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Home My WebLink About204-126 • • C 0 0 a) v m � wtlw a) � ci NJ, a o�w a, 3 w rM QY <V x n3 QoQ - a) O 0tl 0 � M . a 0 �! TTTTT • a ao ~ C@O ro 0 .1-, m 0- < "i co s0 co co co CO co 0 0 = m T T T T T .L U y,, L J 5:. 0 f6 16 16 f6 CO f6 CO t C C my 7: W222 - Q a) �n oo ao n or T Q N T T T 0co d > Ou -O � O T � � u a� 0 a) ry 0 O 0 0 0 0 0 0 0 O C r 6 L'''' J J J J J J J �, W W W W W W W t)0 0 a) 0 0 F- LL LL LL LL LL LL LL a) E - Q J J J J J J J N O ma) F- Q Q Q Q Q Q Q Q ., c 0 Qzzzzzzz Q - v v LL. LL U. LL LL LL LL a) _C U CC w 00 ^� a) O 5 'cL 4.403 '., > Y u 5 I a) Q a] E QQ v UO C O _0 v tea) a) a _ Can "' p~ r > > c C01,o y < C s o) > N v a F V W LL LL F LL Tq it O o U o a 0 0 g) d � 0 � •Fa � a � aa ''r 10 Z 7 mQ - a o a a —.t • F. o z a P4• 8 % cn > Va) 03 ao 0 Kt 411 g 3(i C„ ._. ' c� _ (7) ,x CO tAl CG 4 boe„ W > i J d J O J 0 J O J !� .,,,,,, 2 W ZZZZZZ z D DODDDD W m cceccew a cc a g w w w w w w w � Q > > > > > > > E o Y Y Y Y Y Y Y1 W D D D D M M v t u LL cc w reccccce �. • 0 < < < < < <( ..1 r 0 CL a a a a a a > > > > > > > no >, LU x n c Q CO N 00 O N O CO Ou xLLI0 0 0 0 0 0 0 ra 000040, 000 —ra C i.7 V 0 CO CI O t0 O a E • N > v 2 v 2 Y 2 a a) ®■� p.1 =� 0 0 0 0 0 0 0 @ (V,4 ns c • >- c C 000 � 000 ' N r0 O N r0 N IA w E OC M O N M T (0 h M N N O Nvs o ryNOINNNNN •- u , . OO O O O M O O O N N N N N 0 N '1 Q1 O O O O O CO g to 1n In 1[) N N U) i+ O a ) C..C13 wae ti c u rZ CNi E °; 5 a) cri6 a) 9 � W � Y W. T 0[ ` ,0 i▪D _ 4J z T f0 N Qv In M N r E 4-, ,J,rn I▪ __ 0- < , N -1 n- ,. N N J M E z OJ to C �, a N W N C to �C '�� y1 f0 .E G/ t9 C/� Fa- a0j F d a Q · . Inlage 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. ~ ()!J.- j & (.¡; Well History File Identifier Organizing (done) D Two-sided 111111111111111111I D Rescan Needed 111111111111111111I RESCAN ~olor Items: ~reYSCale Items: D Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NofType: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date Lla-d-Io 0 D Other:: BY: ~ 151 ~ Project Proofing 111111111111111111I BY: ~ Date U laJ.ID~ {L X 30 = (/J 0 151 mP BY: Date: + L1- = TOTAL PAGES r¡ t+ ~t does not include cove~ 151 p Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: -1S- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: t/ YES BY: ~ Date: 1/ I ~ ~J ob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 11111 NO 151 VV\ P NO BY: Maria Date: 151 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 11I11111111111 1111I BY: Maria Date: 151 Comments about this file: Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc • • °~._ '~,,~: MICROFILMED 03/0112008 DO NOT PLACE _~:v._, _~,, . , „ r~ °, ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~rCl~~~l~bl~~l'' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # n - - ' NO. 4505' ~ ~ ~~ Com an Alaska Oil & Gas Cons Comm P y ~,/ ` ~ ~>~~'~ Attn: Christine Mahnken ,~., -) ~~~ ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 11 / 16/07 3J-16 11850468 INJECTION PROFILE ~ "` 11/02/07 1 1J-122 11745241 MEM PROD PROFILE - ~-(~ 11/03/07 1 1C-26 11745244 MEM INJECTION PROFILE v 1 11/09/07 1 2Z-07 11850476 PRODUCTION PROFILE 11/11/07 1 1Y-01 11839683 INJECTION PROFILE 11/15/07 1 1Y-24AL1 11837535 LDL p 11115/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • .? It? IlA" ~ ~ () '" DATA SUBMITTAL COMPLIANCE REPORT 1 0/13/2006 S' ,~¿ II 0)-~ API No. 50-029-22371-60-00 Permit to Drill 2041260 Well Name/No. KUPARUK RIV UNIT 1Y-24AL 1 Operator CONOCOPHILLlPS ALASKA INC MD 9678.......- TVD 6064 ....-- Completion Date 10/18/2004 - Completion Status 1-01L UIC N Current Status 1-01L REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ..~-- DATA INFORMATION Types Electric or Other Logs Run: GR, Pressure (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T~Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~c Directional Survey 7855 9678 Open 11/8/2004 l Lis 13779 Gamma Ray 7902 9677 Open 4/12/2006 GR I 13779 LIS Verification 7902 9677 Open 4/12/2006 GR I ~ Gamma Ray 25 Blu 7902 9677 Open 4/12/2006 GR I Gamma Ray 25 Blu 7902 9677 Open 4/12/2006 GR I ~Ð v LiS 13Töu Gamma Ray 7873 9918 Open 4/12/2006 PB 1 GR , RJ.¡t 1'3780 LI S 'lerift'Oãfio n 7873 9918 Open 4/12/2006 PB 1 GR I [~ Gamma Ray 25 Blu 7873 9918 Open 4/12/2006 PB 1 GR I I ._ J ~--- OSrI'Iffi8 Ray 25 Blu 7873 9918 Open 4/12/2006 PB 1 GR Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFOR~ON Well Cored? ~ J..W Chips Received? ~ Analysis ~ Received? Daily History Received? ~N &N Formation Tops Comments: . . Permit to Drill 2041260 MD 9678 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Well Name/No. KUPARUK RIV UNIT 1Y-24AL 1 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-22371-60-00 TVD 6064 ~Daœ1W1WOO~ Completion Status 1-01L Current Status 1-01L UIC N Date: 7 ~~ ~ . . . . Transmittal Form r&11I BAKIR HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1 Y -24APBl Contains the following: Ii II II I' '\ II II II !! II II " i! f REVISED 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GRlDirectional Measured Depth Log 1 blueline - GRlDirectional True Vertical Depth Log I LAC Job#: 737190 II i i II I I Sent By: Deepa JL--. Received By: o--e, l~E Dat il J"~~'? ,,"'j. 'Q. ~],~,,-~!,-'}. Date: f'IUV i) "-' .LUUO .:A¡;ehcf39S 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 ~)(j_I-1 d~ 11: JLI dl ( II ........ ,........... ¡:t,~'!.-:-"" ~_!'__._.~_"._.:'~.. _'~~n__'!");. ...... ~.~ - ,,' ,,,. .'.. "·U'"':;.r' .,.... f~!E§ I:::"," i~~-·;.":" ;""1 i_..: ..:';~~~'~;/>:' -., '"'' I··..·· ,,,'if .. , . '. i .¡.....-.;;'t~,',..__ -"'-cl "ill BAKER HUGHES , . Transmittal Form II.· "f"'~~om',., ,'1«~';'>,~. _"I': _ U' "" ,,,,," .. :~r~: ''0 ¡:NlI~ ~,,,!_. - ._~m ----!~t -'-~"-;~'\~~- INTEQ ~_'...." ~.~"<;d Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: lY-24ALl Contains the following: I !I il fi :¡ II 11 ¡¡ II " ¡ ¡ II i ~ ¡ REVISED 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional True Vertical Depth Log II II II !I 11 'I II H I, LAC Job#: 737190 Sent By: Deep. Jlekar Received By: C¿ ¿ L,----- Date: ~~t\/E Date: :j"¡lJV '0 õ . ;~ """,'r<'1~"<:~ _~ - >,1'''' "..:.: -. i[~~fJ.11i~ :1-·"~:r,·,- ~;¡... ~ ~', :'" .,', r j P, "--·"'......-v PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RE'"FtJ'RNING 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 go"-{- IQ(P ø:- ¡.(./810 ------"------------" . . Transmittal Form r41_ SAKI. HUGHES INTEQ Anchorage GEOScience Center _. To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: % n 779 .~ Robin Deason Reference: 1 Y -24ALl Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log lblueline ~GR/Directional True Vertical Depth Log LAC Job#: 737190 SentBY:GI~Orel Received By: ~ t!J W Date: APR 05, 06 Date: JJ,~~tJ 6~ 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 01' """" ~ ;;~;! >;¡W\ I!I\;.~ (j,~", II'."": '- .... ,I) .""': ""... ....... ¡,)j]~tI$j¡Fl", =,~"' ~'£. -:~ .; ,.",:~ vr ~~<l~:N_ ¡"I'~ " --=~:.-:~-~. : 'I' ._ : u __ :< ~V/ - J )"fA ~ 'Ie.- . STATE OF ALASKA . ALASKA AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: cIa P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 570' SNL, 1762' EWL, SEC. 01, T11 N, R09E, UM Top of Productive Horizon: 68' SNL, 3004' EWL, SEC. 12, T11 N, R09E, UM Total Depth: 1562' SNL, 2980' EWL, SEC. 12, T11N, R09E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-._ 5314~ y- 5974756 Zone- ASP4 TPI: x- 532696 y- 5969984 Zone- ASP4 Total Depth: x- 532679 y- 5968490 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: GR, Pressure 2. One Other 5. Date Comp., Susp., or Aband. 10/18/2004 .I 6. Date Spudded 10/11/2004 / 7. Date T.D. Reached 10/14/2004 8. KB Elevation (ft): 106' 9. Plug Back Depth (MD+TVD) 9678 + 6064 10. Total Depth (MD+TVD) J 9678 + 6064' 11. Depth where SSSV set 1966' MD 19. Water depth, if offshore N/A MSL / CASING SIZE 16" 9-5/8" GRADE H-40 L-80 I J-55 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD :smINGOEPTH MD :smINGOEPTHTVD HOLE TOÞ BOTTQM IOÞ I t:SOTTQM SIZE Surface 121' Surface 121' 24" Surface 4599' Surface 3600' 12-114" Surface 7568' Surface 5733' 8-1/2" 7264' 7857' 5501' 5968' 6-1/8" 7600' 9500' 5757' 6073' 3" WT. PER FT. 62.5# 47# 136# 26# 18# 4.7# 7" 5" 2-3/8" 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 7603' - 9480' 5759' - 6072' 26. Date First Production: October 24, 2004 Date of Test Hours Tested PRODUCTION FOR 11/612004 12 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED -II.. Press. 241 1418 24-HoUR RATE""'" 27. 