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Home My WebLink About204-168 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ CJ y.. - 1 fr¿ g Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 7 to (Count does include c?r sheet) Page Count Matches Number in Scanning Preparation: V YES Date: 111/4-1 00 If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 11111111111" 111111 R~CAN v6 Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NofType: D Poor Quality Originals: D Other: NOTES: BY: ~ Date 1/ / /if-IO (¡; Project Proofing BY: ~ (,,- ...... ''''-..I Date II 'I If /0 (p ~ X 30 = {f} () Date: / I { I if / n (~ Scanning Preparation BY: ~ BY: ~ Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: flúP 111111111111111111I wtP /5/ /5/ + /5 = TOTAL PAGES r¡ ¿¡- (Count does not include cover stket) J\ A P /5/ r V\ 11/1111111111111111 NO YES /5/ /A1p NO /5/ 11/11111111I1111111 11111111111111 1111I /5/ Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • -~,: -_ ~, A~ E _ v~~ ~ 'S.. - a ~. 03~0~ zoos DO NOT PLACE ~~ ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc ;tC1 bet- À-ß~~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041680 Well Name/No. KUPARUK RIV UNIT 1F-18AL 1 Operator CONOCOPHILLIPS ALASKA INC MD 9144~· TVD 6272'--- Completion Date 9/29/2004-- Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION r .>11 ú..-J. I f' ¥~ '1 API Nc!. 50-029-22654-60-00 UIC N Mud Log No Samples No Directional Survey Yes ~~_..- DATA INFORMATION Types Electric or Other Logs Run: GR / Rap / PRESS Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Type Med/Frmt Number Name I Rpt Directional Survey Rpt Directional Survey ...éB"""'" C Lis 13807 Gamma Ray 4 13807 LIS Verification ~ Gamma Ray U4J Gamma Ray ~·C Lis 13808 Gamma Ray ~ 13808 LIS Verification ~og Gamma Ray ~ Gamma Ray Log Log Run Scale Media No Interval OH/ Start Stop CH Received 8034 9144 Open 11/8/2004 7409 8256 Open 11/8/2004 8045 9144 Open 3/13/2006 8045 9144 Open 3/13/2006 8045 9144 Open 3/13/2006 8045 9144 Open 3/13/2006 7430 8254 Open 3/13/2006 25 Blu 5 Blu 7430 8254 Open 3/13/2006 25 Blu 7430 8254 Open 3/13/2006 25 Blu 7430 8254 Open 3/13/2006 Sample Interval Set Start Stop Sent Received Number Comments Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / Ð Chips Received? ¥ , t4 Daily History Received? ~N &)/ N Formation Tops Analysis Received? Y~ Comments: . Comments PB 1 GR Rap GR ROP GR Rap GR Rap PB 1 GR Rap plus Graphics PB 1 GR ROP PB 1 GR Rap PB 1 GR Rap . Permit to Drill 2041680 MD 9144 TVD 6272 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well Name/No. KUPARUK RIV UNIT 1F-18AL 1 Operator CONOCOPHILLIPS ALASKA INC Completion Date 9/29/2004 Completion Status 1-01L Current Status 1-01L UIC N ~ API No. 50-029-22654-60-00 Date: -J~)¡- . . It Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: IF-18ALIPBI Contains the following: 1 LDWG Compact Disc r\1-- (Includes Graphic Image files) 11 1 LDWG lister summary . r&l_ BAKER HUGHES Anchorage GEOScience Center \7Í~ 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional True Vertical Depth Log LAC Job#: 751636 Sent By: Gle;¡rrel ¡J 11! I / Received By: ' /Jftuv-Y.- U ¡¡/AI Date: March 7, 2006 Date: I)~)..M (¡ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907)267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~v{ -LCbr I ....._m.,.... I .~flllt1t··~ ",~I ~:>",__._..._""""," U .., ,....;: "........".".--.....---......., ""." .... , ''''', ....... ... ,""( ....... _~.'!"_____~_H-:;r~ ,,' n. .,.. ""...." .n ,,,,",,, ........ -. - . Transmittal Form '4111 BAKEl HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: IF-18ALl Contains the following: -þ ß8Dl 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 b1ue1ine - GR/Directional Measured Depth Log 1 blueline - GR/Directional True Vertical Depth Log LAC Job#: 751636 Sent By: GI~ ¡Orel¡ / J A Re<eived By: ~() WI Date: March 7, 2006 Date: )) HI./IÆt-I ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 d--DL./ - [Co~ II ...!...._~I<.. .. 1,or\!~I'l!~_1(^1f 1,.,'H";¡! _w: ..11IIIII._ ..U .... ._;; -.-_..._.___._.... .... _...____nmn_______ <, '."( ...-, . '''''. .....-.. ... ,;>" ......, ~·I(1\I¡' _'II! _ -ox ... ,.....~' ,,, n.... ,-,.. _n....,... . .. ,.--------- r " .. , _ STATE OF ALASKA .- AlAS~ll AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, liNER AND CEMENTING RECORD SE1'TINsÐEF'TIi MD SETTINODEPl"HTVÞ 'lOP BOTTOM Surface 121' Surface 4254' Surface 7208' 7000' 7435' 7254' 9080' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 792' SNL, 455' WEL, SEC. 19, T11 N, R10E, UM Top of Productive Horizon: 1905' NSL, 201' WEL, SEC. 18, T11N, R10E, UM Total Depth: 2792' NSL, 1658' EWL, SEC. 17, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539521 y- 5958733 Zone- ASP4 TPI: x- 539752 y- 5961432 Zone- ASP4 Total Depth: x- 541603 y- 5962329 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: GR/ROP/PRESS 22. 16" 7-5/8" 5-1/2" 3-1/2" 2-3/8" 62.5# 29.7# 15.5# 9.3# 4.7# H-40 L-80 L-80 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-3/8" Slotted Section MD TVD MD TVD 7257' - 9036' 5977' - 6270' 26. Date First Production: October 12, 2004 Date of Test Hours Tested PRODUCTION FOR 10/14/2004 6 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 1037 1417 24-HoUR RATE 27. One Other 5. Date Comp., Susp., or Aband. 9/29/2004 ' 6. Date Spudded ¡-g ,¡.;Þ,./.1..t>ll 91.1-5/2004 7. Date T.D. Reached 9/25/2004 ' 8. KB Elevation (ft): 108' 9. Plug Back Depth (MD+TVD) 9144 + 6272 10. Total Depth (MD+TVD) - 9144 + 6272- 11. Depth where SSSV set 499' MD 19. Water depth, if offshore N/A MSL v 1 b; . well Class: 181 Developm~nt 0 Exploratory o Stratigraphic D service 12. Permit to Drill Number 204-168 13. API Number 50- 029-22654-60-00 14. Well Name and Number: Kuparuk 1 F-18AL 1 15. Field / Pool(s): Kuparuk River Ft Ft 16. Property Designation: ADL 025652 17. Land Use Permit: 20. Thickness of Permafrost 1380' ss (Approx.) ï7û.,)~ 74~/:rnJ:> ,¡{p ,~ /ofl' 'rvz:> il· 17.0'1 AMOUNT PULLEO 24" Surface Surface Surface 5785' 5974' 121' 3730' 5940' 6111' 6273' 9-7/8" 6-3/4" 4-3/4" 3" SIZE 3-1/2",9.3#, L-80 DEPTH INTERVAL (MO) PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift OIL-BsL GAs-McF WATER-BsL 148 499 530 OIL-BsL 591 GAs-McF 1995 WATER-BsL 2121 230 sx Arcticset I 710 sx AS 111,300 sx Class 'G' 70 sx Class 'G' 99 sx Class 'G' Uncemented Slotted Liner DEPTH SET (MD) 7000' PACKER SET (MD) 6999' AMOUNT & KIND OF MATERIAL USED CHOKE SIZE I GAS-OIL RATIO 54 3377 OIL GRAVITY-API (CORR) 23 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFL NOV 1 7 1004 Form 10-407 Revised 12/2003 OR!GINAL CONTINUED ON REVERSE SIDE r (;Í~~.;c}·J:;;':··¡ 1 1.~¿'i;._~1! iV[)'X'D ¡ ! -AV----- ¡ ....·.·,.,.L..._...__'.....-",.__~,."'.....".""'~ Gf ,. , ?8. GEOLOGIC MARKER. NAME MD Top B27495 6042' Top B17538 6061' Top A67597 6095' Top A57621 6104' Top A4 7683 6121' 29. .ORMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 5046' None 5066' 5081' 5094' 5101' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~.J tlt~Title Technical Assistant Date! l-O;;l-{)<-{ Kuparuk 1 F-18AL1 204-168 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Dan Kara, 564-5667 Permit No. I 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ . . BP EXPLORATION Operations Summary· Report Page 1 of 24 Legal Well Name: 1 F-18 Common Well Name: 1 F-18 Spud Date: 5/1/1996 Event Name: DRILL+COMPLETE Start: 9/8/2004 End: 9/29/2004 Contractor Name: PARKER DRILLING CO. Rig Release: 5/31/1996 Rig Name: Rig Number: Code NPT Phase Description of Operations 9/8/2004 17:00 - 18:00 1.00 MOB P PRE Preparing to move off of 1 D-30a 18:00 - 18:40 0.67 MOB P PRE Safety meeting prior to moving off of location. Review premove checklists. Discuss hazards, such as soft pads, culverts, personnel entering moving rig. Confirm that all pre move checklist items have been completed, including rig move notification to Kuparuk security. 18:40-19:10 0.50 MOB P PRE Perform 1 last walk around to ensure the rig is ready to move. 19:10 - 20:10 1.00 MOB P PRE Back rig off well. Move to the end of 1 D pad. Call Kuparuk tool service to confirm the spine road to KOC is blocked to traffic. 20:10 - 00:00 3.83 MOB P PRE Enter the spine road, and begin the move to 1 F pad. Weather conditions for move are poor. It is raining at the present time and the roads are saturated with water. All culvert crossings and other possible soft spots along the spine road are covered by a single layer of rig mats. Location of the rig at midnight is just short of the KOC/CPF1 pad. 9/9/2004 00:00 - 01 :20 1.33 MOB P PRE Continue move from 1 D pad. 01 :20 - 08:00 6.67 MOB P PRE Arrive at KOC/CPF1 pad. Park rig off to the side of the spine road. Wait while Kuparuk tool service shuttles 190 rig mats from the spine road behind the rig, and places them from the end of the KOC/CPF1 pad to the 1 F pad access road, and starting down the access road. 08:00 - 00:00 16.00 MOB N MISC PRE On the move again, Matting 1 FPad access road Stair stepping mats along 1 F Pad access road At midnight, >1/2 mile down 1 F access road. 9/10/2004 00:00 - 06:00 6.00 MOB N MISC PRE Moving rig along 1 F-Pad access road. At 0600 hrs the rig approximately 213 the way down the access road. Using 4 fork lifts to stair step mats then at midnight, down to 2 because of personnel work time. Back to 4 forklifts at 0600 hrs 06:00 - 16:00 10.00 MOB N MISC PRE Moving along. Notified AOGCC, Chuck Sheve wavered witness the BOP test 16:00 - 18:00 2.00 MOB N MISC PRE Moving mats for the last move to the pad. WiI still need to mat the Pad 18:00 - 00:00 6.00 MOB N MISC PRE 18:00 update. Rig currently about 3/4 of the way down the 1 F pad access road. Continuing to single stack mats, and pull forward on them, then double stack and back up, then repeat. Continuing to inch slowty towards 1 F pad. Raining intermittantly. 9/11/2004 00:00 - 03:00 3.00 MOB N MISC PRE Rig is 1/4 mile short of 1 F pad as of midnight. Continue shuttling mats back and forth, and slowty moving toward the pad. Continuing to rain. 03:00 - 06:00 3.00 MOB N MISC PRE Arrive on 1 F pad. Pull onto pad and stop. Wait for mats to be laid down pad and around to well. Still Raining. 06:00 - 08:00 2.00 MOB P PRE Move rig around pad on mats Held Move over well PJSH and move over well. Conducted Pad inspection Rig accepted at 0800 hrs 9-11-2004 63 hr Pad to Pad rig move. 48 hrs on 1 F Pad access road. 08:00 - 10:15 2.25 MOB P PRE Set in yard and started NU BOP's. AOGCC Chuch Sheave wavered witnessing BOP test Kuparuk Safety and DS Operator approved setting office at different location. NU BOP's WHP = 750 psi Working to get 1 F17 ESD actuator Printed: 10/1/2004 9:09:13 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/11/2004 9/12/2004 Date From 08:00 - 10:15 10:15 - 14:30 14:30 - 14:50 14:50 - 15:25 15:25 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 20:30 20:30 - 20:45 20:45 - 21 :20 21:20 - 21:55 21:55-22:10 22: 1 0 - 23:30 23:30 - 00:00 00:00 - 00:15 00:15-01:30 01:30 - 01 :45 01 :45 - 02:45 02:45 - 03:15 03: 15 - 03:30 03:30 - 03:45 03:45 - 05:30 05:30 - 06:00 06:00 - 06:15 06:15 - 07:30 07:30 - 09:45 09:45 - 10:35 . . BP EXPLORATION Operations Summary Report Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Code NPT Phase 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. 2.25 MOB P 4.25 BOPSUF P 0.33 BOPSUF P 0.58 BOPSUP P 1.58 BOPSUF P PRE PRE PRE PRE PRE 1.00 BOPSUP P 0.50 BOPSUF P PRE PRE 2.00 KILL P 0.25 KILL P 0.58 KILL P WEXIT WEXIT WEXIT 0.58 KILL P WEXIT 0.25 KILL P WEXIT 1.33 KILL P WEXIT 0.50 KILL P WEXIT 0.25 KILL P 1.25 KILL P 0.25 KILL P 1.00 KILL P 0.50 KILL N WEXIT WEXIT WEXIT WEXIT WAIT WEXIT 0.25 KILL P WEXIT 0.25 WHIP P 1.75 WHIP P WEXIT WEXIT 0.50 WHIP P WEXIT 0.25 WHIP P 1.25 WHIP P WEXIT WEXIT 2.25 WHIP P 0.83 WHIP P WEXIT WEXIT Page 2 of 24 Spud Date: 5/1/1996 End: 9/29/2004 panel on rig PT BOP to 250/3500 psi Hauling fluid and installing reel. PJSM on pulling reel over pipe shead Pulling CT over pipe shed. RU actural for ESD on 1 F-17 tree. Cut CT off, pulled wire out, stab on well and pump fluid Pumped= 44 bbl Unstab injector, cut CT and fish wire, rehead to BHI Pre spud safety meeting with all rig hands, SWS Team Leader, Nordic Toolpusher, BP, and 1 APC vac truck driver. Discuss present condition of well, hazards and mitigations to the hazards, and the plan forward for tonights tour. Resume attaching Ecoil head to 2' Coil tubing. Safety meeting prior to making up BHA to RIH and kill well. MU BHA #1: 2.5' JSN - Blind Sub - BHI DPS - EDC - Powercoms - Ball Valve Sub - LQC - UQC - CTC. Stab injector on well. Circulate mud down coil to finish slack management. Pumping at 2.0 bpm, 3200 psi. Pressure test hardline to tiger tank to 1500 psi. Passed ok. Pressure test lubricator to 3500 psi. Passed ok. Bleed off well to 1000 psi, open master valve. Open up well. WHP=975 psi. RIH, bleeding off well bore fluids to tiger tank thru rig choke. Holding 975 psi on WHo Stop at 7400'. SI pumps and rig choke. Monitor BHA. WHP=975 psi, BHP=3010 psi. Bring pumps on with diesel on the backside, circulating BHP=3100 psi. Holding 975 psi on surface choke. Gradually opening choke as mud gets up around coil. Final BHP while circulating=3475 psi. Continue to circulate well to mud. POOH following pressure schedule with choke. Safety meeting prior to laying down BHA #1. Lay down BHA #1. Waiting on Schlumberger hand with pip tags. (He has never been to Kuparuk before and may be lost.) Install RA pip tag into whipstock. 5.67' from top of WS to RA tag. PJSM re: pressure deployment of WS BHA. MU BHI MWD BHA in mousehole. PU into lubricator. Distance from no go to MU point is 3.5'. MU WF whipstock in hole. MU MWD to WS. Scribe to high side of tray. PU into lubricator. PT to 1000 psi. Bleed off to WHP. RIH, WHP=7oo psi. Tag no go, PU 3.5' and set combis. Bleed off lubricator. MU injector. PT lub to 500 psi, open combis, O-ring leak on lubicator, PUH and slack off 0.5 ft, shut combies and engerize. Held PJSM on undeploying BHA to change o-ring. Set combi, pull tested BHA, Bleed lub pressure, slip chains, and PU lub, close DBV, bleed pressure off CT, Unstab BHA, Change out O-ring. Stab on BHA PT lub 1000 psi. Unlock rams, de- engerize rams, Open Combis. WHP = 377 psi. Need to change packoft following WS setting run. RIH wI WS as per schedule Tie-in from 7200 ft down (Corrected -1 ft) Printed: 1011/2004 9:09:13 AM '; 9/12/2004 . . BP EXPLOHA TION Operations Summary Report WEXIT RIH to set WS Tagged CIBP at 7452 ft PUH to 7389' RIH to 7404 ft TOW at 7395 ft, Working at closing EDC. Closed Tray oriented TF to 33R from HS Set at 3350 psi Set 2500 Ib down solid. PUH clean WEXIT POOH following pressure schedule Held Pressure un-dep PJSM Fill across top to keep required WHP when OOH WEXIT Tagged up, RIH 0.5 ft Set 2-3/8" Combi's, Depressured above combi's, OK, RU Lub and PT to 600 psi, Equalized pressure, PUH with WS running tools. Closed MV/SV. Change out BHA in mouse hole. Stab in lub and stab on well. PT lub to 600 psi. RIH slow, Falling real slow. Worked down to No/Go Closed combi's. Depressured lub, Un stung, DBV to high for Injector head. Stab back on well. PT to 550 psi, released combi's PUH and greased line. RIH and hit No/Go PU 3.8 ft Set combi's and released pressure. Unstabbed lub and stand back in derrick. Ru lub and injector head WEXIT RIH using presssure schedule WEXIT No GR tool in this BHA. No tie in pass made. Tag top of WS at 7398'. Make -3' correction. Up weight = 20 klbs. Kick on pumps. Free spin 3140 psi at 1.55 bpm. BHP=3375 psi. Tag top of whipstock. Confirm depth is still 7395'. Begin window milling. IAP=911 psi, OAP=500 psi. Bleed both down. 7395.4', 1.57/1.59/3280 psi. Pit vol=438 bbls. IAP=73 psi, OAP=495 psi. Still bleeding OAP. Getting good motor works and drill offs every 0.1'. 7396.3', 1.57/1.613400 psi. Pit vol=436 bbls. IAP=430 psi, OAP=304 psi. 7397.1', 1.57/1.60/3320 psi. Pit vol=436 bbls. IAP=468 psi, OAP=376 psi. Starting to get metal back accross the magnets. 7398.2', 1.57/1.59/3230 psi. Pit vol=435 bbls. IAP=497 psi, OAP=426 psi. 7399.0', 1.57/1.6/3290 psi. Pit vol=435 bbls. IAP=527 psi, OAP=466 psi. 4.0' milled since start of window. Motor work and WOB suggest that we are in open hole. Attempt to drill ahead. Making hole. 1 F-18 1 F-18 DRILL+cOMPLETE PARKER DRILLING CO. Code NPT Phase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10:35 - 11 :20 0.75 WHIP P 11:20-12:55 1.58 WHIP P 12:55 - 17:00 4.08 WHIP P 17:00 - 18:20 18:20 - 19:00 1.33 WHIP P 0.67 STWHIP P 19:00 - 20:00 1.00 STWHIP P WEXIT 20:00 - 21:00 1.00 STWHIP P WEXIT 21:00 - 22:00 1.00 STWHIP P WEXIT 22:00 - 23:00 1.00 STWHIP P WEXIT 23:00 - 23:05 0.08 STWHIP P WEXIT Page 3 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Description of Operations Window depth prior to logging correction on next pass is 7395'-7399'. Drill 10' of rathole. Getting drill offs. ROP=1Q-20 fph. Definately in sand. 10' of rathole finished. Begin reaming window. Continue to ream window. SI pumps. Dry drift window up and down smooth. POOH for build section BHA. Following pressure schedule while POOH. Tag up at surface. Shut in choke trapping 750 psi on well. Hold PJSM re: pressure undeploy of milling BHA. Discuss proceedure. Review each step on checklist. Discuss hazards and mitigations to hazards. WEXIT Undeploy BHA #3 using the pressure undeploy checklist. Both mills recovered at 2.74" go, 2.73" No-go. Window should be in good shape. 23:05 - 23:45 0.67 STWHIP P WEXIT 23:45 - 00:00 0.25 STWHIP P WEXIT 9/13/2004 00:00 - 00:15 0.25 STWHIP P WEXIT 00:15 - 01:30 1.25 STWHIP P WEXIT 01 :30 - 02:00 0.50 STWHIP P WEXIT 02:00 - 03:40 1.67 STWHIP P Printed: 101112004 9:09:13 AM . . BP EXPLORATION Operations Summary Report Page 4 of 24 Legal Well Name: 1 F-18 Common Well Name: 1 F-18 Spud Date: 5/1/1996 Event Name: DRILL+COMPLETE Start: 9/8/2004 End: 9/29/2004 Contractor Name: PARKER DRILLING CO. Rig Release: 5/31/1996 Rig Name: Rig Number: Date From -To Hours NPT Phase 9/13/2004 03:40 - 04:05 0.42 DRILL P PROD1 Safety meeting re: Picking up and pressure deploying build section BHA. 04:05 - 05:20 1.25 DRILL P PROD1 Deploy BHA #4, Build section BHA. MWD tool failed after deploying. 