0.5289798 Contents of Data Frame at 19000. (ft), 5791.2 (m) INDE 2E+08 ATDN 0.5845147 RA 3.933783 ATRD 4.835443 ATRU 3.287401 A'I-I'N 0.7112855 ATUP 0.8380566 DT 78.00298 GR 79.98256 VERD 8.601145 CRAT 0.008413775 NPHI -0.03731181 RTIM 10976.31 ROP5 32.40,.'.'.'.'.'.'.'.~ ROBU 2.651581 ROBR 2.665431 ROBL 2.637445 ROBB 2.639722 RHOB 2.639112 PSRU 4.714748 PSRD 5.40293 RP 5.040348 PEU 15.55803 PER 8.01421 PEL 11.14165 PEF 9.432291 PEB 5.462248 HORD 8.602047 DTAB 20432.61 DRHU °0.0216748 DRHR -0.003537658 DPHU -0.0009581777 DPHR -0.009351695 DPHL 0.007609153 DPHI 0.006598814 DPHB 0.006228981 DCAL 0.3033124 BS 8.5 D'I-rP -999.25 CHCO 0,7525984 Contents of Data Frame at 18500. (ft), 5638.8 (m) INDE 2E+06 ATDN 0.7482656 RA 3.29846 ATRD 3.724051 ATRU 2.949405 ATTN 0.835506 ATUP 0.9227463 DT 87.60001 GR 110.9699 VERD 8.935101 CRAT 0.008580459 NPHI -0.03730974 RTIM 1916,547 ROP5 1501.466 ROBU 2.59955 ROBR 2.589243 ROBL 2.571208 ROBB 2.562309 RHOB 2.58153 PSRU 3.131825 PSRD 2.898695 RP 3.011847 PEU 23.61255 PER 10.07121 PEL 10.33676 PEF 11.70329 PEB 7.431723 HORD 8.601601 DTAB 3797.175 DRHU -0.04490617 DRHR -0.01062843 DRHO -0.02036288 DRHL -0.02379409 DRHB -0.003189793 DPOR 0.02249451 DPHU 0.03057565 DPHR 0.036822.21 DPHL 0.0477526 DPHI 0.04149719 DPHB 0.05314616 DCAL 0.1526903 BS 8.5 DTTP 87,88156 DTRP 86,63346 DTC 8725201 CHTP 0.8959125 CHRP -999.25 DTCU -999.25 DT -999.25 Contents of Data Frame at 18000. (ft), 5486.4 (m) INDE 2E+O6 ATDN 0.5671524 RA 4.295819 ATRD 4.987153 ATRU 3.755327 A'I-rN 0.6548388 ATUP 0.7425251 DT 85.08228 GR 103.6045 VERD 8.904778 CRAT 0.00817135 NPHI -0.03731483 RT1M 82.32918 ROP5 2088.398 ROBU 2.585071 ROBR 2.617513 ROBL 2.607971 ROBB 2.62242 RHOB 2.608884 PSRU 4.20183 PSRD 3.959614 RP 4.077976 PEU 29.95613 PER 12.26528 PEL 11.45678 PEF 11.97512 PEB 5.596094 HORD 8.771378 DTAB 5976.731 DRHU -0.08522472 DRHR -0.01038003 DRHO -0.03502763 DRHL -0.04202274 DRHB 0.01191039 DPOR -0.01447313 DPHU 0.0393513 DPHR 0.01968941 DPHL 0.02547223 DPHI 0.02491897 DPHB 0.01671532 DCAL 0.3805 BS 8.5 D'I-rP 85.4857 DTRP 84.68294 DTC 85.08434 CHTP 0.9020001 CHRP 0.89115 DTCU - -999.25 DT -999.25 Contents of Data Frame at 17500. (ft), 5334. (m) INDE 2E+O6 ATDN 0.7206845 RA 4.064861 ATRD 3.882082 ATRU 4.264171 AI-TN 0.6900785 ATUP 0.6594723 DT 84.59937 GR 110.828 VERD -999.25 CRAT -999.25 NPHI -999.25 RTIM 3221.299 ROP5 -999.25 RP 3.862123 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 DTTP 54.33905 DTRP 84.86951 DTC 64.60445 CHTP 0.8947842 CHRP 0.8942904 DTCU -999.25 DT -999.25 Contents of Data Frame at 17000. (fi), 5181.6 (m) INDE 2E-i-06 ATDN 0.3743771 RA 7.831402 ATRD 7.474705 ATRU 8.220869 ATTN 0.3559656 ATUP 0.3375535 DT 80.82301 GR 83.67896 VERD -99925 CRAT -999.25 NPHI -999.25 R'rlM 10459.79 ROP5 ;999.25 RP 7.646687 PEU -999.25 PER -909.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 DTTP 81.33255 DTRP 80.34145 DTC 80.83701 CHTP 0.8236879 CHRP 0.8631868' DTCU -999.25 DT -cj99.25 Contents of Data Frame at 16500. (ft), 5029.2 (m) INDE 2E+08 ATDN 0.5428647 RA 4.689917 ATRD 5.214597 ATRU 4.085198 A'I-rN 0.614746 ATUP 0.6866268 DT 82.64,397 GR 102.1882 VERD 8.668301 CRAT 21.35942 NPHI 0.3,.'.'.'.'.'.'.'.'.~591 RTIM 4461.593 ROP5 25.45726 ROBU 2.434657 ROBR 2.540306 ROBL 2.532345 ROBB 2.597128 RHOB 2.526851 PSRU 5.198548 PSRD 4.~ RP 4.852695 PEU 12.03696 PER 6.107804 PEL 6.97749 PEF 7.129299 PEB 4.405075 HORD 8.534628 DTAB 17610.95 DRHU 0.02243704 DRHR 0.0299845 DRHO 0.03590339 DRHL 0.O,.-':':':':':~1329 DRHB 0.007031059 DPOR 0.08169596 DPHU 0.1002077 DPHR 0.06648125 DPHL 0.07130587 DPHI 0.07536328 DPHB 0.03204343 DCAL 0.2114206 BS 8.5 DTTP 82.92487 DTRP 82.36467 DTC 82.64476 CHTP 0.9182311 CHRP 0.9194622 DTCU -999.25 4.893907 4.669078 4.956786 5.523922 5.732487 4.196355 3.857608 4.33325 4.56274 4.806927 8.179562 8.013399 8.23225 8.090673 7.668697 5.723572 5.437629 5.448646 5.542613 5.618848 6.759001 6.835032 6.865891 6.729961 6.487059 . Contents of Data Frame at 16000. (ft), 4876.8 (m) INDE 2E+06 ATDN 0.5841159 RA 4.284953 ATRD 4.8392 ATRU 3.832374 ATrN 0.6564221 ATUP 0.7287287 DT 81.22281 GR 107.7656 VERD 7.635224 CRAT 21.33726 NPHI 0.3392479 RTIM 8783.873 ROP5 83.95003 ROBU 2.577463 ROBR 2.577465 ROBL 2.577465 ROBB 2.577465 RHOB 2.577465 PSRU 5.427993 PSRD 4.724135 RP 5.057167 PEU 3.945199 PER 3.945199 PEL 3.945199 PEF 3.945188 PEB 3.945199 HORD 7.956877 DTAB 19258.64 DRHU -0.003698155 DRHR -0.003698155 DRHO -0.00369875 DRHL -0.003698155 DRHB -0.003698155 DPOR 0.04171922 DPHU 0.~ DPHR 0.04396068 DPHL 0.~ DPHI 0.043961 DPHB 0.04396068 DCAL 0. BS 8.5 DTTP 81.58937 DTRP 80.85228 DTC 81.22113 CHTP 0.8763019 CHRP 0.9293838 DTCU -999.25 DT -999.25 CHCU -999.25 CHCO -999.25 4.502067 4.429699 4.368298 4.293486 4.111542 4.283655 4.28521 4.287141 4.291432 4.295038 - 28 - 7.767058 7.785399 7.69031 7.717222 7.380802 5.108605 4.998694 4.986345 5.010312 4.973422 8.762798 8.950575 8.140903 8.031754 7.936917 Contents of Data Frame at 15500. (ft), 4724.4 (m) INDE 2E+06 ATDN 0.5033503 RA 4.844065 ATRD 5.597917 ATRU 4.251318 ATTN 0.5817945 ATUP 0.6602381 DT 87.7798 GR 119.0885 VERD -999.25 CRAT 0.01036483 NPHI -999.25 RTIM 1302.543 ROP5 94.31401 ROBU 1.559708 ROBR 2.048024 ROBL 2.004725 ROBB 2.536227 RHOB 1.877498 PSRU 5.565076 PSRD 4.367111 RP 4.910485 PEU 21.34815 PER 8.978022 PEL 11.39794 PEF 10.94688 PEB 3.854233 HORD -999.25 DTAB 13271.02 DRHU -0.01481227 DRHR 0.07594573 DRHO 0.03042826 DRHL 0.09103665 DRHB 0.022395 DPOR 0.3806722 DPHU 0.6607832 DPHR 0.3648342 DPHL 0.3910757 DPHI 0.468183 DPHB 0.06895369 DCAL 1.616622 BS 12.25 DTTP 92.60872 DTRP 82.91147 DTC 87.75961 CHTP 0.4619209 CHRP 0.8217521 DTCU -999.25 Contents of Data Frame at 15000. (fi), 4572. (m) INDE 2E+06 ATDN 0.4799324 RA 5.138319 ATRD 5.864159 ATRU 4.556684 A'FI'N 0.5487729 A'I'UP 0.6176131 DT 64.30057 GR 118.1159 VERD -999.25 CRAT 0.00961037 NPHI -999.25 RTIM 2268.113 ROP5 111.715 ROBU 1.549284 ROBR 2.05338 ROBL 1.995596 ROBB 2.566767 RHOB 1.878336 PSRU 6.003503 PSRD 4.583552 RP 5.22001 PEU 21.77005 PER 8.389484 PEL 10.87478 PEF 10.78347 PEB 4.063722 HORD -999.25 DTAB 19047.28 DRHU -0.02937949 DRHR 0.07683572 DRHO -0.001874648 DRHL 0.07760487 DRHB 0.02609245 DPOR 0.3562734 DPHU 0.6671008 DPHR 0.381588 DPHL 0.3966088 DPHI 0.4676753 DPHB 0.05044443 DCAL 1.589722 BS 12.25 DTI-P 85.25859 DTRP 83.35693 DTC 84.30774 CHTP 0.8903167 CHRP 0.8766042 C,(x~ents of Data Frame at 14500. (fi), 4419.6 (m) INDE 2E+06 ATDN 0.4741439 RA 5.231127 ATRD 5.93345 ATRU 4.662889 A'I-I'N 0.5390356 ATUP 0.6039274 DT 64.99556 GR 107.1006 VERD -999.25 CRAT 0.008873213 NPHI -999.25 RTIM 1154.677 ROP5 138.3119 ROBU 1.480349 ROBR 2.08961 ROBL 1.927588 ROBB 2.538838 RHOB 1.830353 PSRU 6.424513 PSRD 4.682063 RP 5.447483 PEU 14.99263 PER 6.743587 PEL 8.470554 PEF 8.478674 PEB 3.46985 DPOR 0.4014227 DPHU 0.7088794 DPHR 0.3396303 DPHL 0.4378256 DPHI 0.4.967561 DPHB 0.06737077 DCAL 2.142823 BS 12.25 D'I-rP 84.41035 DTRP 85.59418 DTC 85.00273 CHTP 0.678 CHRP 0.9045938 DTCU -999.25 Contents of Data Frame at 14000. (fi), 4267.2 (m) INDE 2E+06 ATDN 0.5703264 RA 4.427627 ATRD 4.942841 ATRU 3.998922 ATrN 0.6350057 ATUP 0.6996851 DT 87.66431 GR 125.6701 VERD -999.25 CRAT 0.008153256 NPHI -999.25 RTIM 2559.267 ROP5 81.80292 ROBU 1.409414 ROBR 2.058708 ROBL 1.68243 ROBB 2.535164 RHOB 1.774741 PSRU 5.234054 PSRD 3.996234 RP 4.551396 PEU 10.31881 PER 5.710423 PEL 6.536422 PEF 6.786989 PEB 3.449341 DPOR 0.4235532 DPHU 0.7518704 DPHR 0.3583589 DPHL 0.4651943 DPHI 0.5304604 DPHB 0.0695979 DCAL 2.458748 BS 12.25 D'I-rP 87.67558 DTRP 87.61925 DTC 87.64789 CHTP 0.7901875 CHRP 0.8826251 DTCU -999.25 Contents of Data Frame at 13500. (ft), 4114.8 (m) INDE 2E+06 ATDN 0.456657 RA 5.277998 ATRD 6.151891 ATRU 4.601211 ATTN 0.534233 ATUP 0.6118089 DT 85.24944 GR 124.3178 VERD -999.25 CRAT 0.007450407 NPHI -999.25 RTIM 3708.251 ROP5 166.7762 ROBU 1.397805 ROBR 2.082077 ROBL 1.782494 ROBB 2.487648 RHOB 1.750275 PSRU 5.929855 PSRD 4.442763 RP 5.104057 PEU 8.732948 PER 4.451422 PEL 6.124937 PEF 5.910936 PEB 3.382605 DPOR 0.4682738 DPHU 0.7589062 DPHR 0.344196 DPHL 0.5257615 DPHI 0.5452877 DPHB 0.1105193 DCAL 2.468852 BS 12.25 D'I-I'P 86.40907 DTRP 84.03683 DTC 85.22296 CHTP 0.4751875 CHRP 0.9318875 DTCU -999.25 Contents of Data Frame at 13000. (fi), 3962.4 (m) INDE 2E+O6 ATDN 0.3737678 RA 6.263947 ATRD 7.416843 ATRU 5.396163 ATrN 0.4481092 ATUP 0.5224507 DT 86.25922 GR 115.0598 VERD -99925 CRAT 0.00676457 NPHI -999.25 RTIM 16918.72 ROP5 165.2552 ROBU 1.366927 ROBR 2.112283 ROBL 1.814103 ROBB 2.514 RHOB 1.737281 PSRU 7.226352 PSRD 5.156802 RP 6.057048 PEU 5.154579 PER 3.597899 PEL 4.180693 PEF 4.332746 PEB 3.296703 HORD -999.25 DTAB 30851.33 DRHU 0.03040047 DRHR 0.05849919 DRHO -0.0002265532 DRHL 0.1219782 DRHB 0.0162752 DPOR 0.4265776 DPHU 0.7776198 DPHR 0.3258893 DPHL 0.5066043 DPHI 0.5531631 DPHB 0.08242415 DCAL 2.669871 BS 12.25 D'I-rP 87.10124 DTRP 85.32172 DTC 86.21098 CHTP 0.890075 CHRP 0.8937376 DTCU -999.25 Contents ot Data Frame at 12500. (ft), 3810. (m) INDE 2E.,,-06 ATDN 0.5330356 RA 4.750286 ATRD 5.289797 ATRU 4.299962 A'I-FN 0.5930685 ATUP 0.653101 DT 89.38411 GR 105.7914 VERD -999.25 CRAT 0.006095652 NPHI -999.25 RTIM 931.5084 ROP5 174.9308 ROBU 1.423018 ROBR 2.022852 ROBL 1.842016 ROBB 2.537102 RHOB 1.747615 PSRU 5.501574 PSRD 4.130599 RP 4.74101 PEU 4.011091 PER 3.636334 PEL 3.887571 PEF 3.94904 PEB 3.276425 DPOR 0.4308458 DPHU 0.7436256 DPHR 0.3800896 DPHL 0.4896875 DPHI 0.5468999 DPHB 0.06842315 DCAL 2.789998 BS 12.2.5 DT'I'P 87,02515 DTRP 91.72975 DTC 89.37746 CHTP 0.4841125 CHRP 0.9181875 DTCU -999.25 Contents of Data Frame at 12000. (ft), 3657.6 (m) INDE 1E+06 ATDN 0.5386124 RA 4.663479 ATRD 5.235228 ATRU 4.192303 A'I-rN 0.6038529 ATUP 0.689094 DT 90.15837 GR 109.6421 VERD -999.25 CRAT 0.005443559 NPHI -999.25 RT1M 947.344 ROP5 151.3991 ROBU 1.457278 ROBR 2.(K)0391 ROBL 1.88221 ROBB 2.500152 RHOB 1.774428 PSRU 5.194762 PSRD 4.029856 RP 4.555834 PEU 4.472538 PER 3.677712 PEL 3.944588 PEF 4.062304 PEB 3.211473 DPOR 0.4238022 DPHU 0.7228621 DPHR 0.3937026 DPHL 0.46,53274 DPHI 0.5306495 DPHB 0.09081702 DCAL 2.527761 BS 12.25 DTTP 90.02777 DTRP 90.30466 DTC 90.16669 CHTP 0.5741125 CHRP 0.8938625 DTCU -999.25 Co~ents of Data Frame at 11500. (ft), 3505.2 (m) INDE 1E+06 ATDN 0.6280928 RA 4.042567 ATRD 4.478154 ATRU 3.675179 A'FI'N 0.6925582 ATUP 0.7570231 DT 95.10699 GR 130.6838 VERD -999.25 CRAT 0.004808201 NPHI -999.25 RTIM 866.0393 ROP5 191.7153 ROBU 1.472068 ROBR 1.966316 ROBL 1.894543 ROBB 2.515037 RHOB 1.772561 PSRU 4.800723 PSRD 3.593142 RP 4.130402 PEU 4.88098 PER 3.754988 PEL 4.051942 PEF 4.145184 PEB 2.657363 DRHB 0.006681965 DPOR 0.4224938 DPHU 0.7138983 DPHR 0.4143542 DPHL 0.4578526 DPHI 0.5317811 DPHB 0.08179589 DCAL 2.689366 BS 12.25 DTrP 97.29077 DTRP 92.86012 DTC 95.07547 CHTP 0.461225 CHRP 0.8790001 DTCU -999.25 DT -999.25 CHCU -999.25 CHCO -999.25 - 29 - Contents of Data Frame at 11000. (ft), 3352.8 (m) INDE 1E+06 ATDN 0.9893215 RA 2.490593 ATRD 2.726357 ATRU 2.287014 A'I-I'N 1.069511 ATUP 1.1497 DT 92.95378 GR 126.3268 VERD -999.25 CRAT 0.004189489 NPHI -999.25 RT1M 2106.022 ROP5 176.545 ROBU 1.439454 ROBR 2.09464 ROBL 1.864425 ROBB 2.51237 RHOB 1.774372 PSRU 4.438288 PSRD 3.238335 RP 3.766608 PEU 4.702431 PER 3.657207 PEL 3.840658 PEF 4.350353 PEB 4.200749 DPOR 0.4080182 DPHU 0.7~ DPHR 0.336582 DPHL 0.4761062 DPHI 0.5306838 DPHB 0.08341248 DCAL 2.481(:~;3 BS 12.25 D'I-I'P 92.06883 DTRP 93.82729 DTC 92.94806 CHTP 0.6181855 CHRP 0.9318937 DTCU -999.25 Contents of Data Frame at 10500. (ft), 3200.4 (m) INDE 1E+06 ATDN 0.5094657 RA 4.679541 ATRD 5.531897 ATRU 4.032472 A~-rN 0.6018311 ATUP 0.6941971 DT 92.6479 GR 114.5413 VERD -999.25 CRAT 0.003587338 NPHI -999.25 RTIM 1740.969 ROP5 209.4809 ROBU 1.449834 ROBR 2.107966 ROBL 1.906461 ROBB 2.477228 RHOB 1.794541 PSRU 5.166741 PSRD 4.110115 RP 4.592232 PEU 6.060488 PER 3.439058 PEL 4.547532 PEF 4.633795 PEB 3.41455 DPOR 0.4038591 DPHU 0.7273731 DPHR 0,3285053 DPHL 0.4506301 DPHI 0.5184599 DPHB 0.1047104 DCAL 2.2335~1 BS 12.25 DTTP 91.62839 DTRP 93.6571 DTC 92.64278 CHTP 0.4899292 CHRP 0.9360354 DTCU -999.25 Contents of Data Frame at 10000. (ft), 3048. (m) INDE 1E+06 ATDN 0.5180501 RA 4.631144 ATRD 5.441513 ATRU 4.009929 ATTN 0.6079606 ATUP 0.6978717 DT 93.174 GR 113.324 VERD -999.25 CRAT 0.003001659 NPHI -999.25 RTIM 20684.38 ROP5 189.5705 ROBU 1.361583 ROBR 2.192608 ROBL 1.865287 ROBB 2.52438 RHOB 1.780435 PSRU 5.274448 PSRD 4.1171 RP 4.640991 PEU 5.270479 PER 3.81698 PEL 4.195827 PEF 4.432937 PEB 3.433136 HORD -999.25 DTAB 29240.2 DRHU -0.00984074 DRHR 0.07357492 DRHO -0.01145153 DRHL 0.06530175 DRHB 0.04580756 DPOR 0.4041579 DPHU 0.7808586 DPHR 0.277207 DPHL 0.4755837 DPHI 0.5270094 DPHB 0.07613361 DCAL 2.147547 BS 12.25 DTTP 91.53517 DTRP 94.80347 DTC 93:16931 CHTP 0.5116105 CHRP 0.942 DTCU -999.25 DT -999.25 CHCU -999.25 CHCO -9992.5 Contents of Data Frame at 9500. (ft), 2895.6 (m) INDE 1E+06 ATDN 0.6062654 RA 4.119971 ATRD 4.6d4dd5 ATRU 3.689891 A~-rN 0.6892442 ATUP 0.7542229 DT 94.11438 GR 106.8013 