24. SIZE 3-1/2",9.3#, L-80 3-1/2", 9.3# 19.2#, J-55 I L-80 25. A.CID, ro, 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-126 13. API Number 50- 029-22371-60-00 14. Well Name and Number: Kuparuk 1Y-24AL 1 15. Field I Pool(s): Kuparuk River I Kuparuk River Oil Pool Ft Ft 16. Property Designation: ADL 025646 17. Land Use Permit 20. Thickness of Permafrost 1500' (Approx.) " f'\MVU'~ I PULLED 260 sx Arctic Set (Approx.) 00 sx PF 'E', 480 sx 'G', Top Job: 105 sx PF 'C· 250 sx Class 'G' 175 sx Class 'G' Uncemented Slotted Liner T'·"'"'' DEPTH SET (MD) 7185' 7185' - 7681' PACKER SET (MD) 7193' CEMENT , ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7906' Kicked Off of 1Y-24A wI OH Whipstock 2000' Freeze Protected with Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Oll-BBl GAs-McF WATER-BBl 692 2000 2363 O'l-BBl 1384 GAs-McF 4000 W A TER-BBl 4727 CHOKE SIZE GAS-Oil RATIO 176 2889 Oil GRAVITY-API (CORR) 24 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 2 6 2D04 Form 10-407 Revised 12/2003 '........ IGI¡\]Al CONTINUED ON REVERSE SIDE í'éÔMk,rw:/ ! DATE ¡ID'/~·Ó. I :,....' j'N.'FIEI·· I ..... 't':·ii¡-.' . , ._:;/..JS.~__ . 1,. ··-~_""-.v_.~."""".",,.,,_--.\' {g f~ 28. GEOLOGIC MARKERS 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD rvD and attach detailed supporting data as necessary. If no tests were conducted, state "None". C4 7765' 5889' None C3 7831' 5945' C2 7839' 5952' C1 7860' 5970' B4 7880' 5986' B3 7905' 6004' B2 7965' 6044' B1 8006' 6070' A6 8050' 6094' AS 8068' 6102' A4 8106' 6116' 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 Title Technical Assistant Date \ \-/8"0 Kuparuk 1Y-24AL 1 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Dan Kara, 564-5667 204-126 Permit No. I A roval 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. IrEM 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. IrEM 4b: TPI (Top of Producing Interval). IrEM 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. IrEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IrEM 20: True vertical thickness. IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrEM 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). IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IrEM 27: If no cores taken, indicate "None". IrEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 20:00 - 20:20 20:20 - 21 :00 21 :00 - 00:00 101212004 100:00 - 01 :50 01 :50 - 02:00 02:00 - 03:05 03:05 - 03:15 03:15 - 04:00 04:00 - 05:15 05:15 - 07:00 07:00 - 12:30 Page 16 of 34 BP EXPLORATION Operations Summary Report P PRE Legal Well Name: 1Y-24 Common Well Name: 1 Y-24 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date J~~~~~- To Hours Task 10/1/2004 100:00 - 06:00 6.00 MOB i i 106:00 - 15:00 i I 115:00 - 17:20 17:20 - 20:00 9.00 MOB P PRE 2.33 MOB 2.671 MOB P P PRE PRE 0.33 MOB P 0.67 MOB P 3.00 RIGU P PRE PRE PRE 1.83 RIGU 0.17 BOPSU 1.08 BOPSU 0.17 BOPSU 0.75 BOPSU 1.25 BOPSU 1.75 BOPSU 5.50 BOPSU PRE PRE PRE PRE PRE PRE PRE PRE 12:30 - 13:00 0.50 BOPSU P PRE 13:00 - 16:00 3.00 BOPSU SFAL PRE 16:00 - 17:00 1.00 BOPSU SFAL PRE 17:00 0 23:00 6.00 BOPSU P PRE 23:00 0 00:00 1.00 WHSUR P DECOMP 10/3/2004 00:00 0 02:00 2.00 WHSUR N DECOMP 02:00 0 03:00 1.00 WHSUR P DECOMP 03:00 - 03:15 0.25 WHSUR P DECOMP 03: 15 0 03:35 0.33 PULL P DECOMP 03:35 - 05:00 1.42 PULL P DECOMP 05:00 - 06:00 1.00 PULL P DECOMP 06:00 - 07:00 1.00 PULL P DECOMP 07:00 -15:00 8.00 PULL P DECOMP 15:00 - 18:00 3.00 PULL P DECOMP Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Continue with rig move on 1 F access road and arrive at the Spine road at 0600 hrs. WO crew change and morning shift traffic before laying mats on Spine and resuming move. Also PU extra mats and take to 1 Y Pad and begin setting mats on the Pad Enter Spine and make a quick 3 mile move to 1Y Pad Park on access road to back Pad while continue to lay mats on back Pad up to well. Pick up mats on Spine and shuttle to Pad. Install 7-116" double gate to bottom of TOT stack. PJSM prior to moving over well. Move last 100 yds and move onto well. Accept rig at 2100 hrs. Rig up out buildings. Set-in upright and Tiger tanks. RlU to circulate well with 10.5ppg brine. Continue RU. Offload 290 bbls 10.5ppg brine. PT circulation lines to 3500 psi. Open well, no pressure. Circulate bottoms up at 4bpm. Monitor well for flow. Dead. RD circulation lines. Make up and set BPV. Test to 1000 psi from below. ND Production tree and load out for inspection and redressing. Fin MU stack and get measurements for test jt. Swap lower rams to put 3-1/2" in top set and 4" in bottom set. NU BOPE. NU riser, replace boot in riser Tubing and accessories AOL APC fin berm and set tanks Load out rig mats. Move camp from front Pad and park in normal spot Function test rams. Fill stack and body test. Leaked thru blanking plug and JA ended up w/ 400 psi Begin loading pipeshed wI 3-1/2" tubing Bleed off press. WO FMC. Remove test jt. Try a few tricks. Pull blanking plug-nothing obvious WO FMC to get parts and/or another blanking plug. Changed out ball and worked Fin load 3-1/2' tubing in pipeshed BOPE test. 250/4500psi Witness waived by AOGCC Pull FMC blanking plug. Pull BPV. Had problem with jointed puller lining up properly. P/U 4' elevators and landing joint. MU circulating line. PJSM review plan forward for pulling hanger to rig floor. Block wt = 8k. String wt in 10.5ppg brine 62k. Pull to 70k and continue wt increase. Seals released at 105k. Pull hanger to floor level. Fluid level +1-10' below wellhead. Circulate at 4bpm wI full returns. Same time clear floor and RlU Cameo spooler equipment. RD circulation equipment. LD landing jt and breakout 4' hanger. Prep to LD 4' tbg. Load completion jewelry in pipeshed LD 4898' 4' 11 # J-55 DSS-HTC(AB) R2 tubing wI Camco 4' TRDP SSSV and pups, Merla GLM #5 wI pups. Recovered 25 of 32 reported SS bands RU and stand back 35 stds 3-1/2' 9.3# Jo55 EUE8Rd R2. Find that collars are pitted fairly good (on low side). WO Kuparuk Printed: 11/1S12OO4 2:57:54 PM 1 Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To~~o~~lTask Code 15:00 - 18:00 I 3.001 PULL P 18:00-18:10 i 0.1711 PULL P 18:10 - 18:251 0.25 PULL P I ' I I j I ¡ I ! I I I I , 18:25 - 21 :00 I 2.581 PULL N I I 21 :00 - 21 :30 I 21 :30 - 00:00 I 1 ¡ 00:00 - 04:20 I 04:20 - 08:30 I I 08:30 - 09:40 I I 09:40 - 12:10 I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/3/2004 10/4/2004 12:10 - 13:15 13:15 - 14:00 14:00 - 16:15 16:15 - 17:30 17:30 - 21 :05 0.50 CASE 2.50 CASE I 4.331 CASE 4.171 CASE 1.17 CASE 2.50 CASE 1.08 CASE P 0.75 CASE P 2.25 CASE P 1.25 CASE P 3.58 CASE P BP EXPLORATION Operations Summary Report Page 17 of 34 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations ~---~- P DECOMP RWO specialist. Evaluate and decide to replace collars when RBIH. Fin stand back 3-1/2" J-55. Total of 70 jts. Remaining is 1 single and PBR's seal assembly to breakdown. DECOMP PJSM with new crews. Review hazards and plan forward. DECOMP Start to make break on the last full joint and PBR seal assembly. ( Seal assembly contains stuck Weatherford OHWS and tbg jt contains a Weatherford RBP) Crews noticed this connection was wet and also possibly held trapped pressure. This was reviewed in the PJSM. Crews wrapped the connection with Herculite and absorb while the pressure was bleeding down. Useing the Eckel tongs one more round was backed out of the connection and the connection parted due to the remaining trapped pressure. No injuries were incurred. Thick oily fluid sprayed on the front of the 3 rig hands working the area. Safety glasses prevented any fluids entering the eyes. DECOMP Called HSE field advisor and town engineer. Cleaned up the rig hands and the rig floor. Paided special attention to face areas to be sure all residual fluids were completely washed off with soap and water. No adverse affects to righands. DECOMP PJSM with all hands. Reviewed trapped presure incident, the plan forward and running order for new 3-1/2' completion string. DECOMP Run 3-112' completion string. Useing 70jts of the pulled 3-1/2' J-55 tbg and replacing the collars on each one. Remaining 3-1/2' tbg is new L-80. DECOMP Continue running 3-1/2" completion string. Changeing out collars on first 70jts of re-run tbg. DECOMP MU new 3-1/2" 9.3# L-80 EUE8Rd R2 tubing and GLM's from pipe rack DECOMP Install SWS (Camco 3-1/2" TRM-4E) safety valve. Change out Camco spooler. Install control line and PT DECOMP MU 3-1/2' 9.3# L-80 EUE8Rd R2 with control line installing SS bands on every other joint Sent seal assy and one full jt (w/ WRP) to WII. Used borescope and saw WS anchor in seal assy confirming that no iunk from OH WS was left in well DECOMP PU extra it and see textbook entry into PBR. Determine spaceout pups and none needed. Close annular. PT IA to 550 psi and hold for 5 min to verify seals holding. Bleed off press. Swap to pump down tubing. PUH 52k to put seals above PBR DECOMP Pump 16.7 bbls corrosion inhibitor FRW132 mixed in 10.5# brine and displace wI 10.5# brine to leave in the IA above PBR DECOMP MU last jt, tubing hanger wI XO, and landing it. Install control line and test. RIH and land 27.50' below N2 RKB. Left landing it in hanger as guide for WL. Left control line in stack pressured up (SSSV open) Used 35 SS bands. String wts before landing 54K up, 42k down DECOMP Safety mtg: RU and run WL RU HES slickline unit. MU tool string and strip thru TIW valve on landing jt DECOMP Make drift run wI 2.70' TS to 7826'. PIU TIP and set in Cameo D nipple at 7211' WLM. R?D SL P P P P P Printed: 11/1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/4/2004 21 :05 - 23:15 10/5/2004 23:15 - 00:00 00:00 - 02:00 02:00 - 04:30 04:30 - 06:30 06:30 - 11:00 11 :00 - 15:00 15:00 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 20:00 20:00 - 21 :00 21:00 - 22:00 22:00 - 22:10 22:10 - 22:50 22:50 . 