05:20 - 08:25 3.08 DRILL N DFAL PROD1 Undeploy failed MWD tool. change out BHI MWD, pressure deploy 08:25 - 10:00 1.58 DRILL P PROD1 RIH as per pressure schedule 10:00 - 10:15 0.25 DRILL P PROD1 Tie-in at GR development at 7263 ft (Corrected -2.5 ft) Closed choke and EDC. 10:15 - 10:40 0.42 DRILL P PROD1 RIH tagged at 7402 ft PUH and orient TF to 30 R Wash dow to 7409 ft 10:40 - 13:25 2.75 DRILL P PROD1 Drilling TF 33R Qp = 1.55/1.51 bpm BHP = 3447 psi = 11.00 ppg EDC Density = 8.85 / 8.89 ppg Vp = 426 bbl at 10:48 hrs Taking 50 ft goo samples 13:25 - 14:05 0.67 DRILL P PROD1 Drilling TF 28R Qp = 1.55 /1.55 bpm BHP = 3436 psi = 11.03 ppg EDC Density = 8.85 / 8.89 ppg Vp = 434 bbl at 14:00 hrs Centrifuge airing up the mud 14:05 - 14:25 0.33 DRILL P PROD1 Wiper trip to window Clean 14:25 - 17:45 3.33 DRILL P PROD1 Drilling TF 25R Qp = 1.52 /1.53 bpm BHP = 3471 psi = 11.07 ppg EDC Density = 8.85/8.89 ppg Vp = 445 bbl at 15:25 hrs 17:45 - 18:00 0.25 DRILL P PROD1 Drill Ahead. 18:00 - 19:45 1.75 DRILL P PROD1 7593', Drilling ahead build section. 1.53/1.59/3540 psi. WHP=50 psi. BHP=3456 psi. IAP=405 psi, OAP=650 psi. Pit vol=444 bbls. ROP=erratic, 2-30 fph. INC=96 deg at bit. TF=60R. 19:45 - 20:00 0.25 DRILL P PROD1 Build and turn section landed as per DD. PUH to make tie in pass prior to POOH for lateral section BHA. Motor work and overpull at 7528' when making wiper trip to window. Keep and eye on this on future runs. 20:00 - 21 :30 1.50 DRILL P PROD1 Log tie in pass over original well gamma marker and RA tag in whipstock. Made -1.8' correction to RA tag. New correlated depths are: Top of window = 7393.2' Bot of window = 7397.2' RA tag = 7399.0' 21 :30 - 22:50 1.33 DRILL P PROD1 POOH with drilling BHA. Choke hand on location to troubleshoot erratic choke. 22:50 - 23: 15 0.42 DRILL P PROD1 Tag up at surface. Hold PJSM for BHA undeploy. 23:15 - 00:00 0.75 DRILL P PROD1 Pressure undeploy BHA #5. 9/1412004 00:00 - 01 :00 1.00 DRILL P PROD1 Continue to lay down build section BHA. 01:00 - 01 :30 0.50 DRILL P PROD1 Safety meeting prior to picking up lateral section BHA. 01 :30 - 03:30 2.00 DRILL P PROD1 Deploy BHA #6 to drill lateral section using pressure deployment techniques. Pick up new Hycalog bicenter bit as per proceedure. Change out upper and lower check valves as per BHI recommendation. 03:30 - 04:55 1.42 DRILL P PROD1 RIH with BHA #6. 1.0 deg motor, Hycalog DS100 bit. Printed: 101112004 9:09:13 AM . . BP EXPLORATION Operations Summary Report Page 5 of 24 Legal Well Name: 1 F-18 Common Well Name: 1 F-18 Spud Date: 5/1/1996 Event Name: DRILL+COMPLETE Start: 918/2004 End: 9/29/2004 Contractor Name: PARKER DRILLING CO. Rig Release: 5/31/1996 Rig Name: Rig Number: Date From - To Hours Task CÔdê NPT Phase 9/14/2004 04:55 - 05:10 0.25 DRILL P PROD1 Log tie in pass over RA tag. Make -5' correction. 05:10 - 05:45 0.58 DRILL N DPRB PROD1 RIH. Tagged at 7530'. worked through, tagged at 7556 ft. worked through. RIH to 7612 ft. PUH pulled tight 34k, PUH above WS. clean above 7535 ft. Above WS open EDC and start mixing KlaGard to inc cone to 12 ppg. Lower B2 shale. fromation top at 7474 ft MD /6025 ft TVD its soft, sticky and troublesome. Qp =2.0 bpm; WHP = 100 psi; BHP = 3452 psi; EDC = 11.27ppg 05:45 - 07:15 1.50 DRILL N DPRB PROD1 At 7300 ft open EDC circulating and mixing KlaGard Bring cone from 6ppb to 12ppb. 07:15 - 07:35 0.33 DRilL N DPRB PROD1 Closed EDC and started cir with 200 psi WHP Qp = 1.53 bpm RIH to 7525 ft slowly BHP = 3666 psi EDC = 11.5ppg 07:35 - 09:05 1.50 DRILL N DPRB PROD1 W /R from 7518ft correct TF Some motor work at 7518 ft / 6042ft TVD Some Motor work at 7530 ft / 6044 ft TVD Set down 7535 ft. PUH to 7500 ft, little pull at 7525 ft. RIH from 7500 ft, motor work at 7513 ft /6040ft TVD Start of trouble section RIH to 75500 PUH 24.5k Clean; RIH clean to 7555ft, some motor work at 7556 ft W /R through to 7580ft. took wt and motor work, PUH clean RIH. clean to 7580ft. W/R from 7580ft 6046ft TVD Motor work at 7583 ft down to 7585ft. PUH. Had some motor work from 7585 ft to 7570 ft. pulled tight to 7535ftMD I 6045 ft TVD. Clean above 7535 ft RIH correct TF to 7605ft PUH to check integrity of upper section All work conducted using EDC = 11.6 ppg 09:05 - 10:00 0.92 DRILL N DPRB PROD1 PUH 28 to 30k to 7588ft Pulled tight and motor work at 7536ft MD I 6045ft TVD Some motor work 7500ft MD I 60300 MD RIH , tagged at 7543ftMD TF at 48R PU orient TF to 30R. RIH to 761 Oft 16042ft TVD. PUH to 7445ft pulled 33k at 761 Oft to 75800 .Motor work at 7538ft I 6045ft TVD. Motor wok at 74800 MD 16028ft TVD RIH and clean to 7610 ft. PUH little pull. PUH to 7520 ft. RIH to corrected TD of 7615 ft MD 10:00 . 10:05 0.08 DRILL P PROD1 W/R to 76151 6041ft TVD could be bottom. TF at 60R Drilling TF @ 90R Qp = 1.55/1.55bpm BHP = 3622 psi EDC = 11.56ppg Vp = 435 bbl at 1000 hrs 10:05 - 10:10 0.08 DRILL P PROD1 EDC inc to 12.4ppg. PUH clean to 7593ft. RIH clean 10:10 - 10:35 0.42 DRILL P PROD1 Drilling TF @ 93R Qp = 1.55/1.55bpm BHP = 3642 psi EDC = 11.6 ppg IAlOA = 463/714 psi. WHP = 200 psi ROP 15-33 fph 10:35 - 10:55 0.33 DRILL P PROD1 PUH 15fpm to check hole integrity. Little bobble at 7543ft TF at 90R Little motor at 7499 ftTF still at 90R. Tumed around at 7474ft. RIH. down Wt = 5.2k Clean to 76300 10:55 - 12:00 1.08 DRILL P PROD1 Drilling TF @ B8R Qp = 1.57/1.55bpm BHP = 36 psi EDC = 11.7 ppg IAlOA = 433/205 psi. WHP = 242 psi ROP 15-33 fph 12:00 - 12:30 0.50 DRILL P PROD1 Drilling ahead. 1.57/1.613530 psi. Free spin=3250 psi at 1.57 Printed: 1011/2004 9:09:13 AM . . BP EXPLORATION Operations Summary Report Page 6 of 24 Legal Well Name: 1 F-18 Common Well Name: 1 F-18 Spud Date: 5/1/1996 Event Name: DRILL+COMPLETE Start: 9/8/2004 End: 9/29/2004 Contractor Name: PARKER DRILLING CO. Rig Release: 5/31/1996 Rig Name: Rig Number: From -To Hours Task Code Description of Operations 9/14/2004 12:00 - 12:30 0.50 DRILL P PROD1 bpm. 200 psi on wellhead. BHP=3690 psi. EMW=11.7 psi. IAP=490 psi, OAP=250 psi. Pit vol=433 bbls. ROP=90 fph. 12:30 - 13:05 0.58 DRILL P PROD1 Make wiper trip to shoe. Clean PU at 23 klbs. Clean thru previous problem area at 7528' both up and down. 13:05 - 15:20 2.25 DRILL P PROD1 Tag bottom, and resume drilling. 1.57/1.6/3700 psi. 200 psi on choke. Pit vol=431 bbls. 15:20 - 16;00 0.67 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 22 klbs. 200 Ibs motor work thru 7528'. Clean when running back thru. 16:00 - 18:10 2.17 DRILL P PROD1 Resume drilling. 1.54/1.62/3700 psi, 200 psi on the wellhead. IAP=600 psi, OAP=340 psi. Pit vol=427 bbls. 18:10 - 18:45 0.58 DRILL P PROD1 Maker wiper trip to shoe. Clean PU off btm (22k#). 18:45 - 21:10 2.42 DRILL P PROD1 Resume drilling. 1.54/1.42/3250 psi Is, WHP: 200 psi. WOB: 2-3K# BHP: 3680 psi, ECD: 11.9. PVT: 414 bbls. Mostly fast drilling with some hard spots. 21: 1 0 - 21 :45 0.58 DRILL P PROD1 Wiper trip to shoe @ 201pm. Clean PU off btm, (22K#). No sign of shales at 7528' or 7588'. Some motor work at 7490' 21 :45 - 22:00 0.25 DRILL P PROD1 Log gr tie in outside window. +8' correction. 22:00 - 22:30 0.50 DRILL P PROD1 Complete wiper trip. Hole smooth. 22:30 - 00:00 1.50 DRILL P PROD1 Resume drilling. 1.54/1.42/3250 psi Is, WHP: 200 psi. WOB: 2-3K# BHP: 3740 psi, ECD: 12.1. PVT: 404 bbls. Mostly fast drilling with some hard spots. 9/15/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Wiper trip to window. Hole smooth. 22k# off btm. 01 :00 - 02:45 1.75 DRILL P PROD1 Resume drilling. 1.54/1.42/3250 psi Is, WHP: 200 psi. WOB: 2-3K# BHP: 3740 psi, ECD: 12.1. PVT: 404 bbls. Mostly fast drilling with some hard spots. 02:45 - 04:30 1.75 DRILL P PROD1 Wiper trip to window. 21 K# PU off btm. Hole smooth. 04:30 - 06:00 1.50 DRILL P PROD1 Drill ahead. 1.56/1.54/3300 psi Is. WHP: 200 psi. ECD: 11.92. PVT: 393 bbls. 06:00 - 09:00 3.00 DRILL P PROD1 Drilling ahead. 1.55/1.53/3430 psi. WHP=200 psi. IAP=420 psi, OAP=450 psi. Pit vol=389 bbls. Drilling ahead with mostly good ROP. with an occasionaly siderite stringer. Appear to be having slight seapage losses to formation. 2-4 bbllhr. 09:00-11:15 2.25 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 23 klbs. 300 Ibs motor work and a 5 klbs overpull at 7530' when coming up hole. This is the same problem depth observed yesterday. Tagged up and had motor work at 7545' on way down. TF is same as drilled, 15R. PU, made it thru on 2nd attempt. 11:15 -12:00 0.75 DRILL P PROD1 Resume drilling. 1.59/1.55/3700 psi. 200 psi on WHo Taking mud out of pits to clean pits prior to swapping to new mud. 12:00 - 13:00 1.00 DRILL P PROD1 New mud going downhole. 9.4 ppg. 14 ppb Kla-gard. 13:00 - 13:50 0.83 DRILL P PROD1 New mud around. 1.59/1.55/3900 psi. 0 psi on choke. BHP=3790 psi. IAP=340 psi, OAP=420 psi. Free spin=3800 psi at 1.56 bpm. 13:50 - 17:05 3.25 DRILL P PROD1 Wiper trip to shoe. 5 klbs overpull off bottom. Ratty for first 50'. The new mud appears to be really cleaning the hole. We have about 3 times the amount 01 cuttings on this wiper trip as opposed to previous trips. Had motor work at 7540', but very little overpull on the way up. Open EDC, and chase cuttings up into 3-1/2" to 6500'. RIH. Set down at 7550'. PU, and got thru ok. Clean to bottom. 17:05 - 18:30 1.42 DRILL P PROD1 Resume drilling. 1.56/1.54/3800 psi. 0 surface choke Printed: 10/1f2004 9:09:13 AM . . BP EXPLORATION Operations Summary Rfi!port Page 7 of 24 Legal Well Name: 1 F-18 Common Well Name: 1 F-18 Spud Date: 5/1/1996 Event Name: DRILL+COMPLETE Start: 9/8/2004 End: 9/29/2004 Contractor Name: PARKER DRILLING CO. Rig Release: 5/31/1996 Rig Name: Rig Number: From- To Hours Task Code NPT Phase Description· of Operations 9/15/2004 17:05 - 18:30 1.42 DRILL P PROD1 pressure. IAP=235 psi, OAP=311 psi. Pit vol=319 bbls. BHP=3710 psi. Drilling break. Lose all returns. 18:30 - 19:30 1.00 DRILL P PROD1 Wiper trip up into casing. Discuss options with town team. Order additonal 8.8 ppg mud from MI. Transfer extra 9.4 mud from tanks on location to pits. 19:30 - 20:00 0.50 DRILL P PROD1 Into csg with no hole problems or overpulls. Cycle EDC. Problems with commands to downhole tools. Re-boot Inteq systems. EDC opened. Attempt to verify proper function. ECD not working. 20:00 - 20:45 0.75 DRILL N DFAL PROD1 POOH to change out MWD tools. Slowly regaining circulation while POOH. Able to hold 200 psi WHP with 90% rtns. 20:45 - 21 :00 0.25 DRILL N DFAL PROD1 At surface. Tag up and position BHA. Shut in well with 300 psi WHP. Hold PJSM to review pressure un-deploy procedure in ops cab. Review entire un-deploy proc line by line. Discuss possibility EDC is not closed. Will get flow back if EDC is open, and double checks are not holding. 21 :00 - 22:30 1.50 DRILL N DFAL PROD1 Undeploy BHA. CHange out float valves and bit (LD Hycalog, PU re-built HTC) 22:30 - 00:00 1.50 DRILL N DFAL PROD1 Review procedure with floor crew. Pressure deploy BHA. Get on tools. Test. OK. Get on well. RIH. 9/16/2004 00:00 - 01 :15 1.25 DRILL N DFAL PROD1 RIH with lateral assembly (1.0 deg mtr w/ HTC bicenter, BHA #7) 01:15-01:30 0.25 DRILL N DFAL PROD1 Log gr from 7400'. Tie into RA tag @ 7399. -6 correction'. 01 :30 - 03:00 1.50 DRILL P PROD1 RIH. Tag up at 7610'. PU. Run through ok. Tag up at 8575'. Ream through, not too difficult. Drilled TF maintained. 1.55 bpm in/1.15 bpm out while circulating in hole. 3500 psi fs. 03:00 - 04:35 1.58 DRILL P PROD1 Drill ahead. 3400 psi fs. 200-400 dpsi. 1.53 in/1.1 0 out, with 9.4 ppg mud. ECD:11.6, BHP:3612 psi. WHP: 0 psi. PVT:225 bbls. 04:35 - 06:00 1.42 DRILL P PROD1 Wiper trip to window. Clean off bottom, and µp thru 7528'. Tagged up and fell thru 7540' when RIH. Clean back to bottom. 06:00 - 07:15 1.25 DRILL P PROD1 Continue wiper trip in hole. Had to work it to get from 8650' to TD. Lots of set downs and drag. 07:15 - 08:30 1.25 DRILL P PROD1 Resume drilling. Free spin=3530 psi at 1.55 bpm. Drilling at 1.54/1.213620 psi. 0 psi on choke. IAP=70 psi, OAP=103 psi. Pit vol=335 bbls. Mud weight=9.4 ppg. BHP=3670 psi. Getting a significant amount of cuttings over the shaker, and lots of clay out of the centrifuge. 120-15 fph. Drilling good sand with an occasional hard stringer. 08:30 - 08:45 0.25 DRILL P PROD1 312 bbls in the pits. Drilling slowly at 16 fph. Lost 23 bbls in last 1 :15. Or about 17 bbls/hr. 08:45 - 09: 15 0.50 DRILL P PROD1 Weight transfer getting difficult. Make 500' wiper, then go back to drilling. Clean PU off bottom at 25 klbs. RIH at 2800 Ibs. Clean back to bottom. Still getting huge cow patties from the centrifuge discharge. It is 90% clay with some fine sand. The most likely source of this clay is the invert section of the well at the heel. The hole is probably washing out or sloughing. 09:15 - 10:25 1.17 DRILL P PROD1 Resume drilling. 297 bbls of 9.4 pg mud in pits. Pump 15 bbl 100klsrv sweep. Drilling at 17 fph. 10:25 - 11 :35 1.17 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. BHP=3677 ECD=11.85 ppg. IAP=78 psi, OAP=160 psi. Pit vol=269 bbls. 7524', had an overpull to 36 klbs, and packing off. Now stuck. Printed: 1011/2004 9:09:13 AM . . BP EXPLORATION Operations Summary Report Page 8 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date Hours Task Code NPT Operations 9/16/2004 10:25 - 11 :35 1.17 DRILL P PROD1 Losing returns. Could be cuttings laying in the belly of the well packing off around us. 11 :35 - 11 :50 0.25 DRILL N STUC PROD1 Partially retums. 1.74/0.3/4200 psi. Trying to work back down hole. Retums trending down. Try working pipe down. Got max stacked on it of -8500 Ibs at surface. WOB=7500 Ibs. downhole. Annular pressure=3320 psi. We are packed off around the BHA below the WOB and Annular pressure sensor. Continue stacking weight and rotating orienter. Not making any footage in hole. Returns now 1.74/0.17/4260 psi. We are just about toast. SI pumps. Open EDC. Pump at max rate. Popped free!!! 11 :50 - 12:45 0.92 DRILL P PROD1 EDC open. Continue wiper trip up into tubing Pumping 2.3/1.7714450 psi. Annular pressure=3670 psi. Pull this pass up to 6500' to space out cuttings and clean up well. We will need to work the area in the belly of the well. Probably have cuttings and sloughing siltstone laying in washed out/low A V interval here. Still getting huge cow patties down the centrifuge discharge chute. 12:45 - 17:20 4.58 DRILL P PROD1 Run thru window. Shut EDC. RIH at 20 fpm. Tagged up at 7413', and lost retums. Heavy pickup. Chase it to the window. RBIH until we see weight loss and retums dropping off at 7520', and chase it back to the window. Repeat at 7530', 7560',7600',7650',7700'; 7750', 7850', 8000'. Pump High vis sweep on last bite, and chase it up hole. Chase everything up to 6500'. 17:20 - 18:00 0.67 DRILL P PROD1 RIH to log tie in pass across RA tag at 7399'. Add 3' correction. 18:00 - 19:30 1.50 DRILL P PROD1 Wiper trip to verify TD. No set downs or tight spots. Tag TD: corrected depth is 9065'. Pump 15 bbl hi vis sweep. 19:30 - 21 :30 2.00 DRILL P PROD1 Circulate and condition while pulling out of hole. Clean out tbg to 6500'. Continue to wait on KWF to arrive from MI. 21:30 - 00:00 2.50 DRILL P PROD1 RIH. Set down at 7398' 3-4 times (btm of window). Finaly bounce through at 10R TF (window drilled at 30R). Continue to RIH to TD. Hole smooth all the way to TD. No set downs, bobbles, motor work at all. 9/17/2004 00:00 - 01 :30 1.50 DRILL P PROD1 POOH from TD, laying in new 9.4 ppg mud. Hole 100% smooth on trip out to window. Swap to 11.7 ppg KWF to coincide with arriving at window depth of 7400'. 01 :30 - 01 :45 0.25 DRILL P PROD1 Displace coil annulus to 11.7 ppg KWF from 7400'. Monitor BHP annular pressure. Initial: 3677 psi @ 1.53 in/1.20 out. Begin losing too much KWF to formation. 01:45 - 03:15 1.50 DRILL P PROD1 pooHat1:1 (115fpm @ 1 bpm). Paint EOP flag @ 6000'. Continue to POOH. 03:15 - 03:45 0.50 DRILL P PROD1 Stop coil at 500'. KWF back to surface. Monitor well for flow. Well on a vac. Fill hole. Took 3.5 bbls to fill after 30 min flow check. Continue to load pits with KWF. 03:45 - 04:30 0.75 DRILL P PROD1 POOH. Tag up. Hold short PJSM. Get off well. Unstab coil. LD tools. 04:30 - 04:45 0.25 RUNCOM=> RUNCMP Hold PJSM to discuss running liner. Verify safety joint readiness. Discuss roles & assignments. 04:45 - 06:00 1.25 RUNCOM=> RUNCMP MU 2·3/8" liner assembly with bent guide shoe. Printed: 1011/2004 9:09: 13 AM . . BP EXPLORATION Operations Summary Report Page 9 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date Code NPT Phase 9/17/2004 06:00 - 06:15 0.25 RUNCOMP RUNCMP 06:15 - 06:35 0.33 RUNCOMP RUNCMP 06:35 - 07:50 1.25 RUNCOMP RUNCMP 07:50 - 09:30 1.67 RUNCOMP RUNCMP Description of Operations 09:30 - 10:50 1.33 RUNCOMP SD running liner for crew change. PJSM for running liner. Discuss hazards and mitigations to hazards while running liner. Resume making up liner. Now on joint 17 of 31. Filled hole. Took 2 bbls. Last filled 35 minutes ago. IAP-67, OAP=O, Pit vol=314. 96 bbls of 11.7 brine in pit 3, 48 bbls left on vac truck. Land 2-3/8' deployment sleeve in slips. Position false table and slip bowl. Begin running l' CS hydril. Drifting CSH with ball as we pick up the joints. Well continues to take 4 bbls/hr of fluid static. RUNCMP MU pup joints to space out CSH. MU GS spear. MU BHI MWD tools. MWD tools check out ok. MU injector. Stab on well. Establish circulation at minimum rate. RUNCMP RIH with 2-318' predrilled liner. BHA length is 1057.04. Slotted interval length is 983.6'. Getting a trickle of retums as we RIH. Should be displacing 3.5 bbls/1000' of pipe RIH. Probably bullheading it all away. 10:50 - 12:10 1.33 RUNCOMP 12:10 - 12:40 0.50 RUNCOMP Stop at 6000' EOP flag. Make -6' correction. Make weight check at the window. Up weight=26 klbs. RUNCMP RIH from 7300'. Pumping 0.8 bpm, 2750 psi. 0 returns. Smooth thru window, and thru bad spot at 7528'. Lost a bunch of weight as we started shoving the CTC up hole past the heel of the well. Set down at 8890', PU at 27 klbs. Work it and loosing hole each time we pick up. PU 4 times, and now at 8862'. Bring on pumps. Pumping 1.4 bpm, 4300 psi. PU at 21 klbs. Liner is in the hole. 12:40 - 12:50 0.17 RUNCOMP 12:50 - 13:05 0.25 RUNCOMP 13:05 - 14:30 1.42 RUNCOMP 14:30 - 15:15 0.75 RUNCOMP 15:15 - 15:50 0.58 RUNCOMP 15:50 - 16:15 0.42 RUNCOMP 16:15 - 17:45 1.50 RUNCOMP Bottom of liner #1 at 8862', top of liner at 7855.5'. (Uncorrected) RUNCMP Drop pumps to 0.5 bpm, 1780 psi. PUH. RUNCMP Log tie in pass accross RA flag. Make + 1.5' correction. 