VERD -999.25 Gl:CAT 0.00243237 NPHI -999.25 RTIM 2043.519 ROP5 204.5312 ROBU 1.43347 ROBR 2.001192 ROBL 1.87607 ROBB 2.485673 RHOB 1.758601 PSRU 4.544658 PSRD 3.593754 RP 4.026742 PEU 5.572018 PER 3.77215 PEL 4.328568 PEF 4.422686 PEB 2.962111 HORD -999.25 DTAB 13916.77 DRHU 0.06074926 DRHR 0.0671252 DRHO 0.01769096 DRHL 0.09110464 DRHB 0.03004064 DPOR 0.4262536 DPHU 0.7372907 DPHR 0.3932174 DPHL 0.4690489 DPHI 0.540242 DPHB 0.09959212 DCAL 2.5343 BS 12.25 D']-I-P 93.93982 DTRP 94.27377 DTC 94.1068 CHTP 0.9619646 CHRP 0.9562833 DTCU -999.25 DT -999.25 Contents of Data Frame at 9000. (ft), 2748.2 (m) INDE 1E+O6 ATDN 0.6635294 RA 3.727824 ATRD 4.229218 ATRU 3.320241 ATTN 0.7471129 ATUP 0.8306959 DT 102.791 GR 109.9788 VERD -999.25 CRAT 0.001879388 NPHI -999.25 RTIM 1404.666 ROP5 -999.25 ROBU 1.415497 ROBR 2.182296 ROBL 1.927521 ROBB 2.435741 RHOB 1.828734 PSRU 4.199613 PSRD 3.18,3938 RP 3.638491 PEU 6.102117 PER 3.101985 PEL 4.044262 PEF 4.202311 PEB 2.986042 HORD -999.25 DTAB 9499.062 DRHU -0.01000146 DRHR 0.04933078 DRHO -0.01659541 DRHI_ 0.0L~)19903 DRHB 0.02619566 DPOR 0.3761221 DPHU 0.7481835 DPHR 0.2834569 DPHL 0.4378659 DPHI 0.497737 DPHB 0.1298541 DCAL 1.797125 BS 12.25 DTTP 103.9528 DTRP 101.6028 DTC 102.7773 CHTP 0.6718937 CHRP 0.9011064 DTCU -999'.25 DT -999.25 CHCU -9992.5 CHCO -9992.5 Contents of Data Frame at 8500. (ft), 2590.8 (m) INDE 1E+06 ATDN 0.9104213 RA 2.571571 ATRD 2.997148 ATRU 2.237998 A'I'TN 1.040582 ATUP 1.170744 RP 2.54067 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 8000. (ft), 2438.4 (m) INDE 1E+06 ATDN 0.7738975 FCA, 3.101472 ATRD 3.588334 ATRU 2.716603 ATTN 0.8831471 ATUP 0.9923973 RP 3.466941 PEU -999.25 PER -999.25 PEL -9992.5 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 7500. (fl), 2286. (m) INDE 9E+05 ATDN 1.083418 RA 2.095368 Al'RD 2.507288 ATRU 1.784116 ATTN 1.236696 ATUP 1.409976 RP 1.752447 PEU -999.25 PER -999.25 PEL -9992.5 PEF -999.25- PEB -999.25 HORD -999.25 Contents ol' Data Frame at 7000. (ft), 2133.6 (m) INDE 8E+05 ATDN 0.7829708 FCA 2.973063 ATRD 3.543047 ATRU 2.542126 ATTN 0.9169461 ATUP 1.050921 RP 3.104515 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB '-999.25 HORD -999.25 Contents of Data Frame at 6500. (ft), 1981.2 (m) INDE 8E+O5 ATDN 1.400565 RA 1.654404 ATRD 1.799027 ATRU 1.527756 A'I-rN 1.497598 ATUP 1.59463 RP 1.698298 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 6(X)0. (ft), 1828.8 (m) INDE 7E+O5 ATDN 12.39515 RA 1.832253 A'I'RD 2.089612 ATRU 1.622913 ATTN 1.38(X:N9 ATUP 1.520582 RP 1.666303 PEU -999.25 PER -999.25 PEL -999.25 'PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 5500. (ft), 1676.4 (m) INDE 7E+05 ATDN 1.019407 RA 2.224264 ATRD 2.633673 ATRU 1.919287 ATTN 1.176788 ATUP 1.334169 RP 2.126688 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 - 30 - Contents of Data Frame at 5000. (ft), 1524. (m) INDE 6E+05 ATDN 1.676785 RA 1.339863 ATRD 1.432326 ATRU 1.256825 ATTN 1.765265 ATUP 1.853745 RP 1.233868 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 4500. (ft), 1371.6 (m) INDE 5E+05 ATDN 2.080137 RA 1.053945 ATRD 1.077597 ATRU 1.031109 ATTN 2.114568 ATUP 2.149 RP 1.053421 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 4000. (fi), 1219.2 (m) INDE 5E+05 ATDN 1.698468 RA 1.336136 ATRD 1.408737 ATRU 1,269362 Al-TN 1.769037 ATUP 1.839605 RP 2.029637 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 3500. (ft), 1066.8 (m) INDE 4E+05 ATDN 0.9700605 RA 2.547925 ATRD 2.788558 ATRU 2.340008 AI-rN 1.048871 ATUP 1.12768 RP 2.360237 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 3000. (ft), 914.4 (m) INDE 4E+05 ATDN 1.830315 RA 1.271513 ATRD 1.277844 ATRU 1.265233 A'I-I'N 1.837243 ATUP 1.844171 RP 1.311592 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 contents of Data Frame at 2500. (ft), 762. (m) INDE 3E+05 ATDN 2.10455 RA 0.9785415 ATRD 1.060739 ATRU 0.9059952 A'i-I'N 2.233041 ATUP 2.361533 DT -999.25 GR 49.98756 VERD -999.25 CRAT -999.25 NPHI -999.25 RT1M 2344. ROP5 -999.25 RP 1.011162 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 2000. (ft), 609.6 (m) INDE 2E+05 ATDN 1.071551 RA 2.273151 ATRD 2.485034 ATRU 2.089567 A'FI'N 1.155543 ATUP 1.239535 RP 2.069043 PEU -999.25 PER -999.25 PEL -9992.5 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 1500. (fi), 457.2 (m) INDE 2E+05 ATDN -0.01575124 RA 102.2691 ATRD 72.44565 ATRU 252.6072 Contents of Data Frame at 1000. (ft), 304.8 (m) INDE 1E+05 ATDN 0.2899764 RA 10.02042 ATRD 9.272381 ATRU 10.88939 A'I-rN 0.2643555 ATUP 0.238735 RP 6.634171 PEU -999.25 PER -999.25 PEL -999.25 PEF -999.25 PEB -999.25 HORD -999.25 Contents of Data Frame at 500. (ft), 152.4 (m) INDE 6E+04 ATDN 0.003626793 FL& 119.715 ATRD 48.83704 ATRU 2000. CRAT -999.25 NPHI -999.25 RTIM 2410. ROP5 -999.25 ROBU -999.25 ROBR -999.25 ROBL -999.25 End of File SNAM .003 -1- Red Dog #1 LIS Tape Verification Listing The following information was extracted from the enclosed EDITED WELL LOG DATA TAPE Company: Well Name: Red Dog gl Field Name: Wildcat Borough: North Slope State: Alaska API Number: 50-089-20027 Date Logged: 15-MAR-1999 Top of Logged Interval: F F 14500.(F) Bottom of Logged Interval: F F 18740.(F) TAPE FORMAT: LIS RECE VF - Tape was created on: Tape was created by: Schlumberger - Geo.ques_t, Alaska Interpretation an:d Compubng Services (ICS) - Tue Apr 13 13:37:43 AKDT 1999 .-,rS ! 6 1999 Files Included on this Tape: Logical File Name: HILTD .001 START DEPTH STOP DEPTH INCREMENT 18727. 15734. -0.5 ft Logical File Name: DSS'F-B .002:..~'~:--~-~*-' ':-~,,',-' :-~' ::'- --:, , :'-- -?'.'" ..................................... START DEPTH STOP DEPTHINCREMENT' APR 16 1999 1857o.5 16612.5 -0.5 , ft Logical File Name: SNAM .003 START DEPTH STOP DEPTH INCREMENT 18328. 96. -0.5 ft Logical File Name: DSSTB .004 START DEPTH STOP DEPTH INCREMENT 15872.5 14530.5 -0.5 ft Schlumberger GeoQuest -2- LISTING of ALL PARAMETERS, COMMENTS and LOG CURVES for FILE: List of set - TOOL, Set Name 2 NAME MNEM STAT HEIG VOLU WEIG PRES TEMP ~--~--.~1-~.:~-~--~-~.~-~:~:i1~i--;~):i~:-~.)-~.~)~-(.~-~:~(Ps~) -50000.(D.E_G_F]_ AMS AMS DISA -50000.(IN) -50000.(F3} -50000.(LB) -50000.(.P_$1A) -50000.(..L)_~_(~._~_). CMRT CMRT DISA-50000.(IN)-50000.(F3)-50000.(LB)-50000.(PSIA)-50000.(.U~-L~-} List of set - OUTP, Set Name 4 NAME GR RHGX SP CFTC CNTC ECGR PXND NPHI NPHI CRAT GDEV MRES MTEM BS CS CVEL TENS KTIM KSDR KCMR TCMR CMFF CMRP BFV T2LM T12R LT2C ATRX ATRT ATD2 ATD1 AT90 AT60 AT30 AT20 ATIO AO90 AO60 AO30 AO20 AO10 AF90 AF60 AF30 AF20 AFl0 HMNO HMIN PEFZ RSOZ RXOZ RHOZ DPHZ HCAL MNEM TUNI PUNI DESC GR GAPI GAPI RHGX G/C3 C-JC3 SP MV MV CFTC CPS CPS CNTC CPS CPS ECGR GAPI GAPI PXND CFCF CFCF NPHI CFCF CFCF NPHI CFCF CFCF CRAT GDEV DEG DEG MRES OHMM OHMM MTEM DEGF DEGF BS IN IN CS F/HR' F/HR CVEL F/MN F/MN TENS LBF LBF KTIM MD MD KSDR MD MD KCMR MD MD TCMR CFCF CFCF CMFF CFCF CFCF CMRP CFCF CFCF BFV CFCF CFCF T2LM MS MS T12R LT2C MS MS ATRX OHMM OHMM ATRT OHMM OHMM ATD2 IN IN ATD1 IN IN ATgO OHMM OHMM AT60 OHMM OHMM AT30 OHMM OHMM AT20 OHMM OHMM AT10 OHMM OHMM AO90 OHMM OHMM AO60 OHMM OHMM AO30 OHMM OHMM AO20 OHMM OHMM AOIO OHMM OHMM AF90 OHMM OHMM AF60 OHMM OHMM AF30 OHMM OHMM AF20 OHMM OHMM AFIO OHMM OHMM HMNO OHMM OHMM HMIN OHMM OHMM PEFZ RSOZ IN IN RXOZ OHMM OHMM RHOZ G/C3 G/C3 DPHZ CFCF CFCF HCAL IN IN List of set - XNAM, Set Name 6 NAME MNEM TYPE NAME ORIG CNUM GR GR CHANNEL GR 0 0 RHGX RHGX CHANNEL RHGX_HILT 0 0 SP SP CHANNEL SP 0 0 CFTC CFTC CHANNEL CFTC 0 0 CNTC CNTC CHANNEL CNTC 0 0 ECGR ECGR CHANNEL ECGR 0 0 PXND PXND CHANNEL PXND_HILT 0 0 NPHI NPHI CHANNEL NPHI 0 0 NPHI NPHI CHANNEL TNPH 0 0 CRAT CRAT CHANNEL TNRA 0 0 MRES MRES CHANNEL MRES 0 0 MTEM MTEM CHANNEL MTEM 0 0 K'rIM K-rIM CHANNEL KTIM 0 0 KSDR KSDR CHANNEL KSDR 0 0 KCMR KCMR CHANNEL KCMR . 0 0 TCMR TCMR CHANNEL TCMR 0 0 CMFF CMFF CHANNEL CMFF 0 0 CMRP CMRP CHANNEL CMRP_3MS 0 0 BFV BFV CHANNEL BFV 0 0 T12R T12R CHANNEL T12R 0 0 LT2C LT2C CHANNEL LOG_T2CUTOFF 0 0 ATRX ATRX CHANNEL AHTFIX 0 0 ATRT A'I-FITCHANNEL AHTRT 0 0 ATD2 ATD2 CHANNEL AHTD2 0 0 ATD1 ATD1 CHANNEL AHTD1 0 0 ATgO AT90 CHANNEL AHT90 0 0 AT60 AT60 CHANNEL AHT60 0 0 AT30 AT30 CHANNEL AHT30 0 0 AT20 AT20 CHANNEL AHT20 0 0 AT10 AT10 CHANNEL AHT10 0 0 AO90 Aogo CHANNEL AHO90 0 0 HILTD .001 -3- ao60 AO60 CHANNEL AHO60 0 0 ao30 AO30 CHANNEL AHO30 0 0 AO20 AO20 CHANNEL AHO20 0 0 AOlO AO10 CHANNEL AHOIO 0 0 AF90 AF90 CHANNEL AHF90 0 0 AF60 AF60 CHANNEL AHF60 0 0 AF30 AF30 CHANNEL AHF30 0 0 AF20 AF20 CHANNEL AHF20 0 0 AFl0 AFl0 CHANNEL AHF10 0 0 List of set - CONS, Set Name 7 NAME MNEM STAT TUNI PUNI DESC VALU lA la ALLO PDAT PDAT ALLO EPD EPD ALLO LMF LMF ALLO APD APD ALLO EDF EDF ALLO EGL EGL ALLO EKB EKB ALLO 2A 2A ALLO LCP LCP ALLO MMDU MMDU ALLO TD 'rD ALLO E E ALLO TREF TREF ALLO DIFF DIFF ALLO HVCS HVCS ALLO IHVC IHVC ALLO FCD FCD ALLO CD CD ALLO AMD AMD ALLO STEM STEM ALLO TWS TWS ALLO RW RW ALLO BSAL BSAL ALLO MRT MRT ALLO MRT3 MRT3 ALLO MRT2 MRT2 ALLO MRT1 MRT1 ALLO RMFB RMFB ALLO RMB RMB ALLO MCST MCST ALLO RMCS RMCS ALLO MFST MFST ALLO RMFS RMFS ALLO MST MST ALLO RMS RMS ALLO DFPH DFPH ALLO DFL DFL ALLO DFV DFV ALLO DFD DFD ALLO CWEI CWEI ALLO CSIZ CSIZ ALLO BS BS ALLO MHD MHD ALLO CTOP CTOP ALLO FLEV FLEV ALLO CBLO CBLO ALLO CBDR CBDR ALLO BLI BU ALLO TLI TLI ALLO TDL TDL ALLO TDD TDD ALLO ELZ ELZ ALLO OPER OPER ALLO LCC LCC ALLO LUN LUN ALLO PVER PVER ALLO SON SON ALLO CJT CJT ALLO CASN CASN ALLO HIDE HIDE ALLO HID1 HID1 ALLO HID2 HID2 ALLO HLD HLD ALLO R16 R16 ALLO R3 R3 ALLO R2 R2 ALLO R1 R1 ALLO OS5 OS5 ALLO OS4 OS4 ALLO OS3 OS3 ALLO OS2 OS2 ALLO OS1 OS1 ALLO MCSS MCSS ALLO MFSS MFSS ALLO MSS MSS ALLO TCS TCS ALLO DCS DCS ALLO DFT DFT ALLO CASG CASG ALLO WITN WITN ALLO ENGI ENGI AIIO LUL LUL ALLO TLAB TI_AB ALLO DLAB DLAB ALLO RUN RUN ALLO DATE DATE ALLO CONT CONT ALLO NATI NATI ALLO RANG RANG ALLO TOWN TOWN ALLO SECT SECT ALLO BP Exploration (Alaska) Inc. Ground Level .lIN .lIN 1260.(.11N) Rotary Table .lIN .lIN 2754.(.11N) .lIN .lIN 4014.(.11N) .lIN .lIN 1260.(.11N) .lIN .lIN 4134.(.11N) BP Exploration (Alaska) Inc. ALLOW F F 18740.(F) LB-1 LB-1 9.63E-07(LB-1) LBF LBF 1000.(LBF) F F 1 .(F) HCAL START IN IN 7.(IN) F F 15852.(F} DEG DEG 352.5(DEG) DEGF DEGF -40.(DEGF) DEGF DEGF 100.(DEGF) OHMM OHMM 1.(OHMM) PPM PPM 33000.(PPM) DEGF DEGF 203.(DEGF) DEGF DEGF 203.(DEGF) DEGF DEGF 203.(DEGF) DEGF DEGF 203.(DEGF) OHMM OHMM 0.04519875(OHMM) OHMM OHMM 0.07480074(OHMM) DEGF DEGF 60.(DEGF) OHMM OHMM 0.76(OHMM) DEGF DEGF 60.(DEGF) OHMM OHMM 0.142(OHMM) DEGF DEGF 60.(DEGF) OHMM OHMM 0.235(OHMM) 9. C3 C3 2.8(C3) S S 66.(S) LB/G LB/G 14.(LB/G) LB/F LB/F 67.(LB/F) IN IN 9.625(IN) IN ~.~IN ~_ 8.5(IN) -.- DEG :IDEG ':' .... 64.15001(DEGi?-~''-'' ;:~;:------'~',,.:~---: 7,_A.,;.~ ........ >~..;_v F F F F F F F F' F F F F F F F F 0.(F) 15850.(F) 15852.(F) 18740.(F) 14500.(F) 18740.(F) 18740.(F) 33.45(F) -999 1805 801-205 6109824 Primary Platform Express Combinable Magnetic resonance tool PEX-CMRT INCLUDE Crew;. Mike Foust/Troy Pabst/Greg Pearson Cores RFT FMI-DSI Measured Measured Mud Engineer 12:30 15-MAR-1999 Fresh Water Mud Jerry Siok. Khedher Mellah/ Daniel Palmer Kenai - Alaska 10:28 15-MAR-1999 One 15-MAR-1999 21E 10N 21 t -4- LONG LONG LATI LATI APIN APIN DMF DMF FL2 FL2 FL1 FL1 FL FL STAT STAT COUN COUN FN FN WN WN CN1 CN1 RLAB RI_AB 3A 3A LLAB LLAB CLAB CLAB SLAB SLAB 4A 4A DO DO LQMS LQMS PP PP SPEE SPEE ENVI ENVI VHOL VHOL VCEM VCEM 5A 5A MPOI MPOI OFFS OFFS DCON DCON GAIN GAIN EUCF EUCF SHIF SHIF 6A 6A 7A 7A 8A 8A 9A 9A 10A 10A 11A 11A 12A 12A 13A 13A 14A 14A 15A 15A 16A 16A 17A 17A 18A 18A 19A 19A 20A 20A 21A 21A 22A 22A 23A 23A 24A 24A 25A 25A 26A 26A 27A 27A 28A 28A 29A 29A 30A 30A 31A ;~1.~ 32A 32A 33A 33A 34A 34A 35A 35A 36A 36A 37A ' 37A 38A 38A 39A 39A 40A 40A 41A 41A 42A 42A 43A 43A 44A 44A 45A 45A 46A 46A 47A 47A 48A 48A ORDU ORDU UNAL List of set - XNAM, Set NAME MNEM TYPE NAME ORIG CNUM lA lA PARAMETER 2A 2A PARAMETER 3A 3A PARAMETER 4A 4A PARAMETER 5A 5A PARAMETER 6A 6A PARAMETER 7A 7A PARAMETER 8A 8A PARAMETER 9A 9A PARAMETER 10A 10A PARAMETER 11A 11A PARAMETER 12A 12A PARAMETER 13A 13A PARAMETER 14A 14A PARAMETER 15A 15A PARAMETER 16A 16A PARAMETER 17A 17A PARAMETER 18A 18A PARAMETER 19A 19A PARAMETER 20A 20A PARAMETER 21A 21A PARAMETER 22A 22A PARAMETER 23A 23A PARAMETER 24A 24A PARAMETER ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO AM_O F F ALLO ALLO ALLO F/HR F/HR ALLO ALLO F3 F3 ALLO F3 F3 ALLO ALLO IN IN ALLO GAPI GAPI ALLO ALLO ALLO ALLO ALLO F F ALLO IN IN ALLO MV MV ALLO ALLO ALLO ALLO ALLO F F Al_LO IN IN ALLO CPS CPS ALLO ~LLO ALLO ~LLO ALLO F F ~,LLO IN IN ALLO CPS CPS ~,LLO ALLO ~,LLO ALLO ~,LLO F F ALLO IN IN ~LLO ALLO ALLO .. · .... ALLO ALLO ALLO F F ALLO IN IN ALLO IN IN ALLO ALLO ALLO ALLO ALLO F F ALLO IN IN ALLO DEGF DEGF ALLO ALLO ALLO ALLO ALLO F F FEET Name 8 50-089-20027 Rotary Table Total depth: 3671' NSL, 1058' WEL Surface: 1682' NSL, 4508' WEL Alaska North Slope Wildcat Red Dog #1 RANGE TOWNSHIP SECTION BOROUGH: STATE: NO 0F) N~NE RECOMPUTE 1800(F/HR) FTB_TELEMETRY 7.142033(F3) 2.99977(F3) MEASURED_DEPTH 104.