23:30 101612004 23:30 . 00:00 00:00 . 00:30 00:30 - 01:15 01:15 - 03:15 03:15 - 03:35 03:35 - 05:15 05:15 - 07:30 07:30 - 10:30 10:30 -11:00 11:00 - 12:30 12:30 - 13:00 13:00 - 14:30 14:30 - 15:00 15:00 - 16:50 Page 18 of 34 BP EXPLORATION Operations Summary Report To 1 Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours t::~Jcode 2.171 CASE i P I I i i 0.7511 CASE !p 2.00 WHSUR I P 2.50 I WHSUR~I P 2.00 i WHSUR P I 4.50 BOPSU P 4.00 BOPSUFt P 1.50 WHSUB! P I I I ' 1.001 WHSUB!P 1.00 WHSUR I P I I 1.50 PULL iN 1.00 PULL IN I 1.001 PULL iP I 0.17 DHEOP ip 0.67 DHEOP I P 0.67 PULL t Ip P 0.50 PULL 0.50 PULL 0.75 PULL P 2.00 CLEAN P 0.33 CLEAN P 1.67 CLEAN P 2.25 CLEAN P 3.00 DRILL P 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 1.83 DRILL P Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 NPT Description of Operations DECOMP DECOMP DECOMP DECOMP DECOMP PRE PRE DECOMP DECOMP DECOMP DPRB DECOMP DPRB DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Open IA RIU to tbg and PT to 2500 psi/15 min - good test. Bleed off to 1500 psi then PT IA to 2500psi 15 min - good test. Drop pressure on tbg and sheared DRC valve. Pressure up tbgllA to 1500 psi and close SSSV dump pressure above SSSV. Monitor pressure and SSSV is working. Dump all pressures. RID hoses. Remove landing joint and set FMC BPV. ND lower double gate and spools. NU production tree. PT tbg hanger pack-off to 5k. Pull BPV and set FMC test plug. PT tree to 5000 psi. Pull test plug NU BOPE Test BOPE. Witness waived by AOGCC Line up on IA and pump 55 bbls diesel. Final differential pressure 300psi. Blowdown lines. RIU slickliner equipment including lubricator. RIH with slickline pulling tool. Pull DRC plug from GLM station #1. Run dummy GLM in station #1. Kickover tool activated in station #2 while RIH. POOH to recock tool. Run dummy GLM again to set in station #1. Had 2nd failure to set. Unable to set the dummy. Reconfigure setting tool. Attempt to set dummy GL V in station 1 again. This attempt was successful. Hold safety meeting prior to PT'ing IA. Pressure test dummy GL V in station #1. 1512 psi at 22:28 pm. 1465 psi at 22:45 pm. Holding like a rock for the last 10 minutes. RIH with slickline to pull the prong from the TT plug. Recovered prong ok. RIH to recover TT plug. POOH, tag up at surface with TT plug. Recovered plug and all seals. Nothing left in hole. Rig down HES slickline lubricator and eq. Slip and cut drilling line. Safety meeting prior to stabbing coil and pumping slack management. Stab coil into injector, change packoffs. Pump slack management prior to cutting 2500' of coil. Cut 2500' of coil. Install SLB Kendel CTC. Pull test to 35k. Rehead with BHI upper quick connect. PT to 4k P/U BHi tools and 2.50· nozzle for cleanout. RIH to 7030'. Log tie in at GR marker -5' correction RIH 2.0/2.0 3400 11.8ECD tagged at 7815' with no progress. PU to 7800' RIH went to 7830'. PU clean to 7775'. RIH to 7854' pu clean RIH tagged at 7857' PU to 7850'. RIH 7870'. Work area to clean up fine snad over the shaker at bottoms up and small amount o1"gas. Still introducing new mud to the hole but as of now at 1.96 bpm 3360psi with the ECD at 11.9ppg annular at 3580psi Well is Printed: 11/1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/6/2004 10/7/2004 Page 19 of 34 BP EXPLORATION Operations Summary Report Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Phase 1 Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Task Code NPT 15:00 - 16:50 1.83 DRILL P ¡WEXIT IWEXIT I ¡WEXIT !WEXIT I IWEXIT I I i I i , !WEXIT ¡ I IWEXIT I I I I I 16:50 - 18:30 1.67 DRILL P 18:30 - 19:30 1.00 CLEAN P 19:30 - 20:00 0.50 WHIP P 20:00 - 22:10 2.17 WHIP P 22:10 - 22:35 22:35 - 23:00 23:00 - 00:00 00:00 - 00:25 00:25 - 01:00 01:00 - 04:00 0.42 WHIP P 0.42 WHIP P 1.00 WHIP P WEXIT 0.42 WHIP P WEXIT 0.58 WHIP P 'WEXIT 3.00 FISH N HMAN WEXIT 04:00 - 04:45 0.75 FISH N HMAN WEXIT 04:45 - 06:15 1.50 FISH N HMAN WEXIT 06:15 - 06:40 0.42 FISH N HMAN WEXIT Spud Date: 6/10/1993 End: 8/28/2004 Operations ----.-.--- drinking about. 15bpm Shutdown pump and trapped 95psi on well. Stabilized annular 2911 psi and 9.86ECD reout (no circulation) TOH following pressure schedule designed to maintain 3500psi at window. Trap 200 psi on WHP, close the SSSV. Check for flow. None. Tag up, lay down nozzle BHA. Make up BHA #20. Baker 2.625" WS, Baker setting tool, BHI BHA. RIH with BHA #20 to set whipstock. EDC open, RIH at 80 fpm, circulating at minimum rate. Following Dan Kara pressure schedule. Losing fluid to hole while following pressure schedule. We are basically getting 1 for 1 retums, with no extra for pipe displacement. Losing 3.8 bbls for every 1000' we run in the hole. Log tie in pass over GR spike at 7760' based on Cement Bond Log of 7-16-2004. Make -10' correction. RIH position botton of WS at 7867', TOW at 7854'. Attempt to shut EDC. BHI had problems with the EDC. There is a new generation of EDC in hole. It only appears to close 67% of the way. BHI had to muck about in the diagnostics software for 10 minutes to get it shut completely. Pressure up on Baker setting tool. Got good indication of shear at 2670 psi. WS tool face for face of tray set at 0 deg. Set 3000 Ibs down on WS tray. It appears to be set. Depths for whipstock; TOWS=7854'. Pinch Point=7857' RA tag=7861.35' BOWS=7867' Attempt to open EDC to be able to pump while POOH. BHI couldn't get the EDC open. It would only open 67% of the way. BHI had to muck about in the diagnostics software again to finally get it open. Additionally, BHI reports power and coms are working, but rest of BHA is not working properly. Will need to change out for next run. POOH pumping 1 bpm to keep hole full. Follow pressure schedule while POH. Continue POH with whipstock setting BHA. Trap 400 psi below SSSV. Close SSSV, continue to POH. Tag up at surface. Lay down WS setting BHA. Found that BHI EDC had been activated to disconnect and the lower section of the BHA left in the hole. In theory, this is not possible. I am not too impressed with the new generation of BHI EDC tool. Call Baker TT for fishing equipment. Need a hydraulic GS, and a set of jars. They will prep and hotshot to rig ASAP. BHI has a model of the fishing neck, and gave to the BTT hand on location. The GS will match the model BHI has. The fish is 43.03'long, and should be setting on top of the whipstock. Top of fish at 7814'. Rig up fishing BHA. BHA #21 RIH with BHA #21 to retrieve fish. 2.5" Hydraulic G Spear, 2.125" Bowen Bi directional oil jars, 1 joint of 2-1/16" CSH, BHI MWD tool. Log tie-in at 7760' .84/.83 1992 psi annular 3515psi 11.79 Printed: 11/1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From- To 1017/2004 06:15 - 06:40 06:40 - 06:50 106:50 - 07:55 07:55 - 08:30 08:30 - 09:10 09:10 - 10:30 10:30 - 15:00 15:00 - 13:50 13:50 - 17:15 17:15 - 18:40 18:40 - 19:00 19:00 - 19:45 19:45 - 20:30 20:30 - 22:15 22:15 - 22:40 22:40 - 00:00 05:55 - 08:30 08:30 - 09:15 BP EXPLORATION Operations Summary Report Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Code NPT I Ph~se J____ Descriptieratiöns N HMAN- ~;;XIT i ECD 21 ap,; wetlh,ad -,' "",i: N HMAN IWEXIT ¡ RIH pumping at.9 bpm and tagged fish at 7812'. Seen I I pressure. Shutdown pump. P/U to 77790. RIH dry and tagged I iat7812. HMAN I WEXIT i TOH pumping down backside maintaining scheduled BHP to I i SSSV. Close SSV and continue TOH. HMAN WEXIT I Bleed trapped WH and monitor for flow. Pull BHA. Recovered ¡ entire fish. UD same and fishing tools. I' P/U window milling BHA ,RIH tagged pinch point. Correct depth and flag CT. ¡Time milling window 1.65/1.64 3060psi 11.71ecd 3528psi I annular milled to 7859.5' Need to stop and change shaker ! screens blinding off with sand changed to 135 and 110 mesh. ¡ Continue on time milling 500psi MW good show of metal : cuttings. Punch though at 7862.1', i Drill formation from 7862'.2 to 7867.2' 1.55/1.58 3125psi 111.84 ECD 3576psi annular. Drilled only 5' to prevent possible I interferance with other lateral below at 7874' I Ream and backream window area 3 times. 