17:45 - 19:45 2.00 RUNCOtÆ> RUNCMP 19:45 - 19:00 23.25 RUNCOMP RUNCMP 19:00 - 19:45 0.75 RUNCOMP RUNCMP Corrected liner #1 depth is 8863.5-7857.0' RUNCMP POOH, circulating accross the top. Hold PJSM while POOH for standing back CSH. RUNCMP Tag up at surface. Stand back injector. Lay down MWD tool and Baker deployment eq; RUNCMP POH with 15 stands and 1 single of l' CSH. Standing CSH back in the derrick. RUNCMP Safety meeting Re: Running 2nd string of liner. RUNCMP Make up second liner string for the 'A" lateral: Bullet guide shoe with a 1" thru hole, 10' bent pup, o-ring sub, 13 joints of solid liner, WF Aluminum deployment sleevelOH whipstock, WF G spear, BHI MWD tool. Check MWD tool. Checks ok. Stab on Injector. RIH with liner. Circulate across the top with charge pump. Tie into flag at 7071', Correct -7 correction. Dn wt: 4.1k#. Up wt: 20.1k#. Tag liner at 7853'. RIH wt: 4000#. Set -4000# down. Line up to circ down coil. Circ 1.3 bpm @ 3800 psi. PU. Log gr tie in across RA tag. Add 3' correction. Est TOL 7856". Printed: 1011/2004 9:09:13AM . . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRllL+COMPLETE PARKER DRILLING CO. Date From - To Hours TaSK>CÛdé NPT Phase 9/17/2004 19:45 - 21 :00 1.25 RUNCOMP 21 :00 - 21 :15 0.25 RUNCOMP 21 :15 - 22:00 0.75 RUNCOMP 22:00 - 23:30 1.50 DRILL P 23:30 - 00:00 0.50 DRILL P 00:00 - 01 :15 1.25 STWHIP P 01:15 - 01:45 0.50 STWHIP P 01:45 - 02:30 0.75 STWHIP P 02:30 - 04:15 1.75 STWHIP P 04:15 - 04:30 0.25 STWHIP P 04:30 - 05:00 0.50 STWHIP P 05:00 - 06:00 1.00 STWHIP P 06:00 - 07:30 1.50 STWHIP P RUNCMP RUNCMP RUNCMP PROD2 9/18/2004 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 07:30 - 08:30 1.00 STWHIP P PROD2 08:30 - 09:00 0.50 STWHIP P PROD2 09:00 - 10:30 1.50 STWHIP P PROD2 10:30 - 10:50 0.33 STWHIP P PROD2 10:50 - 12:15 1.42 STWHIP P PROD2 12:15 - 12:35 0.33 DRILL P PROD2 12:35 - 14:15 1.67 DRILL P PROD2 14:15 - 15:45 1.50 DRILL P PROD2 15:45 - 16:00 0.25 DRILL P PROD2 16:00 - 16:20 0.33 DRILL P PROD2 16:20 - 21 :30 5.17 DRILL P PROD2 Page 10 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 POOH. Check up wt at 6649'. +/-2k# lighter. Appear to have released from liner. Stop coil at 500'. Flow check well. Lost 1 bbl. Continue to surface. At surface. Get off well. Unstab coil. LD BHA assembly. Prep to pump slack management. Cut 115' of coil and 85' of e-line. Install Kendall connector. MU e-line connection. Continue to MU e-coil head. Pressure, electrical, & pull test same. Displace KWF from coil at surface. Transfer KWF from pits into upright tank for storage. MU kick off drilling assembly (BHA #9, 2.2 deg mtr wI 2.75" STR-324 bit). Surface test MWD. Stab coil. Get on well. RIH. Open EDC. Circulate at 0.6 bpm in! 0.81 out. Stop at 3500 psi. Get 95% rtns. Continue to RIH. Log GR tie in across RA tag at 7399'. Subtract 12' correction. Tag liner top billet at 7432'. PU. Close ECD. RIH. Begin time milling. 7429.5', Time milling ramp on WF deployments sleeve/WS at 1 fph. 1.52/1.25/3680 psi. IAP=76 psi, OAP=76 psi. Pit vol=232 bbls. New mud in route from MI. TF=90R. 7431.0', Begin time milling at 6 fph. 1.55/1.36/3740 psi. 3675 psi BHP, 0 psi on choke. Pit vol=421 bbls. IAP=79 psi, OAP=115 psi. 7437.0', Begin drilling ahead. ROP=50 fph. Good ROP. Confirmed off the deployment sleeve. It went smooth. Downhole WOB=45oo Ibs. POOH attempting to follow the choke pressure schedule, and pumping at full rate with the EDC open. Due to fluid losses to the original lateral, it became more and more difficult to follow the pressure schedule, and still get good returns to surface. Had to compromise by using less choke back pressure. Safety meeting prior to undeploying BHA. Undeploy BHA #10 Safety meeting prior to deploying BHA #11. Pressure deploy BHA #11 to drill build section of Lateral L 1. RIH with BHA #11, following pressure schedule as close as possible. Log tie in pass at RA tag. Made correction of -10.5'. Shut EDC. Run to TD. No problems at the window. RIH with pumps down, and set down at the whipstock 2 times. Had correct tool face of 90R. PU, pumps to 0.5 bpm, set down. PU, 0.5 bpm and 5 fpm, and made it thru. Kick pumps on, free spin=37oo psi at 1 .55 bpm. Pit vol=367 bbls. IAP=71 psi, OAP=61 psi. BHA=3660 psi. Drilling at 1.56/1.24/3880 psi. Losing 18 bbls/hr. TF=85R, ROP=50 fph. Slow drilling from 7520'. Increase rate to 1.75 in!1.50 out. ROP increased slightly, but still erratic and slow. 21:30 - 00:00 2.50 DRILL P Still no good surveys due to A leg magnetic interference. PROD2 Drilling build. 3750 psi fs. 300-400 dpsi. 1.55 in!1.29 out Printed: 10/112004 9:09:13 AM . . BP EXPLORATION OperatiO"f) Summary Report PROD2 WOB:3-5k#. ROP:10-30 fph. Tf:60R. PVT:251 bbls. ECD:11.9 ppg, BHP:3707 psi. PROD2 Wiper trip to 7435'. Hole smooth. PROD2 Drilling build. 3750 psi fs. 300-400 dpsi. 1.55 in/1.33 out WOB:3-5k#. ROP:10-30 fph. Tf:60R. PVT:247 bbls. ECD:11.9 ppg, BHP:3707 psi. Plan to hold 80 deg inc through A5 interval. Correlation with 1Y-24 B & A intervals & TVD tops very close. TF: 30L from 7670' PROD2 Continue to drill build. Transfer 250 bbls 9.4 mud from uprights to pits. PROD2 Well is landed. PU off bottom was clean at 22 klbs. Clean in build section and thru OH whipstock/deployment sleeve. Clean thru window. POH following choke schedule as much as possible, but had to reduce choke pressure lower than schedule to maintain retums to clean well. Pump at full rate thru an open EDC while POH. Tag up at surface. Hold PJSM prior to undeploying BHA. Pressure undeploy BHA #11 following proceedure checklist. Bit in good shape, and graded 1,1. Adjust motor bend to 1.0 deg. Change out lower checks, and lower quck connect. ReRun same bit. Pressure deploy BHA following procedure checklist. RIH Started getting gas cut retums at 1500'. Swap from drilling choke to rig choke and run thru the gas buster. Sure be nice to be able to use the Swaco choke and gas buster at the same time. Not possible with current rig choke configuration. Flowing thru gas buster, taking returns to pit 1. Getting crude cut retums to pit 1. Continue RIH. Log tie in pass over RA collar. EDC open. Make -6.5' correction. Shut down pumps, Shut EDC, holding WHP with choke. RIH to resume drilling. Pumps down, TF 15 R, set down at 7430', top of whipstock. Kick pumps on 0.2 bpm, set down. 0.5 bpm and got thru ok. Continue to bottom. Tagged up at 7560'. PU, TF is correct at 30R. RIH again and made it thru. Set down at 7583'. PU, and made it to 7591', 7599'. Getting motor work at each set down. We've played this game before on this well. Continue working it to bottom. Had to ream all the way to 7700'. These Band A6 shales are not very friendly. PROD2 Swap back to Swaco choke. Kick on pumps. Free spin=3750 psi at 1.44 bpm. Pit vol=373 bbls. IAP=80 psi, OAP=32 psi. Surface choke pressure=O psi. BHP=3880 psi. ROP=90 fph. Drilling at 1.45/1.3/3770. PROD2 Got another kick. Gas alarms and crude in the mud. Swaped back to the gas buster. Don't have a return MM again. This well is really trying to flow. Hard to believe that the original lateral is flowing when our BHP is 3830 psi. PROD2 Wiper trip to shoe. Clean PU at 24klbs. PUH at 20 fph to avoid surging shales in build section. Drop rate when pulling thru OH whipstock. No problems up thru whipstock to shoe. RIH to resume drilling. Weight bobbles at 7613'. PROD2 Resume drilling. Pit vol=367 bbls. Free spin=3650 @ 1.5 bpm. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Date From - To Hours 9/18/2004 21 :30 - 00:00 2.50 DRILL P 9/19/2004 00:00 - 00:20 0.33 DRILL P 00:20 - 04:00 3.67 DRILL P 04:00 - 06:00 2.00 DRILL P 06:00 - 07:20 1.33 DRILL P 07:20 - 07:40 0.33 DRILL P PROD2 07:40 - 09:00 1.33 DRILL P PROD2 09:00 - 10:05 1.08 DRILL P PROD2 10:05 - 10:50 0.75 DRILL P PROD2 10:50 - 11 :45 0.92 DRILL P PROD2 11 :45 - 12:05 0.33 DRILL P PROD2 12:05 - 13:10 1.08 DRILL P PROD2 13:10 - 13:30 0.33 DRILL P 13:30 - 15:10 1.67 DRILL P 15:10 - 15:50 0.67 DRILL P 15:50 - 16:05 0.25 DRILL P Page 11 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Description of Operations Printed: 101112004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/19/2004 9/20/2004 . . BP EXPLORATION Operations· Summary Report 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Page 12 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 15:50 - 16:05 From - To Hours Task Code NPT Phase Description of Operations 16:05 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 19:50 19:50 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 00: 15 00:15 - 00:30 00:30 - 01 :00 01 :00 - 04:00 04:00 - 06:00 06:00 - 07:00 0.25 DRILL P 0.92 DRILL P 1.00 DRILL P 0.50 DRILL P 1.00 DRILL P 0.33 DRILL P 0.67 DRILL P 0.50 DRILL P 3.00 DRILL P 0.25 DRILL 0.25 DRILL 0.50 DRILL 3.00 DRILL 2.00 DRILL 1.00 DRILL P PROD2 Drilling at 1.5/?/3760 psi. IAP=287 psi, OAP=145 psi. Tried swapping back to the pits, still have gas in retums. Continue drilling on Triflo choke. WHP using triflow choke is 90 psi. PROD2 Pit vol now 372 bbls. No MM meter to monitor out flow rate. Probably bringing in formation fluid from 'A' lateral. BHP=3720 psi. Formation pressure=3010 psi. It is possible we are venturi'ing in formation fluid from the 'A' lateral. Adjust choke back pressure to hold an additional 200 psi BHP to help contain bottom hole flow if that is the case. Circulate bottoms up 2 x, and don't see any evidence of a 5 bbl gain in fluid. Continue to have constant traces of crude in mud. PROD2 Wiper trip to shoe. Clean PU off bottom at 25 klbs. Clean in open hole up to window. Open EDC. Circulate and chase cuttings up to 6500'. PROD2 Shut in well. Monitor BHP & WHP. WHP increased to 840 psi (there is crude on the back side). BHP at 5900 TVD: 3710 psi. This is 12.1 ppg. Looks like the A sand has a higher formation pressure than C sand. PROD2 Attempt to circulate back side to clean mud. 1.5 bpm. Losing about 90% rtns. with 700 psi WHP. PROD2 RIH. Through window at min rate at 20 fpm. Never saw billet. Clrc at 1.0 bpm, WHP:500 psi. B interval had several bobbles. Set down at 7710. Adjust TF to 90R. RIH. PROD2 Drill ahead. 3850 psi@ 1.52 bpm. WHP: 330 psi. Unable to bring rtns inside due to crude & gas. Trico choke unable to hold constant pressure. Cannot drill ahead with rig choke & gas buster. Will fill gas buster with sand or worse. PROD2 POOH above window. PROD2 Circulate above window while waiting on iron to RU to go outside through Swaco choke. This will allow rtns to go outside when too gassed up. Circulate well at 1.0 bpm with 500-600 WHP. ECD: 12.51 ppg, BHA:3800 psi. Try to get good mud in coil annulus. Still too much gas to by pass buster. Test hard line tie-in from Swaco to outside line. Good. PROD2 Continue to RU hardline tie in from Swaco to outside line. Test to 500 psi PROD2 Hold PJSM to discuss procedure for circulating outside, handling rtns, choke operation etc. PROD2 Take retums outside to tiger tank. Shut in well close ECD. RIH to resume drilling. Through window ok with HS TF, min rate. Past billet at TF:75R at 0.5 bpm. RIH at 25 fpm, 0.94 bpm. PROD2 Drill ahead. 4000 psi @ 1.52 bpm fs. 300-400 dpsi. A mix of hard & fast drilling. Bring rtns inside. OK for 10 minute, then more gas. Take rtns outside.. Plan to watch tank & line full time. Strap tank, and test rtns back inside every 30 minutes. PROD2 Drill ahead. 3900 psi @ 1.45 bpm fs. Rtns outside. 200-400 dpsi. WHP: 400 psi. ECD: 12.97. BHP: 4131 psi WOB:4k#-6k#. ROP very erratic. Take on more mud from uprights PROD2 Wiper trip to shoe. Clean PU off bottom and thru build section. Printed: 101112004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . BP EXPLORATION Operations Summary Report 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Page 13 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date From- To Hours Task Code NPT 9/20/2004 06:00 - 07:00 1.00 DRILL P PROD2 07:00 - 08:05 1.08 DRILL P PROD2 08:05 - 09:00 09:00 - 11 :00 11 :00 - 12:45 12:45 - 13:15 13:15 - 13:30 13:30 - 13:55 13:55 - 15:30 15:30 - 16:00 16:00 - 17:20 17:20 -18:00 18:00 - 18:15 0.92 DRILL P PROD2 2.00 DRILL N DPRB PROD2 1.75 DRILL N DPRB PROD2 0.50 DRILL N DPRB PROD2 0.25 DRILL N DPRB PROD2 0.42 DRILL N 1.58 DRILL N DPRB PROD2 DPRB PROD2 0.50 DRILL P 1.33 DRILL N PROD2 DPRB PROD2 0.67 DRILL P PROD2 0.25 DRILL P PROD2 Description of Operations No problems at OH whipstock. Wiper back in we set down at 7620', and had to ream it back down Resume drilling. Holding 400 psi on surface choke. Driling at 1.4/?/3600 psi. ROP=variable. 120 fph, then 5 fph at hard stringers. BHP=3974 psi, 12.5 ppg equivelant. IAP=310 psi, OAP=157 psi. Pit vol=170 bbls, Tiger tank vol=300 bbls. We will wiper trip and SD returns to tiger tank at 350 bbls volume to load a vac truck and transfer it to the pits. 320 bbls in the tiger tank. Need to SI retums to the tiger to allow a safe fluid transfer. Make wiper trip up inside the tubing, and circulate bottoms up to clean up the cuttings enough to SI retums and trap pressure. Need to determine BHP, and also empty tiger tank. Can't flow to the tiger tank while taking retums to it. SI retums. Trap 700 psi with choke. Let well pressure stabalize to determine static BHP. WHP built up to 930 psi. BHP stabalized at 3825 psi at 7351' MD,. 5865' TVD. Equivelant mud weight=12.54. Up in liner, pumping new mud. Pump down the coil, taking retums thru the Swaco choke to the tiger tank. Holding choke back pressure to achieve a BHP of 3970 psi, 13.0 ppg EMW. Circulate 1 coil + 1 annular volume to the tiger tank to get rid of contaminated mud. Circulating at 3630 psi, pump pressure, and 850 psi surface choke pressure. Continue to circulate, but now saving return to pits after running thru gas buster. Not getting any crude back. BHP=4oo9 psi, ECD=13.05 ppg, WHP=400 psi. Pumping new 9.4 ppg in, getting 9.0 ppg back. Mud looks gas cut. Continue to circulate, monitoring BHP, and holding 13.0 ECD. Continuing to circulate, new 9.4 mud in. Getting 9.2+ ppg mud back at 13:00. Still seems a little gas cut. Out rate seems to be getting a little better with time. Continue to circulate. Getting 1 for 1 retums based on in MM rate, and pit volume total. Getting 9.3 ppg back. Continues to improve. Swap back to the pits, not going thru the gas buster. Circulating at 1.62/1.14/3890 psi, 410 psi surface choke pressure. 4017 psi Annular BHP, ECD=13.08 ppg. Everything is looking as expected at this depth. The well is cleaned up, no gas or oil returns, and we are loosing returns. Probably to the loss zone in the "A" lateral. Continue circulating bottoms up to ensure the well is stable. RIH. Slight problem at 7615', but fell thru ok. Circulate bottoms up prior to resuming drilling. Got gas alarms and crude to surface. Take outside to tiger tank. Trying to fine tune pressures. At 12.59 ECD we are making gas and crude. At 12.9 ECD the upper lateral is taking 100% fluid. We will try for the happy medium of 12.75 ECD. Attempt to drill. Free spin 3830 psi at 1.4 bpm. 500 psi choke pressure. 12.7 ECD. Mist release from gas buster. Take rtns outside. Hold PJSM to discuss flow back & transfer procedures. Strap tank every 30 min. Use buddy system to monitor hand on tank. Bring rtns inside every 30 min to check for gas etc. Printed: 101112004 9:09: 13 AM . . BP EXPLORATION Operations Summary Report Page 14 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date Hours Task Code NPT Phase Description of Operations 9/20/2004 18:15 - 20:00 1.75 DRILL P PROD2 Drill ahead. 3700 psi@ 1.57 bpm fs. Rtns outside. WHP:560 psi. ECD: 12.96. BHP: 4126 psi. Rtn rate to tiger tank variable. 20:00 - 22:30 2.50 DRILL P PROD2 Drill ahead. 3900 psi @ 1.58 bpm fs. 100-200 dpsi. Returns to tiger tank very close to 1:1 with 12.9 ECD. PU and run into btm to try and stall. Unable to stall. Making no ROP at all. 22:30 - 00:00 1.50 DRILL P PROD2 POOH to check mtr and bit. POOH at 100 fpm (60%) to ensure clean hole. Take rtns inside. Follow BHP schedule for 9.3 mud hold 12.9 ECD on formation 9/21/2004 00:00 - 00:30 0.50 DRILL PROD2 Continue to POOH. Circ at 1.7 bpm at 2000' to clean up any cuttings above BHA. Continue to pull to surface. 00:30 - 00:50 0.33 DRILL PROD2 Hold extensive PJSM to discuss un-deployment procedure. Assign job tasks, discuss hazards. 00:50 - 02:45 1.92 DRILL PROD2 Undeploy lateral drilling assembly. SHut in well with 1250 psi WHP. Bled down to and stabilized at 952 psi just prior to closing master. LD motor. HTC RWD324 bit broken in half. PDC & matrix cutting structure (5· long) left in hole. Polished steel shank w/ pin recovered. 02:45 - 04:00 1.25 DRILL PROD2 Discuss options with town team. 04:00 - 06:00 2.00 STKOH PROD2 Decide to opeh hole sidetrack. MU RST60 bit w/ brass nose on 2.3 deg mtr. Pressure deploy BHA. 06:00 - 08:00 2.00 STKOH N DFAL PROD2 Continue to pressure deploy Sidetrack BHA. (BHA #13) 08:00 - 10:30 2.50 STKOH N DFAL PROD2 RIH with the sidetracking BHA. This BHA has a 2.3 deg motor, and an R60ST bit with a brass nose to assist in RIH. Made it thru window, top of the· A· lateral deployment sleeve/OH whipstock, and the shales in the heel of the well. A few weight bobbles when RIH thru the shales, but nothing significant. 10:30-11:10 0.67 STKOH N DFAL PROD2 Start troughing hole for sidetrack at 8065'. Not getting good .... sliding. Just stacking weight. Make a reaming pass uphole to 7950' to help clean up the hole. 11:10 - 12:40 1.50 STKOH N DFAL PROD2 Trough hole. Pumping 1.47 bpm, 3865 psi CTP, 500 psi choke pressure. Pit vol=240 bbls. Taking returns to a tiger tank outside. Troughing at 15 fph. Trough to 8055'. 12:40 - 14:00 1.33 STKOH N DFAL PROD2 PU. Drill 2nd trough pass from 8040' to 8055'. 3650 psi @ 1.46 bpm fs. 1.0 to 1.3 bpm out rate. WHP: 505 psi. ECD: 13.2, BHP:4180 psi. PVT: 245. Taking rtns inside. Reduce WHP to 400 psi. ECD: 13.2. 1.45 in/1.30 out. 14:00 - 14:30 0.50 STKOH N DFAL PROD2 Begin time milling at 8055'. Lock brake for 30 min. 3550 psi @ 1.45/1.24 bpm fs. TF:150L. Jnc: 88.5 deg. 14:30 - 16:30 2.00 STKOH N DFAL PROD2 Drill 1 'lhr for 2 hrs. WOB slowly increasing. 3530 psi @ 1.45/1.42 bpm fs. ECD:12.91. BHP: 4100 psi. Drill from 8055 to 8057. 16:30 - 18:30 2.00 STKOH N DFAL PROD2 Continue to time drill from 8057'. 2' I hr for two feet. PVT: 347. INcrease WHP to 350 psi due to bubbling rtns. 18:30 - 19:10 0.67 STKOH N DFAL PROD2 See 85 deg and prior hole was at 89 deg so appear to be off. Clean 'out' MM. Drill ahead to finish KO and get lined out for lateral. Returns are 7.5 ppg, ECD 13.17 ppg w/9.2 ppg MW 'in'. Drilled to 8072', but stacking (and having to PU), so call this good, PVT 327 19:10 - 19:35 0.42 STKOH N DFAL PROD2 Wiper to window. CJean by OH WS and window. 