(IN) 0.(GAPI) 3. 1.063993 0.36 0. 8.666668(F) 1.(IN) 0.(MV) 0. 1. 0.0625 0. 0.08333334(F) 34.(IN) -29.92664(CPS) 3. 1.150804 1. 0. 2.833333(F) 28.(IN) -28.30965(CPS) 5. 1.074279 1. 0. 2.333333(F) 2e.(IN) 0. 3. .... 0.9652077 .... 0. 2.333333(F) ~ -71 .(IN) 0.3448029(IN) 0. 0.955115 0.000377 2. .5.916667(F) 70.(IN) 1.52589E-O6(DEGF) 9. 1. 1. 0. .63.44667(F) COMPANY 0 0 COMPANY 0 1 TLLAB 0 0 FLSHSTRM 0 0 LOGMODE 0 0 TOOL_STRING_MEASURE_POINT_OFFSET 0 0 MPOI 0 1 OFFS 0 1 DCON 0 1 GAIN 0 1 EUCF 0 1 SHIF 0 1 TOOL_STRING_MEASURE_POINT_OFFSET 0 1 MPOI 0 2 OFFS 0 2 DCON 0 2 GAIN 0 2 EUCF 0 2 SHIF 0 2 TOOL_STRING_MEASURE_POINT_OFFSET 0 2 MPOI 0 3 OFFS 0 3 DCON 0 3 GAIN 0 3 -5- 25A 26A 27A 28A 29A 30A 31A 32A 33A 34A 35A 36A 37A 38A 39A 40A 41A 42A 43A 44A 45A 46A 47A 48A Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: 25A 26A 27A 28A 29A 30A 31A 32A 33A 34A 35A 36A 37A 38A 39A 40A 41A 42A 43A 44A 45A 46A 47A 48A PARAMETER EUCF 0 3 PARAMETER SHIF 0 3 PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 3 PARAMETER MPOI 0 4 PARAMETER OFFS 0 4 PARAMETER DCON 0 4 PARAMETER GAIN 0 4 PARAMETER EUCF 0 4 PARAMETER SHIF 0 4 PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 4 PARAMETER MPOI 0 5 PARAMETER OFFS 0 5 PARAMETER DCON 0 5 PARAMETER GAIN 0 5 PARAMETER EUCF 0 5 PARAMETER SHIF 0 5 PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 5 PARAMETER MPOI 0 6 PARAMETER OFFS 0 6 PARAMETER DCON 0 6 PARAMETER GAIN 0 6 PARAMETER EUCF 0 6 PARAMETER SHIF 0 6 PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 6 * Schlumberger * Schlumberger Data Services Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska EDITED DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline This data file contains primary log curves and is grouped into 4 logical files as follows: 1. PLATFORM EXPRESS - Array Induction/LithoDensity/Compensated Neutron and CMR - Combinable Magnetic Resonance 2. DSI/FMI - Dipole Sonic and Micro Imager Calipers/Deviations (no Images) 3. LWD - CDPJCDN/RAB - tools run over selected intervals, curves depth matched to the PLATFORM EXPRESS 4. DSI - Sonic data from cased hole section (14,530 - 15,872 ft) Summary of shifts applied to LWD data: Final Logged Depth Depth ft ft 18308.900 18328.00000 18183.300 18202.36914 18087.400 18107.80664 18054.900 18076.13867 17794.700 17815.92773 17695.500 17714.27930 17476.700 17493.26758 17328.900 17345.99609 17294.400 17307.46289 17264.900 17278.45117 17228.200 17248.99805 17164.400 17176.35938 17099.700 17112.58008 17006.700 17019.56836 16976.200 16990.77930 16920.100 16931.42969 16863.400 16877.39453 16844.200 16855.69141 16820.300 16830.44531 16805.000 16818.70703 16782.800 16795.45508 15850.500 15867.99414 78.900 96.50000 PRIMARY DEPTH LOG: Primary Resistivity, Neutron, Density and Mag. Resonance (ALT, CNL, LDT, CMR) curves were taken from - HILTD .011 field data File Information: DLIS data File Name Start Stop Sample Index Tool String HILTD .011 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) File name : HILTD .011 Company: Well: Field: 15734.00(ft) -60.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.08(ft) -10.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.01(ft) -1.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.02(ft) -2.0010'1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.17(ft) -20.00 0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.04(ft) -5.00 0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.25(ft} -30.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/'DTCA 15735.00(ft) -120.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.50(ft) -180.00 (0.1 in) TDEP HIL'rD/CMRT/AMS/DTAA/DTCA BP Exploration (Alaska) Inc. Red Dog #1 Wildcat -6- Cmnt: Omni: Omnt: Omnt: Omnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnt: Cmnh Cmnh Cmnt: Cmnl: Cmnt: Cmnf: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Omni: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: County: North Slope State: Alaska Service Order #: 610982 Location: Sudace: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: FMI-DSI, RF-~, Cores, Permanent Datum: Ground LevelElev: Log Measured From: RotaP/ Tab 22.95 Drilling Measured From: Rotary Tab Elevabon: K.B.: 34.45 D.F.: Date: 15-MAR- 1999 Run No: One Depth Driller: 18740.00 Depth Logger: 18740.00 BTM Log Interval: 18740.00 Top Log Interval: 14500.00 Casing Driller: 9.625 @ 0.00 Casing Logger: 0.00 Bit Size: 8.5 Type Fluid in Hole: Fresh Water Mud Dens: 14.00 pH: 9.00 Source of Sample: Mud Engineer Rm @ Meas Temp: 0.23 @ Rmf @ Meas Temp: 0.14 @ Rmc @ Meas Temp: 0.76 @ Source: Rmf: Measured Rm @ BHT: 0.07 @ Time Circ. Stop: 12:30 Logger on Bottom: 10:28 Max Rec Temp: 203.00 Equip: 1805 Location: Recorded by: Khedher Mellah/ Dani Witnessed by: Jerry Siok. Magnetic Decl: 0.000 33.45 G.L: Rge: 21E 1(~.50 Above Perm Datum 10.50 risc: Fluid Loss: Rmc: Measured 203.00 Kenai- N 66.00 2.80 Remarks: Crew: Mike Foust/Troy PabstJGreg Pearson SECOND/THIRD DESCENT RECORDED ON DEPTH WiTH PRIMARY: Primary Sonic, FMI CALIPER, NGT curves were taken from - FBSTA .061 field data ............. Schlumberger Data Services * S,c?lumberger ' Formation Micro-lmager Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska, .'.~: .~:-: -:' ' Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' Sec: 21 Twn: 10N Rge: 21E File Name Start FBSTA .061 1657o.5o(ft) 1857o.5o(ft) 1857o.5o(ft) Stop Sample Index Tool String 16913.01(ft) 0.1 in 'DDEP FBSTNDSSTB/NGTD/AMS/DTANDTCA 16913.12(ft) -15100 .1 in TDEP FBSTA/DSSTB/NGTD/AMS/DTANDTCA File name : FBSTA .061 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Rge: 21E Other Services: PEX-CMR, RFT, Cores, Permanent Datum: Ground LevelElev: 10.~0 Log Measured From: Rotary Tab 22.95 Above Perm Datum Drillin~ Measured From: Rotary Tab Elevahon: K.B.: 34.45 D.F.: 33.45 G.L: 10.50 Date: 15-MAR- 1999 Run No: One Depth Driller: 18740.00 Depth Logger: 18740.00 BTM Log Interval: 18740.00 Top Log Interval: 14500.00 Casing Driller: 9.625 @ 0.00 Casing Logger: 0.00 Bit Size: 8.5 Type Fluid in Hole: Fresh Water Mud Dens: 14.00 Visc: 66.00 pH: 9.00 Fluid Loss: 2.80 Source of Sample: Mud Engineer Rm @ Meas Temp: 0.23 @ 60.00 Rmf @ Meas Temp: 0.14 @ 60.00 Rmc @ Meas Temp: 0.76 @ 60.00 Source: Rmf: Measured Rmc: Measured Rm @ BHT: 0.07 @ 212.00 Time Cim. Stop: 12:30 Logger on Bottom: 10:28 -9- AMS TENS ................... 68 AMS KTIM ................... 68 CMR KSDR ................... 68 CMR KCMR ................... 68 CMR TCMR ................... 68 CMR CMFF ................... 68 CMR CMRP ................... 68 CMR BFV ................... 68 CMR T2LM ................... 68 CMR T12R ................... 68 CMR LT2C ................... 68 CMR ATRX ................... 68 AITH ATRT ................... 68 AITH ATD2 ................... 68 AITH ATD1 ................... 68 AITH AT90 ................... 68 AITH AT60 ................... 68 AITH AT30 ................... 68 AITH AT20 ................... 68 AITH AT10 ................... 68 AITH AO90 ................... 68 AITH AO60 ................... 68 AITH AO30 ................... 68 AITH AO20 ................... 68 AITH AO10 ................... 68 AITH AF90 ................... 68 AITH AF60 ................... 68 AITH AF30 ................... 68 AITH AF20 ................... 68 AITH AFl0 ................... 68 AITH HMNO ................... 68 MCFL HMIN ................... 68 MCFL PEFZ ................... 68 LDT RSOZ ................... 68 HILTD RXOZ ................... 68 LDT RHOZ ................... 68 60 64 MD 1 ....... '"'""""1'" 68 MD I ........ -'""'"'"1" 72 MD I ......... '"'-'"'"1' 76 CFCF I ......... 80 CFCF I ........ ~'"'[' 84 CFCF 1 ......... ::::":1" 88 CFCF 1 ........ .'.'.:'"~"' 92 MS I ........ :.::'"'[" 96 ...... ::::.-~ ..... 1 lOO MS 1 ....... '"'"'""1 104 OHMM 1 ....... ...._......1... 108 OHMM 1 ......... '"'-'""'1' 116 IN I ..... ...._......1 124 IN I ..... '"'--'"'1 132 OHMM I ........ 140 OHMM 1 ........ '"'"'"'"1" 148 OHMM I ........ 156 OHMM I ........ ~[~"'i" 164,-, .... OHMM 1 '"":'"~:::'"i" 172 OHMM 1 ......... '"'-'""'1' 180 OHMM 1 ......... '"'-'""'1' 188 OHMM I ......... ::::'"'i' 196 OHMM I ......... 204 OHMM I ......... '"'"'""'1' 212 OHMM 1 ......... '"'"'""1" 220 OHMM 1 ......... '"'-'"'"1" 228 OHMM 1 ......... '"'""'"1" 236 OHMM I ......... '"'"'""1" 244 OHMM I ......... '"'""'"1" 252 OHMM 1 ........... '"'-'""'1 260 OHMM I ........ '"'-'"'"1" 272 1 .... 1 284 IN I ............ '""'""1 296 .................. OHMM 1 .... 1 308 C-JC3 1 ......... ::::":[" ...... 0 1 1 1 ...... 0 1 1 1 ...... 0 1 1 1 ...... 0 1 1 1 ...... 0 1 I 1 ...... 0 1 1 1 ...... 0 1 I 1 ...... 0 1 1 1 ...... 0 1 I 1 ...... 0 1 1 1 ...... 0 1 1 1 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 .... T....:"~)" 1 ' 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 2 2 ...... 0 1 3 3 ...... 0 3 3 ...... 0 1 3 3 3 3 ...... 0 1 3 3 ...... 0 -10- 3 3 LDT 320 DPHZ ................... 68 CFCF I ......... :~":1' . ..... 0 1 3 3 LDT 332 HCAL ................... 68 IN 1 ..... '-""'"'"1 ..... . ..... 0 1 6 6 AMS 344 Contents of Data Frame at 18727. (fi), 5707.9896 (m) I NDE 2247240 GR 116.072 RHGX 4.337529 SP 0. CFTC 1117.91 CNTC 2964.222 ECGR 148.9254 PXND 302.6947 NPHI 0.2852551 NPHI 0.2892318 CRAT 2.697405 GDEV -999.25 MRES 11.95146 MTEM 203.1468 BS 8.5 CS 923.0769 CVEL -15.38462 TENS 2967. KTIM 1.902173E-08 KSDR 0.0001046098 KCMR 0.0001046098 TCMR 0.06455061 CMFF 2.1359E-05 CMRP 0.007143869 BFV 0.06452926 T2LM 1.227314 T12R 0. LT2C 1531.191 ATD2 ATD1 AT90 AT60 AT30 AT20 AT10 AO90 AO60 AO30 AO20 AO10 AF90 AF60 AF30 AF20 AFl0 Contents of Data Frame at 18500. (ft), 5638.8 (m) INDE 2220000 GR 93.71037 RHGX 2.972763 SP -97.125 CFTC 1005.837 CNTC 2716.697 ECGR 119.2586 PXND 0.1831091 NPHI 0.3008125 NPHI 0.2979711 CRAT 2.787926 GDEV 26.24241 MRES 11.95146 MTEM 203.5884 BS 8.5 CS 1245.816 CVEL -20.7636 TENS 2382. KTIM 2.622914E-08 KSDR 0.0001797396 KCMR 0.0001797396 TCMR 0.06075323 CMFF 2.664601E-05 CMRP 0.02095355 BFV 0.06072658 T2LM 1.816156 T12R 0. LT2C 1531.191 3.779116 3.871934 3.571272 3.630333 ATD2 9.067394 9.068033 ATD1 9.067394 9.068033 AT90 3.585745 3.649964 AT60 3.691506 3.758623 AT30 3.833784 3.945813 AT20 3.92241 4.083135 .- _. ,. ............... ~:, AT10 3.79933 3.923174 AO90 3.633428 3.66335 AO60 3.784308 3.816169 AO30 4.00163 4.123858 AO20 4.114121 4.267876 AO10 3.930574 4.198802 AF90 3.493867 3.516695 AF60 3.62747 3.651419 AF30 3.806401 3.83443 AF20 3.79841 3.823642 AFl0 3.720279 3.741137 1.068436 1.0921 1.075236 0.88258 0.9076117 0.8850433 5.68062 5.733896 5.742389 0,086189 0,08157463 0.07640658 4.723351 4.749903 4.794727 2.613257 2.614141 2.615563 0.0222683 0.02173294 0.02087073 8.95537 8.984177 9.007221 9.022585 9.030266 9.030266 Contents of Data Frame at 18000. (ft), 5486.4 (m) INDE 2160000 GR 92.01839 RHGX 2.952684 SP -28,375 CFTC 1129,555 CNTC 2917.529 ECGR 116.6097 PXND 0.1755331 NPHI 0.2759693 NPHI 0.2804734 CRAT 2.615518 GDEV 30.96033 MRES 11.95146 MTEM 195.9952 BS 8.5 CS 568.1479 CVEL -9.469133 TENS 2582. KTIM 0.0002629918 KSDR 0.001008932 KCMR 0.001008932 TCMR 0.08349337 CMFF 0.001898156 CMRP 0.02713555 BFV 0.08159521 T2LM 2.278227 T12R 0. LT2C 1531.191 4.646035 4.671931 4.519869 4.51108 ATD2 8.890717 8.897654 ATD1 8.890717 8.897654 AT90 4.518997 4.503795 AT60 4.685352 4.667828 AT30 4.798873 4,800644 AT20 4.873462 4.926938 AT10 4.637983 4.683489 AQ90 4.196873 4.494765 AO60 4.364964 4.685575 AO30 4.603234 4.759379 AO20 5.34289 5.118593 AO10 4.667269 4.752223 AF90 4.504013 4.493133 AF60 4.693168 4.680215 AF30 4.881099 4.865145 AF20 4.865614 4.857709 ^Fl0 4.661448 4.654703 2.452793 2.464005 2.343314 3.437192 3.451575 3.152857 4.967891 4.964791 4.959273 0.00307487 0.004017559 0.004017559 5.52665 5.602493 5.579799 2.612569 2.61306 2.613788 0.02268574 0.02238837 0.02194665 8.932325 8.933477 8.943848 8.933477 8.938087 8.947304 Contents of Data Frame at 17500. (ft), 5334. (m) INDE 2100000 GR 92.53748 RHGX 2.965149 SP -11.625 CFTC 1037.221 CNTC 2825.403 ECGR 117.5931 PXND 0.1884232 NPHI 0.2870612 NPHI 0.3017316 CRAT 2.693894 GDEV 33.9957 MRES 11.95146 MTEM 189.4467 BS 8.5 CS 514.6451 CVEL -8.577419 TENS 2232. KTIM 0.0001046119 KSDR 0.0004747419 KCMR 0.0004747419 TCMR 0.07357877 CMFF 0.0013643 CMRP 0.02303421 BFV 0.07221447 T2LM 2.012304 T12R 0. LT2O 1531.191 4.171172 4.23785 4.362373 4.440096 ATD2 8.917316 8.917032 ATD1 8.917316 8.917032 AT90 4.361787 4.355474 AT60 4.458581 4.450387 AT30 4.439835 4.492995 AT20 .-.. 4.664764 4.766816 .......... AT10 4.197925 4.285152 AO90 3.929941 4.265869 AO60 4.037308 4.390143 AO30 4.170312 4.661823 AO20 4.946226 5.221709 AOIO 4.210069 4.680017 AF90 4.23553 4.266223 AF60 4.365221 4.395141 AF30 4.519095 4.570189 AF20 4.457144 4.501543 AFl0 4.041379 4.083736 1.996223 2.055758 2.060089 2.666767 2,753423 2.708777 5.956558 5.808611 5.664029 0.001928642 0.00414646 0.00552286 3.420649 3.495166 3.65252 2.594529 2.596141 2.599019 0.03361905 0.03264167 0.03089803 8.998581 8,992819 8.995699 8.995699 8.992819 9.001461 Contents of Data Frame at 17000. (fi), 5181.6 (m) INDE 2040000 GR 68.37979 RHGX 2.83,.'