1.54/1.57 2900psi i 11.76 ECD 3550psi annular. Made dry run thru window - no Î problems. I TOH following pressure schedule. I Tag up at surface. Hold PJSM prior to making BHA swap. ì Check well for flow. No flow observed. WEXIT I Lay down BHA #22, window milling BHA. Mills recovered with I good center wear on the D0261 showing a swirt pattem. The D0261 gauged 2.74 90/2.73 no go. The string mill gauged 2.74 I go/2.73" no go. PROD1 " PU BHA #23. Hycalog DS100 2.7x3.0" bicenter bit, 2.8 deg BHI X-tream mud motor, Full BHI MWD tool. PROD1 RIH with BHA #23 to drill build section. Open SSSV with 500 psi on the wellhead. Follow choke schedule while RIH, pumping thru an open EDC at minimum rate. PROD1 Log tie in pass at 7680'. Make -10' correction. PROD1 RIH thru window slick with pumps down. Shut EDC. Orient to o deg. Pit vol=300 bbls. IAP=470 psi, OAP=363 psi. Come on line with pumps. Free spin=3160 psi at 1.65 bpm. Drilling with choke open. 1.64/1.66/3230 psi. BHP=3612 psi. ECD=11.9 ppg. PROD1 Continue drilling the build section of the well. 1.75/1.78/3460 psi. IAP=916 psi, OAP=581 psi. Pit vol=297 psi. TF=75R. ROP=25 fph. BHP=3670 psi. ECD=12.0 ppg. WHP=O. PROD1 Wiper trip to the window. Clean PU off bottom at 22 klbs. and back in the hole. PROD1 Resume drilling. 1.67/1.72/3440 psi. Pit vol=314 bbls. (Mud aired up from centrifuge). ROP=75 fph. @ 8155' TF 50R BHP=3714 ECD=11.95 Drilled to 8165' need to trip for lower bend motor. Pull above window. Open EDC. TOH following pressure schedule pumping at 2.4bpm flushing long tangent section. Change shaker screens to 175/175 Close SSSV. Tag up RIH 400' TOH flush annulus. PROD1 UD build assembly and P/u lateral BHA # 24 RR bit#11 1 Y -24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 0.42 FISH 0.17 FISH 1.08 FISH N 10/8/2004 00:00 - 03:05 3.08 DRILL 03:05 - 03:30 0.42 DRILL 03:30 - 05:55 2.42 DRILL 0.58 FISH N 0.67 STWHIP P 1.33 STWHIP P 4.50 STWHIP P 22.83 STWHIP P 3.42 STWHIP P 1.42 STWHIP P 0.33 STWHIP P 0,75 STWHIP P 0.75 DRILL P 1.75 DRILL p 0.42 DRILL 1.33 DRILL P P P P P 2.58 DRILL P 0.75 DRILL P Page 20 of 34 Spud Date: 6/10/1993 End: 8/28/2004 WEXIT ¡WEXIT jWEXIT I I WEXIT ! WEXIT WEXIT WEXIT PROD1 PrInted: 11/1612004 2:57:54 PM BP EXPLORATION Operations Summary Report Page 21 of 34 Legal Well Name: 1 Y-24 Common Well Name: 1 Y -24 Spud Date: 6/10/1993 Event Name: REENTER+COMPLETE Start: 8/10/2004 End: 8/28/2004 Contractor Name: NORDIC CALISTA Rig Release: 8/28/2004 Rig Name: NORDIC 2 Rig Number: 2 Date From - To Hours Task Phase Description· ofQþerati()r'I~ 10/8/2004 09:15-11:15 2.00 DRILL P PROD1 RIH .75bpm to 1900' put 275psi on annulus and open SSSV. Noted 250psi beneath. RIH following pressure schedule. 11:15 - 13:00 1.75 DRILL P PROD1 Tie-in from 7690' to 7904' 13:00 - 14:55 1.92 DRILL P PROD1 Directionally drill ahead f/8165' 1.47/1.51 3260psi Pit Vol= 312bbls BHP=3712 ECD=11.91 WHP=O 65fph 4-5k wob Drilled to 8310'. 14:55 - 15:20 0.42 DRILL P PROD1 Wiper trip to 7880'. 15:20 - 16:50 1.50 DRILL P PROD1 Directionally drill lateral f/8310' 1.59/1.72 9.48/9.453275psi 80-1oofph Pit vol= 308 bbls BHP=3780 EDC=12.14 WHP=O !A=780 OA=530 Bleed down IA > 200psi OA > 200psi 16:50 - 18:15 1.42 DRILL P PROD1 Wiper trip to window. Open EDC sweep 5' annulus. Clean back to bottom. 18:15 - 20:05 1.83 DRILL P PROD1 Resume drilling. IAP=340 psi, OAP=260 psi. Pit vol=302 bbls. Free spin=3350 psi at 1.69 bpm. Drilling at 1.68/1.863620 psi. BHP=3850 psi, ECD=12.33 ppg. In density=9.49 ppg, Out density=8.85 ppg. ??? Catch a sample from the possum belly and check with mud scale. Return mud weight using the mud engineers mud scale=8.7 ppg with the balance, and 9.5 with the presurized scale. No apparent gas in sample. No apparent gas breaking out of the mud in the possum belly. The mud appears a little 'moussed up', kind of like it has in past jobs where we have had crosslinking due to high lubricant content. This. along with the drill solids, and higher bottom hole pressures means we will call for new mud. 20:05 - 22:10 2.08 DRILL P PROD1 Wiper trip to up inside production tubing. Clean PU off bottom. Open EDC above window. Pump at 2 bpm, 3950 psi, pull at 50%, and pump 15 bbls of high vis sweep to clean tubing. Pull up to 6000', then rub back thru window. Shut EDC, and run to bottom. Set down at 8114' when RIH. PU, and made it thru on 2nd attempt. 22:10 - 23:20 1.17 DRILL P PROD1 Back on bottom. Still drilling with old mud. 9.49 ppg in, and 9.27 ppg out. The moussiness seems to be going away. On previous wells we were able to mousse up the mud by shearing the mud violently. We run the mud thru the choke when making a trip in and DOH, and this may be the reason for it. Drilling at 1.61/1.65/3550 psi. Pit vol=290 bbls. IAP=425 psi, OAP=350 psi. 23:20 - 00:00 0.67 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. 10/9/2004 00:00 - 00:35 0.58 DRILL P PROD1 Continue wiper trip back in hole. No problems at 8114' on this trip. 00:35 - 01:10 0.58 DRILL P PROD1 Resume drilling. Free spin with new mud=3360 psi at 1.63 bpm. Drilling at 1.62/1.64/3300 psi. ROP=150 fph. IAP=380 psi, OAP=320 psi. Annular pressure=3770 psi. ECD=12.1 ppg. New mud half way around. In denslty=9.47 ppg, out density=9.45 ppg. 01:10-02:40 1.50 DRILL P PROD1 New mud completely around. BHP=3690 psi. ECD=11.82 ppg. In density=9.48 ppg. Out density=9.53 ppg. The new mud seems to have cleaned up the mousse problem. 02:40 - 03:25 0.75 DRILL P PROD1 Wiper trip to window. Clean PU off bottom at 21 klbs. 03:25 - 03:55 0.50 DRILL P PROD1 Log tie in pass over RA tag in whipstock. Make +4' correction. 03:55 - 04:50 0.92 DRILL P PROD1 Continue back in hole on wiper trip. Set down at 8769'. Try it 3 Printed: 11/1612004 2:57:54 PM BP EXPLORATION Operations Summary Report Page 22 of 34 Legal Well Name: 1 Y-24 Common Well Name: 1 Y-24 Spud Date: 6/10/1993 Event Name: REENTER+COMPLETE Start: 8/10/2004 End: 8/28/2004 Contractor Name: NORDIC CALISTA Rig Release: 8/28/2004 Rig Name: NORDIC 2 Rig Number: 2 Däte From - ~J~ours Task Code NPT Phase Description of Operations 10/9/2004 03:55 - 04:50 i 0.92 DRILL P PROD1 times with the at drilled toolface of 90L. No luck. This was a I hard stringer (Ankerite?) when originally drilled. Orient to 45L, I and got thru it. Probably a hard ledge. Continue to bottom ! clean. 04:50 - 06:00 : 1.17 DRILL P PROD1 Resume drilling. Free spin 2800 psi at 1.5 bpm. Drilling at 1.5/1.5/2890 psi. ROP=110 fph. IAP=230 psi, OAP=170 psi. Pit vol=463 bbls. BHP=3680 psi with 0 psi WHP. ECD=11.8 ppg. In density=9.47 ppg, Out density=9.53 ppg. Mud out looks normal - No Mousse. 06:00 - 08:35 2.58 DRILL P PROD1 Wiper trip to window open ECD continue to 6000'. No problems. Held "Parted Coil Drill". 08:35 - 11 :30 2.92 DRILL P PROD1 Directionally drill ahead f/ 9060' 1.58/1.68 3030psi BHP=3700 EDC=11.87 Drilled to 9214' 11 :30 - 13:30 2.00 DRILL P PROD1 Wiper trip to window. RIH setdown at 9055' pick up then went trough. RIH wt at TD 1800# 20fpm Held "H2S Drill" 13:30 - 17:45 4.25 DRILL P PROD1 Directionally drill ahead f/9214' 1.58/1.60 FS=2950psi 2-300psl mw BHP=3730 ECD=11.9 pits=435bbls (aired up) IA=343 OA=250 ankorite drilling on bottom 15fph. Chert nodules in last few samples. Then at 1710hrs drilling break at 9313' 120'/hr 1.5311.609.48/9.45 3OO0psi FS 2-300psi MW BHP=3740 ECD=12.03 pit vol 426 bbls Lost 80% retums at 9363'. BHP=3520 Drilled ahead regaining retums slowiy at 9372' 1.54/1.06 increasing to 1.12 at 9385'. BHP=3680 17:45 - 18:50 1.08 DRILL P PROD1 Wiper trip. Ratty PU off bottom up to 9300', then smoothed out. Pulling at 27 fpm, 1.54 in, 1.27 out. Retums have mostly healed up. Losing about 0.2 bbl/min. (12 bph) 18:50 - 19:50 1.00 DRILL P PROD1 Open the EDC at the window, and pull up hole pumping 2.211.94 bpm to 6000'. 19:50 - 20:20 0.50 DRILL P PROD1 Run back to window, and log tie in pass over the RA tag at 7862.5'. Make -15' correction. 20:20 - 21 :05 0.75 DRILL P PROD1 Continue wiper trip in back to bottom. 