19:35 - 20:00 0.42 STKOH N DFAL PROD2 SI choke to open EDC and WHP=1ooo psi. POOH following pressure schedule 1.7/3450 PVT 320. POOH to 5400' and PVT is 324 (have gained 12 bbls due to cyclic Swaco choke Printed: 101112004 9:09:13 AM . . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRilLING CO. 9/21/2004 0.42 STKOH N Date From- To Hours Task Code NPT Phase 19:35 - 20:00 20:00 - 20:30 20:30 - 21:45 0.50 STKOH N 1.25 STKOH N 21:45 - 22:10 0.42 STKOH N 22:10 - 00:00 1.83 STKOH N 9/22/2004 00:00 - 01 :45 1.75 DRILL N 01 :45 - 02:30 0.75 DRILL N 02:30 - 04:00 04:00 - 06:30 1.50 DRILL N 2.50 DRILL N Page 15 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 DFAL PROD2 operation due to something probably washed out and cutting pressure schedule too close) DPRB PROD2 RIH to CBU. Had to take returns outside after too gassy DPRB PROD2 CBU from 7380' 1.8/3740 wI 650 psi whp holding 3940-4000 psi bhp (12.8-13.1 ppg ECD) and taking retums to tiger tank. Switch to manual bypass of Swaco choke and cautiously take returns back to pits at 8.8 ppg DPRB PROD2 CBU 1.5/1.14/3200 from 7380' and gradually reduce WHP to 680 psi while circ'ing out gas cut mud and maintain bhp at 4000 psi w/13.04 ppg ECD DFAL PROD2 Resume POOH from 7380' following pressure schedule 1.7/3400 Safety mtg re: pressure undeploy Tag up w/1250 psi WHP wI closed EDC DFAL PROD2 Pressure undeploy wI 1055 psi initial. Had trouble breaking out BHI quick connect. Change it out and test. Fin LD BHA. WHP 950 psi DFAL PROD2 Change bit, adjust motor. Change packoff Bit was 0-8-' Had one lost cutter and 3 badly broken (of eight outside cutters) Safety mtg re: pressure deploy DFAL PROD2 Pressure deploy BHA w/950 psi WHP DFAL PROD2 RIH w/ BHA #14 (new HYC bi bit, 1.1 deg). Have trouble starting to RIH due to injector kickout from preset limits and high WHP. Circ at 0.311720 while hold 950 psi WHP and took 30 min to get started RIH (new packoff too) Log gr tie in from 7410'. -9' correction. Circulate out gas. Load pits with new mud from uprights. Drill ahead. 3730 psi @ 1.4 bpm fs. Rtns to tiger. ECD:12.98, BHP:4135 psi. ROP:100+ Wiper trip to 7410'. Over pulls through 81 & B2 interval (5-10k#). RIH. Having to work through shales at 7600 to 7700'. Ream and back ream two passes. Cleaned up some, but still bumpy Drill ahead. 3350 psi @ 1.42 bpm fs. Rtns to tiger. ECD: 12.2 BHP: 3870 psi. WOB: 1-2K#. ROP: 100-120 fph. Wiper trip to 6500'. 81 & 82 had some overpulls, better than previous short trip. Circulate inside casing while adjusting genset frequency. Continue to RIH after wiper trip. Rough spots from 7650' to 7775'. Drill ahead to 8420' and find a hard spot. Begin slow drop from 94 deg at 6139' TVD Took 40 min to get thru 8420', then drill at 1OO'lhr in 40 api sand wI neg wt 1.67/?/37oo/120R wI 530 psi bp, 12.25 ECD taking returns to tiger tank. Attempted to bring returns inside twice, but too gassy. 'In' density varies from 9.00-9.23 ppg and mud looks like 'black magic'. Increase bp to 600 psi to maintain 12.55 ECD (4000 psi bhp) after getting 20 bbl gain over an hour-hard to know retum rate when going to tiger tank. Begin vac'ing tank for transfer to pits PROD2 Drill ahead in and out of hard streaks and swap to 11 OL. Drilled to 8500' wI 12.55 ECD and gained 10 bbls in last hour. 06:30 - 07:00 0.50 DRILL N DFAL PROD2 07:00 - 08:00 1.00 DRILL N DFAL PROD2 08:00 - 10:30 2.50 DRILL N DFAL PROD2 10:30 -11:45 1.25 DRILL N PROD2 11 :45 - 13:30 1.75 DRILL P PROD2 13:30 - 15:00 1.50 DRILL P PROD2 15:00 - 16:00 1.00 DRILL N SFAL PROD2 16:00 - 17:00 1.00 DRILL P PROD2 17:00 - 18:00 1.00 DRILL P PROD2 18:00 - 20:00 2.00 DRILL P PROD2 20:00 - 22:00 2.00 DRILL P Printed: 101112004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date . . Page 16 of 24 BP EXPLORATION Operations Summary Report 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. From - To Hours 9/22/2004 20:00 - 22:00 22:00 - 22:30 22:30 - 23:35 23:35 - 00:00 9/23/2004 00:00 - 01 :00 01 :00 - 02:45 02:45 - 04:30 04:30 - 05:45 05:45 - 06:15 06:15 - 07:00 07:00 - 10:00 10:00 - 13:30 13:30 - 15:15 15:15 - 18:00 18:00 - 18:30 2.00 DRILL P 0.50 DRILL P 1.08 DRILL P 0.42 DRILL P 1.00 DRILL P 1.75 DRILL P 1.75 DRILL P 1.25 DRILL P 0.50 DRILL P 0.75 DRILL P 3.00 DRILL P 3.50 DRILL P 1.75 DRILL P 2.75 DRILL P 0.50 DRILL P Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Phase Description PROD2 Incr WHP to 700 psi (12.65 ECD) PROD2 Drill ahead in another hard streak at 8500' 1.75/?/3800/80L w/ 710 psi bp, ECD 12.65 (4035 psi bhp) w/-8k surface wt and 2.7k wob and try to stay in lower A4 40 api sand PROD2 Incr whp to 900 psi after 7 bbl gain in last 30 min. Initial resultant ECD was 12.9 ppg (4100 psi). Red rate to 1.6/3800 psi to maintain 13.0 ppg ECD after one circ. Begin fluid transfer from tiger tank again. IA has declined from 700 psi to 140 psi and OA from 320 psi to 140 psi over 5 hours-assume a leaking DGLV. Strap a 20 bblloss over last hour-finally gaining on it. 'In' density is 8.95 ppg. Drill to 8508' and time to test the water PROD2 Wiper to window 1.6/3700 23.4k Had 5-8k overpulls 7650-7700' w/ minor MW PROD2 Fin wiper to 7410' and clean by OH WS. RBIH at 1.4/3500 w/ ECD 13.1 and clean by OH WS, shales at 7700' and thru OH sidetrack point. Get to TD w/ + 1 k string wt at 20'/min. Lost 14 bbls on wiper PROD2 Drill from 8508' 1.52/3530/85L wI 800 psi bp, 13.0 ECD and still in a hard spot w/-8.5k wt and 2.85k wob. Losing average 14 bbls/hr. Try to bring returns inside, but still too gassy IA and OA stabilized at 80 psi and 50 psi PROD2 Finally get thru a 20' thick hard spot and penetration rate picked back up to 60-120'/hr and GR later showed 100 api rock-should be in vicinity of a fault. Holding 88 deg, but lost some incl in faster drilling (same as first leg at 8569-8600') which was also a guesstimated fault. Cuttings gradually increased ECD to 13.15 ppg wI 800 psi bp. Able to take retums to pits again, but too bubbly to 'see' rate and density thru 'out' MM. Drill to 8647' and had signs of diff sticking, then couldn't get back to TD without setting down from 8620-32'. GR also got back down to 50 api at 8615' PROD2 Wiper to 6500' 1.51/3460 wI 800 psi bp, 13.0 ECD. No overpulls anywhere. Open EDC above window and circ 1.6/3400 to 6500'. RBIH to 7420' holding 13.0 ECD PROD2 Log tie-in down from 7420'. Add 18.5' correction. PROD2 Continue to RIH. Hole much smoother holding 12.8 to 13.0 ECD. PROD2 Drill ahead. 3350 psi @ 1.43 bpm fs. 100-200 dpsi. Rtns to tiger. WHP: 900 psi ECD: 12.98 BHP: 4130 psi. ROP: very erratic. PROD2 Drill ahead to 8753'. Pump new 9.4 mud around. Slowly reduce WHP to 800 psi with new mud. Drilling still erratic. 1.7K# on bit. PROD2 Wiper trip to window. B1 & B2 smooth.a couple of tight spots/set downs between 8500 to 8700. PROD2 Drill ahead. 3700 psi @ 1.46 bpm fs. Rtns to tiger. WHP:8oo psi w/ 9.4 mud around. ECD: 13.2 BHP: 4237. Continued erratic drilling. Appears to be spotty hard spots. PROD2 Adding new 9.4 ppg mud while drill ahead from 8900' 1.45/1.15/37oo/90R wI 9.4 ppg 'in', 8.75 ppg 'out' at 13.35 ECD (4233 psi) holding 600 psi bp thru repaired Swaco choke at 6O-1OO'!hr. Take returns to tiger after returns got too gassy Printed: 101112004 9:09:13 AM . . BP EXPLORATION Operations Summary Report Page 17 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/23/2004 18:30 - 20:10 1.67 DRILL P PROD2 Wiper to window at 1 .45/3800 holding 800 psi bp after getting drilled solids to surface to maintain 13.0 ppg. No overpulls anywhere. Open EDC and circ 1.6 bpm while pull to 6500'. RBIH holding 13.0 ECD while circ 1.4 bpm 20:10 - 20:25 0.25 DRILL P PROD2 Log tie-in down from 7410' 1 .5/2950 thru E DC w/ 800 psi bp and 13.1ppg ECD. Corr -2.5'. Take returns back to pits and getting 1/1, but that didn't last too long and go back to tiger tank when alarms went off. Losing fluid when above window, but gaining when tie-ing in at 13.0 ppg both at 1.5 bpm. Bring WHP up to 900 psi to keep ECD at 13.0 ppg 20:25 - 21 :15 0.83 DRILL P PROD2 Wiper back to TD was clean until set down at 8813', ECD is 12.96 w/900 psi bp. Acts like we are into something with higher pressure-still adding fresh 9.4 ppg mud 21 :15 - 21:55 0.67 DRILL P PROD2 Ream at drilled TF to TD and have gained 14 bbls over last hour. Increase WHP to 1000 psi and ECD is 13.2 ppg (4240 psi). Have trouble getting past 8920', but get to TD tagged at 8949.5' 21 :55 - 22:20 0.42 DRILL P PROD2 Wiper back to 8760' 1.47/3560 w/13.3 ECD w/1000 psi bp 29.4k. 5k overpull at 8860, 8805' and 8785'. Adding last of new mud on location-have a total of 500 bbls between pits, tiger tank and vac truck. MI mixing 290 bbls 9.4 NaF mud (products just arrived on Slope) Wiper back in hole and had to slow ream 8885-8930' due to low string wt-assume tite rock. Get back to bottom and swap TF to left 22:20 - 23:00 0.67 DRILL P PROD2 Resume drilling w/-5k wt, 1.2k wob 1.47/3750/90L wI 1000 psi bp and watch ECD climb to 13.6 ppg. (4340 psi) Lower WHP to 900 psi after 30 min strap showed a 8 bbl toss. Find another hard spot at 8961' 23:00 - 00:00 1.00 DRILL P PROD2 Continue drilling on hard spot Lower WHP to 800 psi after 30 min strap showed a 30 bblloss at 13.6 ECD Lower WHP to 700 psi after 30 min strap showed a 19 bblloss at 13.52 ECD Lower WHP to 650 psi after 30 min strap showed a 10 bblloss at 13.35 ECD 9/24/2004 00:00 - 01:00 1.00 DRILL P PROD2 Continue drilling in hard spot from 8965' at 1.47/3450/85L wI 650 psi bp at 13.24 ECD continuing slow drop at 86 deg at 6155' TVD. Divert returns back into pits after 15 min strap showed 1/1, but too gassy. Take retums back to tiger tank. Incr WHP to 700 psi and ECD slowly dropped to 13.09 ppg. Incr WHP to 800 psi after 30 min strap showed a 8 bbl gain. Looks like 13.2 ppg ECD is very minimum and 13.25 may be optimum. Incr WHP to 900 psi after 800 psi only showed 13.15 ppg ECD 01 :00 - 02:00 1.00 DRILL P PROD2 Drill ahead in hard spot wI 900 psi WHP at avg 13.25 ppg ECD and lost 1 bbl in 30 min. ECD climbed to 13.4 ppg (as gas was worked out of the system) over the next 30 min and lost 32 bbls. Red WHP to 850 psi to maintain 13.25-13.35 ECD which is new working range 02:00 - 04:00 2.00 DRILL P PROD2 Drill ahead slowly and maintain 13.30-13.35 ECD to minimize large losses and avoid gains. New 9.4 ppg mud has been cut to 9.2 ppg during 3 transfers Printed: 101112004 9:09: 13 AM . . BP EXPLORATION Operations Summary Report Page 18 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Dåte From - To Hours Task Code NPT Phase Description of Operations 9/24/2004 02:00 - 04:00 2.00 DRILL P PROD2 Lost 3 bbl at 13.32 ECD in 30 min w/825 psi WHP Lost 1 bbl at 13.24 ECD in 30 min w/840 psi WHP 04:00 - 06:00 2.00 DRILL P PROD2 Continue slow penetration rate and ECD's slowly fell to 13.15 ppg wI 850 psi bp and gained 3 bbls in 30 min. Incr WHP to 900 psi and ECD's stabilized at 13.25 ppg and lost 3 bbls in 30 min. Do a 100' wiper and was clean. Get back to bottom and drill wI 200 psi ditt, -4.5k wt w/1.5k wob and still slow. ECD climbed to 13.45 ppg and lost 19 bbls in 30 min. Reduce WHP to 800 psi 06:00 - 07:00 1.00 DRILL P PROD2 Wiper trip to window. Hole smooth. 07:00 - 08:30 1.50 DRILL P PROD2 Pull out of hole to inspect BHA and perform BOP pressure test. Follow WHP schedule. 08:30 - 08:45 0.25 DRILL P PROD2 Hold PJSM to discuss un-deployment. Discuss job assignments, procedure, & hazards. 08:45 - 11 :00 2.25 DRILL P PROD2 Shut in well with 1190 psi WHP. Space out coil. Un-deploy BHA. LD MWD & motor. Bit (Hycalog Bi) nose cumers in good shape. Several broken and/or missing gauge cutters on wings. Mtr feels good & tight. 11 :00 - 15:30 4.50 BOPSUP P PROD2 Test BOP equipment. Witness waived by AOGCC J. Spaulding. Mixing 580 bbls of 10.0 ppg formate mud at MI. 15:30 - 15:45 0.25 DRILL P PROD2 Hold PJSM before deploying BHA. 15:45 - 18:15 2.50 DRILL P PROD2 Pressure deploy BHA #15. (1.1 deg mtr w/ Hycalog DS100 bi-bit). WHP=1220 psi and confirmed w/ PWD annular and bore pressure wI assumed 9.20 ppg mud in well bore 18:15 - 19:30 1.25 DRILL P PROD2 RIH w/ BHA #15 following pressure schedule 19:30 - 19:45 0.25 DRILL P PROD2 Log tie-in down from 7420' at 1.3 bpm holding 13.35 ECD and losing fluid, corr -7' 19:45 - 21 :05 1.33 DRILL P PROD2 RIH at 35'/min 1.35 bpm holding 13.25-13.35 ECD to 8785' and started losing wt and have motor work. PU and precautionary slow ream probable undergauge hole at 7'/min to TD tagged at 9011.0' w/13.4 ECD at 900 psi WHP 21 :05 - 21 :35 0.50 DRILL P PROD2 Resume drilling ahead w/9.23# mud in hard spot 1.54/3600/85L w/ 800-900 psi bp thru Swaco choke to hold 13.25-13.35 ECD w/-3.7k wt, 1.82k wob, 200 psi ditt at 86 deg at 6157' TVD while load pits wI 10.0# NaF mud and take retums to tiger tank 21 :35 - 22:20 0.75 DRILL P PROD2 Stall at 9016' and then penetration rate picked back up to 90'/hr w/1.5k wt, 1.4k wob, 100 psi ditto Lost 10 bbls in 30 min wI ECD of 13.45 avg w/9.2# mud. Purposely staying high on ECD's to keep gas out of system. Transfer last of 9.2# mud directly to pump before swap to 10# mud (while waiting on second vac truck which just left MI) 22:20 - 23:00 0.67 DRILL P PROD2 Drill ahead at 6O-90'lhr 1.57/3670/30L and swap to 9.92# mud. Lost 20 bbls in 30 min at 13.46 ECD. Reduce WHP to 850 psi. Found another hard spot at 9100' when new mud was at the bit. Reduce WHP to 825 psi as ECD started to climb due to heavier mud. PU 28k and red pump rate to 1.47/3760 after new mud ¡ncr FSp due to LSRV 23:00 - 00:00 1.00 DRILL P PROD2 Continue to drill on hard spot and red WHP in 25 psi increments to try to keep on the slightly losing side while circ new mud up annulus. Didn't do too good of a job tho and lost Printed: 10/112004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/24/2004 23:00 - 00:00 9/25/2004 00:00 - 01 :00 01 :00 - 02:15 02:15 - 03:00 03:00 - 03:40 03:40 - 04:50 04:50 - 07:30 . . Page 19 of 24 BP EXPLORATION Operations Summary Report Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: HourS Task Code NPT Phasë 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. 1.00 DRILL P 1.00 DRILL P 1.25 DRILL P 0.75 DRILL P 0.67 DRILL P 1.17 DRILL P 2.67 DRILL P Spud Date: 5/1/1996 End: 9/29/2004 Operations PROD2 around 40 bbls while getting 9.92# mud back to surface. Bring retums back inside and were okay for 5 min, but then too gassy so send to MT tiger tank. Saw about a 0.5 bpm loss rate on 'out' MM at 13.46 ECD wI 475 psi WHP. Transfer remaining 153 bbls of 9.2 ppg black magic to open top tanks. Lost 13 bbls in last 30 min at 13.43 ECD. Reduced WHP to 425 psi by 0000 hrs PROD2 Drill ahead from 9105' in hard spot 1.47/3800 w/425 psi bp and 13.38 ECD Lost 9 bbls in 30 min. Bring returns back inside for 15 min and actually see 'mud' (although it was gas cut and sli crude stained) at 1.47/1.33 bpm and had 9.5 ppg initial but declined to 8.0 ppg and eventually alarms went off. Go back to tiger tank and raise bp to 500 psi to maintain 13.40 ECD PROD2 Drill ahead from 9112' 1.47/38oo/95L wI 500 psi bp and 13.41 ECD. New target range is 13.40-13.45 ppg ECD which gives an avg loss rate of 25 bph. Stall at 9114' then back to 90'lhr, but that only lasted for 30'. Drill on another hard spot at 9144' for 10 min and turn TF down to 160L to get out of this stuff PROD2 Wiper to window was clean. Kept ECD 13.35 and higher so assume true 9.92# mud thru out and a 5 min check of returns showed no gas. Trap 900 psi surface pressure and SI at Swaco choke PROD2 Park at 7415' (6097' TVD) to get pressure buildup data Time WHP DHP ECD 0302 900 4142 13.36 0312 900 4114 13.28 0322 900 4108 13.26 0332 900 4107 13.26 Open EDC and begin circ at 1.50 bpm while reduce bp to 450 psi, but had too much gas and MM wouldn't record initially PROD2 Circ test at 1.50 bpm PVT Rate Out Density Out 0339 450 4134 13.35 188 0347 450 4135 13.35 186 1.35 9.17 0353 450 4134 13.34 184 1.25 9.86 0405 450 4131 13.34 181 1.25 9.92 Btms up, red whp to 400 0410 400 4121 13.30 177 1.45 9.95 0416 400 4118 13.29 177 1.42 9.96 0424 400 4115 13.28 175 1.42 9.95 0434 400 4111 13.27 175 1.61 8.90 Rate incr and lite mud 0438 400 4110 13.27 175 1.70 7.40 Just before MM quit-gassy 0445 400 4109 13.27 174 Too gassy to measure-end of test Trap 840 psi WHP and DHP=4112 psi. RIH by OH WS while close EDC (Kai lied, used min rate instead) PROD2 Wiper back in hole 1.5 bpm w/4oo psi to resume drilling holding 13.35 ECD and continue going to pits, but not seeing 'out' MM. Sat down at 8060' in wrong hole . .. Had to take returns to tiger tank at 86oo'-too gassy. Lost wt at 9010' and PU, clean 28k. Precautionary ream slowly to TD. Last batch Printed: 101112004 9:09:13 AM . . BP EXPLORATION Operations Summary Report Page 20 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date Hours Task Code NPT Phase Descriþtion of Operations 9/25/2004 04:50 - 07:30 2.67 DRILL P PROD2 of 10.0# mud is leaving MI (out of materials to build any more Formate based mud other than that held in reserve for KWF) 07:30 - 09:30 2.00 DRILL P PROD2 Condition hole for liner. Losing 20-40 BPH with 13.5 ECD. wI 650 psiWHP. Reduce WHP to 550 psi @ 1.45 bpm. Hole smooth. 09:30 - 10:00 0.50 DRILL P PROD2 Log gr tie in. -1' correction. 