.'.'.'.'.'.'.'.~359 SP -35,8125 CFTC 1381.633 CNTC 3532.28 ECGR 68.90848 PXND 0.1988722 NPHI 0.2576048 NPHI 0.2727919 CRAT 2.535063 GDEV 47.45858 MRES 10.92467 MTEM 183.7041 BS 8.5 CS 489.4698 CVEL -8.157831 TENS 2256. K-rIM 0.3877622 KSDR 0.02955186 KCMR 0.02955186 TCMR 0.1004048 CMFF 0.03771269 CMRP 0.06659399 BFV 0.06269209 T2LM 8.526165 T12R 0. LT2C 1531.191 6.077145 7,489515 8.320604 8.471678 ATD2 11.42457 9.737833 ATD1 11.391 9.737833 ATg0 8.323555 8.513885 ^T60 ].2- 8.514914 8.706839 AT30 9.460249 9.870256 AT20 14.88662 16.34412 AT10 7.28828 8.863661 AO90 7.832572 8.254734 AO60 7.974123 8.394604 AO30 10.14736 9.380793 AO20 7.578469 9.089542 AO10 5.931208 6.831628 AFg0 8.145124 8.185722 AF60 8.478292 8.515533 AF30 9.300949 9.471735 AF20 8.561131 8.822819 AFl0 5.856033 5.902076 1.185232 1.285223 1.265741 0.9249697 1.029285 1.021298 3.451005 3.426235 3.40293 0.09311257 0.08347677 0.07107301 6.604611 6.88321 7.546053 2.476954 2.474077 2.473134 0.1048764 0.1066201 0.1071917 9.565422 9.527014 9.488607 9.468122 9.447638 9.46044 Contents of Data Frame at 16500. (ft), 5029.2 (m) INDE 1980000 GR 94.13678 RHGX 2.928667 SP -57.75 CFTC 961.5437 CNTC 2596.143 ECGR 127.1231 PXND 0.1892675 NPHI 0.2787807 NPHI 0.2891159 CRAT 2.742392 GDEV 60.49617 MRES 11.95146 MTEM 178.2434 BS 8.5 CS 1739.488 CVEL -28.99147 TENS 1929. KTIM -999,25 KSDR -999.25 KCMR -999.25 4.683305 4.600464 5.02903 4.968843 ATD2 10.27726 10.24824 ATD1 10.27726 10.24824 ATgO 5.045547 4.953705 AT60 5.253596 5.155241 AT30 5.464759 5.318353 AT20 5.175696 5.310308 AT10 ..... .~ . . ' 4.647503 4.539542 ' -! ' ao90 '" 4.619102 3.797227 AO60 4.786683 3.91306 AO30 5.310228 4.59016 AO20 4.127743 7.362836 AO10 3.983877 4.212607 AF90 5.040645 5.035149 AF60 5.278598 5.274561 AF30 5.490019 5.482689 AF20 5.369139 5.327386 AFl0 4.737209 4.698578 0.9526006 0.8251871 0.8128083 0.7318228 0.5993181 0.5850134 4.747403 4.827458 4.898488 0.1341571 0.1438226 0.155858 4.823261 4.929312 4.948359 2.575283 2.571594 2.5678 0.04528349 0.0475187 0.04981821 10.21478 10.27247 10.2747 10.27051 10.26938 10.2692 Contents of Data Frame at 16000. (ft), 4876.8 (m) INDE 1920000 GR 87.35757 RHGX 2,972631 SP -34.5625 CFTC 849.4329 CNTC 2528.521 ECGR 118.7267 PXND 0.2087033 NPHI 0.2988801 NPHI 0.3310539 CRAT 2.888148 GDEV 62.05036 MRES 10,92467 MTEM 172.9442 BS 8.5 CS 1863.497 CVEL -31.05828 TENS 1310. K'rIM -999.25 KSDR -999,25 KCMR -999.25 4.043093 3.906186 5.105305 5.092911 ATD2 10.1855 10.18252 ATD1 10.1855 10.18252 ATgO 5.212529 4.621311 AT60 5.329181 4.707631 AT30 4.843547 4.309259 -13- AT20 4.549511 4.186512 AT10 4.029787 3.763526 AO90 3.89979 3.563971 AO60 3.971466 3.605077 AO30 4.539251 4.519763 AO20 4.727898 3.32306 AO10 4.180097 3.684594 AFgO 4.942001 4.827819 AF60 5.108406 4,998246 AF30 5.328592 5.289602 AF20 4.713964 4.765724 AFl0 3.979595 4.019019 0.923351 0.9268413 0.9354939 0.6832316 0.6867698 0.7000254 4,361534 4.343382 4.325854 0.1582171 0.157616 0.1515967 5.366067 5,387043 5,406229 2.567957 2.566841 2.565532 0.04972284 0.05039981 0.05119295 10.40144 10.38992 10.44753 10.40144 10.3976 10.41297 End of File HILTD .001 - 14- LISTING of ALL PARAMETERS, COMMENTS and LOG CURVES for FILE: List of set - TOOL, Set Name 2 NAME MNEM STAT HEIG VOLU WEIG PRES TEMP DSSTB DSSTB DISA -50000.(IN) -50000.(F3) -50000.(LB) ~50000.(PSIA) -50000.(DEGF) FBSTA FA~SsTA ~,S~A,-57~0~0~.:([.N.!.-5__0~3___.(.F_3).-50000.(LB)-50000.(PSIA)-50000.(DEGF) AMS ~1,.,.~' ~,~-~u~u~{.?.!,-b___g~J~__.(.F_3_).-50000.(LB}-50000.(PSIA)-50000.(DEGF) NGTD 1^0 ~'r,,~°/'~,~,,;[?~.~_U(c~?~(.P3)__-5__0~0...(LB)-50000.(PSIA) '50000.(DEGF-') lA ,', ~,,o~', -ovuuv.t,'~) 'ouu~J.{~-;~) ',5OOO0.(LB) -50000.(PSIA) -50000.(DEGF) List of set - XNAM, Set Name 4 NAME MNEM TYPE NAME ORIG CNUM DSSTB .002 List of set - OUTP, Set Name 5 NAME MNEM TUNI PUNI DESC DT4S DT4S US/F US/F DT DT US/F US/F DT2 DT2 US/F US/F DT2R DT2R US/F US/F DTRS DTRS US/F US/F DTRP DTRP US/F US/F DTSH DTSH US/F US/F DT DT US/F US/F DTD4 DTD4 F F DEV DEV DEG DEG AZ AZ DEG DEG PIAZ P1AZ DEG DEG RB1 RB1 DEG DEG MRES MRES OHMM OHMM MTEM MTEM DEGF DEGF CGR CGR GAPI GAPI POTA POTA GR GR GAPI GAPI THOR THOR PPM PPM TPRA TPRA TURA TURA URAN URAN PPM PPM UPRA UPRA C13 C13 IN IN C24 C24 IN IN List of set - XNAM, Set Name 7 NAME MNEM TYPE NAME ORIG CNUM DT DT CHANNEL DT4P 0 0-. DTSH DTSH CHANNEL DTSM-0 0 ' ~' DT. DT CHANNEL DTCO 0 0 DEV DEV CHANNEL DEVI 0 0 AZ AZ CHANNEL HAZI 0 0 P1AZ P1AZ CHANNEL P~AZ 0 0 RB1 RB1 CHANNEL RB 0 0 MRES MRES CHANNEL MRES 0 0 MTEM MTEM CHANNEL MTEM 0 0 CGR CGR CHANNEL CGR 0 0 GR GR CHANNEL SGR 0 0 C13 O13 CHANNEL C1 0 0 C24 C24 CHANNEL C2 0 0 List of set - CONS, Set Name 8 NAME MNEM STAT TUNI PUNI DESC VALU 2A 2A ALLO BP Exploration (Alaska) Inc. PDAT PDAT ALLO EPD EPD ALLO .lIN .lIN LMF LMF ALLO APD APD ALLO .lIN .lIN EDF EDF ALLO .lIN .lIN EGL EGL ALLO .lIN .lIN EKB EKB ALLO .lIN .lIN 3A 3A ALLO TD TD ALLO F F MMDU MMDU ALLO E E ALLO LB-1 LB-1 TREF TREF ALLO LBF LBF DIFF DIFF ALLO F F HVCS HVCS ALLO CD CD ALLO F F AMD AMD ALLO DEG DEG STEM STEM ALLO DEGF DEGF TWS TWS ALLO DEGF DEGF BSAL BSAL ALLO PPM PPM MRT MRT ALLO DEGF DEGF MRT3 MRT3 Al_LO DEGF DEGF MRT2 MRT2 ALLO DEGF DEGF MRT1 MRT1 ALLO DEGF DEGF RMFB RMFB ALLO OHMM OHMM RMB RMB ALLO OHMM OHMM MCST MCST ALLO DEGF DEGF RMCS RMCS ALLO OHMM OHMM MFST MFST ALLO DEGF DEGF RMFS RMFS ALLO OHMM OHMM MST MST ALLO DEGF DEGF Ground Level 1260.(.11N) Rotary Table 2754.(.11N) 4014.(.11N) 1260.(.11N) 4134.(.11N) BP Exploration (Alaska) Inc. 'Ie740.(F) FEET 9.63E-07(LB-1) 1000.(LBF) 1 .(F} HCAL 15852.(F) 352.5(DEG) -40.(DEGF) 100.(DEGF) 33000.(PPM) 203.(DEGF) 203.(DEGF) 203.(DEGF) 203.(DEGF) 0.04519875(OHMM) 0.07480074(OHMM) 60.(DEGF) 0.76(OHMM) 60.(DEGF) 0.142(OHMM) 60.(DEGF) -15- RMS RMS ALLO DFL DFL ALLO DFPH DFPH ALLO DFV DFV ALLO DFD DFD ALLO CWEI CWEI ALLO CSIZ CSIZ ALLO BS BS ALLO MHD MHD ALLO CBLO CBLO ALLO CBDR CBDR ALLO BLI BU ALLO TLI TLI ALLO TDL TDL ALLO TDD TDD ALLO ELZ ELZ ALLO OPER OPER ALLO LCC LCC ALLO LUN LUN ALLO PVER PVER ALLO SON SON ALLO CJT C, JT ALLO HIDE HIDE ALLO HID1 HID1 ALLO HID2 HID2 ALLO HLD HLD ALLO R16 R16 ALLO OS3 OS3 ALLO OS2 OS2 ALLO OS1 OS1 ALLO MCSS MCSS ALLO MFSS MFSS ALLO MSS MSS ALLO TCS TCS ALLO DCS DCS ALLO DFT DFT ALLO WITN WITN ALLO ENGI ENGI ALLO LUL LUL ALLO TLAB TLAB ALLO DLAB DLAB ALLO RUN RUN ALLO DATE DATE ALLO RANG RANG ALLO TOWN TOWN ALLO SECT SECT ALLO APIN APIN ALLO DMF DMF ALLO FL1 FL1 ALLO FL FL ALLO STAT STAT ALLO COUN COUN ALLO WN WN ALLO FN FN ALLO VHOL VHOL ALLO VCEM VCEM ALLO MPOI MPOI ALLO OFFS OFFS ALLO DCON DCON ALLO GAIN GAIN ALLO EUCF EUCF ALLO SHIF SHIF ALLO 4A 4A ALLO 5A 5A ALLO 6A 6A ALLO 7A 7A ALLO 8A 8A ALLO 9A 9A ALLO 10A 10A ALLO 1 lA 11A ALLO 12A 12A ALLO 13A 13A ALLO 14A 14A ALLO 15A 15A ALLO 16A 16A ALLO 17A 17A ALLO 18A 18A ALLO 19A 19A ALLO 20A 20A ALLO 21A 21A ALLO 22A 22A ALLO 23A 23A ALLO 24A 24A ALLO 25A 25A ALLO ORDU ORDU UNAL OHMM OHMM 0.235(OHMM) C3 C3 2.8(C3) 9. S S 66.(S) LB/G LB/G 14.(LB/G) LB/F LB/F 67.(LB/F) IN IN 9.625(IN) IN IN 8.5(IN) DEG DEG 64.15001(DEG) F F 15850.(F) F F 15852.(F) F F 18740.(F) F F 14500.(F) F F 18740.(F) F F 18740.(F) F F 33.45(F) -999 1805 8Cl-205 6109824 Primary Platform Express Combinable Magnetic resonance tool PEX-CMRT INCLUDE Crew: Mike FoustJTroy Pabst/Grog Pearson Cores RFT FMI-DSI Measured Measured Mud Engineer 12:30 15-MAR-1999 Fresh Water Mud Jerry Siok. Khedher Mellah/ Daniel Palmer Kenai - Alaska 10:28 15-MAR-1999 One 15-MAR-1999 21E 10N 21 50-O89-20O27 Rotary Table Total depth: 3671' NSL, 1058' WEL Sudace: 1682' NSL, 4508' WEL Alaska North Slope Red Dog #1 Wildcat F3 F3 7.142033(F3) F3 F3 2.99977(F3) IN IN 16.(IN) - IN -. IN. ..... -O.5600631(IN) .... ?-~;--:;:--- ~ ,;:~,~ .............. - 1.105284 1. 0. · F F 1.333333(F) IN IN 16.(IN) IN IN -0.8111686(IN) 0. 1.120309 1. 0. F F 1.333333(F) IN IN 70.(IN) DEGF DEGF 1.52589E-06(DEGF) 9. 1. 1. 0. F F 44.25(F) IN IN 37.(IN) GAPI GAPI 0.(GAPI) 120. 1.225763 1. 0. F F 32.25(F) FEET List of set - XNAM, Set Name 9 NAME MNEM TYPE NAME ORIG CNUM 2A 2A PARAMETER COMPANY 3A 4A 5A 6A 7A 8A 9A 10A 11A 12A 13A 14A 15A 16A 0 0 3A PARAMETER COMPANY 0 1 4A PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 0 5A PARAMETER MPOI 0 1 6A PARAMETER OFFS 0 1 7A PARAMETER DCON 0 1 8A PARAMETER GAIN 0 1 9A PARAMETER EUCF 0 1 10A PARAMETER SHIF 0 1 1 lA PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 1 12A PARAMETER MPOI 0 2 13A PARAMETER OFFS 0 2 14A PARAMETER DCON 0 2 15A PARAMETER GAIN 0 2 16A PARAMETER EUCF 0 2 - ].6- 17A 18A 19A 20A 21A 22A 23A 24A 25A Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: 17A PARAMETER SHIF 0 2 18A PARAMETER TOOL_STRING_MEASURE_POINT_OFFSET 0 2 19A PARAMETER MPOI 0 3 20A PARAMETER OFFS 0 3 21A PARAMETER DCON 0 3 22A PARAMETER GAIN 0 3 23A PARAMETER EUCF 0 3 24A PARAMETER SHIF 0 3 25A PARAMETER TOOL_STRiNG_MEASURE_POINT_OFFSET 0 3 Schlumberger Data Services Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska EDITED DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline This data file contains primary log curves and is grouped into 4 logical files as follows: 1. PLATFORM EXPRESS - Array InductionA_ithoDensity/Compensated Neutron and CMR - Combinable Magnetic Resonance 2. DSI/FMI - Dipole Sonic and Micro Imager Calipers/Deviations (no Images) 3. LWD - CDPJCDN/RAB - tools run over selected intervals, curves depth matched to the PLATFORM EXPRESS 4. DSI - Sonic data from cased hole section (14,530 - 15,872 fi) Summary of shifts applied to LWD data: Final Logged Depth Depth 18308.900 18328,00000 18183.300 18202.36914 18087.400 18107.80664 18054.900 18076.13867 17794.700 17815.92773 17695.500 17714.27930 17476.700 17493.26758 17328.900 17345.99609 17294.400 17307.46289 17264.900 17278.45117 17228.200 17248.99805 17164.400 17176.35938 17099.700 17112.58008 17006.700 17019.56836 ........................... .--~ ......... 16976.200 16990.77930 16920.100 16931.42969 ' 16863.400 16877.39453 16844.200 16855.69141 16820.300 16830.44531 16805.000 16818.70703 16782.800 16795.45508 15850.500 15867.99414 78.900 96.50000 PRIMARY DEPTH LOG: Primary Resistivity, Neutron, Density and Mag. Resonance (ALT, CNL, LDT, CMR) curves were taken from - HILTD .011 field data File Information: DLIS data File Name Start ~-IILTD .011 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) Stop Sample Index Tool String 15734.00(ft) -60.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.08(ft) -10.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.01(ft} -1.00 {0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.02(ft} -2.00(0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.17(ft) -20.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.04(ft) -5.00/0'1 in)'rDEP' HILTD/CMRT/AMS/DTAA/DTCA 15734.25(ft} -30.00 0.1 in) TDEP HILTD/CMRT/AMS/DTAAJDTCA 15735.00(ft) -120.00 (0.1 in) 'rDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.50(ft) -180.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA File name: HILTD .011 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: FMI-DSI, RFT, Cores, Permanent Datum: Ground LevelElev: Log Measured From: Rotary Tab 22.95 Drilling Measured From: Rotary Tab Elevation: K.B.: 34.45 D.F.: Date: 15-MAR- 1999 Run No: One Depth Driller: 18740.00 Depth Logger: 18740.00 Rge: 21E 1(J.50 Above Perm Datum 33.45 G.L: 10.50 - ].7- Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnt: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmn/: Cmnt: Cmnt: Cmn/: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit Size: Type Fluid in Hole: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Cim. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Deck 18740.00 14500.00 9.625 @ 0.00 0.00 8.5 Fresh Water Mud 14.00 Visc: 66.00 9.00 Fluid Loss: 2.80 Mud Engineer 0.23 @ 60.00 0.14 @ 60.00 0,76 @ 60.00 Measured Rmc: Measured 0.07 @ 203.00 12:30 10:28 203.00 1805 Location: Kenai - Al Khedher Mellah/ Dani Jerry Siok. 0.000 Remarks: Crew: Mike Foust/'rroy Pabst/Grog Pearson SECOND/THIRD DESCENT RECORDED ON DEPTH WITH PRIMARY: Primary Sonic, FMI CALIPER, NGT curves were taken from - FBSTA .061 field data .................. Schlumberger Data Services **,., ,S,~! ,u,m, ,b, ,e.r,g,e r ° Formation Micro-lmager Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' Sec: 21 Twn: 10N Rge: 21E File Name Start FBSTA .061 18570.50(ft) 18570.50(ft) 18570.50(ft) Stop Sample Index Tool String 16913.00(ft) -60.00 O.1 in) TDEP FBSTA/DSSTB/NGTD/AMS/DTAA/DTCA 16913.01(ft) -1.001~)0'1 in) TDEP FBSTA/DSSTB/NGTD/AMS/DTAA/DTCA 16913.12(ff) -15.00 .1 in) TDEP FBSTA/DSSTB/NGTD/AMS/DTANDTCA File name : FBSTA .061 Company: BP Exploration (Alasl~a) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: PEX-CMR, RFT, Cores, Permanent Datum: Log Measured From: Drilling Measured From: Elevation: K.B.: Date: Run No: Depth Driller: Depth Logger: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit Size: Type Fluid in Hole: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Deck Ground LevelElev: Rotary Tab Rotary Tab 34.45 D.E: 15-MAR-1999 One 18740.00 18740.00 18740.00 14500.00 9.625 @ 22.95 33.45 G.L.: 0.00 0.00 8.5 Fresh Water Mud 14.00 9.00 Mud Engineer 0.23 @ 0.14 @ 0.76 @ Measured 0.07 @ 12:30 10:28 203.00 1805 Location: Khedher MellalV Dani Jerry Siold Jim Secc -14.304 Visc': Fluid Loss: Rge: 21E 10.