21:05 - 23:15 2.17 DRILL P PROD1 Resume drilling. IAP=6QO psi, OAP=450 psi. Pit vol=380 bbls. Drilling 1.64/1.79/3500 psi. In density=9.5 ppg, Out density=9.1 ppg. It appears the mud is moussing up a bit again. ROP=120 fph. 23: 15 - 00:00 0.75 DRILL P PROD1 Pit vol=373 bbls. Wiper trip to shoe. Clean PU off bottom at 21 klbs. BHP=3820 psi, 12.2 ppg. 10110/2004 00:00 - 01:10 1.17 DRILL P PROD1 Continue wiper trip to window, and back to TD. No problems up to the window. Set down at 9072' while RBIH. (Ankerite stringer). Picked up, hit it a 2nd time, then bounced thru. 01:10-02:45 1.58 DRILL P PROO1 Free spin 3490 psi at 1.65 bpm. Resume drilling. 1.65/1.58/3550 psi. Pit voJ=365 bbls. Lost 8 bbls of mud in last 2 hours. IAP=720 psi, OAP=530 psi. BHP=3820 psi. ECD=12.23 psi. Surface string weight=-7000 Ibs. Density In=9.48, Density out=9.52 psi. 02:45 - 05:00 2.25 DRILL P PROD1 9588', Hit an Ankerite stringer. Drilling at 10 fph. -7000 Ibs string wt at surface. 3500 Ibs downhole weight on bit. 150 psi Printed: 11/1612004 2:57:54 PM BP EXPLORATION Operations Summary Report Page 23 of 34 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 From - To Hours Task Code NPT Phase . Description of Operations 10/10/2004 02:45 . 05:00 2.25 DRILL P PROD1 motor work. Just going to have to nibble our way thru it. 05:00 - 05:20 0.33 DRILL P PROD1 Still beating our head against the wall. Drilling the same hard Ankerite stringer. Geo reports some pyrite in the samples, which won't help our ROP. Drilling at about 25 fph. 05:20·06:10 0.83 DRILL P PROD1 Back in the good stuff! 1.68/1.67/3740 psi. Drilling at 140 fph. I 350 bbls in the pits. IAP=522 psi, OAP=271 psi. BHP=3880 \ psi. ECD=12.43 ppg. Drilled to 9650' then back to the bad. Drill on to 9670'. 06:10 - 08:20 2.17 DRILL P PROD1 Wiper trip to 6000' opened EDC above window. 08:20 - 09:30 1.17 DRILL P PROD1 RIH to 7860' 09:30 - 09:45 0.25 DRILL P PROD1 Log tie-in +2.5' 09:45 . 11 :00 1.25 DRILL P PROD1 Continue RIH 11:00 - 12:10 1.17 DRILL P PROD1 Drilling ahead fl 9670 3050psi FS 300psi MW 1.52/1.49 BHP=38oo ECD=12.20 holding at 120'/hr. Drilled to 9785' and hit another ankorite string. Town wants to call this TD. 12:10 - 14:50 2.67 DRILL P PROD1 Wiper trip to window. RIH no problems. 14:50 - 18:00 3.17 DRILL P PROD1 TOH. No problems off bottom. Following pressure schedule to SSSV. Close valve trapping 350psi. Pull to 200' then RIH to 1000'. TOH 18:00 - 18:40 0.67 DRILL P PROD1 Tag up at surface, lay down BHA #24. Bit recovered in decent shape. DD Graded as 2,2 with 1 chipped cutter on the pilot section. 18:40 - 19:00 0.33 RUNCO RUNCMP Hold PJSM prior to running liner string #1 on 'A' lateral leg. Discuss hazards of running liner, and mitigations to hazards. 19:00-21:00 2.00 RUNCO RUNCMP Make up BHA #25, 'A' lateral liner string #1: 21 :00 - 21 :35 0.58 RUNCO Baker bullet botton nose·10' bent pup jt (1.8 deg)-O ring sub-37 joints of 2-318' predrilled liner at 8 holes/ft·Baker slim/shorty deployment sleeve. Liner string length=1171.01 '. RUNCMP Make up BHI tools to G spear, and attach to liner. BTT hand reports that the deployment sleeve profile has been modified to avoid the problems observed on 1 F pad that prevented releasing from the liner. 21 :35 - 22:00 0.42 RUNCO 22:00 - 22:15 0.25 RUNCO 22:15 - 23:30 1.25 RUNCO 23:30 - 00:00 0.50 RUNCO 10111/2004 00:00 - 01:00 1.00 RUNCO 01 :00 - 02:30 1.50 RUNCO RUNCMP DFAL RUNCMP DFAL RUNCMP RUNCMP RUNCMP RUNCMP MU injector, check the BHI tools. RIH with BHA #25. EDC is open. Pumping at minimum rate. Open SSSV, and follow choke pressure schedule while RIH. Bhi has a short in the BHA. The sort occured at 2500' while RIH. Pull back to surface to repair. Tag up. check for flow. Lay down BHI MWD tool. Found electrical short in BHI upper quick connect. Repair problem. Run back in hole with liner BHA. BHI tool working correctly. Continue RIH pumping at minimum rate thru an open EDC. Following choke pressure schedule while RIH. Weight check at window. Up weight=22 klbs. RtH thru the window. RIH weight= 7400 Ibs. Slick thru the window. Slick in open hole. Slight hang up at the A6 sand at 8125', then fell thru. Made it to 8556'. PU with ratty overpull at 30 klbs, tried to orient 90 deg right, and only got about 30 deg before the orienter locked up. RBIH, and made it past the first bad spot. Ratty running from 8556'. Try to orient to the left. Came all the away around to 315 deg. Set down at 8677'. PU at 29 klbs. RtH, and still hanging up. Orient around to the right 90 deg. Printed: 11'1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/11/2004 01 :00 - 02:30 02:30 - 02:55 02:55 - 04:25 04:25 - 04:35 04:35 - 04:55 04:55 - 05:10 BP EXPLORATION Operations Summary Rep.ort 1Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task Code lNPT' Phase ! 1.50 RUNCO RUNCMP DPRB I RUNCMP DPRB RUNCMP 0.17 RUNCO DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP Page 24 of 34 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 of Operations Set down at 8656'. PU to 8600', RIH with TF at 90R. Tagged up at 8645'. Orient to 0 deg. RIH and set down at set down at 8644'. PU, orient to 180 deg. RIH and made it thru bad spot. Continue in hole. Set down at 8819', PU and made it thru. Set down at 8935,9032, PU and set down 3 more times at 9030'. PU and got thru. Made it to 9085'. PU, set down at 9147', 9169'. Can't get thru, orient to 90L. Set down at 9159'. Orient to 120L, set down at 9163'. Orient to 60L, set down at 9138'. Orient to 90R, and made it to 9170'. Set downs at 9183',9203, 9193,9189', Orient to 270L. Set downs at 9220,9215',9216', Orientto 180 deg. 9215',9220,9221', Orient to 0 deg. Set down at 9215',9221,9215,9221', Orient to 60R. 9218', then made it to 9243'. 9242', Orient to 120R. 9240',9267',9265'. 9259'. Orient to 90R, 9264', 9282', 9282', 9283', 9273', 9271 '. Orient to 150R. 9276',9269',9273',9272, Orient to 150L, 9268', 9272', Orient to 90L, 9267', 9261'. Orient to 60L, 9255', 9266', Heavy pickups at 36 klbs. 9252'. Orient to 0 deg. 9233', Orient to 60R, 9231', 9240', 9243', Orient to 120R, 9260',9269',9271'. Orient to 100R 9269', 9285', 9283'. 9288', 9285',9277. Stack 2000 Ibs on WOB, and try rotating orienter 360 deg to the left. Continue trying to work liner to bottom. Orient to 150R. 9299', 9298',9291,9284',9289',9282',9279'. Orient to 150L. 9271', 9278',9275',9276',9295,9287'. Orient around to the right from 150R in 20 deg increments. 9286'. TF=150R. Try the Dave Duerr technique. Stack weight at 9282', shut EDC, and kick pumps on and pump 15 bbls. Trap 200 psi on WHP, open EDC. PU, RIH, made good hole. and tagged at 9343',9385',9383',9392',9389',9393',9402',9405'. Repeat the pump sequence. RIH easily to 9532', PU, 9561', 9561',9561. This seems to be working good. Repeat pump sequence. RIH making hole to 9653',9654', 9652'. Repeat pump sequence. Made hole to 9718',9717,9714',9714'. Repeat pump sequence. RIH easily to TD at 9796'. PU tag again, this is it. (Tied in depth we drilled to was a TD of 9785') Close ECD, Bring pumps on to 1.95 bpm, 3950 psi. PU at 23 klbs, ratty. Last PU prior to tagging bottom was 26 klbs. RIH, set down at 9778', Stack weight. Rate to 2 bpm, 4050 psi. PU at 24 klbs. DHWOB shows -1750 Ibs on pickup. Probably still have the liner. RIH to 9774'. 2.2 bpm at 4500 psi. PU at 26 klbs, DHWOB=-2600 Ibs. Still have liner. RIH, and set down at 9746', Need to get liner back to bottom. Pump 15 bbls, down on the pumps, RIH. Made it to 9779',9780', then stopped. Repeat pump sequence. RIH to 9796', Back on bottom again! One possibility is the GS is functioning properly, but the keyed portion is in a bind from the orienting we have been doing. Stack weight on BHA. DHWOB shows 6000 Ibs of compression in BHA. Bring up pumps to maximum rate, 2.2 bpm, 4750 psi. PU until DHWOB shows -1000 Ibs indicating the BHA is in tension. Rotate the orienter to remove the bind from the lower GS keyway profile. Cycle string weight trying to get released from GS. No luck, Printed: 11/1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From· ~To 10/11/2004 05:10-05:25 05:25 - 06:15 06:15 - 06:20 Page 25 of 34 BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: Code NP~Phase RUNCOf ~PRB RU~CMP I 1Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 0.25 0.83 RUNCO I DPRB RUNCMP 06:20 - 06:50 RUNCMP 06:50 - 07:10 RUNCMP 07:10 - 09:00 RUNCMP 09:00 - 09:15 RUNCMP 09:15 - 09:25 RUNCMP 09:25 - 11 :45 RUNCMP 11 :45 - 13:25 RUNCMP 0.08 RUNCO DPRB RUNCMP 13:25 - 14:50 1.42 RUNCO RUNCMP 14:50 - 15:05 0.25 RUNCO RUNCMP 15:05 - 16:25 1.33 STWHIP N SFAL PROD2 16:25 - 18:15 1.83 STWHIP P PROD2 18:15 - 18:35 0.33 STWHIP P PROD2 18:35 - 19:30 0.92 STWHIP P PROD2 19:30 - 20:30 1.00 STWHIP