10:00 - 18:30 8.50 DRILL N FLUD PROD2 Pull into csg to get BHP survey while waiting on KWF. 4027 psi @ 6020 TVD: ECD is 12.86 ppg. 18:30 - 19:30 1.00 DRILL N FLUD PROD2 Parked at 7262' and SI wI 1660 psi (3976 psi dhp, 13.11 ECD while wo KWF. Have 450 bbls 10 ppg in pits and vac truck, 290 bbls of 13.4 ppg KWF just arrived. Now sending 210 bbls of prior KWF (12.5 ppg NaBr) to MI for weight up to 13.4 ppg. Will wait for truck to be close to loading before starting displacement and cleanout ops due to probable high fluid losses and safety concems 19:30 - 23:30 4.00 DRILL N FLUD PROD2 SIP 1740 psi (13.14 ECD). Open EDC and begin pump down CT at min rate wI 150 bbls used 9.2# mud 0.25/1740 to keep CT warm and slow down annular swap Second truck wI KWF left MI at 2330 hrs 23:30 - 23:50 0.33 DRILL N PROD2 SIP 1950 psi (13.25 ECD) pumping 0.25/1550 9.2# mud down CT Advise Kup DSO of venting and field announcement of Pad restrictions were made by Security. Safety mtg re: displace well bore to mud 23:50 - 00:00 0.17 DRILL N PROD2 Displace well bore to used 9.2# mud at 1.5/3200 wI 1600 psi bp and 13.4-13.6 ECD 9/26/2004 00:00 - 00:45 0.75 DRILL N FLUD PROD2 Displace well bore to used 9.2 ppg mud at 1.5/3200 wI 1600 psi bp and 13.4-13.6 ECD using manual choke. Lower WHP in 100 psi stages to maintain 13.53 ECD, but got as high as 13.63 ppg and had minimal retums-sorry, Dan(s). RIH to 7415' to match up from prior day data. Retums were mostly crude, very little gas 00:45 - 01:15 0.50 DRILL N FLUD PROD2 Park at 7415' and circ 1.53/3220 wI 850 psi bp to maintain 13.44 ECD (4157 psi) and swap to recycled 9.8 ppg mud. SI manual choke while close EDC and swap back to Swaco choke. Trap 1090 psi=4119 psi bhp (13.30 ECD) Cancel Pad restrictions 01:15 - 02:15 1.00 DRILL P PROD2 Wiper to TO to condition hole for liner holding 13.4-13.5 ECD. Hole was clean. Tagged TD w/-2k string wt and confirmed official TD as 9144'. PUH 29.1k Losing avg 12 bblslhr 02:15 - 02:50 0.58 DRILL P PROD2 Start fresh, slick 9.95 ppg mud while perform ream/backream 1.513950 from 9100' to TD holding 625 psi. Had trouble reaming last 11' twice, but get back to TD 02:50 - 03:30 0.67 DRILL P PROD2 Wiper back to window leaving fresh mud in OH and start 13.4 ppg KWF (NaFCaC03) down CT maintaining 13.5 ECD. After 10 bbls pumped, red rate to 1.25/4000 due to higher densitylviscosity. Take retums back to pits and see 1.29/0.88 at 13.319.4 ppg among a few lite spots 03:30 - 03:50 0.33 DRILL P PROD2 Leave 13.4 KWF in open hole from 8200' as POOH and see avg 1.20/0.75 returns 03:50 - 05:30 1.67 DRILL P PROD2 POOH for liner while fin displacement and lower bp accordingly to maintain 13.4 ECD. Fully open choke by 6500', but still have Printed: 1011/2004 9:09: 13 AM " . . BP EXPLORATION Operations Summary Report Page 21 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date From"'To Hours Task Code NPT Phase DescriptionofQperations 9/26/2004 03:50 - 05:30 1.67 DRILL P PROD2 sli gas cut retums of 9.4 ppg and 1.210.6 pulling 78'/min after 90 total bbls pumped Park at 4700' and monitor and looks like well is taking 0.3 bpm after getting 10.1 ppg retums at surface. Will have to live with some losses so POOH 100'/min 1.15/0.4 and return density slowly increased to 10.3 by 3800',11.0 by 3100',12.4 at 2000', 13.0 at 500'. Pumped a total of 170 bbls of 13.4 ppg NaF mud, leaving 40 bbls in CT and gaining 27 bbls of 10.35-13.4 ppg. Lost 87 bbls of 13.4 mud 05:30 - 06:00 0.50 DRILL P PROD2 Tag up, monitor well and determine loss rate while have crew change 06:00 - 06:15 0.25 CASE P PROD2 PJSM to discuss getting off well and running liner. Discuss concems of well fluid stability and need to expedite liner make up. 06:15 - 09:00 2.75 CASE P PROD2 LD BHA. Make 56 joints of 2-3/8· STL, 4.6# liner with deployment sleeve, o-ring sub, bullnose guide shoe. 09:00 - 09:45 0.75 CASE P PROD2 MU coiltrack EDC assembly with GS spear. Stab coil. Get on well. Well begining to flow while stabbing lubricator. 09:45 - 11 :30 1.75 CASE P PROD2 RIH with liner assembly. Cannot circulate due to GS spear. Well taking fluid. Unable to get more than 125 psi WHP. WT check at 7300': 8k# dn, 25k# up. 11 :30 - 13:00 1.50 CASE N DPRB PROD2 Tag up on A-leg liner top. Work pipe, slow, fast, stop & start. Unable to work past 7437'. 13:00 - 14:45 1.75 CASE N DPRB PROD2 POOH to surface. Rig up NaBr KWF truck. 14:45 - 15:45 1.00 CASE N DPRB PROD2 Kill well by displacing down kill line with 13.4 NaBr mud. Bleed WHP from 868 to 700 psi. Pump 10 bbl10ppg formate spacer followed by 130 bbls NaBr kill fluid. Pump at 3.5 bpm, max WHP 1200 psi. Final circ WHP: 1000 psi. 15:45 - 16:30 0.75 CASE N DPRB PROD2 Monitor WHP. Bled to zero quicly. No flow. Check lubricator. No flow. Prep 2· safety joint. 16:30 - 18:20 1.83 CASE N DPRB PROD2 Get off well. Unstab coil. Set back injector on legs. LD BHI mwd tools. Standback liner 18:20 - 20:00 1.67 CASE N DPRB PROD2 Install tree cap and SI well at choke. Well was taking fluid most of trip, but static last 10 min. Nordic crew change today. Not sure of what fluidslwhere at surface-have 3 vac trucks, 4 pits and four tanks with various volumes, weights and additives. Safety mtg, then STOP to weigh fluids and get lined out. Pump 13.4 ppg from CT to pit #4 thru bung hole and replace CT volume wI 9.9 ppg fluid to give 46 bbls 12.7+ NaF in pit #4 and 40 bbls 13.4 ppg fresh NaBr on truck. Assume this would give 13.1 ppg avg and 20 bbls over hole fill, but too close for comfort 20:00 - 21 :00 1.00 CASE N DPRB PROD2 Wellbore starting to show positive pressure, wo more KWF 21 :00 - 23:45 2.75 CASE N DPRB PROD2 SIP=150 psi. Truck is loading at MI 23:45 - 00:00 0.25 CASE N PROD2 Truck on location at 2330 hrs. SIP 700 psi Safety mtg re: well kill before running liner 9/27/2004 00:00 - 02:15 2.25 CASE N DPRB PROD2 SIP 750 psi. Bullhead kill pumping 46 bbls 12.7 ppg NaF, plus 40 bbls 13.4 ppg NaBr off of truck #1, 40 bbls 13.5 NaBr off of truck #2 at avg 3.65 bpm/650 psi and max 900 psi. ISIP 400 psi and bled to 125 psi in 5 min, 95 psi in 10 min, 80 psi in 15 min, 70 psi in 20 min, 60 psi in 30 min, 50 psi in one hour. Discuss. Bleed off trapped gas pressure at surface. Fill hole w/< 0.5 bbls. Remove tree cap and monitor going slowly south Printed: 1011/2004 9:09: 13 AM . . BP EXPLORATION Operations Summary Report Page 22 of 24 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-1 8 DRILL+COMPLETE PARKER DRILLING CO. Start: Rig Release: Rig Number: 9/8/2004 5/31/1996 Spud Date: 5/1/1996 End: 9/29/2004 Date From - To Code· NPT Phase Descriptionöf Operations 9/27/2004 02:15 - 04:00 1.75 CASE N DPRB PROD2 Rerun liner out of derrick while filling wI pinched back charge pump and took 4 bbls. MU BTT locked GS assy. MU BHI assy wlorientor. PU injector, remove legs, add lubs, stab tool, stab injector 04:00 - 05:10 1.17 CASE P PROD2 RIH wI BHA #17 wI well SI and not circ 05:10 - 05:25 0.25 CASE P PROD2 Work to get by 7438' 'A' leg by orienting. No pump, WHP is O. Got by after rotating 210 deg from start 05:25 - 06: 1 0 0.75 CASE P PROD2 RIH wI liner in open hole, but first try went into old hole (where 1/2 of a bit is) and set down at 8256'. PUH wI a few 10k overpulls initially to above OH sidetrack point, orient 90 deg and try it again, repeat, and got by on third attempt 06:10 - 07:30 1.33 CASE P PROD2 Continue to RIH wI liner. Several set downs. PU wt at 8851: 37k#, 2k# dn wt. Tough spot at 8851'. Work pipe and orient. Unable to get past 2nd spot at 8947'. Work all orientations, speeds. No go. Decide to call it quits. Pump down coil to release from linerlgs spear. 07:30 - 09:00 1.50 CASE N DFAL PROD2 Unable to release from liner. Vary pump rate, orient, vary weight. No good. Discuss options with town team. Order slick seawater and 10 bbls 7% HCL. 09:00 - 09:45 0.75 CASE N DFAL PROD2 Wait on fluids. 09:45 - 11 :30 1.75 CASE N DFAL PROD2 Open ECD. Displace coil to seawater. Close EDC. Circulate at 4600 psi coil pressure at 2.4 bpm. Take rtns to tiger, then shut in well and bull head. Work pipe slowty through up & down wt range. Circulate 40 bbls or more. No go. Had to over pull to 52k# up wt to get liner moving again. 11 :30 - 15:00 3.50 CASE N DFAL PROD2 Wait on acid from SLB in Deadhorse. CPAI designed acid composition to be compatable with KRU reservoir. Move liner every 20 minutes to keep it free. 15:00 - 15:45 0.75 CASE N DFAL PROD2 Spot and RU SLB pumper, acid transport, and vac truck. 15:45 - 16:00 0.25 CASE N DFAL PROD2 Hold PJSM to discuss details of pumping acid. Discuss hazards, procedure, safe area, etc with pump & rig crews. 16:00 - 17:30 1.50 CASE N DFAL PROD2 Pump 5 bbls seawater ahead. Pressure test lines to 4000 psi. Good. Pump 10 bbls 7% HCL with additives into coil using SLB pumpers. Displace with rig pump using seawater. At 40 bbls displacement, slow rate to minimum (0.2 bpm). Displace acid from coil at this rate. Continue to move coil up & down slowty during displacement & spotting process. 17:30 - 18:15 0.75 CASE N DFAL PROD2 Circulate to try and release GS with seawater. 3800 psi @ 2.07 bpm. Liner went down hole to 9075'. Unable to release. Discuss releasing wI EDC 18:15 - 19:00 0.75 CASE N DFAL PROD2 Pull liner thru open hole continuing to pump SW down CT 0.8/1980 wI 1830 psi WHP wI just a few 5k overpulls 19:00 - 20:00 1.00 CASE N DFAL PROD2 POOH with liner. Displ CT to used 9.9# mud 20:00 - 20:30 0.50 CASE N DFAL PROD2 Park at 200', SD pumping on CT and swap to kill line. SIWHP 1710. Bullhead kill wI 50 bbls 11.4 ppg mixed fluids NaFINaCIIINaBr/CaC03 followed by 80 bbls 13.5 ppg CaC03 at 4 bpm. Initial/max WHP 1900 psi 20:30 - 21 :40 1.17 CASE N DFAL PROD2 SD pumping at FIR of 4.0/1460 psi. ISIP 800, 5 min 440,30 min 360. Bleed off trapped gas in lub. Fill hole wI 4 bbls and static 21 :40 - 22:30 0.83 CASE N DFAL PROD2 Break off inj, LD tub, set inj on legs. LD BHI assy and remove BTT GS and deployment sleeve. Break down GS assy and determine that the bull nose extension with locking device (with Printed: 101112004 9:09:13 AM . . BP EXPLORATION Operations Summary Report DFAL PROD2 two locks) bottoms out at the bottom of the deployment sub when in the stacked position and the GS dogs don't have enough room to release from the top of the deployment sub when they shift up under a differential. Meanwhile BHI change out MWD assy and reposition EDC as low as possible in string in case this is the only way to leave the liner in the hole. Discuss DFAL PROD2 PU and hang 2· safety jt in well in proper position for combi setting if necessary (hole staying full). Remove blocks and PU injector, drop 4' lub. RU and surface test GS assy (without deployment sub) and dogs retracted at 1.75 bpm wI 318· orfice (this past run) and 1.0 bpm wI 1/4· orfice. RD test assy. Pull safety jt and LD. MU prior pump off GS assyon deployment steeve wI shorty BHI assy (checks only). Stab back on well wI injector WAIT PROD2 Fill hole from BS and was full. SI well and keep 90 psi charge pump pressure on kill line pumping 13.5 ppg KWF, but well wouldn't take fluid. At 0130 hrs SD charge pump since well pressure was 100 psi. WO BIT to make a tool that works Continue to wait on replacement deployment sub from Baker machine shop. WHP: 525 psi and rising. Hold PJSM in ops cab to discuss killing well. SIP 1250 psi. Bullhead kill well with 112 bbls 11.4 & 13.5 ppg CaCo fluid at 3.6 bpm/1040 psi. ISIP 600,5 min 350 psi. Bleed off trapped gas and well was on sli vac Remove injector and set on legs. Remove GS and deployment sub. Install redesigned and longer deployment sub with GS having extended bullnose and 1/4· orfice. MU reconfigured BHI BHA wI orientor on bottom. Stab back on wI injector PROD2 RIH wI BHA #18 wI well SI and no pump PROD2 7300' 26.0k, 6k RIH thru window, clean. RIH past leg 'A' wI no wt loss. Sat down in old hole (where 1/2 of bit is at 8251'). POOH (and was clean) to above OH sidetrack point at 8040' and orient 100 deg. RIH and got in right hole. RIH w/Uner at 45'/min at 8300' wI +4k string wt and had +2k st wt just before set down at 8745'. PU, clean 31k and orient 120 deg. Get by and RIH to 8815'. Work for 30 min to get to 8850' and started running clean again. Work from 8970' to 9080' in 30 min. Work for additional 20 min wI clean PU's at 31k and call this good (probably same depth reached as prior run so <70' from actual TD). Fill hole from BS wI 13.5 ppg KWF since WHP is still zero Pump down CT at 1.25/3700 and PUH 23k and were released. TOL at 7254', BOL at 9080'. Filled hole pumping down CT at 0.4/1900 and WHP gradually rose to 500 psi as POH Tag up wI 460 psi. WO crew change to undeploy PJSM review well blowdown attempt. Line up to Tiger Tank. Attempt to bleed-off wellhead pressure but unable to drop pressure. Shut-in well with 490psL . PJSM and review procedures for Pressure Undeployment. Pressure undeploy BHA following guidelines and procedures. No problems. Wellhead pressure 610psi. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Date From - To Hours Task Code· NPT Phase 9/27/2004 21 :40 - 22:30 0.83 CASE N 22:30 - 00:00 1.50 CASE N 9/28/2004 00:00 - 05:00 5.00 CASE N 05:00 - 11 :15 6.25 CASE N WAIT PROD2 11: 15 - 11 :30 0.25 CASE N DFAL PROD2 11 :30 - 12:30 1.00 CASE N DFAL PROD2 12:30 - 13:20 0.83 CASE N PROD2 13:20 - 14:30 14:30 - 16:30 1.17 CASE N 2.00 CASE N 16:30 - 17:40 1.17 CASE N PROD2 17:40 - 18:15 0.58 CASE N PROD2 18:15 - 18:25 0.17 CASE N PROD2 18:25 - 18:45 0.33 CASE N PROD2 18:45 - 19:00 0.25 CASE N PROD2 19:00 - 20:30 1.50 CASE N PROD2 Page 23 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Description of Operations Printed: 101112004 9:09:13 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date . . BP EXPLORATION Operations SUl11mary Report 1 F-18 1 F-18 DRlll+COMPlETE PARKER DRilLING CO. 9/28/2004 20:30 - 21:00 From-To Hours Task Code 0.50 WHSUR P 21:00 - 21:10 21:10 - 22:00 22:00 - 00:00 9/29/2004 00:00 - 03:00 0.17 WHSUR P 0.83 WHSUR P 2.00 RIGD P 3.00 RIGD P Page 24 of 24 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Phase Description of Operations POST Line-up on wellhead and bullhead 25bbls diesel. Close Master and Swab valves. Final WHP 700 psi. PJSM discuss coil blowdown operations with N2. Slowdown coil with N2. Unstab coil from injector and secure to reel. Prep to remove reel. Same time cleaning mud pits. Lower reel to Veco flatbed. ND SOPE. Installed tree cap and test to 50oopsi. Finish cleaning oily mud tanks. POST POST POST POST Rig Released at 0300 hrs 9-29-04 Printed: 101112004 9:09:13 AM . BP-GDB Baker Hughes INTEQ Survey Report . ...E INTEQ Survey 8034.38 88.91 97.24 6246.07 6138.07 3644.15 1004.40 5962382.33 540506.63 1193.74 0.00 8051.44 89.76 100.69 6246.26 6138.26 3641.49 1021.25 5962379.76 540523.48 1210.43 20.83 8080.99 81.40 90.16 6248.55 6140.55 3638.70 1050.51 5962377 .12 540552.76 1239.50 45.39 8109.78 84.17 88.97 6252.16 6144.16 3638.92 1079.07 5962377.48 540581.31 1268.03 10.46 8140.13 86.79 87.06 6254.55 6146.55 3639.97 1109.30 5962378.69 540611.54 1298.28 10.67 8170.81 90.11 84.64 6255.38 6147.38 3642.19 1139.88 5962381.07 540642.10 1328.94 13.39 8201.75 90.94 80.72 6255.10 6147.10 3646.13 1170.56 5962385.17 540672.76 1359.78 12.95 8248.10 90.35 85.50 6254.58 6146.58 3651.69 1216.56 5962390.97 540718.72 1406.01 10.39 8280.28 92.84 87.95 6253.68 6145.68 3653.52 1248.67 5962392.98 540750.82 1438.17 10.85 8310.11 93.79 91.47 6251.96 6143.96 3653.67 1278.45 5962393.29 540780.59 1467.91 12.20 8340.54 92.66 95.06 6250.24 6142.24 3651.94 1308.77 5962391.72 540810.92 1498.11 12.35 8369.98 92.47 97.96 6248.93 6140.93 3648.61 1337.99 5962388.54 540840.15 1527.11 9.86 8408.60 94.39 101.93 6246.61 6138.61 3641.95 1375.95 5962382.08 540878.15 1564.67 11.40 8442.33 90.63 106.23 6245.14 6137.14 3633.76 1408.62 5962374.06 540910.86 1596.87 16.92 8472.17 87.62 102.32 6245.59 6137.59 3626.40 1437.53 5962366.86 540939.80 1625.35 16.53 8502.09 85.71 100.20 6247.33 6139.33 3620.57 1466.82 5962361.18 540969.12 1654.30 9.53 8537.40 85.03 96.10 6250.18 6142.18 3615.58 1501.65 5962356.37 541003.97 1688.82 11.73 8569.91 88.26 93.19 6252.09 6144.09 3612.96 1533.99 5962353.92 541036.32 1720.98 13.36 8600.75 90.91 90.95 6252.31 6144.31 3611.84 1564.81 5962352.97 541067.14 1751.69 11.25 8635.44 91.21 87.33 6251.67 6143.67 3612.36 1599.48 5962353.67 541101.81 1786.35 10.47 8666.25 87.47 83.10 6252.02 6144.02 3614.93 1630.17 5962356.40 541132.48 1817.13 18.32 8699.80 86.57 79.38 6253.77 6145.77 3620.03 1663.28 5962361.67 541165.56 1850.46 11.39 8737.57 88.42 81.60 6255.42 6147.42 3626.27 1700.49 5962368.10 541202.73 1887.94 7.65 8767.48 88.27 85.06 6256.28 6148.28 3629.74 1730.18 5962371.73 541232.40 1917.77 11.57 8801.45 86.95 89.31 6257.70 6149.70 3631.41 1764.07 5962373.57 541266.28 1951.71 13.09 8831.12 89.77 92.91 6258.55 6150.55 3630.83 1793.72 5962373.16 541295.92 1981.28 15.41 8860.06 88.88 96.91 6258.89 6150.89 3628.35 1822.54 5962370.83 541324.76 2009.94 14.16 8891.10 87.19 100.30 6259.96 6151.96 3623.71 1853.21 5962366.35 541355.44 2040.32 12.20 8923.31 86.27 103.93 6261.79 6153.79 3616.97 1884.64 5962359.77 541386.91 2071.36 11.61 8960.66 86.26 103.37 6264.23 6156.23 3608.17 1920.86 5962351.17 541423.17 2107.07 1.50 8993.72 85.46 101.32 6266.61 6158.61 3601.12 1953.07 5962344.29 541455.42 2138.86 6.64 9024.89 85.03 97.67 6269.20 6161.20 3596.00 1983.70 5962339.33 541486.07 2169.18 11.75 9060.46 86.64 96.23 6271.78 6163.78 3591.71 2018.92 5962335.22 541521.30 2204.12 6.07 9090.70 89.59 95.61 6272.78 6164.78 3588.59 2048.98 5962332.26 541551.37 2233.98 9.97 9114.29 90.91 93.47 6272.67 6164.67 3586.72 2072.49 5962330.52 541574.90 2257.36 10.66 < 9144.00 90.91 93.47 6272.20 ' 6164.20 3584.92 2102.14 5962328.88 541604.55 2286.88 0.00 . BP-GDB Baker Hughes INTEQ Survey Report . ..a: INTEQ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetit Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1 F Pad North Slope Site Position: Northing: 5958733.30 ft Latitude: 70 17 53.527 N From: Map Easting: 539521.50 ft Longitude: 149 40 47.811 W Position Untertainty: 0.00 ft North RefereDte: True Ground Level: 0.00 ft Grid Convergenu: 0.30 deg Well: 1F-18 Slot Name: 1F-18 Well Position: +N/·S 0.00 ft Northing: 5958733.30 ft Latitude: 70 17 53.527 N +E/-W 0.00 ft Easting : 539521.50 ft Longitude: 149 40 47.811 W Position Untertainty: 0.00 ft Wellpath: 1F-18AL1 Drilled From: 1F-18AL 1PB1 500292265460 Tie-on Depth: 8051.44 ft Current Datum: 1F-18 RKB Height 108.00 ft Above System Datum: Mean Sea Level Magnetit Data: 911712004 DetUnation: 24.56 deg Field Strength: 57568 nT Mag Dip Angle: 80.73 deg Vertital Section: Depth From (TVD) +N/-S +EI-W Direttion ft ft ft deg 0.00 0.00 0.00 87.00 Survey Program for Definitive Wellpath Date: 10/1/2004 VaUdated: Yes Attual From To Survey ft ft 100.00 7300.00 7395.00 7409.96 7430.00 8034.38 8051.44 9144.00 Version: 4 Tookode Tool Name Gyro (100.00-7800.00) (0) MWD (7395.00-9065.00) (1) MWD (7430.00-8256.00) (3) MWD (8051.44-9144.00) Good-'!yro MWD MWD MWD Good Gyro MWD - Standard MWD - Standard MWD - Standard Annotation 8034.38 8051.44 9144.00 6246.07 6246.26 6272.20 TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 9/25/2004 Engineer: Tied-to: From: Definitive Path I ConocoPhillips Alaska, Inc. Cono~illips -- WELLPATH DETAILS 1F-18AL1 5\lOZ9ZZ65400 Parent Weltpath: 1F·18AL 1PB1 Tie on MD: 8051.44 Rì9' Nordic 2 Ref. Datum: 1F.18 RKB 108.0Oft V.Section Origin Starting Anglo +NI-$ From TVD 87.00' 0.00 0.00 0.00 Survey: MWD (1F-1811F~16AL1: Created By: Sni Potnis Date: 10/1f2004 Azimuths to True North Magnetic North: 24.56' Magnetic Fieid Strength: 57566n T D~a'i'::g¿j;:&óg; Model: bggm2004 T LEGEND 1F-18,1F-18AU,Plal #5 IF·18 (1F·18) 1~=~~g~=~~t1PB !