~0 Above Perm Datum 10.50 66.00 2.80 60.00 60.00 60.00 Rmc: Measured 212_00 Kenai - Al Remarks: DSI modes run from 18530 to 1688ft - Cress Dipole: BCR mode - Upper dipole - Lower Dipole - Compressional DSI data missing from 16970 to 16945 DSI modes from 16945 to 14500 - Upper dipole - Compressional -18- Cmnt: Cmnt: Cmnt: Omnt: Omnt: Omnt: Cmnt: Omni: Cmnt: Cmnt: Cmnt: Omnt: Cmnt: Omnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Omni: Cmnt: Cmnt: Cmnt: Omni: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Omni: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Crew: Mike Foust/'rroy Pabst/Greg Pearson Primary LWD curves were taken from - CDR .017 field data ................. Schlumberger Data Services * Schlumberger * Measured Depth Log Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska Service Order #: Location: Sec: SEC. Twn: Rge: File Information: DLIS data File Name Start Stop CDR .017 79.00(ft) 18308.90(ft) 79.00(ft) 18293.00(ft) Sample Index Tool String 0.10 (ft) TDEP CDPJSON675/P~/ADN 0.50 (ft) TDEP CDR/SON675/RAB/ADN File name : CDR .017 Company: SP Exploration (Alaska) inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska APl No: 50-089-20027- Sec: SEC. OIher Services: MWD Direct, Annular Pr, Permanent Datum: Mean Sea Level Elev: 0.00 Log Measured From: Drill Floe Drilling Measured From: Elevation: K.B.: 0.00 D.F.: Date: 99 Run No: 16 Depth Driller: 0.00 Depth Logger: 0.00 BTM LOg Interval: 0.00 Top Log Interval: 0.00 Casing Driller: ..0.000 @ Casing Logger: Bit Size: 16. Type Fluid in Hole: ' ' Dens: 0.00 pH: 0.00 Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded b~;: Witnessed Magnetic Decl: 0.000 Rge: 43.95 Above Perm Datum 43.95 G.L: 10.50 Visc: 0.00 Fluid Loss: 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 Rmc: 0.00 @ 0.00 0.00 Location: bosse List of set - FRAME, Set Name 64 NAME DESCRIPTION CHANNELS INDEX-TYPE DIRECTION SPACING ENCRYPTED INDEX-MIN INDEX-MAX INDEX-STYLE I ........... [50,0,1NDEX BOREHOLE-DEPTH DECREASING -60(.11N) ........................... EXTERNAL-INDEX DTD2 DT4S DT DT2 DT2R DTRS DTRP DTSH DT DTD4 DEV P1AZ RB1 MRES MTEM CGR POTA GR THOR TPRA -]9- TURA URAN UPRA C13 C24 1 0(IN) -999.25 ,lIN 73 \ 1 128 List of set - CHANNEL, Set Name 65 NAME PROPERTIES REPRESENTATION-CODE UNITS DIMENSION AXIS ELEMENT-LIMIT SOURCE APl-CODES FILE-NUMBER SERVICE-ID SERVICE-ORDER-NUMBER OFFSET-IN-FRAME ARTIFICIAL-CHANNEL ............................................... -;i~-'-~- ................. INDEX ................... 73 .... 1 ...... 0 0 I 1 0 1 DTD2 ................... 68 F I .... I ...... 0 2 1 1 DSI 0 DT4S ................... 68 USA:: 1 ...... ~'"'i .... . ..... 0 2 1 1 DSI 4 I 1 DSI 8 1 1 DSI 12 DT2R ................... 68 US/F 1 ....... ~.'~"i .... . ..... 0 2 I 1 DSI 16 DTRS ................... 68 US/F 1 ....... ~i~"~1'''' . ..... 0 2 1 1 DSI 20 1 1 DSI 24 I 1 DSI 28 I 1 DSI 32 DTD4 ................... 68 F I ....... ;~"i .... . ..... 0 2 I 1 DSI 36 .................. DEV ................... 68 DEG 1 .... I ...... 0 2 I 1 DSSTB 40 AZ ................... 68 DEG 1 ........... ~'.~'"1 ...... 0 2 1 1 DSSTB 44 P1AZ ................... 68 DEG 1 .... I ...... 0 2 I 1 DSSTB 48 RB1 ................... 68 DEG 1 .... I ...... 0 2 I 1 DSSTB 52 .................. - MRES ................... 68 OHMM I .... 1 ...... 0 2 1 1 DSSTB 56 .................. MTEM ................... 68 DEGF 1 .... 1 ...... 0 2 1 1 DSSTB 60 - CGR ................... 68 GAPI I ........ ~"i'" . ..... 0 2 I 1 NGT 64 POmA ................... 68 I ....... .'~":1 .... . ..... 0 2 1 1 NGT 68 GR ................... 68 GAPI I ....... ~"'i'" . ..... 0 2 1 1 NGT 72 THOR ................... 68 PPM 1 ......... ~'"~' . ..... 0 2 1 1 NGT 76 1 1 NGT 80 I 1 NGT 84 URAN ................... 68 PPM 1 ......... [[[~"~' . ..... 0 2 I 1 NGT 88 UPRA ................... 68 1 ....... ;~""i"' . ..... 0 2 1 1 NGT 92 O13 ................... 68 IN I .......... ;~":1' . ..... 0 2 4 4 DSSTB 96 C24 ................... 68 IN I ......... [~i['"~' . ..... 0 2 4 4 DSSTB 112 .................. Contents of Data Frame at 18570.5 (fi), 5660.2884 (m) INDE 2228460 DTD2 -999,25 DT4S 159.0999 DT 84.26689 Dm2 163.8125 DT2R 166.7642 D'FRS 159.0999 DTRP 84.26689 DTSH 163,8125 DT 84.26689 DTD4 -999.25 DEV -999.25 AZ -999.25 PIAZ -999.25 RB1 -999.25 MRES -999.25 MTEM -999.25 CGR -999.25 POmA -999.25 GR -999.25 THOR -999.25 C13 C24 - 20 - Contents of Data Frame at 18500. (ft), 5638.8 (m) INDE 2220000 DTD2 -999.25 DT4S 163.3022 DT 85.51164 DT2 168.3221 DT2R 171.3551 DTRS 163.3022 ' DTRP 85.51164 DTSH 168.3221 DT 85.51164 DTD4 -999.25 DEV -999.25 AZ -999.25 P1AZ -999.25 RB1 -999.25 MRES -999.25 MTEM -999.25 CGR -999.25 POTA -999.25 GR -999.25 THOR -999.25 C13 C24 Contents of Data Frame at 18000. (ft), 5486.4 (m) INDE 21600(X) DTD2 -999.25 DT4S 149.6556 DT 81.59441 DT2 156.391 DT2R 158.5311 DTRS 149.6556 DTRP 81.59441 DTSH 156.391 DT 81.59441 DTD4 -999.25 DEV 32.1143 AZ 341.261 PIAZ 89.56729 RB1 111.336 MRES 11.95146 MTEM 196.5515 CGR 102.3151 POTA 0.03526182 GR 112.7178 THOR 9.13131 TPRA 2.589574 TURA 7.29069 URAN 1.252462 UPRA 0.3551892 C13 8.772926 8.768501 8.772926 8.768501 C24 9.417116 9.417116 9.417116 9.417116 Contents of Data Frame at 17500. (ft), 5334. (m) INDE 2100000 DTD2 -999,25 DT4S 149.3201 DT 82.00308 DT2 156.5561 DT2R 157.9938 DTRS 149.3201 DTRP 82.00308 DTSH 156.5561 DT 82.00308 DTD4 -999.25 DEV 35.24961 AZ 344.9507 PIAZ 95.04181 RB1 114.1274 MRES 10.92467 MTEM 189.9397 CGR 116.7581 POTA 0.03772078 GR 119.5583 THOR 11.46021 TPRA 3.03817 TURA 22.92043 URAN 0.3371507 UPRA 0.132553 C13 8,667877 8.663324 8.663324 8.689619 C24 9.363811 9.363811 9.363811 9.310509 Contents of Data Frame at 17000. (fi), 5181.6 (m) INDE 2040000 DTD2 -999.25 DT4S 151.2503 DT 78.64552 DT2 155.746 DT2R 157.1763 DTRS 151.2503 DTRP 78.64552 DTSH 155.746 DT 78.64552 DTD4 -999.25 DEV 49.34068 AZ 345.8271 PIAZ 83.910,39 RB1 102.2967 MRES 11.95146 MTEM 184.995 CGR 82.82503 POTA 0.02649037 GR 95.26981 THOR 8.240112 TPRA 3.110607 TURA 5.499516 UP, AN 1.498334 UPRA 0.5656147 C13 8.400377 8.400377 8.400377 8.405252 C24 9.790245 9.790245 9.790245 9.776918 End of File DSSTB .002 -2! - LISTING of ALL PARAMETERS, COMMENTS and LOG CURVES for FILE: SNAM .003 List of set - OUTP, Set Name 2 NAME MNEM TUNI PUNI DESC DCAL DCAL IN IN NPHI NPHI CFCF CFCF ARPM ARPM RPM RPM RA RA OHMM OHMM DRHB DRHB G/C3 G/C3 DRHL DRHL C-JC3 C-JC3 DRHO DRHO G/C3 G/C3 DRHR DRHR G/C3 G/C3 DRHU DRHU G/C3 G/C3 DTAB DTAB S S GR GR GAPI GAPI GR GR GAPI GAPI HORD HORD IN IN I'Fr 13-[' MS MS PEB PEB PEF PEF PEL PEL PER PER PEU PEU RP RP OHMM OHMM ROBB ROBB G/C3 G/C3 ROBL ROBL G/C3 G/C3 ROBR ROBR G/C3 G/C3 ROBU ROBU G/C3 G/C3 ROP5 ROP5 F/HR F/HR RTIM RTIM S S TVDE TVDE F F VERD VERD IN IN BDAV BDAV OHMM OHMM BMAV BMAV OHMM OHMM BSAV BSAV OHMM OHMM RBIT RBIT OHMM OHMM RING RING OHMM OHMM CHTP CHTP CHRP CHRP DT DT US/F US/F DTRP DTRP US/F US/F D'I-rP DTTP US/F US/F GR GR GAPI GAPI List of set - XNAM, Set Name 4 NAME MNEM TYPE NAME ORIG CNUM DCAL DCAL CHANNEL DCAL 0 0 NPHI NPHI CHANNEL TNPH 0 0 RA RA CHANNEL ATR 0 0 DRHB DRHB CHANNEL DRHB 0 0 DRHO DRHO CHANNEL DRHO 0 0 GR , GR CHANNEL GR 0 0-.. GR GR CHANNEL GR 0 1 PEB PEB CHANNEL PEB 0 0 PEF PEF CHANNEL PEF 0 0 RP RP CHANNEL PSR 0 0 ROBB ROBB CHANNEL ROBB 0 0 ROBL ROBL CHANNEL ROBL 0 0 ROBR ROBR CHANNEL ROBR 0 0 ROBU ROBU CHANNEL ROBU 0 0 BDAV BDAV CHANNEL BDAV 0 0 BMAV BMAV CHANNEL BMAV 0 0 BSAV BSAV CHANNEL BSAV 0 0 RBIT RBIT CHANNEL RBIT 0 0 RING RING CHANNEL RING 0 0 DT DT CHANNEL DT 0 0 GR GR CHANNEL GR 0 2 List of set - CONS, Set Name 5 NAME MNEM STAT TUNI PUNI DESC VALU 1 a 1 a ALLO PDAT PDAT ALLO EPD EPD ALLO .lIN .lIN LMF LMF ALLO APD APD ALLO .liN .lIN EDF EDF ALLO .lIN .lIN EGL EGL ALLO .lIN .lIN EKB EKB ALLO .lIN .lIN BTO4 BTO4 ALLO F F BFM4 BFM4 ALLO F F BMX4 BMX4 ALLO DEG DEG BMN4 BMN4 ALLO DEG DEG BTO3 BTO3 ALLO F F BFM3 BFM3 ALLO F F BMX3 BMX3 ALLO DEG DEG BMN3 BMN3 ALLO DEG DEG BTO2 BTO2 ALLO F F BFM2 BFM2 ALLO F F BMX2 BMX2 ALLO DEG DEG BMN2 BMN2 ALLO DEG DEG BTO1 BTO1 Al_LO F F BFM1 BFM1 ALLO F F BMX1 BMX1 ALLO DEG DEG BMN1 BMN1 ALLO DEG DEG MTO4 MTO4 ALLO F F MF4 MF4 ALLO F F MTO3 MTO3 ALLO F F MF3 MF3 ALLO F F BP Exploration (Alaska) Inc. Ground Level 1260.(.11N) Rotary Table 2754.(.11N) 4014.(.11N) 1260.(.11N) 4134.(.11N) O.(F) O.(F) 0.(DEG) 0.(DEG) 0.(F) 0.(F) 0.(DEG) 0.(DEG) 0.(F) 0.(F) 0.(DEG) 0.(DEG) 1536.(F) 110.(F) 1.(DEG) 0.(DEG) 0.(F) 0.(F) 0.(F) 0.(F) - :2:2 - MTO2 MF2 MTO1 MF1 DLT DPLF TOTD STRN ENRN DPRF SDAT TG3E TG3N TG3T TG2E TG2N TG2T TG1E TG1N TG1T GMDC GMLD GMLH GMLG MCPI PDEP PLAT P-I-VD GINC GDEP LTVD LAZM LINC LDEP CHZU CHYU CHXU MCHZ MCHY MCHX LOCH LOCG LDLS 2A 3A OFFW ALRM GMRO TOTC GRDC TFCP TPRA TPED TPND TPAZ TPIN TP'I-V TPDP CFIL CTAR CBTF CBOF AQDY JSTM DFDL RCON REFP FMFS MFD MWIN MRIN MCIN MTDH MTIN CFL IRP SWI PTYP PCNT HTVD BTVD BHAN SWDT ALGO MNTH NOZA NOZ6 NOZ5 NOZ4 NOZ3 NOZ2 NOZ1 CALC DSCF BCOF MWGT DWBR SWBR 4A PV YP R600 R300 R3 X~DM XPNM A MTO2 MF2 MTO1 MF1 DLT DPLF TOTD STRN ENRN DPRF SDAT TG3E TG3N TG3T TG2E TG2N TG2T TG1E TGIN TG1T GMDC GMLD GMLH GMLG MCPI PDEP PLAT PTVD GINC GDEP LTVD LAZM LINC LDEP CHZU CHYU CHXU MCHZ MCHY MCHX LOCH LOCG LDLS 2A 3A OFFW ALRM GMRO TOTC GRDC TFCP TPED TPND TPAZ TPIN TPTV TPDP CFIL CTAR CBTF CBOF AQDY JSTM DFDL RCON REFP FMFS MFD MWIN MRIN MClN MTDH MTIN CFL IRP SWI PTYP PCNT HTVD BTVD BHAN SWDT ALGO MNTH NOZA NOZ6 NOZ5 NOZ4 NOZ3 NOZ2 NOZ1 CALC DSCF BCOF MWGT DWBR SWBR 4A PV YP R600 R300 R3 )~PDM XPNM A ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO ALLO F F 0.(F) F F 0.(F) F F 1536.(F) F F 110.(F) F F 1536.(F) F F 110.(F) F F 1536.(F) 28538904 28538904 Driller Pipe Tally 25 January 1999 F F -999.25(F) F F -999.25(F) F F -999.25(F) F F -999.25(F) F F -999.25(F) F F -999.25(F) F F -999.25(F) F F -999.25(F) F F -999.25(F) DEG DEG 28.81841(DEG) DEG DEG 80.87704(DEG) 1148.688 1002.671 0. F F -999.25(F) F F -999.25(F) F F -999.25(F) DEG DEG -999.25(DEG) F F -999.25(F) F F 12378.58(F) DEG DEG 332.02(DEG) DEG DEG 15.(DEG) F F 19400.(F) 0. 0. 0. 0. 0. 0. 1148.69 1002.67 D/HF D/HF 1.028845(D/HF) BP Exploration (Alaska) Inc. TVDE -999.25 F F 10.(F) 1. DEG DEG 28,81(DEG) DEG DEG 0.(DEG) DEG DEG 221.2(DEG) DEG DEG 351.59(DEG) F F 0.(F) F F 0.(F) DEG DEG 0.(DEG) DEG DEG 0.(DEG) F F 0.(F) DEG DEG -999.25(DEG) DEG DEG -999.25(DEG) DEG DEG 0.(DEG) 450 S S 917049600(S) 10. NO F F 0.(F) OHMM OHMM 1.2(OHMM) G/C3 GJC3 1.(G/C3) LB/G LB/G 10.(LB/G) OHMM OHMM 100.(OHMM) MM/M MM/M 100.(MM/M) DEGF DEGF 100.(DEGF) DEGF DEGF 80,(DEGF) 1 F F 100.(F) F F IO0.(F) 1 1 1 1 IN2 IN2 1.(IN2) 1/32 1/32 1.(I/32) 1/32 1/32 1.(I/32) 1/32 1/32 1.(1/32) 1/32 1/32 1.(1/32) 1/32 1/32 1.(1/32) 1/32 1/32 1.(I/32) 0. 1. 1. LB/G LB/G 9.700001(LB/G) 3. KLBF KLBF 10.(KLBF) PS~ PS~ 0.(PS~) CP CP 22.(CP) PSI PS~ 46.(PS~) 3. 2. 0. 0.625 0.375 0.6700001 M 5A MDEN RTST GRAD PGRS 6A S3MG S1MG L5MG L4MG S3AL SIAL L5AL L4AL PEFO 7A 8A PEFS HSFZ CDNV TMUD 9A 10A GROF GRSC GTSF 11A ACF LAMB MLRM MLTG MLWN MLA2 MLA1 MLBS MLSS MLSB MLLC MLUC MLFR MLTA MLSP MLST XlW5 XDW3 XDW2 XDWl XlW4 XlW3 XlW2 XlWl DTOF DWOF 12A 13A 14A 15A 16A 17A 18A 19A 20A MGDF SWP5 SWP4 SWP3 SWP2 SWP1 P4DR P3DR P2DR P1DR DHRF PFRF PPRF RVFC P4FC P3FC P2FC P 1FC P4EF P3EF P2EF P1EF P4CP P3CP P2CP P1CP NLS AMD STEM TWS RW SGOR BPT BPP IBG BG BW BO GGRA ODEN TCWL TCDE TCV CWLO M 5A MDEN RTST GRAD PGRS 6A S3MG S1MG L5MG L4MG S3AL SlAL L5AL L4AL PEFO 7A 8A PEFS HSFZ CDNV TMUD 9A 10A GROF GRSC GTSF 11A ACF LAMB MLRM MLTG MLWN MLA2 MLA1 MLBS MLSS MLSB MLLC MLUC MLFR MLTA MLSP MLST XlW5 XDW3 XDW2 XDWl XlW4 XlW3 XlW2 XlWl DTOF DWOF 12A 13A 14A 15A 16A 17A 18A 19A 20A MGDF SWP5 SWP4 SWP3 SWP2 SWP1 P4DR P3DR P2DR P1DR DHRF PFRF PPRF RVFC P4FC P3FC P2FC P1FC P4EF P3EF P2EF P 1EF P4CP P3CP P2CP P1CP NLS AMD STEM TWS RW SGOR BPT BPP IBG BG BW BO GGRA ODEN TCWL TCDE TCV CWLO ALLO 2 ALLO SAND ALLO G/C3 G/C3 2.65(G/C3) ALLO DEGF DEGF 32.(DEGF) ALLO D/HF D/HF 1.(D/HF) ALLO YES ALLO 0. ALLO 4901.11 ALLO 1047.78 ALLO 213.88 ALLO 211.71 ALLO 2426.77 ALLO 344.57 ALLO 36.91 Al_LO 36.38 ALLO 0.5 ALLO 1.65 AIIO 0.5500001 ALLO 4.5 ALLO 2. ALLO 4.1 ALLO NO ALLO RPM RPM 20.(RPM) ALLO RPM RPM 20.(RPM) ALLO 0. ALLO 1. ALLO 3 ALLO PPK PPK 0.(PPI0 AIIO 0.5808001 ALLO 24.19 ALLO 1. ALLO 1. ALLO KLBF KLBF 25.(KLBF} ALLO 0.15 ALLO 0.15 ALLO IN IN 12.25(IN) ALLO 15. ALLO 5. ALLO 0.1 A LLO 0.1 ALLO 0.4 ALLO DEG DEG 20.(DEG) ALLO F F 50000.(F) ALLO F F 0.(F) ALLO 0. ALLO 0.01 ALLO 0.00563 ALLO 0.00563 ALLO -0.0243 ALLO -0.0246 ALLO -0.0264 ALLO -0.02 ALLO KFLB KFLB -9.(KFLB) ALLO KLBF KLBF -64.