P PROD2 20:30 - 21:00 0.50 STWHIP P PROD2 21:00 - 22:30 1.50 STWHIP P PROD2 22:30 - 23:30 1.00 STWHIP P PROD2 8/10/2004 8/28/2004 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations Keep cycling the weight up and down, while turning the orienter, trying to get released. Cycle pump rate from 1.5 to 2.2 bpm. Watching DHWOB. Try cycling coil up and down as fast as possible to jerk the profile free. Keeping pump rate at 1.95 bpm. PU to 9763', DHWOB=-17oo Ibs, and we can't run back in. We still have the liner. Work the liner back down to I bottom. Back on bottom at 9796' (Uncorrected). PU until the BHA is in tension. Rotate the orienter. Try to slack off and pick up to see if we can get free. Make a full 360 rotation in 20deg increments. Check pressures with EDC open and closed. Open EDC pump at 2.15 3800psi vs 4700psi with it closed. SD purnp close surface choke trap 450psi. Close EDC. Open EDC coil wt at 20k(neutral wt.) crank up pump 2.4 at 4800psi then setdown -12k then plu hard on liner. Liner released. P/U wt steady 18-20k that's 10k less than all previous pick-ups. TOH to 7850. Tie-in log -13' correction. Flag pipe at 7900'. TOH following pressure schedule to above SSSV. Close SSSV trapping 3OOpsi. TOH UD BHI and BTT tools. PJSM review Liner Running procedures and hazards, using Lift Subs for the straight bladed centrilizers. Review liner assembly. Change elevator. Start picking up Leg #2 of Lateral A's liner BHA #26 . MU Weatherford Aluminum billet and BHI tools. RIH open SSSV follow p sheduJoe. Check wt at window 21k up. RIH wt 6k RIH setdown at 8581' pIu 26k RIH stop at 8574' quick plu RIH to 8625' uncorrected (bottom at 8614') plu and repeat. Shutdown pump traop pressure and choke. Close EDC . Pump at 1.3bpm 4200psi plu and release from liner PU wt 19k. TOH following presssure shedule. UD liner running tools. PIU BHA #27. Baker having tool problems. RIH open SSSV following RIH pressure schedule. Log tie in pass over RA tag in Whipstock. Make -16' correction. RIH, tag top of whipstock/Deployment sleeve at 7906'. PU, and begin time drilling at 3fph from 7905'. TF=135R. IAP=56 psi, OAP=59 psi. BHP==3630 psi. WHP=O psi. ECD=11.91 ppg. Pit vol=287 bbls. Free spin=3340 psi at 1.66 bpm. Begin time drilling at 6 fph. TF=135R. Start controled drilling at 45 fph. No stalls. We appear to be off the whipstock. Drill ahead until MWD confirms we are not in the old wellbore. Drilled to 7931', and confirmed that we are sidetracked from MWD data. PU and run back to bottom dry. Made it thru sidetrack at WS top with no problems. POH to pick up build section BHA. Follow pressure schedule and pump at full rate while POOH. Tag up at surface. Check well for flow. No flow observed. Printed: 11/1612004 2:57:54 PM BP EXPLORATION Operations Summary Report Legal Well Name: 1 Y-24 Common Well Name: 1Y-24 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task COde NPT 1 0/1 ~;;¿;~-- ¡-;;30 - 23:30 1.00 STWHI P P I I ! 23:30 - 00:00 0.50 DRILL P I ¡ 10/12/2004 :00:00 - 01:10 i 01:1 0 - 01 :35 [01:35 - 05:15 I I 105:15 - 05:30 105:30 - 06:00 ¡ 06:00 - 07:55 I I J 07:55 - 08:20 108:20 - 09:15 I 109:15 - 10:55 i 10:55 - 11 :50 i i 11 :50 - 12:40 I I 112:40 - 13:05 ! i I I I i 13:05 - 13:30 13:30 - 16:40 16:40 - 17:05 17:05 - 19:45 19:45 - 22:00 22:00 - 23:30 23:30 - 00:00 10/13/2004 00:00 - 02:00 02:00 - 02:30 02:30 - 05:00 1.17 DRILL P 0.42 DRILL P 3.67 DRILL P 0.25 DRILL P 0.50 DRILL P 1.92 DRILL P 0.42 DRILL P 0.92 DRILL P 1.67 DRILL P 0.92 DRILL P 0.83 DRILL P 0.42 DRILL P 0.42 DRILL P 3.17 DRILL P 0.42 DRILL P 2.67 DRILL P 2.25 DRILL P 1.50 DRILL P 0.50 DRILL P 2.00 DRILL P 0.50 DRILL P 2.50 DRILL P Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 PhaseL PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Page 26 of 34 Spud Date: 6/10/1993 End: 8/28/2004 Description Change bit from STR324 to DS100 bicenter. Recovered bit graded 1. 1. Leave motor bend at 1.7 deg. RIH with BHA #28. Hycalog bicenter bit. 1.7 deg motor. Full MWD BHA. Continue RIH with BHA #28 to drill L 1 build section. Log tie in pass over RA tag in window whipstock. Made -14' correction. Begin drilling build section. Free spin 3130 @ 1.55 bpm. Pit vol=283 bbls. IAP=60 psi, OAP=45 psi. Mud density in/out=9.45/9.53. Wiper trip to window. Clean. Resume drilling build section. Continue drilling build section. 3150psi FS 1-200psi mw @ 1.60bpm 1 oo'+/hr 9.47/9.50 BHP=3650 Wiper trip above window clean running in past AI. billet Continue drilling build section. 3220psi FS 400psi mw @ 1.60bpm 100'+/hr 9.47/9.40 BHP=3760 ECD: 12.0 Drill to 8377' Wiper trip to 6000'. Clean to bottom. I Directionally drill ahead fl 8377' 9.52/9.48 3130psi FS at 1.6bpm BHP=3740 ECD=11.97 Wiper trip to window. SD pumps pulling thru OH whipstock. Orient to 135 R, and pumps down when running back down thru it. No problems observed up or down thru whipstock. Free spin 3126 psi at 1.54 bpm. Resume drilling in sand. Well is landed but town Gee wants to drill ahead with high dogleg motor to be ready for fault. Potential for high doglegs in initial part of lateral and subsequent reduction in lateral length discussed. Drilling with TF=90R. 1.53/1.57/3501 psi. BHP=3750 psi. ECD=12.02 ppg. In/Out density=9.5/9.48 ppg. IAP=270 psi, OAP=200 psi. Pit vol=278 bbls. Geo wiper to let town look at logs. Pull up to the window and wait. At the window. Wait on orders from town. RIH to continue drilling lateral section with build section BHA. (Average dog leg 21 deg) Resume drilling. Free spin 3200 psi at 1.59 bpm. Pit vol=262 bbls. IAP=290 psi, OAP=244 psi. INC=95 deg. Drilling ahead smoothly. POOH to change motor angle and check bit. Close SSSV with 500 psi WHP. PJSM in Ops Cab before getting to surface. At surface. Get off well. Unstab coil. Hycalog bit in good condition (1-1). Change out motor. AKO adjusted to 1.1 degrees. Stab coil. Get on well Run in hole. Open SSSV with 500 psi on well head. Continue to RIH as per pressure schedule Continue to RIH as per WHP pressure schedule. Some tight spots near TD. Back ream same. Begin getting gas in rtns. Divert one btms up to tiger tank. Monitor tank. Drill ahead. 3700 psi at 1.71 bpm fs. 200-300 dpsi. Rtns:1 :1. TF:270 deg. Inc: 96 deg. BHP: 3827 psi. ECD:12.3 ppg WHP:50 psi. Begin displacing to new mud. ROP variable. Printed: 11/1612004 2:57:54 PM BP EXPLORATION Operations Summary Report Legal Well Name: 1Y-24 Common Well Name: 1 Y-24 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ßrom - To Hours Task 10/13/2004 05~~~6:15 1.25 DRILL P 06:15 - 09:25 3.17 DRILL P I I I ODD - 09,25 1.92 DRILL P I 109:25 - 10:05 0.67 DRILL P Page 27 of 34 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations ~--'--'---- PROD2 Wiper trip to window. PROD2 Resume drilling. Free spin 3157 psi at 1.54 bpm. Holding 130 psi WHP. BHP=3837 psi. ECD=12.38 ppg. Drilling at 1.54/1.58/3300 psi. In/Out Density=9.43/8.81 ppg. IAP=60 psi, OAP=50 psi. PROD2 Long wiper to 6000'. Clean PU off bottom. Getting crude and gas back in returns. Taking returns outside to the tiger tank. Will do a BHP check after the wiper to determine new BHA. PROD2 Stop at window. Trap 400 psi, and SI choke and pumps. 09:30 BHP=3625 psi WHP=6Q5 psi ECD=12.15 ppg. 09:45 BHP=3812 psi WHP=894 psi ECD=12.63 ppg. 10:00 BHP=3813 psi WHP=941 psi ECD=12.63 ppg. Kick on pumps and circulate bottoms up to clean up wellbore. Holding 3950 psi BHP. Getting considerable gas to surface and hose to tiger tank is jumping. Shut down pumping and secure well. Gather up the troops, and hold safety meeting to discuss well kill. Circulate out kick. Taking returns to tiger tank. Call for 10 ppg mud from MI. Call for Kuparuk vac truck to shuttle used mud from tiger tank to pits. RIH to circulate bottoms up from TD. Tagging up at A6 sand at 8050'. Had to drop rate to get thru. Tagged up in A3 shale at 8767' and couldn't get thru. Ream shales near 8760'. Holding drilled tool face. Getting packed off around BHA, and pit volume=150 bbls. Take a bite, and chase it up to the window so we can do another mud swap from the tiger tank. SI pumps at the window trapping 900 psi. Transfer fluid from tiger tank to the rig via AES vac truck. Ream to btm. Several tight spots. but able to get through by varying pump rate. No overpulls, just several set downs while RIH. Some packing off. Ream out of hole at 25 fpm. Hole looks a lot better, at least no overpulls. Taking rtns to Tiger. 