} 1F-18Al1 MWD ~900 i3800 g '11'"3700· .... ......", .:!;}ooo '*= 1::3500 o 13400 . :;;3300 .. :I 03200 tn REFERENCE INFORMATION Well Centre: 1F·18, True North System: Mean Sea level Slot - (O.OON,O.OOE) 1F-18 RKB 108.00 Minimum Curvature - TARGETOETAJlß TVO<wCS +€.t·W Reference: Reference: Reference: Measured Deptti Reference: Calculation Method: ANNOTATIONS NO MD Annotation 8(134.$8 TIP 80$1.44 KOP 9144.00 TO 10/1/2004 3:09 PM . . I 1300 1400 1500 1500 1700 1800 1000 2000 210ú 2200 2300 West(-)/EaSiOt(+)[1 OOft/in) 1 ...1 , 230024002500 2600 VertiealSectionat 81.00"[1 OOft/in) SS300 i 5400 C) ~500 J: '15600 Q Q5700 35800 1: Q5900 > :J Q6000J i! ~ ....6100 " . BP-GDB Baker Hughes INTEQ Survey Report . ..rc: INTfì.Q Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1 F Pad North Slope Site Position: Nortbing: 5958733.30 ft Latitude: 70 17 53.527 N From: Map Easting: 539521.50 ft Longitude: 149 40 47.811 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.30 deg Well: 1F-18 Slot Name: 1F-18 Well Position: +N/-S 0.00 ft Nortbing: 5958733.30 ft Latitude: 70 17 53.527 N +E/-W 0.00 ft Easting : 539521.50 ft Longitude: 149 40 47.811 W Position Uncertainty: 0.00 ft Wellpatb: 1F-18AL1PB1 Drilled From: 1F-18A 500292265470 Tie-on Deptb: 7430.00 ft Current Datum: 1F-18 RKB Heigbt 108.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/17/2004 Declination: 24.56 deg Field Strengtb: 57568 nT Mag Dip Angle: 80.73 deg VerticaJ Section: Deptb From (TVD) +N/-S +EI-W Direction ft ft ft deg 0.00 0.00 0.00 18.64 Survey Program for Definitive Wellpatb Date: 10/1/2004 Validated: Yes Actual From To Survey ft ft 100.00 7300.00 7395.00 7409.96 7430.00 8256.00 Version: 3 Toolcode Tool Name Gyro (100.00-7800.00) (0) MWD (7395.00-9065.00) (1) MWD (7430.00-8256.00) Good_gyro MWD MWD Good Gyro MWD - Standard MWD - Standard Annotation 7409.96 7430.00 8256.00 6093.83 6107.94 6248.81 TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 9/2012004 Engineer: Tied-to: From: Definitive Path . . . BP-GDB Baker Hughes INTEQ Survey Report . -.. ..... INTEQ Survey 7409.96 42.13 15.93 6093.83 5985.83 3506.30 468.34 5962241.67 539971.35 3472.08 0.00 ¡< 7430.00 48.29 22.04 6107.94 5999.94 3519.72 473.00 5962255.11 539975.94 3486.28 37.56 7450.00 48.83 30.04 6121.19 6013.19 3533.17 479.58 5962268.59 539982.44 3501.13 30.10 7480.62 50.58 41.96 6141.04 6033.04 3551.98 493.28 5962287.48 539996.05 3523.33 30.21 7515.94 54.01 54.76 6162.69 6054.69 3570.42 514.14 5962306.03 540016.80 3547.47 30.24 7545.81 58.58 61.71 6179.28 6071.28 3583.45 535.26 5962319.17 540037.85 3566.57 24.66 7577.87 63.10 68.31 6194.91 6086.91 3595.24 560.62 5962331.08 540063.15 3585.84 22.84 7612.94 69.08 76.49 6209.13 6101.13 3604.86 591.15 5962340.87 540093.63 3604.72 27.29 7638.30 71.01 81.90 6217.80 6109.80 3609.32 614.55 5962345.45 540117.00 3616.43 21.45 7668.50 76.18 78.45 6226.32 6118.32 3614.28 643.08 5962350.55 540145.50 3630.24 20.32 7703.07 81.82 74.16 6232.92 6124.92 3622.32 676.03 5962358.77 540178.40 3648.39 20.36 7735.33 83.43 77.74 6237.06 6129.06 3630.08 707.06 5962366.69 540209.39 3665.66 12.08 7765.11 86.13 78.45 6239.77 6131.77 3636.20 736.07 5962372.96 540238.37 3680.73 9.37 7801.10 87.53 84.57 6241.76 6133.76 3641.50 771.60 5962378.45 540273.86 3697.11 17.42 7834.43 87.07 88.73 6243.33 6135.33 3643.44 804.83 5962380.57 540307.08 3709.57 12.54 7869.05 85.65 89.90 6245.53 6137.53 3643.86 839.37 5962381.16 540341.62 3721.01 5.31 7901.65 88.63 87.87 6247.16 6139.16 3644.49 871.92 5962381.97 540374.16 3732.01 11.06 7931.22 90.97 86.10 6247.26 6139.26 3646.05 901.45 5962383.68 540403.67 3742.92 9.92 7961.02 91.09 88.26 6246.73 6138.73 3647.51 931.20 5962385.30 540433.42 3753.82 7.26 7991.36 91.22 91.73 6246.11 6138.11 3647.52 961.53 5962385.46 540463.74 3763.52 11.44 8034.38 88.91 97.24 6246.07 6138.07 3644.15 1004.40 5962382.33 540506.63 3774.03 13.89 8064.64 90.41 103.36 6246.25 6138.25 3638.74 1034.16 5962377.08 540536.41 3778.42 20.82 8098.40 90.02 101.06 6246.12 6138.12 3631.61 1067.15 5962370.11 540569.43 3782.20 6.91 8134.08 89.95 96.82 6246.13 6138.13 3626.06 1102.39 5962364.75 540604.70 3788.21 11.89 8172.28 88.57 90.33 6246.62 6138.62 3623.68 1140.49 5962362.57 540642.81 3798.13 17.37 8210.73 88.48 85.35 6247.61 6139.61 3625.13 1178.89 5962364.22 540681.19 3811.77 12.95 8256.00 88.48 85.35 6248.81 6140.81 3628.80 1223.99 5962368.13 540726.27 3829.67 0.00 +. . 10/1/2004 (1F-18f1F~18AL Date· Survey: MWO Created By: Brij Potnis Azimuths to True North Magnetic North: 24.560 T LEGEND 1F-18, 1F-18Al1,Pia1 #5 1F.1S¡1F-18) 1F-1S 1F-18A 1F-iS 1F-18AL1PBI 1F-18AL1 MWD ConocoPhilUps Alaska, Inc. -WELLPATH DETAILS ·---c:onocciPhillips 3:09 PM 10/1/2001 1400 1800 1900 2000 2100 2200 VeriicalSectiøn at 87.00° [100ft/in) 1F-18AL1 5002922654611 Parent Wellpath: IF-18AL IPBI Tie on MD: 8051.44 Rig; Nordic 2 Ref. Datum: IF-18 RKB 108.0Oft V.Section Origin Origin Starting Angle 'NI-S <EI·W From TVO 87.000 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate ~E¡ Reference: Well Cenlre: 1F-18, True North Vertical ( D Reference: System: Mean Sea Level Sectíon (VS) Reference: Slot - (O.OON,O.OOE) Measured DeþthReference: 1F-18 RKB 108.00 Calculation Method: Minimum GUIVature rAA<'Æ'fDETA!l$ wo +NI>$ #i.i·W $.~¡¡¡X: . . .;'~. ConocoPhillips Alaska, Inc. 1F-18AL 1 API: 500292265460 SSSV Type: NIPPLE \ . . NIP (499-500, 00:3.500) lUBING (0-7000, 00:3.500, 10:2.992) SURFACE (0-4254, 00:7.625, Wt:29.70) 'ROOUCTION (0-7208, 00:5.500, Wt:15.5O) Gas Lift MandreWal... 3 (5577-5578, Gas Lift MandreWaI... 4 (6303-6304, Gas Lift MandreINal... 5 (6930-6931, NIP (6978-6979, 00:3.500) PBR (6986-6987, 00:3.500) PACKER (6999-7000, 00:3.500) SLEEVE (7254-7255, 00:2.700) WINoow ... (7399-7410. 00:7.625) Pert (7257-9036) . KRU Well Type: PROD Orig 9/30/2004 Completion: Last W/O: Annular Fluid: Reference Log: Last Tag: Last Tag Date: Ref Log Date: TD: 9080 ftKB Max Hole 0 deg @ Angle: Cäslngstdl'\{I~CQMMQNSTRINGS Description Size CONDUCTOR 16.000 SURFACE 7.625 PRODUCTION 5.500 WINDOW 7.625 Casing :stdnd-L.INERLEG Al.1 Description I Size LINER LEG AL 1 2.375 TUblngSttlng~ TUSING Size I Top I Bottom 3.500 0 7000 PiI'fOrätlöl'\s:Suitii'i1áiY Interval I TVD I Zone 7257 - 9036 7257 - 9036 Gås··I..IftMål'ldtèlSJVälVes St MD TVD Man Man Type V Mfr Mfr 1 2463 2463 BST AXT 2 4343 4343 BST AXT 3 5577 5577 BST AXT 4 6303 6303 BST AXT 5 6930 6930 BST AXT Othèr(pIOgs.eqI.llÞ;;etc;)·.·~··.COMMON..JEWELRY Depth TVD Type 499 499 NIP 6978 6978 NIP 6986 6986 PBR 6999 6999 PACKER 7254 7254 SLEEVE GéßêrälNötéS Date I Note 9/29/2004 CTD DUAL SIDETRACK - LEG AL 1 Bottom TVD Wt 121 121 62.50 4254 4254 29.70 7208 7208 15.50 7410 7410 0.00 Bottom TVD Wt 9080 9080 4.70 Top o o o 7399 Top 7253 1F-18AL 1 Angle @ TS: deg @ Angle @ TD: deg @ 9144 Rev Reason: CTD SIDETRACK LEG AL1, GLV design Last Update: 10/2212004 Grade Thread Grade I Thread L-80 STL TVD Wt I Grade I Thread 7000 9.30 L-80 ABM-EUE 1 Status 1Ft I SPF r Date I Type I Comment 1779 8 9/2512004 IPERF ~IeS every 3". V Type VOD Latch GLV 1.0 T-1 GLV 1.0 T-1 GLV 1.0 T-1 GLV 1.0 T-1 OV 1.0 T-1 Description Port TRO Date VIv Run Cmnt 0.125 1261 1013/2004 0.156 1295 10/3/2004 0.188 1330 10/3/2004 0.250 1430 1013/2004 0.250 0 10/3/2004 CAMCO 'DS' NIPLE CAMCO 'D' NO GO NIPPLE BAKER PBR BAKER SABL-3 LINER PACKER BAKER DEPLOYMENT SUB FROM MAIN LEG TO LATERAL LEG AL1 ID 2.813 2.850 3.000 3.000 1.875 . . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OILAlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk IF-18ALl ConocoPhillips Alaska, Inc. Permit No: 204-168 Surface Location: 792' SNL, 455' WEL, SEC. 19, TlIN, RIOE, UM Bottomhole Location: 2839' NSL, 2222' EWL, SEe. 17, TlIN, RIOE, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new wellbore segment of existing well KRU 1 F -18A, Permit No 204-167, API 50-029-22654-01. Production should continue to be reported as a function of the original API number stated above. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips Alaska, Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). BY ORDER g¡ THE COMMISSION DATED thisL day of September, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. £'t~ RECEIVEO( AUG 2 72004 . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory II Dev~ØIJi& tiI"~tiømmiSs on o Stratigraphic Test 0 Service 0 Development Gas AhJ:~IffiJ§¡one 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 59-52-180 KUP 1F-18AL 1 6. Proposed Depth: , 12. Field / Pool(s): MD 9800' TVD 6178ss Kuparuk River 7. Property Designation: ADL 025652 13. Approximate Spud Date: September 10, 2004 14. Distance to Nearest Property: 34,500' o Drill II Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): &~œ: . 792' SNL, 455' WEL, SEC. 19, T11 N, R10E, UM / Top of Productive Horizon: 2693' NSL, 20' EWL, SEC. 17, T11N, R10E, UM Total Depth: 2839' NSL, 2222' EWL, SEC. 17, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539521 .- y- 5958733 ' Zone- ASP4 16. Deviated Wells: Kickoff Depth: 7475 ' feet Maximum Hole Angle: 90 degrees 8. Land Use Permit: 9. Acres in Property: 2560 10. KB Elevation 15. Distance to Nearest Well Within Pool (HeightaboveGL): 118' feet 975't01F-13 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3200' Surface: 2583· 18. Casing Program: Size Hole Casing 3" 2-3/8" Grade Coupling Length MD TVD MD TVD (including stage data) L-80 STL 2500' 7300' 5891' 9800' 6178 Uncemented Slotted Liner Weight 4.6# P8E~ENTWFLL·CONDITIQN. ~I.JMMARY (TQ be··compløt!:!c!forRec!rill~NP8è+ân~QPØtªtiØ'\$) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): I Effective Depth TVD 7939 6545 None 7838 6456 Structural Conductor 121' 16" 230 sx Arcticset I 121' 121' Surface 4254 7-5/8" 710 sx AS III, 330 sx Class 'G' 4254' 3730' Intermediate 7208' 5-1/2" 70 sx Class 'G' 7208' 5940' Production Liner 929' 3-1/2" 99 sx Class 'G' 7000' - 7929' 5785' - 6536' Liner 2350' 2-3/8" Uncemented Slotted Liner 7450' - 9800' 6014' - 5993' IPerfOration Depth TVD (ft): 6076' - 6265' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements Perforation Depth MD (ft): 7387' - 7620' 20. Attachments 0 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Dan Title CT Drilling Engineer Date: Contact Dan Kara, 564-5667 Phone 564-5667 Permit To Drill I I API Number: Permit Approval Number: ;2Dï -/{'8 50- 029-22654-60-00 Date: Conditions of Approval: Samples Required 0 Yes ~No Mud Log Required Hydrogen Sulfide Measures ~Yes 0 No Directional Survey Required ~~ ~\J\( \-~~ Co-c;. ~ \.ú..c-..-~8 ~ G \ N A· \ APPROVED BY o R \ .. . THE COMMISSION See cover letter for other requirements DYes l')(t'No ,KJ. Yes 0 No Date 'l /~{þ 'lub~ I: 6uplicate 'RU 1 F-18A & AL 1 Sidetrack - COile"Ubing Drilling Summary of Operations: J BP operated Coiled tubing drilling will sidetrack ConocoPhillips operated KRU well1F-18 using the dynamically overbalanced coiled tubing drilling (DOCTD) technique (see description below). These horizontal laterals (IF-18A & ALl) will target Kuparuk C Sand and A Sand reserves for production. The Kuparuk A Sand" perforations in the existing well will be isolated/abandoned with a CIBP. The window will be milled in the existing Kuparuk C Sand perforations.' ~ CTD Drill and Complete IF-18A & ALl pr02ram: Planned for September 10.2004 1. Pre CTD install cast iron bridge plug at 7450' MD to isolate/abandon A Sand perfs. 2. MIRU Nordic 2. NU 7-1/16" BOPE, test 3. CTD install mechanical WS at 7395' MD 4. Mill 2.74" window at 7395' md and 10' of openhole. 5. Drill 3" bicenter hole horizontal sidetrack 1F-18A to -9800' TD targeting Kuparuk C4 Sands. 6. Run and drop ¡¡ 2-3/8" pre-drilled liner from TD of 9800' , up to -7450' md. 7. Openhole sidetrack at 7450' from the IF-18A wellbore, above the 2-3/8" liner. ----- 8. Drill 3" horizontal sidetrack 1F-18ALl from open-hole side track to -9800' TD targeting Kuparuk A4 '" sand interval. 9. Complete with 2 3/8" pre-drilled liner from the TD of ALl at 9800', up into the 3-112" liner to -7300'. 10. Post CTD; Run GL V s. Bring on production. '" Th\~ o..~ \' \0...., c.... \ Mud Program: · Potassium-Formate based Flo-Pro (8.8 ppg) .; r ~ ~,\o VI Disposal: · No annular injection on this well.' · Class IT liquids to KRU lR Pad Class IT disposal well · Class IT drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · IF-18A: 2-3/8",4.6#, L-80, STL pre-drilled from 9800' md -7450' md · IF-18AL1: 2-3/8",4.6#, L-80, STL pre-drilled from 98()()' md - 7300' md Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for IF-18A & ALl ' · Magnetic and inclination surveys will be taken every 30 ft No gyro will be run. /' Logging · A Gamma Ray log will be run over all of the open hole section. ~ · Memory resistivity logs may be recorded if hole conditions warrant, MAD pass only. Kara 564-5667 office, 240-8047 cell 1/3 'RU 1F-18A & AL1 Sidetrack - COile~bing Drilling Hazards . Several small (10-15') faults in the direction of the well,gath; lost circulation risk is low, especially while DOCTD. Reservoir pressure is estimated to be 10 ppg. Well1F-18 has a H2S reading of 21 ppm (measured 10/13/03). The highest H2S on IF pad was measured at 65 ppm. IF is classified as an H2S ... pad. All H2S monitoring equipment will be operational. Reservoir Pressure " . Reservoir pressure was measured at 3200 psi at 6165' TVD 10 ppg EMW on 8/19/2004. Max. surface pressure with gas (0.1 psi/ft) to surface is 2583 psi. - Dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high" reservoir pressure and high circulating pressures. Plans are to use 8.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BRA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2" rams, see attached BOP configuration), and/or the tested tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. At least two times wellbore volume of kill weight fluid will be on location as a contingency. ~" Measured reservoir pressure: 3200 psi at 6165' TVD, 10 ppg EMW. Expected annular friction losses while circulating (ECD): 700 psi Planned mud density: 8.8 ppg equates to 2825 psi hydrostatic bottom hole pressure. While circulating 8.8 ppg fluid, bottom hole circulating pressure is estimated to be 3525 psi, or 11 ppg EMW When circulation is stopped, a minimum of 700 psi surface pressure will be applied to maintain the reservoir ". at 11 ppg EMW. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling. Kara 564-5667 office, 240-8047 cell 2/3 'RU 1 F-18A & AL 1 Sidetrack - COile~bing Drilling Kuparuk IF-18A & ALl Potential Drilling Hazards POST ON RIG 1. Please perfonn pre-job Hazard ill and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. ,¡ 2. H2S - Well1F-18 has a H2S reading of 21 ppm (measured 10/13/03). The highest H2S on IF pad was measured at 65 ppm. IF is classified as an H2S pad. All H2S monitoring equipment will be '" operational. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in the pit area. 3. Reservoir pressure - Reservoir pressure was measured at 3200 psi at 6165' TVD 10 ppg EMW on 8/19/2004. Max. surface pressure with gas (0.1 psi/ft) to surface is 2583 psi. Reservoir frac gradient is -0.7 psi/ft or 13.5 EMW, 4315 psi. ' 4. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used. Drilling will be done with a less than kill-weight fluid (8.8 ppg FIo-Pro). While drilling and circulating, hydrostatic head from the 8.8 ppg mud (2825 psi), plus 700 psi of annular friction, plus 0 psi choked backpressure held on the return side will provide a 3525 psi BHP and overbalance the reservoir by -300 psi. However, when circulation is shut down, the reservoir could be·,i underbalanced by 400 psi. Maintain at least 700psi WHP when not circulating to prevent reservoir in-flux and to maintain fonnation stability by keeping static BHP close to circulating BHP seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole PWD sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return-line flow rate and pit volume continuously. If a pit gain has been identified (underbalance event occurred), divert those returns to an outside tank. 5. No gas saturated intervals are expected. However, always be prepared for the potential for gas - influx. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit volume continuously. 6. Lost circulation is not expected. Several small faults will be encountered along the wellbore trajectory. The faults should not be sealing and lost circulation is considered low risk. If lost circulation occurs plan to control it with adjustments to the DOCTD parameters. Lower circulation rate would be utilized prior to LCM treatments. However, as a contingency ensure that LCM material is on location so that a pill could be mixed quickly if required. Kara 564-5667 office, 240-8047 cell 3/3 NIP (499-500, 00:3.500) TUBING (0·7000, 00:3.500. 10:2.992) Gas Lift MandrelNalve 1 (2463·2464, GasUft MandrelNalve 2 (4343-4344, Gas Lift MandrelNalve 3 (5577-5578, Gas Lift MandrelNalve 4 (6303-6304, Gas Lift - MandrelNalve 5 (6930-6931, NIP (6978-6979, 00:3.500) PBR (6986-6987, 00:3.500) PKR (6999-7000, 00:3.500) PROD. CASING (0-7208, 00:5.500, Wt:15.50) Perf (7585-7620) IIIIIIIIIIIII KRU 1F..18 ConocoPhillips Alaska, Inc. U::-18 API: 500292265400 SSSVType: Nipple Well Type: PROD Ong 3/8/1996 Completion: Last W/O: An¡:¡le ({i) TS: 39 deg ({i) 7375 Angle @ TO: 27 deg @ 7939 Rev Reason: Tag till, reeovered ROCKS Last Update: 3/512004 Annular Fluid: Reference Log: Last Te¡:¡: 5350' SLM 1/112004 1 Ref Log Data: TD: 7928 ftKB I Max Hole Angle: 45 deg ({i) 4900 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H40 SUR. CASING 7.625 0 4254 3730 29.70 L-80 PROD. CASING 5.500 0 7208 5940 15.50 L-80 LINER 3.500 7928 7928 9.30 L-80 Tubing String - TUBING I Size \ Top Bottom TVD Wt Grade Thread 3.500 0 7000 5785 9.30 L-80 A8M-EUE Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 7387 - 7402 6076 - 6088 C4 15 4 11/25/1999 APERF 2 1/8" Eneljet, 0 deg phase, Onent 0 deg from low side 7585 - 7620 5235 - 5255 A-4 35 4 5/30/1996 IPERF 180 deg Ph; 20 deg CCW I anent, 2.5" Hollow Case Gasl.ift MancfrelsNalves St I MD TVD Man Man Type II V Mfr Mfr 1 2453 2385 BST AXT I 2 4343 3794 BST AXf I 3 5577\ 4689 BST AXf I 4 6303 5249 8ST AXf 5 6930 I 5732 BST I AXf Other (plugs, equip,. ete,) . JEWELRY Depth TVD' Type ! 