(KLBF) ALLO 13 ALLO 27.45099 ALLO 0.3228434 ALLO . 917807719 ALLO ..... ~' 1786.119 ALLO 847.3715 ALLO F F 4272.871(F) ALLO 9.700001 ALLO PSI PSI 2152.77(PSI) ALLO -1 ALLO 53. ALLO F F 10.(F) ALLO F/HR F/HR 36000.(F/HR) ALLO F F 5000.(F) ALLO F F 1000.(F) ALLO 0. ALLO O. ALLO o. ALLO 0. ALLO PJGA R/GA 0.(R/GA) ALLO GPM GPM 0.(GPM) ALLO PSI PSI 125.(PSI) ALLO 0.07700001 ALLO 1. ALLO 1. ALLO 1. ALLO 1. ALLO % % lOO.(%) ALLO % % lOO.(%) ALLO % % 96.(%) ALLO % % 96.(%) ALLO BBL BBL 0.1(BBL) ALLO BBL BBL 0.1(BBL) ALLO BBL BBL 0.10491(BBL) ALLO BBL BBL 0.10491(BBL) ALLO -999.25 ALLO -999.25 ALLO -g99.25 ALLO DEGF DEGF 155.(DEGF) ALLO OHMM OHMM 0.15(OHMM) ALLO -g99.25 ALLO -99g.25 ALLO -999.25 ALLO -99g.25 ALLO -999.25 ALLO -999.25 ALLO -999.25 ALLO -999.25 ALLO -g99.25 ALLO -999.25 ALLO -999.25 ALLO -999.25 ALLO -999.25 - 23 - - 24 - CDEN CDEN ALLO LCVO LCVO ALLO BSAL BSAL ALLO MRT MRT ALLO MRT3 MRT3 ALLO MRT2 MRT2 ALLO MRT1 MRT1 ALLO RMFB RMFB ALLO RMB RMB ALLO MCST MCST ALLO RMCS RMCS ALLO MFST MFST ALLO RMFS RMFS ALLO MST MST ALLO RMS RMS ALLO DFPH DFPH ALLO DFL DFL ALLO DFV DFV ALLO DFD DFD ALLO CWEI CWEI ALLO CSIZ CSIZ ALLO BS BS ALLO MHD MHD ALLO CTOP CTOP ALLO FLEV FLEV ALLO CBLO CBLO ALLO CBDR CBDR ALLO CADT CADT ALLO CDF CDF ALLO BSDT BSDT ALLO BSDF BSDF ALLO BLI BU ALLO TLI TLI ALLO TDL TDL ALLO TDD TDD ALLO ELZ ELZ ALLO OPER OPER ALLO LCC LCC ALLO LUN LUN ALLO ILL2 ILL2 ALLO ILL1 ILL1 ALLO PVER PVER ALLO SON SON ALLO UWID UWID ALLO TCA TCA ALLO TCTY TCTY ALLO CADD CADD ALLO LCMT LCMT ALLO CJT CJT ALLO CASN CASN ALLO HIDE HIDE ALLO HID1 HID1 ALLO HID2 HID2 ALLO HLD HLD ALLO OS2 OS2 ALLO OS1 OS1 ALLO MCSS MCSS ALLO MFSS MFSS ALLO MSS MSS ALLO TCS TCS ALLO DCS DCS ALLO DFT DFT ALLO CASG CASG ALLO WITN WITN ALLO ENGI ENGI ALLO LUL LUL ALLO TLAB TLAB ALLO DLAB DLAB ALLO RUN RUN Al_LO DATE DATE ALLO CONT CONT ALLO NATI NATI ALLO RANG RANG ALLO TOWN TOWN ALLO SECT SECT ALLO LONG LONG ALLO LATI LATI ALLO APIN APIN ALLO DMF DMF ALLO FL2 FL2 ALLO FL1 FL1 ALLO FL FL ALLO STAT STAT ALLO COUN COUN ALLO FN FN ALLO WN WN ALLO CN1 CN1 ALLO RLAB RLAB ALLO 21A 21A ALLO LLAB LLAB ALLO CLAB CLAB ALLO SLAB SLAB ALLO 22A 22A ALLO 23A 23A ALLO DO DO ALLO pp pp ALLO ORDU ORDU UNAL LB/F LB/F IN IN IN IN F F FEET List of set - XNAM, Set Name 6 NAME MNEM TYPE NAME ORIG CNUM lA lA PARAMETER COMPANY 0 2A 2A PARAMETER COMPANY 0 3A 3A PARAMETER ALTDPCHAN 0 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999.25 -999,25 -999.25 -999,25 -999.25 0.(LB/F) O.(IN) 16.(IN) -999.25 -999 -999 -999,25 -999.25 -999.25 -999.25 -999.25 -999.25 -999 -999.25 -999.25 -999.25 -999.25 -999 -999 id5_0c_03 Primary Measured Depth Log FIELD PRINT Scales 1:600 and 1:240 INCLUDE Annular Pressure While Drilling MWD Directional bosse SEC. 34, T10N, R21E, UM 146.791126 W 70.1751421 N 50-089-20027-00 Alaska Nabors 28E Wildcat Red Dog #1 CDR RANGE TOWNSHIP 1682' NS[., 4508' WEL Rig: State: MEASURED_DEPTH NO O.(F) NORMAL - 25 - 4A 5A 6A 7A 8A 9A 10A 11A 12A 13A 14A 15A 16A 17A 18A 19A 20A 21A 22A 23A Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: 4A PARAMETER DPRSS 0 0 5A PARAMETER MATRIX 0 0 6A PARAMETER TNRA OFF 0 0 7A PARAMETER SSEN~ 0 0 8A PARAMETER LSENS 0 0 9A PARAMETER CDN_RPM 0 0 10A PARAMETER ADN RPM 0 0 11A PARAMETER RT I~SAL 0 0 12A PARAMETER DZ~NT 0 0 13A PARAMETER DZTMP 0 0 14A PARAMETER DZDLS 0 0 15A PARAMETER DZTIM 0 0 16A PARAMETER DZSPP 0 0 17A PARAMETER DZ-rFL 0 0 18A PARAMETER DZTVD 0 0 19A PARAMETER DZMDW 0 0 20A PARAMETER DZHDR 0 0 21A PARAMETER TLLAB 0 0 22A PARAMETER LOGMODE 0 0 23A PARAMETER FLSHSTRM 0 0 Schlumberger Data Services Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska EDITED DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline This data file contains primary log curves and is grouped into 4 logical files as follows: 1. PLATFORM EXPRESS - Array Induction/LithoDensity/Compensated Neutron and CMR - Combinable Magnetic Resonance 2. DSI/FMI - Dipole Sonic and Micro Imager Calipers/Deviations (no Images) 3. LWD - CDPJCDN/RAB - tools run over selected intervals, curves depth matched to the PLATFORM EXPRESS 4. DSI - Sonic data from cased hole section (14,530 - 15,872 ft) Summary of shifts applied to LWD data: Final Logged Depth Depth ft ft 18308.900 18328.00000 18183.300 18202.36914 18087.400 18107.80664 18054.900 18076.13867 17794.700 17815,92773 17695.500 17714.27930 17476.700 17493.26758 17328.900 17345.99609 17294.400 17307,46289 17264.900 17278.45117 17228.200 17248.99805 17164.400 17176.35938 17099.700 17112.58008 17006.700 17019.56836 16976.200 16990.77930 16920.100 16931.42969 16863.400 16877,39453 16844.200 16855.69141 16820.300 16830.44531 16805.000 16818.70703 16782.800 16795.45508 15850.500 15867.99414 78.900 96.50000 PRIMARY DEPTH LOG: Primary Resistivity, Neutron, Density and Mag. Resonance (NT, CNI._, LDT, CMR) curves were taken from - HILTD .011 field data ' File Information: DLIS data File Name Start Stop Sample Index Tool String HILTD .011 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) 15734.00(ft) -60.00 (0.1 in) TDEP HILTD/CMRT/AI~IS/DTAA/DTCA 15734.08(ft) -10.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.01(ft) -1.00(0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.02(ft) -2.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.17(ft) -20.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.04(ft) °5.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.25(ft) -30.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15735.00(ft) -120.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.50(ft) -180.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA File name : HILTD .011 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL - ?-.6 - Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Omnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Omnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Omnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnt: Cmnl: Cmnl: Cmnl: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: APl No: Other Services: Permanent Datum: Log Measured From: Drilling Measured From: Elevation: K.B.: Date: Run No: Depth Driller; Depth Logger: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit Size: Type Fluid in Hole: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Decl: Total depth: 3671' NSL, 1058' 50-089-20027 Sec: 21 Twn: 10N FMI-DSI, RFT, Cores, Ground LevelElev: Rotary Tab 22.95 Rotary Tab 34.45 D.F.: 33.45 G.L.: 15-MAR-1999 One 18740.00 18740.00 18740.00 14500.00 9.625 @ 0.00 0.00 8.5 Fresh Water Mud 14.00 9.00 Mud Engineer 0.23 @ 0.14 @ 0.76 @ Measured 0.07 @ 12:30 10:28 203.00 1805 Location: Khedher Mellah/ Dani Jerry Sick. 0.000 Visc: Fluid Loss: 60.00 60.00 60.00 Rmc: 203.00 Rge: 21E 1(~.50 Above Perm Datum 10.50 Kenai - Al Measured 66.00 2.80 Remarks: Crew: Mike FousFTroy Pabst/Greg Pearson SECOND/THIRD DESCENT RECORDED ON DEPTH WITH PRIMARY: Primary Sonic, FMI CALIPER, NGT curves were taken from - FBSTA .061 field data .................. Schlumberger Data Services * Schlumberger * Formation Micro-lmager Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' Sec: 21 . Twn:.' ~..1ON Rge: 2'rE'-'.' -~1 File Name' Start .......... FBSTA .061 18570.50(ft) 18570.50(ft) 18570.50(ft) Stop 'Sample Index Tool String 16913.00(ft) °60.00 10.1 in/ TDEP FBSTAE)SSTB/NGTD/AMS/DTAA/DTCA 16913.01(ft) -1.00 0.1 in TDEP FBSTA~)SSTB/NGTD/AMS/DTAA/DTCA 16913.12(ft) -15.00 (0.1 in TDEP FBSTA/DSSTB/NGTD/AMS/DTAA/DTCA File name: FBSTA .061 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Sudace: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: PEX-CMR, RFT, Cores, Permanent Datum: Ground LevelElev: Log Measured From: Rotary Tab 22.95 Drillin~ Measured From: Rotary Tab Elevation: K.B.: 34.45 D.F.: 33.45 G.L:' 10.50 Date: 15- MAR- 1999 Run No: One Depth Driller: 18740.00 Depth Logger: 18740.00 BTM Log Interval: 18740.00 Top Log Interval: 14500.00 Casing Driller: 9.625 @ 0.00 Casing Logger: 0.00 Bit Size: 8.5 Type Fluid in Hole: Fresh Water Mud Dens: 14.00 risc: pH: 9.00 Fluid Loss: Source of Sample: Mud Engineer Rm @ Meas Temp: 0.23 @ 60.00 Rmf @ Meas Temp: 0.14 @ 60.00 Rmc @ Meas Temp: 0.76 @ 60.00 Source: Rmf: Measured Rmc: Measured Rm @ BHT: 0.07 @ 212.00 Time Circ. Stop: 12:30 Logger on Bottom: 10:28 Max Rec Temp: 203.00 Equip: 1805 Location: Kenai - Al Recorded by: Khedher Mellah/ Dani Witnessed by: Jerry Sick/ Jim Secc Rge: 21E 10.~0 Above Perm Datum 66.00 2.80 - 27 - Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Crnnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: List Magnetic Decl: -14.304 ========== Remarks: DSI modes run from 18530 to 1688ft - Cress Dipole: BCR mode - Upper dipole - Lower Dipole - Compressional DSI data missing from 16970 to 16945 DSI modes from 16945 to 14500 - Upper dipole - Compressional Crew: Mike FousFTroy PabstJGreg Pearson Primary LWD curves were taken from - CDR .017 field data .................. Schlumberger Data Services Schlumberger * Measured Depth Log Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska Service Order #: Location: Sec: SEC. Tv,n: Rge: File Information: DLIS data File Name Start Stop CDR .017 79.00(ft) 18308.90(ft) 79.00(fi) 18293.00(ft) Sample Index Tool String 0.10 (ft) TDEP CDR/SON675/RAB/ADN 0.50 (ft) TDEP CDP,/SON675/RAB/ADN File name : CDR .017 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska APl No: 50-089-20027- Sec: SEC. Twn: Other Services: MWD Direct, Annular Pr, Permaner~t Datum: Elev: 0.00 Log Measured From: Drilling Measured From: Elevation: K.B.: 0.00 D.F.: Date: 99 Run No: 16 Depth Driller: 0.00 Depth Logger: 0.00 BTM Log Interval: 0.00 Top Log Interval: 0.00 Casing Driller: 0.000 @ Casing Logger: Bit Size: 16. Type Fluid in Hole: Dens: 0.00 pH: 0.00 Source of Sample: Rm @ Meas Temp: 0.00 @ Rmf @ Meas Temp: 0.00 @ Rmc @ Meas Temp: 0.00 @ Soume: Rmf: Rm @ BHT: 0.00 @ Time Circ. Stop: Logger on Bottom: Max Rec Temp: 0.00 Equip: Location: Recorded by: bosse Witnessed by: Magnetic Deck 0.000 Rge: , Mean Sea Level . .~. · Drill FIoo 43.95 Above Perm Datum 43.95 G.L: 10.50 0.00 0.00 Visc: Fluid Loss: 0.00 0.00 0.00 Rmc: 0.00 0.00 0.00 of set - FRAME, Set Name 67 NAME DESCRIPTION CHANNELS INDEX-TYPE DIRECTION SPACING ENCRYPTED INDEX-MIN INDEX-MAX INDEX-STYLE 1 ........... [70,0, INDEX BOREHOLE-DEPTH DECREASING -60(.11N) ........................... EXTERNAL-INDEX DCAL NPHI ARPM RA DRHB DRHL DRHO DRHR DRHU DTAB - 28 - GR GR HORD I'I-I' PEB PEF PEL PER PEU RP ROBB ROBL ROBR ROBU ROP5 RTIM TVDE VERD BDAV BMAV BSAV RBIT RING CHTP CHRP DT DTRP D'I-rP GR 1 O(IN) -999.25 .lIN 73 \ I 236 List of set - CHANNEL, Set Name 68 NAME PROPERTIES REPRESENTATION-CODE UNITS DIMENSION AXIS ELEMENT-LIMIT SOURCE APl-CODES FILE-NUMBER SERVICE-ID SERVICE-ORDER-NUMBER OFFSET-IN-FRAME ARTIFICIAL-CHANNEL INDEX ................... 73 .lIN 1 .... I ...... 0 0 I 1 0 1 DCAL ................... 68 IN 1 .... 1 ...... 0 3 I 1 ADN 0 NPHI ................... 68 CFCF 1 ........ :::;":1'" . ..... 0 3 I 1 ADN 4 ARPM ................... 68 RPM 1 .......... ~":1' . ..... 0 3 I 1 ADN 8 RA ................... 68 OHMM 1 .......... ~:":1' . ..... 0 3 1 1 CDR 12 DRHB ................... 68 G/C3 1 ........ ~i:~"i'" . ..... 0 3 1 1 ADN 16 DRHL ................... 68 G/C3 1 ........ :~.']":l'" . ..... 0 3 I . j,- 1 ADN 20 '" : .... DRHO ................... 68 G/C3 I ........ ~'"~" . ..... 0 '~' ........... 1 1 ADN 24 DRHR ................... 68 G/C3 1 ........ iiii'"~" . ..... 0 3 I 1 ADN 28 DRHU ................... 68 G/C3 I ........ ii~;'"~" . ..... 0 3 1 1 ADN 32 DTAB ................... 68 S 1 ....... iiii":'1'"' . ..... 0 3 I 1 ADN 36 eR ................... 68 GAPI 1 ....... ~'"i'" . ..... 0 3 I 1 ADN 40 GR ................... 68 GAPI 1 ..... [~[""i ..... . ..... 0 3 I 1 RAB 44 HOED ................... 68 IN I ........ ~i~"i'" . ..... 0 3 I 1 ADN 48 ITl' ................... 68 MS 1 ...... [~[:'"~ .... . ..... 0 3 1 1 ISON 52 PEB ................... 68 1 .... I ...... 0 3 1 1 ADN 56 PEF ................... 68 1 ...... ~'"'i .... . ..... 0 3 I 1 ADN 60 PEL ................... 68 1 ...... ::::"~ .... . ..... 0 3 1 1 ADN 64 PER ................... 68 I ....... ~":1"" . ..... 0 3 I 1 ADN 68 PEU ................... 68 1 ....... :~:":1'"' . ..... 0 3 1 1 ADN 72 RP ................... 68 OHMM 1 .......... ~i~":1' . ..... 0 3 I 1 CDR 76 ROBB ................... 68 G/C3 1 ....... '::::"i'" . ..... 0 3 I 1 ADN 80 ROBL ................... 68 GJC3 1 ........ .'.'~."'i'" . ..... 0 3 I 1 ADN 84 .................. - 2.9 - ROBR ................... 68 G/C3 1 .... 1 ...... 0 3 1 1 ADN 88 ROBU ................... 68 G/C3 1 ........ iiii":I'" . ..... 0 3 1 1 ADN 92 ROP5 ................... 68 F/HR 1 ........ .'.'.'."'i'" . ..... 0 3 1 1 CDR 96 RTIM ................... 68 S 1 ...... ~'"'i .... . ..... 0 3 1 1 CDR 100 TVDE ................... 68 F 1 ....... ]]ii":1'"' . ..... 0 3 1 1 ISON 104 VERD ................... 68 IN I ........ ~i~"i'" . ..... 0 3 1 1 ISON 108 BDAV ................... 