1:1 according to 30 minute strap. Pull into liner above window. Hold 3950-4000 psi on formation while circulating at min rate, waiting on rest of 10.0 ppg mud. Line up vac trucks. Displace well to 10.0 ppg flopro while RIH. Tag up at several spots from 8050 to 8150. Appear to be packing off. Reduce pump rate to 1.04 bpm @ 2580 psi. 1:1 rtns. Smooth from 8100 to 8825. WHP: 400 psi. ECD: 12.7 to 13.0. BHP: 3990 psi. Set down at 8826,8860. Reduce circ rate to 0.4 bpm. Continue in hole. Increase rate to 1.55 bpm I 3700 psi fs. Lots of gas with old mud gettting to surface. Divert outside. Continue to circulate off btm to get new mud around. Continues to try and pack off when RIH near 9025. 10:05 - 10:45 0.67 DRILL P PROD2 10:45 - 11 :00 0.25 DRILL P PROD2 11 :00 - 14:20 3.33 DRILL P PROD2 14:20 - 15:15 0.92 DRILL P PROD2 15:15 - 16:00 0.75 DRILL P PROD2 16:00 - 16:45 0.75 DRILL P PROD2 16:45 - 18:00 1.25 DRILL P PROD2 18:00 - 19:00 1.00 DRILL P PROD2 19:00 - 21 :30 2.50 DRILL N WAIT PROD2 21 :30 - 23:30 2.00 DRILL P PROD2 23:30 - 00:00 0.50 DRILL P PROD2 Back ream hole to try and clean up shale intervals, to clean up pack off problem. Increase BHP to 4250 psi, 13.7 ppg ECD. Back ream to 8500. Run back in hole. 1.66 bpm @ 4000 psi fs. WHP: 285 psi. Having trouble getting past 8679. Printed: 11/1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/14/2004 03:00 - 04:15 04:15 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 08:15 08:15 - 10:40 Page 28 of 34 BP EXPLORA TJON Operations Summary Report 1.50 DRILL 0.25 DRILL 2.42 DRILL Start: Rig Release: Rig Number: Phase 8/10/2004 8/28/2004 2 Spud Date: 6/10/1993 End: 8/28/2004 PROD2 PROD2 PROD2 P P P PROD2 PROD2 PROD2 1 Y-24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 FrofT)_-_~~j~~our~gask Code NPT 00'00 - OJ,30 i ,.501 DRILL P ! I ! \ 01 :30 - 03:00 i 1.50 I DRILL P I I I I 1.25\ DRILL P I I I 0.751 DRILL 1.00 II DRILL 0.50 DRILL N RREP PROD2 N RREP PROD2 N RREP PROD2 10:40 - 10:45 0.08 DRILL N RREP PROD2 10:45 - 11 :25 0.67 DRILL N RREP PROD2 11 :25 - 11 :50 0.42 DRILL N RREP PROD2 11:50-12:50 1.00 DRILL N RREP PROD2 12:50 - 13:00 0.17 DRILL P PROD2 13:00 -15:20 2.33 DRILL P PROD2 15:20 - 17:30 2.17 DRILL P PROD2 17:30 - 21:00 3.50 DRILL P PROD2 Description of Operations Drill ahead. 1.55 bpm @ 3900 Is. 200-400 dpsi. 1:1 Rtns. Very soft formation. high ROP. WHP: 350 psi. BHP: 4300 psi. ECD: 13.7-9 ppg. Some gas in rtns. Able to take rtns to pits most 01 the time. Climbing at 93.7 deg to get into upper target lobe. PVT: 355 bbls. Wiper trip to top 01 lirst liner. Motor work at 8650 on up pass. Several rough spots from 8600 to 8900 on trip back in. Only one set down, hole seems to be improving. Maintained 1.49 bpm, ran at 35 Ipm. Drill ahead. 1.49 bpm @ 3650 Is. 200-400 dpsi. 1: 1 Rtns. Very soft formation, high ROP. WHP: 311 psi. BHP: 4223 psi. ECD: 13.6-7 ppg. PVT: 335. Some gas in rtns. Able to take rtns to pits most of the time. Reduce angle to 91 deg in upper target lobe. Wiper trip to window. Log GR tie in. Make +3' correction, RIH. Drilling ahead at 180 fph. Free spin 3550 psi at 1.5 bpm. Drilling at 1.5/?/3690 psi. Taking returns to the tiger tank. IAP=60 psi, OAP=45 psi. Pit vol=239 bbls. WHP=4oo psi, BHP=4230 psi. Driller found large blister on choke side rubber 3· flex hose. Need to repair ASAP. Pull up to the tubing tail to make repairs. Wiper trip up thru shaley interval mostly clean execpt lor overpulls and motor work at 8650'. Safety meeting prior to starting rig repairs. Hazards, and mitigations to hazards discussed. Shut lower 2· combi rams. Blow down stack. Shut choke side HCR and manual valve. 3 barriers to flow. Change out flex hose on choke side of BOP. Pressure test hose with test pump against a blocked HeR valve. PT to 3800 psi. Held pressure fine. Pull up hole to inspect pipe where combi rams were shut to ensure that it is in good shape. RBIH, holding 14.4 ppg ECD. Log tie in pass over RA tag. Make -6' correction. RBIH to resume drilling. Pumping 1.0 bpm, holding 750 psi on the well. BHP=44oo psi. Returns are comeing inside, and are free of gas and crude. A few weight bobbles at 8700'. Had to work it to get past 9300'. Resume drilling. Keeping retums inside. Pit volume=337 bbls. IAP=60 psi, OAP=21 psi. Free spin =3880 psi at 1.63 bpm, and 420 psi. Drilling at 1.65/1.65/3930 psi. Getting gas back. Take returns outside. Continue drilling ahead. Wiper trip to the shoe. Clean PU off bottom at 24 klbs. Some small overpulls and motor work from 8700'-8600', but better than it has been previously on the way up. Relatively clean back to bottom. Minor motor work and no set downs going back thru shale from 8500'-8900'. Had to work it down from 9300'. Drill ahead. 1.65 bpm @ 4000 psi fs. 200-400 dpsi. 1:1 rtns. WHP: 510 psi, ECD: 14.14 ppg, BHP: 4360 psi. Soft formation, ROP variable. Hold 93 incl. Rtns to tiger tank due Prinled: 11/16r2004 2:57:54 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: From - To 10/14/2004 17:30 - 21 :00 21 :00 - 22:30 10/15/2004 00:00 - 03:00 22:30 - 00:00 03:00 - 03:45 03:45 - 04:00 04:00 - 06:00 06:00 - 06:15 06:15 - 06:30 06:30 - 08:00 08:00 - 08:40 08:40 - 10:45 BP EXPLORATION Operations SUn:f1'l'laryReport 1 Y-24 1 Y-24 REENTER+COMPlETE NORDIC CALISTA NORDIC 2 Hours 1 Task Code NPT 3.50/ DRILL P 1.50 DRILL P I I 1.50 DRILL i P I I 3.00 DRILL P Page 29 of 34 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 PROD2 PROD2 PROD2 PROD2 0.75 DRILL P 0.25 RUNCO 2.00 1 RUNCO 0.251 RUNCO 0.251 RUNCO 1.50 I RUNCO 0.67 r RUNCO I I I 2.081 RUNCO PROD2 RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Description of Operations to gas. PVT: 121 bbls. Load pits with new 10.5 ppg flopro. Wiper trip to window to tie in. Prep to lay in new mud. Rtns going outside to tiger. GR tie in correction: add 2.5'. Official TD is 9678'. Run in hole, wiper to TD. A few sets downs: 9361, 9390, 9535. Verify TD. POOH laying in new mud. POOH for final wiper pass. Lay in new mud. Close SSSV with 900 psi on well. COntinue out of hole. At surface. Get off well. Unstab coil. LD drilling BHA. Hold PJSM with crew to discuss liner running procedure. MU 60 jts 2-318' pre-drilled liner with round nose guide shoe, o-ring sub, and shorty GS deployment sleeve. Safety meeting re running liner. Hazards of tagging SSSV are discussed and mitigations to hazards reviewed. Make up remaining liner. Make up BHI BHA. Confirm that the tool works electrically. Make up injector. Pressure up WHP to 1000 psi. Open SSSV. RUNCMP Kick on pumps to minimum rate. RIH with BHA #30 holding pressure schedule. Swabbing mud away, only getting a trickle of returns. Stop at the window. Make a -14' correction (Average of last runs). Check weight up = 22500 Ibs. RIH weight at the window=7000 Ibs. BHI WOB=-5OO0 Ibs. DPRB RUNCMP RIH slick past OH whipstok on top of "A" lateral. Slick to 8710', set down. PU at 28k Ibs and sticky. Work pipe down slowly. RIH weight=45oo Ibs, WOB=-1000 Ibs. Stack weight, and can't get thru. Stack +8000 Ibs down hole. Try the Dave Duerr pump technique. Shut the EDC, bring the pumps on to 1.5 bpm, and pump 15 bbls. Open EDC. Work pipe. No luck. Still can't get past 8710'. Tag up solid each time we set down. Work pipe repeatedly. Hit it from 10 to 100 fpm, and set down at the same place. Stack weight and watch it for 10 minutes, no movement. PU to 8650'. RIH slow while we shut the EDC and bring pumps on. No luck. Can't get past 8710'. The log shows a small sand at this depth in the midst of the 500' shale we drilled. May be a ledge here due to gauge hole in the sand with washed out shale on each side. Hole 'nc is 95 deg, so this doesn't help any. PU 100' and RIH to hit it as hard as possible. RIH at 150 fpm. Still can't get thru it. Need to make cleanout run. Call town while we POH. Last PU off of tight spot =26000 Ibs. WOB=-7oo0 Ibs. We still have the liner. PUH clean in OH, and thru window. Follow pressure schedule on way OOH. Tag up at surface. Shut SSSV. Hold no-flow check and safety meeting to discuss standing back liner. Lay down BHI BHA (#30). Stand back 2-318' predrilled liner in derrick. Inspected bottom nose, and did not find any plugging in guide shoe. It was a clean as it could be. Make up BHA #31. Hycalog DS100 bi center bit. 1.1 deg motor. Full BHI MWD eq. RIH with BHA #31 to cleanout well. Log tie in pass over RA tag. Make -16' correction. 10:45 - 12:25 DPRB RUNCMP 12:25 - 12:50 0.42 RUNCO DPRB RUNCMP 12:50 - 13:05 0.25 RUNCO DPRB RUNCMP 13:05 - 14:00 0.92 RUNCO DPRB RUNCMP 14:00 - 14:45 DPRB RUNCMP 14:45 - 16:30 1.75 RUNCO DPRB RUNCMP 16:30 - 16:45 0.25 RUNCO DPRB RUNCMP Printed: 1111612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/15/2004 16:45 - 19:00 19:00 - 19:45 19:45 - 20:45 20:45 - 22: 15 22: 15 - 23:00 23:00 - 00:00 10/1612004 00:00 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 08:30 Page 30 of 34 BP EXPLORATION Operations Summary Report 0.75 F!UNCO~ I ! 