499 499 NIP I Cameo 'DS' 5978 5768 NIP Cameo 'D' Nipple NO GO 6986 5774 P8R Baker 6999 5784 PKR [Saker SABL-3 Liner Packer (Stabbed into 3112" Csç¡) General Notes Date I Note 712212001 Ta¡¡ged obstruction @7551' SLM, appears to be something solid (metal). Lostjar action @7553' SLM 10/17/2001 VIDEO LOG SHOWED COLLAPSED LINER @7560' RKB I V Type GLV GLV GLV GLV OV Port I TRO I Date . , Run 0.125 1301 11112912003 0.156 1331 11/29/2003 0.156 1320 11/29/2003 0.063 1342 11/29/2003 0.188, 0 11/2912003 Vlv Cmnt VOD Latch 1.0 1.0 1.0 1.0 1.0 T-1 T-1 T-1 T-1 T-1 Description ID 2.813 2.750 3.000 3.000 . KRU 1 F-18A & 1 F-18AL 1 Producer Proposed CrD Sidetracks I' U 7-5/S" 29.7# L-SO casing @ 425£-1 3.5" liner top @ 7000' MD 2·3/8" liner top @ +1-7300' MD Top of Whipstock +1-7395' MD C4-Sand CIBP plug set - +/-7450' MD Fill cleaned out toJ 7540' RKB Liner collapsed @ 7560' A4-Sand 3.5" 9.3# L-SO @ 792S' MD ... . eonocó'Phillips Alaska Inc. l G. Cameo DS Nipple at 499' MD, 2.S13" ID F. 3-1/2' 9.3# L-80 tubing wI 3-1/2" x 1" BST 'AXT'mandrels B. 3-W Cameo D nipple with 2.75" ID at 6978' MD (may be milled out to 2.80" for CTD bits) C. Baker 3-1/2' SABL-3 Liner packer at 6999' MD with PBRlseal assembly A. 3-1/2" tubing tail at 7000' MD (stung into 3-1/2" liner) Window in 3.5" 3" open hole Open hole KOP @ 7450' md off wfd alum kick off tool 1F-18A, TD @ 9800' md 00000000000000) o 0 ~ o °00 0 0 0 0 0 0 01 0000000' 2-3/S" pre-drilled liner Lateral (1F-1SAL 1), TD @ 9800' md I T LEGEND 1~=~g f~¡;~:11F-1€A) P!an#21F-18Al1 P!an#2 Plan: Plan #2 (1F-1BJP!an#2 1F-18Al1) Azimuths to True North Magnetic North: 24,58° Date: 8/26/2004 WELLPATH -DETAJt..s PJIiIII#Z.1F484,L1 SOOU2t354$& ConocoPhUlips Alaska, Inc. ConocciPnillips Contact information' "area! W.llpilÜt¡ Tk>"IIM~ Pbmti21F~18A 1415.00 ""', Ref. Datui'll! V.hl:tloa ...... 87.6Q' ........ 1r:·URKe ~= t¡~= 0.00 0.(10 10t.oOtt :~ .... REFERENCE INFORMATION Cú-ordìnate (NJE) Reference: Well Centre: 1F-18, True North Vertlca! (TVD) Reference: skstem: Mean Sea Level Mea~~â~r6 ~:~:~~~:~ fþ:\š ~~N.O,~~~oo Calculation Method: Minimum Curvature $£CTJON ÞeTAU .... MO ,~ TV' ..'" .Wo. TI'~. 1'41-5.00 4&.77 1'&.34- S$e9At4 ~."2ð ,w"", ~.. ... """,'" 1'471t.OO ".'71 n,n ....... :35\H,3!: 487.21 .." .... "..., 7üf..ØCl 44.:11 ..... ........ ...."'. ...... ..,.. ,..... ...... 71(13,.$1 90.00 ",,," $127.29 $f!~7& ...... ..... ..... $14.$5 n&~37 iIIh!:ID 1'$." fl121'.:t$ 37'ii.tt fimM~$ ..... ..... ...,,. 1i003.1I7 øo.ØG 105."$4 !J1Z7,," "'''''... $iO,01' ,.... ..... 1-108,&3 $":ulð? -8'1.17 121U;7 81.10.39 :)$$1..4Q 1.03:0.51 ..,.. 10-1.(10 12M-53 . U.%IU7 _60- ..... *1141.42 3594.3. ~:1::~ 1<tJIO ...... 1404,..1'1 ~1}7 $$.20 .."" $161.$$ -... 1-Z>00 2n.7U 1&~." 1U ./1&03.87 M.U 1HAT $1$'1.fW 3$i-$.9:7 17-8:1.4$ 12;-00 00,00 19&&.3-1 " 9z«te:r &9.15 u"', $1M.&1 ........ 2075.& ;2.,00 VQ.4Ø: .\1:261.31$ 12 ~$t ".24 1)¡!.S'f 611t,Q3 ~.~o ~,7.e ,,,.. ..... ........ 1:1 9ß7A87 M.:7$ 7-2&7 $17""" 3&11.33' ,....'" 12.-00 2$&..00 2731.19 14 93OI).W -$S.ð3 "'.., i!l117.U $$;J2.4¡t ....... 12,00 ..... ~1.o!l ANNO'fATIQN$ Jþ fltD AAMtation TARG€fP¡;Ti\/!,$ TOU 0'" 0.00 ggg SI1apa SOOI}-, 5101} 5200 .... c: S300 ~ 5401}~¡ Q ~5S00 .c: 1.5600 ~ a 5700 1i U 580cr t! ~ S901}- :> ~ 6000-, i! .... 6100- Created By: Brij Potnis ...-.4400 c: ~4201} ~ 4000 - +3800 - .c: 1:: 3600 o ~ 3400 -. .- . - .c: 320 .... ::; : 3000 2800 1000 1400 1000 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 West{-)fEast(+) [100ft/in] 200 300 400 500 600 700 800 900 1000 11001200 1300 1400 1500 1600 1700 1800 19002000210022002300 24D0 2500 2600 2700 2800 2900 3000 3100 3200 3300 34D0 3S00 3600 3700 3800 3900 4000 4100 Venical Section at 87.00' [100ft/in] AM . . -- ..... INTB.Q BP-GDB Baker Hughes INTEQ Planning Report I Field: Kuparuk River Unit North Slope I UNITED STATES II Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) ~_~atum: ~e_an Sea Level _ ______ Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 - . ..~_.,---~~-_.-.--! --~ I _.,---------~- Site: KRU 1 F Pad North Slope Site Position: From: Map Position Uncertainty: Ground Level: Northing: 5958733.30 ft Easting: 539521.50 ft Latitude: 70 17 Longitude: 149 40 North Reference: Grid Convergence: 53.527 N 47.811 W True 0.30 deg 0.00 ft 0.00 ft ~~-~--- -~-~ --- -~_.- -------~--- ~] 1F-18 1F-18 Well Position: Well: Slot Name: +N/-S +E/-W Position Uncertainty: 0.00 ft Northing: 0.00 ft Easting: 0.00 ft 5958733.30 ft' Latitude: 70 17 53.527 N 539521.50 ft Longitude: 149 40 47.811 W -~-- ~-~-~.~- ~-~~.,~-- -- ~--~'~------. Wellpath: Plan#2 1 F-18AL 1 500292265460 Current Datum: 1F-18 RKB Magnetic Data: 8/26/2004 Field Strength: 57566 nT Vertical Section: Depth From (TVO) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Plan#2 1 F-18A 7415.00 ft Mean Sea Level 24.58 deg 80.73 deg Direction deg 87.00 Height 108.00 ft Targets 1F-18AL1 Fault 1 0.00 3823.62 1047.72 5962562.00 540549.00 70 18 31.132 N 149 40 17.254 W -Polygon 1 0.00 3823.62 1047.72 5962562.00 540549.00 70 1831.132N 149 40 17.254 W -Polygon 2 0.00 3664.72 1024.89 5962403.00 540527.00 70 18 29.569 N 149 40 17.921 W -Polygon 3 0.00 3470.80 1004.86 5962209.00 540508.00 70 18 27.662 N 149 40 18.506 W -Polygon 4 0.00 3664.72 1024.89 5962403.00 540527.00 70 1829.569 N 149 40 17.921 W 1F-18AL1 Fault 2 0.00 3792.63 1425.60 5962533.00 540927.00 70 18 30.826 N 149 40 6.233 W -Polygon 1 0.00 3792.63 1425.60 5962533.00 540927.00 70 18 30.826 N 149 40 6.233 W -Polygon 2 0.00 3622.21 1501.72 5962363.00 541004.00 70 1829.150 N 149 40 4.015 W -Polygon 3 0.00 3339.09 1709.25 5962081.00 541213.00 70 18 26.365 N 149 39 57.964 W -Polygon 4 0.00 3622.21 1501.72 5962363.00 541004.00 70 1829.150 N 149 40 4.015 W 1F-18AL 1 Fault 3 0.00 3797.62 1997.69 5962541.00 541499.00 70 18 30.874 N 149 3949.548 W -Polygon 1 0.00 3797.62 1997.69 5962541.00 541499.00 70 18 30.874 N 149 39 49.548 W -Polygon 2 0.00 3587.88 2323.63 5962333.00 541826.00 70 18 28.811 N 149 39 40.044 W -Polygon 3 0.00 3326.68 2547.28 5962073.00 542051.00 70 18 26.241 N 149 3933.524 W -Polygon 4 0.00 3587.88 2323.63 5962333.00 541826.00 70 18 28.811 N 149 39 40.044 W 1 F-18AL1 Polygon2.1 0.00 3697.31 533.00 5962433.00 540035.00 70 18 29.890 N 149 40 32.266 W -Polygon 1 0.00 3697.31 533.00 5962433.00 540035.00 70 18 29.890 N 149 4032.266 W -Polygon 2 0.00 3823.62 1047.72 5962562.00 540549.00 70 1831.132N 149 40 17.254 W -Polygon 3 0.00 3792.63 1425.60 5962533.00 540927.00 70 18 30.826 N 149 40 6.233 W -Polygon 4 0.00 3797.62 1997.69 5962541.00 541499.00 70 18 30.874 N 149 3949.548 W -Polygon 5 0.00 3812.21 3216.91 5962562.00 542718.00 70 18 31.014 N 149 39 13.989 W -Polygon 6 0.00 3335.02 3243.40 5962085.00 542747.00 70 18 26.320 N 149 39 13.223 W -Polygon 7 0.00 3326.68 2547.28 5962073.00 542051.00 70 18 26.241 N 149 39 33.524 W -Polygon 8 0.00 3339.09 1709.25 5962081.00 541213.00 70 18 26.365 N 149 39 57.964 W -Polygon 9 0.00 3470.80 1004.86 5962209.00 540508.00 70 18 27.662 N 149 40 18.506 W -Polygon 10 0.00 3588.95 599.44 5962325.00 540102.00 70 1828.824 N 149 40 30.329 W I --1 . BP-GDB Baker Hughes INTEQ Planning Report . ..E tt'{'rB;Q Annotation 7415.00 5989.80 TIP 7475.00 6028.09 KOP 7525.00 6058.64 3 7703.87 6127.29 4 7753.87 6127.29 end 30 DLS I begin 12 DLS 8003.87 6127.29 6 8128.87 6130.39 7 8328.87 6141.42 8 8553.87 6151.83 9 8903.87 6161.89 10 I r03·" .'.7.82 11 9428.87 6171.03 12 9678.87 6175.41 13 9800.00 6177.93 TD ---~ --~ b~- - l Plan: Plan #2 Date Composed: 8/26/2004 Identical to Lamar's Plan #2 Version: 3 Principal: Yes Tied-to: From: Definitive Path ~ -- ~ ~ ~--~-~ Plan Section Information 7415.00 40.77 16.34 5989.80 3509.28 469.21 0.00 0.00 0.00 0.00 7475.00 59.71 28.32 6028.09 3551.36 487.21 35.01 31.57 19.97 30.01 7525.00 44.71 28.32 6058.64 3586.04 505.91 30.00 -30.00 0.00 180.00 7703.87 90.00 60.94 6127.29 3692.79 622.58 30.00 25.32 18.23 42.00 7753.87 90.00 75.94 6127.29 3711.12 668.95 30.00 0.00 30.00 90.00 8003.87 90.00 105.94 6127.29 3707.09 916.07 12.00 0.00 12.00 90.00 8128.87 87.17 120.67 6130.39 3657.80 1030.51 12.00 -2.26 11.79 101.00 8328.87 86.60 96.64 6141.42 3594.38 1218.33 12.00 -0.28 -12.01 268.00 8553.87 88.20 69.66 6151.83 3620.96 1439.41 12.00 0.71 -11.99 272.70 8903.87 88.66 111.67 6161.89 3616.97 1781.46 12.00 0.13 12.00 90.00 9203.87 89.15 75.67 6167.81 3598.08 2075.88 12.00 0.16 -12.00 270.40 9428.87 89.24 102.67 6171.03 3601.30 2298.76 12.00 0.04 12.00 90.00 9678.87 88.79 72.67 6175.41 3611.33 2545.67 12.00 -0.18 -12.00 268.90 9800.00 88.83 87.21 6177.93 3632.42 2664.60 12.00 0.03 12.00 90.00 Survey 16.34 5989.80 3509.28 469.21 5962244.66 539972.21 652.23 0.00 TIP 18.87 5997.20 3515.69 471.25 5962251.08 539974.21 654.60 35.01 MWD 24.11 6014.00 3532.87 478.07 5962268.29 539980.94 662.31 35.01 MWD 28.32 6028.09 3551.36 487.21 5962286.82 539989.99 672.41 35.01 KOP - 28.32 6042.07 3569.58 497.04 5962305.09 539999.71 683.17 30.00 MWD 7525.00 44.71 28.32 6058.64 3586.04 505.91 5962321.60 540008.49 692.89 30.00 180.00 3 7550.00 50.48 34.82 6075.50 3601.72 515.60 5962337.33 540018.10 703.39 30.00 42.00 MWD 7575.00 56.55 40.30 6090.36 3617.61 527.87 5962353.28 540030.28 716.48 30.00 37.61 MWD 7600.00 62.84 45.05 6102.98 3633.45 542.50 5962369.19 540044.84 731.92 30.00 34.34 MWD 7625.00 69.26 49.28 6113.12 3648.95 559.26 5962384.79 540061.51 749.46 30.00 31.94 MWD 7650.00 75.79 53.17 6120.63 3663.87 577.84 5962399.79 540080.01 768.80 30.00 30.22 MWD 7675.00 82.37 56.83 6125.37 3677.93 597.94 5962413.96 540100.04 789.61 30.00 29.05 MWD 7700.00 88.98 60.39 6127.25 3690.90 619.21 5962427.04 540121.23 811.53 30.00 28.36 MWD 7703.87 90.00 60.94 6127.29 3692.79 622.58 5962428.95 540124.59 814.99 30.00 28.09 4 7725.00 90.00 67.28 6127.29 3702.02 641.58 5962438.28 540143.54 834.45 30.00 90.00 MWD 7750.00 90.00 74.78 6127.29 3710.14 665.21 5962446.52 540167.12 858.47 30.00 90.00 MWD 7753.87 90.00 75.94 6127.29 3711.12 668.95 5962447.52 540170.86 862.25 30.00 90.00 end 30 D 7775.00 90.00 78.47 6127.29 3715.80 689.55 5962452.31 540191.44 883.08 12.00 90.00 MWD 7800.00 90.00 81.47 6127.29 3720.15 714.17 5962456.79 540216.03 907.89 12.00 90.00 MWD ---~------- . BP-GDB Baker Hughes INTEQ Planning Report . ..w: INTEQ Survey 7825.00 90.00 84.47 6127.29 3723.21 738.98 5962459.98 540240.82 932.82 12.00 90.00 MWD 7850.00 90.00 87.47 6127.29 3724.97 763.91 5962461.87 540265.74 957.82 12.00 90.00 MWD 7875.00 90.00 90.47 6127.29 3725.42 788.91 5962462.45 540290.73 982.80 12.00 90.00 MWD 7900.00 90.00 93.47 6127.29 3724.56 813.89 5962461.72 540315.71 1007.70 12.00 90.00 MWD 7925.00 90.00 96.47 6127.29 3722.39 838.79 5962459.68 540340.62 1032.46 12.00 90.00 MWD 7950.00 90.00 99.47 6127.29 3718.92 863.55 5962456.35 540365.40 1057.00 12.00 90.00 MWD 7975.00 90.00 102.47 6127.29 3714.17 888.09 5962451.72 540389.96 1081.26 12.00 90.00 MWD 8000.00 90.00 105.47 6127.29 3708.13 912.35 5962445.81 540414.25 1105.17 12.00 90.00 MWD 8003.87 90.00 105.94 6127.29 3707.09 916.07 5962444.79 540417.97 1108.83 12.00 90.00 6 8025.00 89.52 108.42 6127.38 3700.84 936.26 5962438.65 540438.19 1128.66 12.00 101.00 MWD 8050.00 88.95 111.37 6127.71 3692.34 959.76 5962430.27 540461.74 1151.69 12.00 100.99 MWD 8075.00 88.38 114.32 6128.30 3682.64 982.79 5962420.69 540484.82 1174.18 12.00 100.95 MWD 8100.00 87.81 117.26 6129.13 3671.77 1005.29 5962409.94 540507.36 1196.07 12.00 100.88 MWD 8125.00 87.25 120.22 6130.20 3659.76 1027.18 5962398.05 540529.32 1217.31 12.00 100.78 MWD 8128.87 87.17 120.67 6130.39 3657.80 1030.51 5962396.11 540532.66 1220.53 12.00 100.66 7 8150.00 87.08 118.13 6131.45 3647.44 1048.90 5962385.85 540551.10 1238.35 12.00 268.00 MWD 8175.00 86.99 115.13 6132.74 3636.25 1071.21 5962374.77 540573.47 1260.05 12.00 268.13 MWD 8200.00 86.90 112.13 6134.08 3626.24 1094.08 5962364.89 540596.39 1282.37 12.00 268.28 MWD 8225.00 86.83 109.12 6135.44 3617.45 1117.44 5962356.22 540619.80 1305.23 12.00 268.44 MWD 8250.00 86.76 106.12 6136.84 3609.89 1141.23 5962348.79 540643.62 1328.59 12.00 268.61 MWD 8275.00 86.70 103.12 6138.27 3603.60 1165.38 5962342.62 540667.80 1352.38 12.00 268.77 MWD 8300.00 86.65 100.11 6139.72 3598.57 1189.82 5962337.73 540692.27 1376.53 12.00 268.95 MWD 8325.00 86.61 97.11 6141.19 3594.84 1214.49 5962334.12 540716.96 1400.97 12.00 269.12 MWD 8328.87 86.60 96.64 6141.42 3594.38 1218.33 5962333.68 540720.79 1404.77 12.00 269.30 8 8350.00 86.72 94.10 6142.65 3592.40 1239.33 5962331.81 540741.80 1425.64 12.00 272.70 MWD 8375.00 86.88 91.10 6144.05 3591.27 1264.26 5962330.81 540766.74 1450.48 12.00 272.85 MWD 8400.00 87.04 88.10 6145.38 3591.44 1289.22 5962331.12 540791.69 1475.42 12.00 273.02 MWD 8425.00 87.21 85.11 6146.63 3592.92 1314.15 5962332.72 540816.60 1500.38 12.00 273.17 MWD 8450.00 87.39 82.11 6147.81 3595.70 1338.96 5962335.64 540841.40 1525.31 12.00 273.33 MWD 8475.00 87.57 79.11 6148.91 3599.77 1363.60 5962339.84 540866.02 1550.13 12.00 273.47 MWD 8500.00 87.76 76.11 6149.93 3605.13 1387.99 5962345.33 540890.38 1574.77 12.00 273.60 MWD 8525.00 87.96 73.12 6150.86 3611.76 1412.08 5962352.08 540914.43 1599.17 12.00 273.72 MWD 8550.00 88.16 70.12 6151.70 3619.64 1435.79 5962360.08 540938.09 1623.25 12.00 273.83 MWD 8553.87 88.20 69.66 6151.83 3620.96 1439.41 5962361.43 540941.71 1626.95 12.00 273.93 9 8575.00 88.20 72.20 6152.49 3627.87 1459.38 5962368.43 540961.64 1647.24 12.00 90.00 MWD 8600.00 88.20 75.20 6153.28 3634.88 1483.36 5962375.57 540985.58 1671.56 12.00 89.92 MWD 8625.00 88.22 78.20 6154.06 3640.63 1507.67 5962381.45 541009.86 1696.14 12.00 89.83 MWD 8650.00 88.23 81.20 6154.83 3645.09 1532.25 5962386.04 541034.41 1720.92 12.00 89.73 MWD 8675.00 88.25 84.20 6155.60 3648.27 1557.04 5962389.35 541059.18 1745.84 12.00 89.64 MWD 8700.00 88.28 87.20 6156.36 3650.14 1581.95 5962391.35 541084.08 1770.82 12.00 89.55 MWD 8725.00 88.31 90.21 6157.10 3650.70 1606.93 5962392.04 541109.06 1795.79 12.00 89.46 MWD 8750.00 88.35 93.21 6157.83 3649.96 1631.91 5962391.43 541134.03 1820.70 12.00 89.37 MWD 8775.00 88.39 96.21 6158.54 3647.91 1656.81 5962389.51 541158.94 1845.46 12.00 89.28 MWD 8800.00 88.43 99.21 6159.24 3644.56 1681.57 5962386.29 541183.72 1870.01 12.00 89.19 MWD 8825.00 88.48 102.21 6159.91 3639.91 1706.13 5962381.78 541208.29 1894.29 12.00 89.11 MWD 8850.00 88.53 105.21 6160.56 3633.99 1730.40 5962375.98 541232.60 1918.22 12.00 89.03 MWD 8875.00 88.59 108.21 6161.19 3626.81 1754.34 5962368.93 541256.57 1941.74 12.00 88.95 MWD I 8900.00 88.65 111.21 6161.79 3618.38 1777.86 5962360.62 541280.13 1964.80 12.00 88.88 ~owu 8903.87 88.66 111.67 6161.89 3616.97 1781.46 5962359.23 541283.74 1968.31 12.00 88.80 8925.00 88.68 109.14 6162.38 3609.60 1801.26 5962351.97 541303.58 1987.70 12.00 270.40 MWD 8950.00 88.70 106.14 6162.95 3602.03 1825.08 5962344.52 541327.43 2011.09 12.00 270.46 MWD 8975.00 88.73 103.14 6163.51 3595.71 1849.26 5962338.33 541351.64 2034.91 12.00 270.53 MWD l_~_~_~ --~~ ---~~~--- . BP-GDB Baker Hughes INTEQ Planning Report . ..I: INTßQ 9000.00 88.77 100.14 6164.05 3590.67 1873.73 5962333.42 541376.14 2059.09 12.00 270.59 MWD 9025.00 88.80 97.14 6164.58 3586.92 1898.44 5962329.80 541400.87 2083.56 12.00 270.66 MWD 9050.00 88.84 94.13 6165.10 3584.47 1923.31 5962327.48 541425.75 2108.27 12.00 270.72 MWD 9075.00 88.88 91.13 6165.59 3583.32 1948.28 5962326.46 541450.72 2133.14 12.00 270.79 MWD 9100.00 88.93 88.13 6166.07 3583.48 1973.27 5962326.75 541475.71 2158.11 12.00 270.84 MWD 9125.00 88.98 85.13 6166.53 3584.94 1998.22 5962328.35 541500.64 2183.10 12.00 270.90 MWD 9150.00 89.03 82.13 6166.96 3587.72 2023.06 5962331.25 541525.47 2208.05 12.00 270.96 MWD 9175.00 89.08 79.13 6167.37 3591.78 2047.72 5962335.45 541550.10 2232.89 12.00 271.01 MWD 9200.00 89.14 76.13 6167.76 3597.14 2072.13 5962340.93 541574.49 2257.55 12.00 271.06 MWD 9203.87 89.15 75.67 6167.81 3598.08 2075.88 5962341.89 541578.23 2261.35 12.00 271.10 11 9225.00 89.15 78.21 6168.13 3602.85 2096.47 5962346.77 541598.79 2282.15 12.00 90.00 MWD 9250.00 89.15 81.21 6168.50 3607.32 2121.06 5962351.37 541623.35 2306.94 12.00 89.96 MWD 9275.00 89.16 84.21 6168.87 3610.49 2145.85 5962354.67 541648.13 2331.87 12.00 89.92 MWD 9300.00 89.17 87.21 6169.23 3612.36 2170.78 5962356.67 541673.04 2356.86 12.00 89.87 MWD 9325.00 89.18 90.21 6169.59 3612.92 2195.76 5962357.37 541698.02 2381.84 12.00 89.83 MWD 9350.00 89.19 93.21 6169.95 3612.18 2220.75 5962356.75 541723.00 2406.75 12.00 89.79 MWD 9375.00 89.20 96.21 6170.30 3610.13 2245.66 5962354.83 541747.92 2431.52 12.00 89.74 MWD 9400.00 89.22 99.21 6170.64 3606.77 2270.43 5962351.61 541772.71 2456.08 12.00 89.70 MWD 9425.00 89.24 102.21 6170.98 3602.13 2294.99 5962347.09 541797.29 2480.36 12.00 89.66 MWD 9428.87 89.24 102.67 6171.03 3601.30 2298.76 5962346.28 541801.07 2484.09 12.00 89.62 12 9450.00 89.20 100.14 6171.32 3597.12 2319.47 5962342.21 541821.80 2504.55 12.00 268.90 MWD 9475.00 89.14 97.14 6171.68 3593.37 2344.19 5962338.59 541846.53 2529.03 12.00 268.93 MWD 9500.00 89.09 94.14 6172.07 3590.91 2369.06 5962336.27 541871.41 2553.75 12.00 268.98 MWD 9525.00 89.04 91.14 6172.48 3589.76 2394.03 5962335.25 541896.38 2578.62 12.00 269.02 MWD 9550.00 88.99 88.14 6172.90 3589.92 2419.02 5962335.54 541921.37 2603.59 12.00 269.07 MWD 9575.00 88.95 85.14 6173.35 3591.38 2443.97 5962337.13 541946.31 2628.58 12.00 269.13 MWD 9600.00 88.91 82.14 6173.82 3594.15 2468.81 5962340.03 541971.13 2653.53 12.00 269.18 MWD 9625.00 88.87 79.14 6174.31 3598.22 2493.47 5962344.23 541995.77 2678.37 12.00 269.24 MWD 9650.00 88.83 76.14 6174.81 3603.57 2517.88 5962349.71 542020.15 2703.03 12.00 269.29 MWD 9675.00 88.80 73.14 6175.33 3610.19 2541.98 5962356.45 542044.21 2727.44 12.00 269.35 MWD 9678.87 88.79 72.67 6175.41 3611.33 2545.67 5962357.61 542047.90 2731.19 12.00 269.42 13 9700.00 88.80 75.21 6175.85 3617.17 2565.98 5962363.56 542068.17 2751.77 12.00 90.00 MWD 9725.00 88.80 78.21 6176.38 3622.92 2590.30 5962369.43 542092.46 2776.36 12.00 89.95 MWD 9750.00 88.81 81.21 6176.90 3627.38 2614.89 5962374.03 542117.02 2801.15 12.00 89.88 MWD 9775.00 88.82 84.21 6177.42 3630.55 2639.68 5962377.33 542141.79 2826.07 12.00 89.82 MWD . 