68 OHMM 1 ......... iiii"~1'' . ..... 0 3 5 5 RAB 112 BMAV ................... 68 OHMM 1 ......... iiii":1" . ..... 0 3 5 5 RAB 132 BSAV ................... 68 OHMM 1 ........ ~'"'i" . ..... 0 3 5 5 RAB 152 REIT ................... 68 OHMM I ....... ~'"~'" . ..... 0 3 5 5 RAB 172 RING ................... 68 OHMM 1 ........ iiii"~1''' . ..... 0 3 5 5 RAB 192 CHTP ................... 68 I ........ ;.~"'~'" . ..... 0 3 1 1 ISON 212 CHRP ................... 68 1 ........ ~'"i" . ..... 0 3 1 1 ISON 216 DT ................... 68 US/F I ....... ~;ii'"~'" . ..... 0 3 1 1 ISON 220 DTRP ................... 68 US/F I ........ ii~'"~" . ..... 0 3 1 1 ISON 224 DTTP ................... 68 US/F I ........ ~i~":1"' . ..... 0 3 1 1 ISON 228 GR ................... 68 GAPI 1 ........ ~ii~'"~" . ..... 0 3 1 1 ISON 232 .................. Contents of Data Frame at 18328. (ft), 5586.3744 (m) INDE 2199360 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA -999.25 DRHB -999.25 DRHL -999.25 · ~ Contents of Data Frame at 18000. (ft), 5486.4 (m) INDE 2160000 DCAL 0.3794676 NPHI -999.25 ARPM 131, RA 4.41401 DRHB 0.01046824 DTAB 5976.348 GR 103.1724 GR -999.25 HORD 8.7684 ITl' 64,22624 PEB 5.610703 PEF 11.97556 PEL 11.48465 PER 12.29519 PEU 29.77494 RP 3.952785 ROBE 2.619602 ROBL 2.609267 ROBR 2.62066 ROBU 2.583746 ROP5 62.49817 RTIM 2694.042 TVDE 11080.63 VERD 8.9018 CHTP 0.9020001 CHRP 0.8936334 DT 85.04027 DTRP 84.79779 DTTP 85.28207 GR 102.7102 Contents of Data Frame at 17500. (fi), 5334. (m) INDE 2100000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 4.031113 DRHB -999.25 DRHL -999.25 I'FI' 21.74861 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 3.736136 CHTP 0.8962356 CHRP 0.8930084 DT 84.51343 DTRP 83,96576 D'I-rP 85.06108 GR 108.2133 Contents of Data Frame at 17000. (ft), 5181.6 (m) INDE 2040000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 8.317511 DRHB -999.25 DRHL -999.25 ITT 37.3682 PEB -999.25 PEF -999,25 PEL -999.25 PER -999.25 PEU -999.25 RP 8,530413 CHTP 0.8348216 CHRP 0.8890618 DT 80.6261 DTRP 80.73369 DTI'P 80.51851 GR 82,24661 Contents of Data Frame at 16500. (ft), 5029.2 (m) INDE 1980000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 4.552789 DRHB -999.25 DRHL -999.25 ITT 66.03783 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.878711 6.759001 6.835032 6.865891 6.729961 6.467059 5.723572 5.437629 5.448646 5,542613 5.618846 8,179562 8.013399 8.23225 8.090673 7.668697 4.196355 3.857608 4.33325 4.56274 4.806927 4.893907 4.669078 4.956786 5.523922 5.732467 CHTP 0.9187323 CHRP 0.9125355 DT 82.03606 DTRP 81.83568 DTTP 82.23645 GR 102.7806 Contents of Data Frame at 16000. (ft), 4876.8 (m) INDE 1920000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 4.292626 DRHB -999.25 DRHL -999.25 I'lq' 24.43699 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 5.035715 8.762798 8.950575 8.140903 8.031754 7.936917 5.108605 4.998694 4.986345 5.010312 4.973422 7.767058 7.785399 7.69031 7.717222 7.380802 4.283655 4.28521 4.287141 4.291432 4.295038 4.502067 4.429699 4.368298 4.293486 4.111542 - :30- CHTP 0.8789959 CHRP 0.9298327 DT 81.19554 DTRP 80.72388 DTTP 81.66705 GR 108.2944 Contents of Data Frame at 15500. (fi), 4724.4 (m) INDE 1860000 DCAL -999,25 NPHI -999.25 ARPM -999.25 RA 4.854016 DRHB -999.25 DRHL -999.25 I'I-I- 585.0184 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.919165 CHTP 0.4602084 CHRP 0.8380208 DT 87.16708 DTRP 82.70511 DTTP 91.62917 GR 115.2597 Contents of Data Frame at 15000. (ft), 4572. (m) INDE 1800000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 5.14668 DRHB -999.25 DRHL -999.25 I-I-r 543.1183 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 5.224915 CHTP 0.8972 CHRP 0.868 DT 84.51941 DTRP 83.7467 DTTP 85.293 GR 117.2637 Contents of Data Frame at 14500. (ft), 4419.6 (m) INDE 1740000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 5.199572 DRHB -999.25 DRHL -999.25 ITT 501.8777 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 5.432577 CHTP 0.678 CHRP 0.9175313 DT 85.21492 DTRP 85.57607 D'rTP 84.85367 GR 107.1019 Contents of Data Frame at 14000. (ft), 4267.2 (m) INDE 1680000 DCAL -999.25 NPHI -999.25 ARPM -999.25 IRA 4.4134 DRHB -999.25 DRHL -999.25 I-I-r 459.5215 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.543382 CHTP 0.7250313 CHRP 0.8739376 DT 87.15878 DTRP 87.57841 DTTP 86.73906 GR 122.9247 Contents of Data Frame at 13500. (ft), 4114.8 (m) INDE 1620000 DCAL -999.25 NPHI -999.25 ARPM -999.25 IRA 5.2663 DRHB -999.25 DRHL -999.25 ITT 415.8063 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 5.108666 CHTP 0.4795521 CHRP 0.9292688 DT 84.43034 DTRP 84,26553 DTTP 84.59515 GR 121.9772 Contents of Data Frame at 13000. (fi), 3962.4 (m) INDE 1560000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 6.254534 DRHB -999.25 DRHL -999.25 ITT 372.4029 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 6.05269 CHTP 0.8918251 CHRP 0.8876126 DT 84.76373 DTRP 83.72835 DTTP 85.80011 GR 110.8936 Contents of Data Frame at 12500. (ft), 3810. (m) INDE 1500000 DCAL -999.25 NPHI -999.25 ARPM -999.25 IRA 4.755309 DRHB -999.25 DRHL -999.25 ITT 327.9454 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999,25 RP 4.740352 CHTP 0.48675 CHRP 0.9225833 DT 89.177 DTRP 91.53633 DTTP 86.81767 GR 106.8391 Contents of Data Frame at 12000. (ft), 3657.6 (m) INDE 1440000 DCAL -999.25 NPHI -999.25 ARPM -999.25 IRA 4.664184 DRHB -999.25 DRHL -999.25 ITT 283.2732 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.555698 CHTP 0.6474292 CHRP 0.9141792 DT 90.41844 DTRP 90.46485 D'I'-TP 90.35194 GR 112.2807 Contents of Data Frame at 11500. (ft), 3505.2 (m) INDE 1380000 DCAL -999.25 NPHI -999.25 ARPM -999.25 IRA 4.039325 DRHB -999.25 DRHL °999.25 ITT 237.8031 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.109612 CHTP 0.4665375 CHRP 0.8790001 DT 94.11833 DTRP 93.17003 DTTP 95.06572 GR 131.574 Contents of Data Frame at 11000. (ft), 3352.8 (m) INDE 1320000 DCAL -999.25 NPHI -999.25 ARPM -999.25 IRA 2.497084 DRHB -999.25 DRHL -999.25 ITT 192.0977 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 3.736696 CHTP 0.5976771 CHRP 0.9292188 DT 92.7733 DTRP 93.6329 DTTP 91.9137 GR 126.9003 Contents of Data Frame at 10500. (ft), 3200,4 (m) INDE 1260000 DCAL -999.25 NPHI -999.25 ARPM -999.25 IRA 4.685146 DRHB -999.25 DRHL -999.25 ITT 145.5675 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.598093 CHTP 0.4881417 CHRP 0.9369292 DT 92.48547 DTRP 93.76079 DT'I'P 91.20923 GR 113.5658 Contents of Data Frame at 10000. (ft), 3048. (m) INDE 1200000 [3(3AL -999.25 NPHI -999.25 ARPM -999.25 RA 4.621725 DRHB -999.25 DRHL -999.25 ITT 98.82407 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.6405 CHTP 0.5017333 CHRP 0.942 DT 93.02473 DTRP 95.01807 DTTP 91.03233 GR 111.0466 Contents of Data Frame at 9500. (ft), 2895.6 (m) INDE 1140000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 4.127895 DRHB -999.25 DRHL -999.25 ITT 52.16767 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 4.028763 CHTP 0.9610626 CHRP 0.9635 DT 93.87225 DTRP 93.55481 DTTP 94.1897 GR 108.1033 -3! - Contents of Data Frame at 9000. (fi), 2743.2 (m) INDE 1080000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 3.721873 DRHB -999.25 DRHL -999.25 ITl' 5.071069 PEB -999.25 PEF -999.25 PEL -999.25 PER -999.25 PEU -999.25 RP 3.630702 CHTP 0.6691813 CHRP 0.9038187 DT 102.3505 DTRP 102.1082 DTTP 102.5938 GR 109.4639 Contents of Data Frame at 8500. (ft), 2590.8 (m) INDE 1020000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 2.570622 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 8000. (fl), 2438.4 (m) INDE 960000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 3.102871 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 7500. (fi), 2286. (m) INDE 900000 DCAL -999.25 NPHI -999.25 ARPM -999.25 .... RA 2.099773 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 7000. (ft), 2133.6 (m) INDE 840000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA- 2.978477 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 6500. (ft), 1981.2 (m) INDE 780000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 1.654374 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 6000. (ft), 1828.8 (m) INDE 720000 DCAL -999.25 NPHI -999.25 ARPM -999.25 PA, 1.836869 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 5500. (ft), 1676.4 (m) INDE 660000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 2.22123 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 5000. (ft), 1524. (m) INDE 600000 DCAL -999.25 NPHI -999.25 ARPM -999.25 PA, 1.338007 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 4500. (ft), 1371.6 (m) 1.054149 INDE 540000 DCAL -999.25 NPHI- ~999.25 ARPM- ~999.25 ' RA _ _. DRHB -999.25 DRHL -999.25 Contents of Data Frame at 4000. (ft), 1219.2 (m) INDE 480000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 1.335095 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 3500. (ft), 1066.8 (m) INDE 420000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 2.5428 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 3000. (ft), 914.4 (m) INDE 360000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 1.261299 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 2500. (ft), 762. (m) i~'-~3-(~ ......... ~,~'":~,~Ji~,~- ..... ~'~1i-"*'~)-.~',~---'~'~1~-'----~'.~-~'--'~'----~.9810154 DRHB-999.25 DRHL-999.25 Contents of Data Frame at 2000. (ft), 609.6 (m) INDE 240000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 2.279124 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 1500. (ft), 457.2 (m) INDE 180000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 100.2151 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 1000. (ft), 304.8 (m) INDE 120000 DCAL -999.25 NPHI -999.25 ARPM -999.25 PA, 9.872425 DRHB -999.25 DRHL -999.25 Contents of Data Frame at 500. (ft), 152,4 (m) INDE 60000 DCAL -999.25 NPHI -999.25 ARPM -999.25 RA 115.007 DRHB -999.25 DRHL -999.25 - 32 - End of File SNAM .003 - 33 - LISTING of ALL PARAMETERS, COMMENTS and LOG CURVES for FILE: List of set - TOOL, Set Name 2 NAME MNEM STAT HEIG VOLU WEIG PRES TEMP DSSTB DSSTB DISA -50000.(IN) -50000.(F3) -50000.(LB) -50000.(PSIA) -50000.(DEGF) FBSTA FBSTA DISA -50000.(IN) -50000.(F3) -50000.(LB) -50000.(PSIA) -50000.(DEGF) List of set - OUTP, Set Name 4 NAME MNEM TUNI PUNI DESC DT6~ ....~¥~¥¥ ...... DT4S DT4S US/F US/F DT DT US/F US/F DT2 DT2 US/F US/F DT2R DT2R US/F USA: DTRS DTRS US/F US/F DTRP DTRP US/F US/F DTSH DTSH US/F US/F DT DT US/F US/F DTD4 DTD4 F F List of set - XNAM, Set Name 6 NAME MNEM TYPE NAME ORIG CNUM DT DT CHANNEL DT4P 0 0 DTSH DTSH CHANNEL DTSM 0 0 DT DT CHANNEL DTCO 0 0 List of set - CONS, Set Name 7 NAME MNEM STAT TUNI PUNI DESC VALU lA lA ALLO PDAT PDAT ALLO EPD EPD ALLO .lIN .lIN LMF LMF ALLO APD APD ALLO .lIN .lIN EDF EDF ALLO .lIN .lIN EGL EGL ALLO .lIN .lIN EKB EKB ALLO .lIN .lIN ORDU ORDU UNAL FEET FN FN wildcat WN WN red dog I BP Exploration (Alaska) Inc. Ground Level 1260.(.1lN) Rotary Table 2754,(.1 IN) 4014.(.11N) 1260.(.11N) 4134.(.11N) List of set - XNAM, Set Name 8 NAME MNEM TYPE NAME ORIG CNUM lA lA PARAMETER COMPANY 0 . .(3- Cmnt: ....................... Cmnt: Cmnt: .................. Cmnt: * Schlumberger * Cmnt: .................. Cmnt: Cmnt: Cmnt: Company: Cmnt: Well: Cmnt: Field: Cmnt: County: Cmnt: State: Cmnt: Cmnt: Cmnt: Schlumberger Data Services BP Exploration (Alaska) Inc. Red Dog #1 Wildcat North Slope Alaska Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: EDITED DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline This data fife contains primary log curves and is grouped into 4 logical files as follows: 1. PLATFORM EXPRESS - Array Induction/LithoDensity/Com_pensated Neutron and CMR - Combinable Magnetic [--[esonance 2. DSI/FMI - Dipole Sonic and Micro Imager Calipers/Deviations (no Images) 3. LWD - CDR./CDN/RAB - tools run over selected intervals, curves depth matched to the PLATFORM EXPRESS 4. DSI - Sonic data from cased hole section (14,530 - 15,872 ft) Summary of shifts applied to LWD data: Final Logged Depth Depth ff ft 18308.900 18328.00000 18183.300 18202.36914 18087.400 18107.80664 18054.900 18076.13867 17794.700 17815.92773 17695.500 17714.27930 17476.700 17493.26758 17328.900 17345.99609 17294.400 17307.46289 17264.900 17278.45117 17228.200 17248.99805 17164.400 17176.35938 17099.700 17112.58008 DSSTB .OO4 - 34 - Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: 17006.700 17019.56836 16976.200 16990.77930 16920.100 16931.42969 16863.400 16877.39453 16844.200 16855.69141 16820.300 16830.44531 16805.000 16818.70703 16782.800 16795.45508 15850.500 15867.99414 78.900 96.50000 PRIMARY DEPTH LOG: Primary Resistivity, Neutron, Density and Mag. Resonance (ALT, CNL LDT, CMR) curves were taken from - HILTD ,011 field data File Information: DLIS data File Name Start HILTD .Oll 18727,00(ft) 18727.00(ft) 18727.00(ff) 18727.00(ft) 18727.00(ff) 18727.00(ft) 18727.00(ft) 18727.00(ft) 18727.00(ft) Stop Sample Index Tool String 15734.00(ft) -60.