9800.00 88.83 87.21 6177.93 ' 3632.42 2664.60 5962379.33 542166.70 2851.05 12.00 89.76 TD ~~-"-~--~--~- Well w I, I. Tree Size BOP-Tree Rig Floor · · · i I I :II Swab Valve I I I, ssv . I Master Valve I I · Base Flange I Page 1 J . . . Kara, Danny T From: Venhaus, Dan E [Dan.E.Venhaus@conocophillips.com] Sent: Friday, June 18, 2004 9:36 AM To: Kara, Danny T Subject: Permit authorization Dan, This is the standard verbage that we have forwarded to AOGCC in the past authorizing permit delivery to BP: The Kuparuk CTD program starting up in August 2004 consists of 5 wells. The proposed wells are 1 C-08A, 1 Y-24A, 1 D-30A, 1 F-18A, #5 TBD and will be drilled with BP's Nordic 2 CTD unit and managed through BP's CT drilling organization. BP's CT drilling services are being provided to the operator, ConocoPhillips, via a Shared Service operation. As such, ConocoPhillips authorizes the delivery of these permits to BP (Terrie Hubble). ConocoPhillips does request that BP provide a copy of the approved permits for COP's files (Sharon Allsup-Drake). If you need anything else, let me know. Dan Venhaus ConocoPhillips AK Wells (907)263-4372 office (907)230-0188 cell KRU 1 F..18A & 1F..18AL 1 670 & 2041680 SFD 17 20 . . PERMIT TO DRILL 20 MC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. ,. ; . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ¡¿12¿¿ / r -/fA L I zøL( ~. / bg' WELL NAME PTD# ¡ Development Service CHECKWßAT APPLIES / / ADD-ONS (OPTIONS) MULTI LATERAL (1f API number last two (2) digits are between 60-69) PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Exploration Stratigraphic ~'CLUE"· Tbe permit is for a new wellboresegment of existing wen KR /Á I F- /8' /( 'D.-d zq. Z. 2..~ 5"'Y- D I Permit No,WY-/6 7 API No. 5l .. Production. sbould continue to be reponed as a function 'of tbe original API number. stated above. HOLE ]n accordance witb 20 AAC 25.005(f), all records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject ·to fun compliance witb 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation or4er appr~}lg.Jt spacing' exception. (~{¿;_//I ~ 5.- (Company Name) assumes tbe liability of any protest toæe spa. cing/;ex cepty. t. tfJ¿. sf/-· occur. . I!.../. /}f.:f-'4.C - . 7'-. [Æ; ~ Ie.. . All dry ditch~;le ~su:mitted to tbe ~":D Commission must be in no greater ·tban 30' Cí?-O f sample intervals from below tbe permafrost / or from where samples are first caugbt and 10' sample inter:vals through target zones. '"' . . '" The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips Alaska, Inc. assumes the liability of any protest to the spacing exception that may occur. · Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1F-18AL1 Program DEV Well bore seg PTD#: 2041680 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 1 P~rmit fee attaçhe.d. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . . I\IIvltilateral weJI~ fee waived.per 20AAG 25,Q05(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Leas~nIJmberappropri<lte.. . . . . . . . Yes. . . . . . . . _ . _ . . _ . _ . _ _ _ . . _ _ _ . . _ 3 .U_nlqIJe wellllam~_aod Ol.!.mb_er _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ _ _ . . _ _ _ _ _ . . . _ y~s _ _ . _ _ _ _ _ . . _ _ _ . _ _ _ . _ _ _ . _ _ . . _ _ _ . . . _ _ _ _ _ . . . . _ . . _ . _ _ _ _ _ _ _ . . . . . . _ . _ _ _ _ _ _ _ . . _ _ _ _ _ 4 WelUoC<lt~d inadefine~ppol _ _ . . _ _ _ _ . . _. _ _ _ _ .. _ _ _ .Y~s _ _ _ _ . . . KUPARUKßIYE:R,KUPARJJKRVOI1-~490JOO _ _ _ _ . . . . _ _ _ _ _ .. . _ _ _ _ . 5 WellJocated pr.operdlstaoce. from driJling vnitb9IJndaI"Y_ . . . _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ y~s _ . . SPACING EXCEPTIONHEQUJßED _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ . . _ . 6 WelUoC<lted proper _distance from otber wells _ _ _ _ _ . . . _ _ _ _ _ . _ . . _ _ _ . . . _ y~s _ _ . . . _ _ WelJ will be the .3rd_weJl ppenJo the pool intbe NWl4.of Sc 17, T1 tN, R10E_ 7 .S.ufficienLacreage_aYail<lble in.dJiUiog lJniL . _ _ _ _ . . _ _ _ _ _ . _ . . _ . _ No. _ _ _ . .. _ _ _ . . . _ _ _ _ _ . . _ _ _ _ . _ . _ . _ _ . _ . 8 Jfdeviated, is. weJlbore platJncJuded . _ . _ _ _ . . _ _ _ . y~s _ _ _ _ _ _ . . . _ _ _ _ . . _ . _ _ . _ _ _ _ _ _ _ . . 9 .0J'erator only: affected party. . _ _ _ _ _ _ _ . y~s _ _ _ _ _ _ . . . _ _ _ _ . . . _ _ _ . . . _ _ _ . _ _ _ . _ _ _ . . . _ _ 10 _OJ'er:ator bas_apprpprlateJ).ond In.force _ . _ _ _ . _ _ _ _ . . _ . . _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ y~s . _ _ _ _ _ _ _ . _ . . . _ _ _ . . _ _ . . _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ . . . _ _ _ . _ _ _ _ _ _ _ _ . . _ . _ . _ . . _ _ _ _ . _ . _ _ _ _ _ _ 11 P~rmit cao be lSSl.!.ed witbout conserva.tion order _ _ . _ _ _ . . . . . _ _ _ _ . _ . . No _ _ _ . . .. _ _ _ _ . . _ _ _ . . . _ _ _ _ _ . . . . . . _ _ 12 P~rmitcao be lSSl.!.ed witbout administrati\leapprpvaL . _ _ _ _ . . _ . _ . _ _ y~s _ _ _ . . . . . . _ _ . . . _ _ _ _ _ _ . . . _ _ _ . . . _ . _ _ _ . . _ . _ 9/7/2004 13 Can permit be approved before 15-daywait Yes 14 WeJUoC<lt~d within area alldstrat<l.avthorlzed by.lojectipo Ord~r # (pIJtlO# in_cprnmeotsUForNA _ _ _ _ _ . . . _ _ _ _ . . . . _ _ _ . _ . . _ _ _ _ _ . . . . . _ _ _ . . 15 _AJlweIJs.witninJl4_l1Jile.area_ofreyiewid~otlfied(F9rseNjc.e"N.eUonly:). _.. _ _ _ _" _ _... _NA.. _ _ _ _ _ _......... _ _ _ _ _ _' _.. _ _ _ _ _ _ _ _. _... _... _ _ _ _ _ _ _ _ _... _.... _ _ _. _. _... _..' 16 PJe-produced iojector; .dvr<ltionof pre-J'rodvctipn less. than 3 montbs (Forservlce well onJy) . _NA _ _ _ . . . _ _ _ _ . . . . _ _ _ . . . _ _ _ . _ _ . _ _ _ _ _ . . . _ _ _ _ _ . . . 17 .AÇMPFïllding9f Consisteocy.h.as been Js.sIJed fortbis pr.ojeçt . _ . . .. _ _ . NA _ _ . . . .l\IIvltilater.al from existiog weJI. . . _ _ _ . . _ _ _ _ _ . . . _ 18 .C90ductorstrillg.PJovlded... _ _.... _ _... _ _ _.. _ _ _ _ _ _ _ NA.. _... . CondlJctor.seUoorigin.alweJI.1F-t8. _ _ _.... _ _..... _ _ _.. _' 19 .S.ud'ac~cas.ing.pJotects. alLknowll USDWs . . . _ _ _ . . . . _ _ _ . . . . . _ _ _ _ . _ _ _ . .NA _ _ _ _ ..A.1l aquifers exernpted,AOCFR1047.'1021b)(3).. _ _ . . . . 20 .CMT vol adequateto çirc.ulateoncond_uctor:& surfC$g _ . _ _ _ . . . . _NA _ SlJrfaçe ca.slng setjll originalwell. 21 .CMT v_oj adequ.ateto tie-lnJongstriog tOSIJd' csg _ _ . _ _. _ _ . . . . _ _ _ No _ _ _ . . . Pr9dl.!.ction. Gasiog seHn.origiOal well.. _ _ _ _ _ . . _ _ _ _ . . . . _ _ _ _ _ . . . _ _ _ . . . 22 _CMTwillcoyeraJlkoown.ProdlJctiyeborizons . _ _ _.... _ _ _ _ _" _ _ _ _ _.... No_ _ _Slotte.dJioercompletiooplaoned. Origioalprpdl.!.ction.casiogce.mentabpveaILhYdrocarboos.._ 23 _Casiog desigos adeçlJa"te fpr CoT, B.&.pernJafr_ost _ _ _ _ . . . . . _ _ _ _ _ . _ . _ _ _ _ _ . . . _ Yes. _ . _ _ _ _ . . . _ . _ _ _ _ . . . . _ _ . . . _ . . _ _ . . . _ _ _ _ _ . . . _ _ . . . 24 .Adequ<lteJan.kage_oneserye pit _ _ _ . . . . _ _ _ _ . .. _ _ _ . . . . . _ _ . . y~s _ . Rig iSßqIJippedwitb st~eLpits. No reseJ\le.pjtJ'laooed, AU waste to. Glass JLweU(st _ . _ 25 Jf.aJe-drilL bas a_ tO~403 for <lbandon.ment be~o apPJoved . . _ _ _ _ . _ . _ _ _ _ _ . . . _ _ _ y~s . . .304-331 . _ _ _ _ . . . _ _ _ _ . . . _ _ _ _ _ _ . . . _ _ _ _ _ _ . . . _ _ _ . . . _ 26 Adequ<lteweUbore separatio.n.proJ'Psed _ . _ . . _ _ _ _ _ _ . . . _ _ _ _ . _ . _ _ _ _ _ . . . . _ . _ _Y~s _ _ _ _ _ . . Sidetraç~ io reservoir. }Ie.arest weJlbore is :'A"_sid.etrac_k.-nO: tvd deeJ'er, . _ _ . . _ _ _ . . _ _ _ _ _ _ _ . _ . _ _ . . 27 Jf.diverter Jequired, does iLmeet reguJations . _ _ _ . . . . _ _ _ _ . . . _ . _ _ _ _ . . . _NA _ _ 60P will be in.pJa.ce._ . _ _ _ _ . _ . . _ _ _ _ _ . . . _ _ _ _ . . . . . _ _ _ . . . . _ _ . . Appr Date 28 DJitliog fJuid.program schematic & ectuipJistadequate. _ _ _ . . . . _ _ . . . . _ _ . . . . . _ y~s .. _ _ Expected 6Hp 10.0 EI\IIW, .Dyoamic Ollerb_alaocetechniqve plan.ned with_MW.of 8.8 ppg alldappli~d bac.k-pre.sSl.!.r TEM 9/7/2004 29 _S.oPEs,_dpthey meetreguJa.tion _ _ _ . . . . _ _ _ Yes _ _ _ _ . . _ _ _ _ _ . . . _ _ _ . . _ _ _ _ _ .. _ _ _ . .. _ _ _ _ _ . . . _ _ _ _ . . _ _ ~ A 'IN... 30 .S.oPEpress rajiog apJ'ropriate;testto.(put psig in.comments)_ . . . . _ _ _ _ . _ . . . y~s. _ CalcuJatedsja.tic MASP 2563.psl.GaJc!Jl<lted dyn_amic.MASPJOOJ'sic .3500.p.slplanned BOp test _ - ~ý "/ 'ì 31 .CM~elllanifold compJies. w/API RP-53 (May 84) . _ _ _ . . . . _ _ _ _ _ . . . _ . y~s . _ _ _ . . . . _ _ . . . . _ _ _ _ . . . _ _ _ . . _ _ _ _ _ _ . . . . . _ _ _ . . . . _ . . _ _ . . 32 Wor~ will pCC.ur withputoperationsblJtdown. _ _ _ . . . . _ _ _ _ . . . . . _ _ _ . . _ . . _ . . .Y~s _ _ _ _ _ . . . . _ _ _ _ _ . . _ _ _ . _ . . _ . . _ _ _ _ _ _ . . _ _ . . . _ 33 Js.pres.ence.ofH2Sgas_prQb.able _ _ _ _. _" _.. y~s. . _1F:padJs.desigoated_as_anH2SJ'ad..MlJd.shOlJldprecludeH2S.onJig._Rig_hassensorsalld.aJaJms. 34 Meçba.nlcaLcpodJlloopfwellswlthin.A.ORyerlfied(Fpr_s_ervicewelJonJy:). _ . _ _..... _ _NA. _ _ _ _... _ _..... _ _ _.... _ _ _ _..... _ _ _.... _ _ _... _' Administration D D - - - - - - Appr SFD Date ~ - - ~ - - - Engineering - - - - - ~ - - - - - - - - - - - - -- - - - - - - Appr SFD Date 9/7/2004 35 P~rmitcao be lSSl.!.edwfo hydrogen sulfide rneas!Jres _ . . . . _ _ _ . . . . _ _ . . . . _ _ _ _ No. . KRU 1f-16 meas!Jred 21 PPIll H2S 0010/1312003.. sm . . _ _ . . . . . _ _ _ _ . . _ . . . _ _ _ . . 36 .D_ata.PJeseoted Oil pote.ntial pveJPres.sIJr~ .zones . _ _ _ . . . _ . _ _ . y~s _ . . Expected reservoir J'ressuJe ls1 0 PPG.EMW;will be.dJiUe.d.dyoa.micaJly: ov~rbal<loced witb CoRed rvbing~ . . _ 37 .S~lsrnicanalysJs. of sbaJlow gaszpoes. . . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ .NA . _ _ _ . . . . _ _ _ . . . . _ _ _ . . . _ _ _ _ _ . . . _ . _ _ _ _ _ . . . _ _ _ _ . . . 38S~abedconditipo SlJrvey(if off-shpre) _ . _ _ . . . . _ _ _ _ . . . . _ _ . _ NA _ _ . . . _ _ _ _ . . . . _ _ _ _ _ . . . _ _ _ _ . . . _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ . . _ 39 _ Conta_ct namelpnone.forweekly prpgressreports [exploratpryooly] _ _ _ . . _ . _ _ _ _ . . . _ _ NA . _ _ _ _ _ .. _ _ _ . . . _ _ _ _ _ . . _ . _ _ _ _ _ _ . . _ _ _ _ . . . _ _ _ _ _ _ . . _ _ _ . . Geology Geologic Engineering Public Date Commissioner: Date: Commissioner: Date cre. fìtS C¡/7/4-- f\ '1" df oJ e e 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. . . **** REEL HEADER **** MWD 05/11/25 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/09/25 751636 01 2.375" CTK # \7&q *** LIS COMMENT RECORD ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! !!! ! ! ! ! ! ! ! ! ! !!!!!!! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7395.7500: STOP.FT 9144.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- *** Remark File Version 1.000 Extract File: ldwg.las 1.20 : NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. 1F-18AL1 Kuparuk River Unit 70 deg 17'53.527" N 149 deg 40'47.811" W North Slope Alaska Baker Hughes INTEQ 2.375 CTK 23-Sep-04 500292265460 .---------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . -Remarks 19 11N 10E MSL o RKB 108 KB 108 N/A N/A 7397 DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~öL(-{(P<¡ . . (1) (2 ) (3) (4 ) Advantage All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is real time data. Baker Hughes INTEQ utilized CoilTrak downhole tools and the (5) Electrical surface system to log this well. Tools ran in the string included Casing Collar Locater, a Disconnect and Circulation Sub, a Driling Performance Sub (inner and outer downhole pressure), downhole weight on bit, a Gamma and Directional Sub, and a Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not adjusted to a PDC (Primary Depth Control). The INTEQ MWD Gamma Ray is the PDC for well 1F-18AL1. (7) The 1F-18AL1 was drilled from 1F-18AL1PB1 through open hole Side track at 8045' MD (6138'SSTVD). The 1F-18AL1PB1 wellbore was drilled from 1F-18A (8) 1/2" Liner. through an openhole sidetrack off an alummum billet at 7430' MD. The 1F-18A was drilled from 1F-18 through a milled window in 3 (9) Top of Window 7393.2' MD (5973.1' SSTVD) Bottom of Window 7397.2' MD (5976.2' SSTVD) The interval from 9116' to 9144' MD (6165.7' to 6165.3' SSTVD) was not logged due to sensor offset. (10) Tied to RA Tag at 7399' MD (5977.5' SSTVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet EOZ END Tape Subfile: 1 66 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1F-18AL1 5.xtf 150 ConocoPhi1lips Alaska Inc. 1F-18AL1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** . . !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the MWD Gamma Ray is the PDC for this borehole. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 42 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7396.000000 9144.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 51 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 . . *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT IF-18ALl.xtf 150 ConocoPhillips Alaska In IF-18AL1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !! ! ! ! ! ! ! ! ! ! !!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPA MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 84 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7396.000000 9144.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 93 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes . **** TAPE TRAILER **** MWD 04/09/25 751636 01 **** REEL TRAILER **** MWD 05/11/25 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . Tape Subfile 2 is type: LIS DEPTH 7396.0000 7396.5000 7400.0000 7500.0000 7600.0000 7700.0000 7800.0000 7900.0000 8000.0000 8100.0000 8200.0000 8300.0000 8400.0000 8500.0000 8600.0000 8700.0000 8800.0000 8900.0000 9000.0000 9100.0000 9144.0000 GR 69.9750 60.7500 106.3600 129.6800 154.5400 106.6200 36.6600 82.0150 60.4900 106.1100 78.5550 56.1400 83.4300 41. 5300 99.9600 109.4400 32.8200 53.0600 31.2800 41. 7900 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units . ROP 1.3000 0.9300 7.1700 50.3300 15.3000 4.4200 28.3800 143.8300 140.4000 83.1200 70.2000 124.1400 91. 1700 5.7400 103.2200 135.2300 10.8300 71.6100 107.9100 30.7400 47.4100 7396.000000 9144.000000 0.500000 feet . f . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPA 7396.0000 69.9750 1.3000 7396.2500 68.9500 1.1800 7400.0000 183.4900 6.3600 7500.0000 128.6500 49.7600 7600.0000 143.2600 17.4600 7700.0000 114.3100 4.6200 7800.0000 37.3000 29.4600 7900.0000 82.2700 143.5600 8000.0000 59.7200 128.3000 8100.0000 102.7700 84.5600 8200.0000 82.2700 83.7000 8300.0000 57.4200 124.1000 8400.0000 86.8900 78.2600 8500.0000 34.6100 6.6000 8600.0000 108.6700 100.7000 8700.0000 103.6700 136.1800 8800.0000 35.7650 12.1300 8900.0000 49.2200 74.5600 9000.0000 32.0500 74.9000 9100.0000 39.9900 44.1000 9144.0000 -999.2500 47.4100 Tape File Start Depth 7396.000000 Tape File End Depth 9144.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . ( . . Tape Subfile 4 is type: LIS . . **** REEL HEADER **** MWD 06/03/07 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/09/20 751636 01 2.375" CTK * \7~~~ *** LIS COMMENT RECORD !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!!! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7430.0000: STOP.FT 8254.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- *** Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. IF-18AL1PB1 Kuparuk River Unit 70deg 17'53.527"N 149deg 40'47.811"W North Slope Alaska Baker Hughes INTEQ 2.375 CTK 20-Sep-04 500292265470 ----------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . -Remarks 19 llN 10E MSL o RKB 108 KB 108 N/A N/A 7397 DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ÂÔt{-{bJ . . -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is real time data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locater, a Electrical Disconnect and Circulation Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit), a Gamma and Directional Sub, and a Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for well IF-18ALlPB1. (7) Sidetrack of (8) 1/2" Liner. The IF-18AL1PB1 was drilled from 1F-18A through openhole Aluminum Billet ai 7430' MD. The 1F-18A was drilled from IF-18 through a milled window in 3 Top of window 7393.2' MD (5973.1' SSTVD) Bottom of window 7397.2' MD (5976.2' SSTVD) (9) The interval from 8228' to 8254' MD (6139.8' to 6140.5' SSTVD) was not logged due to bit sensor offset. (10) Tied to RA Tag at 7399' MD (5977.5' SSTVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet EOZ END Tape Subfile: 1 66 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT IF-18ALPBl 5.xtf 150 ConocoPhillips Alaska Inc. IF-18ALIPB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** . . !!!! !!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the INTEQ MWD Gamma Ray is the PDC for this borehole. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 20 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7430.000000 8253.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 29 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 . . *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1F-18ALPBl. xtf 150 ConocoPhillips Alaska In IF-18ALlPB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! !!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX ROPA ---------------------------------------------------- GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 68 68 AAPI F/HR 1 1 4 4 4 4 GRAX MWD ROPA MWD ------- 8 Total Data Records: 40 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7430.000000 8252.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 49 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes . **** TAPE TRAILER **** MWD 04/09/20 751636 01 **** REEL TRAILER **** MWD 06/03/07 BHI 01 Tape Subfi1e: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . . Tape Subfile 2 is type: LIS DEPTH GR ROP 7430.0000 116.3600 41. 3000 7430.5000 121. 2200 41. 4700 7500.0000 129.6800 50.3300 7600.0000 154.5400 15.3000 7700.0000 106.6200 4.4200 7800.0000 36.6600 28.3800 7900.0000 82.0150 143.8300 8000.0000 60.4900 140.4000 8100.0000 28.2000 9.2700 8200.0000 65.3650 147.9100 8253.0000 -999.2500 -999.2500 Tape File Start Depth 7430.000000 Tape File End Depth 8253.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet . . Tape Subtile 3 is type: LIS DEPTH GRAX ROPA 7430.0000 114.8200 47.3800 7430.2500 116.3600 41. 3000 7500.0000 128.6500 49.7600 7600.0000 143.2600 17.4600 7700.0000 114.3100 4.6200 7800.0000 37.3000 29.4600 7900.0000 82.2700 143.5600 8000.0000 59.7200 128.3000 8100.0000 26.9200 8.0300 8200.0000 68.4400 149.1600 8252.7500 -999.2500 -999.2500 Tape File Start Depth 7430.000000 Tape File End Depth 8252.750000 Tape File Level Spacing 0.250000 Tape File Depth Units teet . . Tape Subfile 4 is type: LIS