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA./DTCA 15734.08(ft) -10.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.01(ft) -1.0010'1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.02(ff) -2.00 0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.17(ft) -20.00 (0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA 15734.04(ft) -5.00 (0.1 in) 'rDEP HILTD/CMRT/AMS/DTANDTCA 15734.25(ft) -30.00/0'1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15735.00(ft) -120.O0 O. 1 in) TDEP HILTD/CMRT/AMS/DTANDTCA 15734.50(ft) -180.00 0.1 in) TDEP HILTD/CMRT/AMS/DTAA/DTCA File name : HILTD .011 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Other Services: FMI-DSI, RFT, Cores, Permanent Datum: Lcg Measured From: Drilling Measured From: Elevation: K.B.: Date: Run No: Depth Driller: Depth Logger: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit. Size: Type Fluid in Hole: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Deck Ground LevelElev: Rotary Tab Rotary Tab 34.45 D.F.: 15-MAR- 1999 One 18740.00 18740.00 18740.00 14500.00 9.625 @ 22.95 33.45 G.L: 0.00 0.00 Rge: 21E 1~.50 Above Perm Datum 10.50 8.5 Fresh Water Mud 14.00 Visc: 9.00 Fluid Loss: .IVI~.. d. Engineer ' "0.23 @ '=-~;;,ov~.~ ........ ~' -- 0.14 @ 60.00 0.76 @ 60.00 Measured Rmc: Measured 0.07 @ 203.00 12:30 10:28 203.00 1805 Location: Kenai - Al I~edher Mellah/ Dani Jerry Siok. 0.000 Remarks: Crew: Mike Foust/Troy Pabst/Greg Pearson SECOND/THIRD DESCENT RECORDED ON DEPTH WITH PRIMARY: Primary Sonic, FMI CALIPER, NGT curves were taken from - FBSTA .061 field data .................. Schlumberger Data Services :._,S.~.l,u.m**b..e.r.g. er ' Formation Uic~'o-lma. ger Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' Sec: 21 Twn: 10N Rge: 21E File Name Start FBSTA .061 18570.50(ft) 1857o.5o(ft) 1857o.5o(ft) Stop Sample Index Tool String 16913.00(ff) -60.00 (0.1 in) TDEP FBSTA/DSSTB/NGTD/AMS/DTAA/DTCA 16913.01(ft) -1.00(0.1 in) TDEP FBSTA/DSSTB/NGTD/AMS/DTAA/DTCA 16913.12(ft) -15.00 (0.1 in) TDEP FBSTA/DSSTB/NGTD/AMS/DTAA/DTCA - 35 - Cmnt: Cmnt: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: File name : FBSTA .061 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska Service Order #: 610982 Location: Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' APl No: 50-089-20027 Sec: 21 Twn: 10N Rge: 21E Other Services: PEX-CMR, RFT, Cores, Permanent Datum: Ground LeveiElev: 10.~0 Log Measured From: Rotary Tab 22.95 Above Perm Datum Drilling Measured From: Rotary Tab Elevation: K.B.: 34.45 D.F.: 33.45 G.L.: 10.50 Date: 15-MAR- 1999 Run No: One Depth Driller: 18740.00 Depth Logger: 18740.00 BTM Log Interval: 18740.00 Top Log Interval: 14500.00 Casing Driller: 9.625 @ 0.00 Casing Logger: 0.00 Bit Size: 8.5 Type Fluid in Hole: Fresh Water Mud Dens: 14.00 Visc: 66.00 pH: 9.00 Fluid LOSS: 2.80 Source of Sample: Mud Engineer Rm @ Moas Temp: 0.23 @ 60.00 Rmf @ Moas Tamp: 0.14 @ 60.00 Rmc @Meas Temp: 0.76 @ 60.00 Source: Rmf: Measured Rmc: Measured Rm @ BHT: 0.07 @ 212.00 Time Circ. Stop: 12:30 Logger on Bottom: 10:28 Max Rec Tamp: 203.00 Equip: 1805 Location: Kenai - Al Recorded by: Khedher Mellah/ Dani Witnessed by: Jerry Siok/ Jim Secc Magnetic Decl: -14.304 Remarks: DSI modes run from 18530 to 1688ft - Cress Dipole: BCR mode - Upper dipole - Lower Dipole - Compressional DSI data missing from 16970 to 16945 DSI modes from 16945 to 14500 - Upper dipole Compressional Crew: Mike Foust/'rroy Pabst/Grog Pearson Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Primary LWD curves were taken from - CDR .017 field data Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnl: Cmnl: Cmnt: Cmnl: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: Cmnt: .................. Schlumberger Data Services * Schlumberger * Measured Depth Log Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska Service Order #: Location: Sec: SEC. Twn: Rge: File Information: DLIS data File Name Start Stop CDR .017 79.00(fl) 18308.90(ft) 79.00(fl) 18293.00(ft) Sample Index Tool String 0.10 (fl) TDEP CDPJSON675/RAB/ADN 0.50 (ft) TDEP CDR/SON675/RAB/ADN File name : CDR .017 Company: BP Exploration (Alaska) Inc. Well: Red Dog #1 Field: Wildcat County: Nabors 28E State: Alaska APl No: 50-089-20027- Sec: SEC. Twn: Other Services: MWD Direct, Annular Pr, Permanent Datum: Mean Sea Level Elev: 0.00 Log Measured From: Drill FIoo Drilling Measured From: Elevation: K.B.: 0.00 D.F.: Date: 99 Run No: 16 Depth Driller: 0.00 Depth Logger: 0.00 BTM Log Interval: 0.00 Top Log Interval: 0.00 Rge: 43.95 Above Perm Datum 43.95 G,L: 10.50 -36- Cmnt: Casing Driller: 0,000 @ Cmnt: Casing Logger: Cmnt: Bit Size: 16. Cmnt: Type Fluid in Hole: Cmnt: Dens: 0,00 Cmnt: pH: 0,00 Cmnt: Source of Sample: Cmnt: Rm @ Meas Temp: 0.00 @ Cmnt: Rml' @ Meas Temp: 0.00 @ Cmnl: Rmc @ Meas Temp: 0.00 @ Cmnt: Source: Rmf: Cmnt: Rm @ BHT: o.00 @ Cmnt: Time Circ. Stop: Cmnl: Logger on Bottom: Cmnt: Max Rec Temp: 0.00 Cmnt: Equip: Location: Cmnt: Recorded by: bosse Cmnt: Witnessed by: Cmnt: Magnetic Decl: 0.000 Cmnt: Cmn/: Cmn/: 0.00 0.00 Visc: Fluid Loss: 0.00 0.00 0.00 Rmc: 0.00 0.00 0.00 List of set - FRAME, Set Name 70 NAME DESCRIPTION CHANNELS INDEX-TYPE DIRECTiON SPACING ENCRYPTED INDEX-MIN INDEX-MAX INDEX-STYLE 1 ........... [117,0, INDEX BOREHOLE-DEPTH DECREASING -60(.lIN} EXTERNAL-INDEX DTD2 DT4S DT DT2 DT2R DTRS DTRP DTSH DT DTD4 1 0(IN) -999.25 .lIN 73 List of set - CHANNEL, Set Name 71 NAME PROPERTIES REPRESENTATION-CODE UNITS DIMENSION AXIS ELEMENT-LIMIT SOURCE APl-CODES FILE-NUMBER SERVICE-ID SERVICE-ORDER-NUMBER OFFSET-IN-FRAME ARTiFICIAL-CHANNEL INDEX ................... 73 .lIN 1 .... 1 ...... 0 0 1 1 0 1 DTD2 ................... 68 F 1 .... I ...... 0 4 1 1 DSI 0 DT4S ................... 68 US/F I ...... ~'"i .... . ..... 0 4 1 1 DSI 4 Dr ................... 68 US/F 1 ...... :iii":1' .... . ..... ~D-~' 4 ~, 1 1 DSI ' 8' ' DT2 ................... 68 US/F I ...... iii~"11' .... . ..... 0 4 I 1 DSI 12 DT2R ................... 68 US/F 1 ....... .'.~'"'~ .... . ..... 0 4 1 1 DSI 16 DTRS ................... 68 US/F 1 ....... iiii":1"" . ..... 0 4 1 1 DSI 20 DTRP ................... 68 US/F 1 ....... :;::"~1'"' . ..... 0 4 1 1 DSI 24 DTSH ................... 68 US/F 1 ....... iiii":1'"' . ..... 0 4 1 1 DSI 28 Dm ................... 68 US/F 1 ...... iiii":1' .... . ..... 0 4 I 1 DSI 32 DTD4 ................... 68 F 1 ...... ~'.'.'"i .... . ..... 0 4 1 1 DSI 36 .................. Contents of Data Frame at 15872.5 (fl), 4837.938 (m) INDE 1904700 DTD2 -999.25 DT4S 86.11542 DT 56.13457 DT2 144.0488 DTRP 56.13457 DTSH 144.0488 DT 56.13457 DTD4 -999.25 DT2R 145.0934 DTRS 86.11542 Contents of Data Frame at 15500. (fl). 4724.4 (m) INDE 1860000 DTD2 -999.25 DT4S 79.26286 DT 55.49083 DT2 159.0914 DTRP 55.49083 DTSH 159.0914 DT 55,49083 DTD4 -999,25 DT2R 160.5524 DTRS 79,26286 Contents of Data Frame at 15000. (ft), 4572. (m) INDE 1800000 DTD2 -999.25 DT4S 81.69504 DT 54.05225 DT2 148.5712 DTRP 54,05225 DTSH 148.5712 DT 54.05225 DTD4 -999,25 End of File DSSTB .004 DT2R 149.6487 DTRS 81.69504 * Schlumberger * Schlumberger Data Services Company: BP Exploration Well: Red Dog #1 Field: Wildcat County: North Slope State: Alaska (Alaska) Inc. EDITED DATA ACQUIRED Feb/Mar 1999 - LWD and Wireline Summary of shifts applied to LWD data: Final Logged Depth Depth ft ft 18308.900 18328.00000 18183.300 18202.36914 18087.400 18107.80664 18054.900 18076.13867 17794.700 17815.92773 17695.500 17714.27930 17476.700 17493.26758 17328.900 17345.99609 17294.400 17307.46289 17264.900 17278.45117 17228.200 17248.99805 17164.400 17176.35938 17099.700 17112.58008 17006.700 17019.56836 16976.200 16990.77930 16920.100 16931.42969 16863.400 16877.39453 16844.200 16855.69141 16820.300 16830.44531 16805.000 16818.70703 16782.800 16795.45508 15850.500 15867.99414 78.900 96.50000 PRIMARY DEPTH LOG: Primary Resistivity, Neutron, Density and Mag. Resonance (AIT, CNL, LDT, C curves were taken from - HILTD .011 field data File Information: DLIS data File Name Start Stop HILTD .011 Sample 18727.00(ft) 15734.00(ft) -60.00 (0.1 in) 18727.00(ft) 15734.08(ft) -10.00 (0.1 in) 18727.00(ft) 15734.01(ft) -1.00 (0.1 in) 18727.00(ft) 15734.02 (ft) -2.00 (0.1 in) Index Tool String TDEP TDEP TDEP TDEP HILTD/CMRT/AMS/ HILTD/CMRT/AMS/ HILTD/CMRT/AMS/ HILTD/CMRT/AMS/ 18727.00 (ft) 18727.00 (ft) 18727.00 (ft) 18727.00 (ft) 18727.00 (ft) 15734.17(ft) -20.00 (0.1 in) 15734.04(ft) -5.00 (0.1 in) 15734.25(ft) -30.00 (0.1 in) 15735.00(ft) -120.00 (0.1 in) 15734.50(ft) -180.00 (0.1 in) TDEP TDEP TDEP TDEP TDEP HILTD/CMRT/AMS/ HILTD/CMRT/AMs/ HILTD/CMRT/AMS/ HILTD/CMRT/AM~/ HILTD/CMRT/AMS/ File name : HILTD .011 Company: Well: Field: County: State: Service Order #: Location: BP Exploration (Alaska) Inc. Red Dog #1 Wildcat North Slope Alaska 610982 Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' API No: Other Services: FMI-DSI, Permanent Datum: Log Measured From: Drilling Measured From: Elevation: K.B.: Date: Run No: Depth Driller: Depth Logger: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit Size: Type Fluid in Hole: Dens: pH: ~ Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Decl: 50-089-20027 Sec: 21 Twn: 10N RFT, Cores, Ground LevelElev: Rotary Tab Rotary Tab 34.45 D.F.: 15-MAR-1999 One 18740.00 18740.00 18740.00 14500.00 9.625 @ 22.95 60.00 60.00 60.00 203.00 0.00 0.00 Rge: 21E 10.~0 Above Perm Datum 33.45 G.L.: 10.50 8.5 Fresh Water Mud 14.00 9.00 Mud Engineer 0.23 @ 0.14 @ 0.76 @ Measured 0.07 @ 12:30 10:28 203.00 1805 Location: Khedher Mellah/ Dani Jerry Siok. 0.000 risc: Fluid Loss: 66.00 2.80 Rmc: Measured Kenai - A1 Remarks: Crew: Mike Foust/Troy Pabst/Greg Pearson SECOND/THIRD DESCENT RECORDED ON DEPTH WITH PRIMARY: Primary Sonic, FMI CALIPER, NGT curves were taken from - FBSTA .061 field data * Schlumberger * Schlumberger Data Services Formation Micro-Imager Company: Well: Field: County: State: Service Order #: Location: Sec: 21 BP Exploration (Alaska) Inc. Red Dog #1 Wildcat North Slope Alaska 610982 Surface: 1682' NSL, 4508' WEL Total depth: 3671' NSL, 1058' i0N Rge: 21E Twn: File Name Start Stop Sample FBSTA .061 18570.50 (ft) 18570.50 (ft) 18570.50 (ft) 16913.00(ft) -60.00 (0.1 in) 16913.01(ft) -1.00 (0.1 in) 16913.12(ft) -15.00 (0.1 in) Index Tool String TDEP TDEP TDEP FBSTA/DSSTB/NGT FBSTA/DSSTB/NGT FBSTA/DSSTB/NGT File name : FBSTA .061 Company: Well: Field: County: State: Service Order #: Location: BP Exploration (Alaska) Red Dog #1 Wildcat North Slope Alaska 610982 Surface: 1682' NSL, Total depth: 3671' Inc. 4508' WEL NSL, 1058' API No: Other Services: PEX-CMR, Permanent Datum: Log Measured From: Drilling Measured From: Elevation: K.B.: Date: Run No: Depth Driller: Depth Logger: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit Size: Type Fluid in Hole: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: 50-089-20027 Sec: 21 Twn: i0N RFT, Cores, Ground LevelElev: Rotary Tab Rotary Tab 34.45 D.F.: 15-MAR-1999 One 18740.00 18740.00 18740.00 14500.00 9.625 @ 8.5 Fresh Water Mud 14.00 9.00 Mud Engineer 0.23 @ 0.14 @ 0.76 @ Measured 0.07 @ 12:30 10:28 203.00 1805 22.95 Rge: 21E 10.~0 Above Perm Datum 33.45 G.L.: 10.50 0.00 0.00 60.00 60.00 60.00 212.00 Visc: Fluid Loss: Rmc: Measured 66.00 2.80 Location: Kenai - A1 Recorded by: Witnessed by: Magnetic Decl: Khedher Mellah/ Dani Jerry Siok/ Jim Secc -14.304 Remarks: DSI modes run from 18530 to 1688ft - Cress Dipole: BCR mode - Upper dipole - Lower Dipole - Compressional DSI data missing from 16970 to 16945 DSI modes from 16945 to 14500 - Upper dipole - Compressional Crew: Mike Foust/Troy Pabst/Greg Pearson Primary LWD curves were taken from - CDR .017 field data * Schlumberger * Company: Well: Schlumberger Data Services Measured Depth Log BP Exploration (Alaska) Inc. Red Dog #1 Field: Wildcat County: State: Service Order #: Location: Sec: SEC. Twn: Nabors 28E Alaska Rge: File Information: DLIS data File Name Start CDR .017 79.00(ft) 79.00 (ft) Stop Sample Index Tool String 18308.90 (ft) 18293.00 (ft) 0.10 (ft) TDEP CDR/SON675/RAB/AD 0.50 (ft) TDEP CDR/SON675/RAB/AD File name : CDR Company: Well: Field: County: State: .017 BP Exploration (Alaska) Inc. Red Dog #1 Wildcat Nabors 28E Alaska API No: 50-089-20027- Sec: SEC. Other Services: MWD Direct, Annular Pr, Permanent Datum: Mean Sea Level Rge: ~lev: 0.00 Log Measured From: Drilling Measured From: Elevation: K.B.: Date: Run No: Depth Driller: Depth Logger: BTM Log Interval: Top Log Interval: Casing Driller: Casing Logger: Bit Size: Type Fluid in Hole: Dens: pH: Source of Sample: Rm @ Meas Temp: Rmf @ Meas Temp: Rmc @ Meas Temp: Source: Rmf: Rm @ BHT: Time Circ. Stop: Logger on Bottom: Max Rec Temp: Equip: Recorded by: Witnessed by: Magnetic Decl: Drill Floo 99 16 0.00 D.F.: 0.00 0.00 0.00 0.00 0. 000 @ 16. 0.00 0.00 0.00 @ 0.00 @ 0.00 @ 0.00 @ 43.95 Above Perm Datum 43.95 G.L.: 10.50 0.00 0.00 0.00 0.00 0.00 0.00 Visc: 0.00 Fluid Loss: .0.00 Rmc: 0.00 bosse Location: 0.000