1.00 RUNCOrr I 1.50 RUNCOt i ! 0.75 1 Y -24 1 Y -24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task I Code NPT Phase 2.25 RUNC~ DPRB RUNCMP I I i 2.50 1.00 DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP DPRB RUNCMP Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations -~-~- RIH to clean out shale from 8500-8900'. Slick down thru build section. Set TF to as drilled TF of 90L, ran down and set down at 8707'. PU at 19 klbs, slightly ratty. Repeat set down several times. Orient to high side and RIH, set down at 8704'. Able to get to 9500' with pump rate at 0.59 bpm. Back ream hole from 8950 to 8500 at 10 fpm. 1.5 bpm @ 3900 psi fs. BHP: 4400 psi, ECD: 14.38 ppg, WHP: 510 psi. 1:1 rtns, PVT: 210 bbls. Ream in hole at 25 fpm. 1.55 bpm @ 3820 fs. A few set downs, hole mostly smooth. High EDC probably holding back formation. Ream to 9550'. Ream ooH from 9550' at 25 fpm. 1.55 bpm @ 3800 psi fs. Some mtr work, mostly smooth. 1.55 in/1.36 bpm out. BHP: 4550 psi, ECD: 14.3 - 14.6 ppg. Ream to 8500. TF: 90R. Ream to 8500. Ream in hole at 25 fpm. 1.55 bpm @ 3820 fs. A few set downs, hole mostly smooth. Problem spots: 8670, 8730. High EDC probably holding back formation. Ream to 9550'. Ream ooH at 10 fpm. 1.55 bpm @ 3850 psi. BHP: 4600 psi. ECD: 14.5 ppg. WHP:450 psi. Continue to back ream hole while circulating new 10.5 ppg flo pro. 1.55 bpm @ 3850 psi fs. 1:1 rtns. BHP: 4600 ps.i ECD: 14.4 ppg. WHP: 475 psi. 30 fpm coil speed. Overpulls from 8750 to 8650. Ream down and back again at 1.45 bpm, 10 fpm. Got stuck at 8680'. Pull 45k. Unable to go down. Able to circ at full rate. SHut dn pumps. Relax hole. Came free down. Continue to ream out of hole at 1.5 bpm 3550 psi fs, 27 fpm. BHP: 4500 psi. ECD: 14.3 ppg. WHP: 550 psi. POOH following WHP pressure schedule. Paint EOP flag at 5800'. CLose SSSV with 1220 psi on well. POOH to surface. Flow check. Get off well. Unstab coil. RU to run liner. Hold PJSM to discuss runnign liner. Verify safety joint is ready to go. Swap solid btm joint for 10' bent pup wI bull nose. Swap solid btm joint for 10' bent pup wI bull nose. Run 30 stands from derrick. Remove extra spiral turbos used as lift nubbins. MU Baker mwd tools wI orienter. RIH with liner BHA #32 at 80 fpm. Pumping at minimum rate down the coil thru and open EDC. Holding to pressure schedule while RIH. Initial WHP=1000 psi with no returns. Surging fluid away. Tie in at 5800' EOP flag. Make -17' correction. Weight check at window = 23000 100. DHWOB=-5500 Ibs (In tension). RIH weight at windoW=5600 Ibs, DHWOB=-3000 Ibs. Non calibrated TF=105L. RIH slick thru window at 40 fpm. Set down at 7895', PU and orient 60 deg R. RIH and set down at 7900. PU, try to rotate 60 deg R, and BHA is in a bind and can't rotate. Kick pumps on down the coil. RIH pumping, and holding 1000 psi on WHP. Set down. Finally got the orienter to tum the liner. Holding 6OR. Set down at 7899'. Kick on pumps down the backside, PU and pump 2 bpm down the backside at 2130 psi. RIH with TF at 120R set down at 7898'. Printed: 11/1612004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 31 of 34 BP EXPLORATION Operations Summary Report 1 Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 HO~:O R:~:~£Od~~~~: , I I I I i 10/16/2004 07:00 - 08:30 08:30 - 10:15 1.75 RUNCO I I iDPRB I Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Phase Spud Date: 6/10/1993 End: 8/28/2004 Operations RUNCMP Orient to 180 deg. RIH slow and set down. Orient all the way around in 20 degree steps, continuing to bullhead at 2 bbllmin to wash thru. No success, and BHA seems to be in a bind in the lower left quadrent. Can't really orient to hold tool face in this quadrant. Having consistent setdowns at 7898'. Orient to 30-60R, and RIH at 120 fpm while continuing to pump at 2 bpm down the backside. Tagged up at the same depth. Clean PU's. Repeat 10 times with no luck. Set down, swap to pumping down the coil. Pump 15 bbls thru a closed EDC. 1650 Ibs of compression in BHA. Try to RIH. Set down at same place. Try orienting on bottom to get thru, no luck. RUNCMP No luck getting past 7898'. This is a spot with 45 deg dog legs in the original well bore. It is 8' above the top of the whipstock/deployment sleeve for the "A" lateral liner. It could be debris stacking up at this point in the well, or our depth uncertainty could put us at the top of the aluminum billett. POOH and consult with town. Looked for flag on way OOH, but it is gone. Continue POOH. Safety meeting prior to running 1" CS hydril inner work string, Stand back injector. Lay down BHA #32, liner attempt #2 on L 1 lateral. Pickup and run a 1" CS hydril inner work string in the 2-3/8" predrilled liner. Space out so slick stick is thru Oring sub. Make injector back up. Check MWD tools electrically. RIH with liner for third attempt at getting liner down the L 1 lateral. BHA #33. RIH at 70 fpm. No flag on coil. Make the same -17 correction as last RIH. Weight check at the window, Up string weight = 26 klbs, WOB=-103oo Ibs. RIH at 40 fpm. Set down at same depth as last time, 7898'. Close EDC. Kick on pumps. String weight=4800 Ibs, DHWOB=6600 Ibs compresson. Pumps to 0.8 bpm, 3400 psi pump pressure. Pumps to 1.0 bpm, 4240 psi. Trying to wash thru it if it is debris/cuttings. Try rotating the orienter 90 deg right. Cycle weight from max tension to neutral weight. Can't PU due to GS releasing. Pumps to 1.1 bpm, 4370 psi. Bullheading fluid away. Try spinning the orienter on bottom. It turns, but no luck making any hole. Circulate 15 minutes with no headway. SI pumps, Open EDC. PU and orient around trying to set down around the clock with the orienter. Solid set downs with no indication of making any headway. Time to call town and make a plan forward. POOH. Tag up at surface. Hold safety meeting while checking well for flow. Stand back injector, begin tripping CS hydril inner work string ooH. Stand back 2-318" STL liner assy. No unusual marks on the shoe joint or guide shoe. MU 1.7 deg mtr with HTC 328 bit on full MWD. Stab coil. Get well. Test mwd. RIH. Get rtns at 1500. Close choke and pressure WH to 950 psi. Open sssv. Continue in hole. Maintain BHP using pressure schedule. Log gr tie in from 7880. Subtract 5.5'. 10:15 - 10:30 0.25 RUNCO DPRB RUNCMP 10:30 - 10:45 0.25 RUNCO DPRB RUNCMP 10:45 - 13:45 3.00 RUNCO DPRB RUNCMP 13:45 - 15:15 1.~O RUNCO DPRB RUNCMP 15:15 - 15:55 0.67 RUNCO DPRB RUNCMP 15:55 - 17:20 DPRB RUNCMP 17:20 - 17:35 DPRB RUNCMP 17:35 - 19:30 DPRB RUNCMP 19:30 - 21:15 DPRB RUNCMP 21:15-21:50 DPRB RUNCMP 21 :50 - 23:30 DPRB RUNCMP 23:30 - 23:40 DPRB AUNCMP Printed: 11/16/2004 2:57:54 PM Page 32 of 34 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Spud Date: 6/10/1993 End: 8/28/2004 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 NPT Phase L---- Descripti.oFl8f>~r:> ions RUNCMP I RIH with HS tf, roll to 135r. Tag up at 7904' (billet depth). PU and circ at min rate. Tag again. Pump at 1.35 wI 3650 psi fs. II Slowly mill ahead with TF: 135. Slight amount of mtr work. WHP: 800 psi BHP: 4450 psi ECD: 14.6 ppg. Mill to 7904.3'. I PU and RIH. Take wt. PU. Mill ahead 0.2'. PU. RIH fast, no I' mtr work or wt, then set dn 7910'. Take wt and mtr work. PU. RIH fast at min rate. Tag again at 7911 '. Punched through at 7914'. Appear to be back in 'correct hole'. DPRB RUNCMP I RIH with HS tf, roll to 135r. Tag up at 7904' (billet depth). PU I and circ at min rate. Tag again. Pump at 1.35 wI 3650 psi fs. Slowty mill ahead with TF: 135. Slight amount of mtr work. IWHP: 800 psi BHP: 4450 psi ECD: 14.6 ppg. Mill to 7904.3'. i PU and RIH. Take wt. PU. Mill ahead 0.2'. PU. RIH fast, no i mtr work or wt, then set dn at 7910'. Take wt and mtr work. II PU. RIH fast at min rate. Tag again at 7911'. Punched through at 7914'. Appear to be back in 'correct hole". RUNCMP ¡ Make several reaming passes past billet. Back ream up at 315 'I deg tool face to try and dress billet. RUNCMP RIH to clean out to 9500. 3700 psi fs @ 1.37 inlout. WHP: '1400 psi ECD: 14.3 ppg BHP: 4400 psi. Hole very smooth going in. Some bobbles from 9300 to 9500. RUNCMP I Ream ooH at 25 fpm. A few overpulls from 8600 to 8550. Otherwise very smooth. Clean out with 2.75 bit is much I smoother than with bi-center. A lesson leamed? Not sure . what's going on here. I Back ream past billet. Run back through dry. Smooth. DPRB RUNCMP POOH to make up dummy liner assy. Hold pressure as per schedule. DPRB RUNCMP I At surface. Get off well. Unstab coil. LD Baker motor. MU dummy liner asembly (MWD, 2 solid jts 2-318" STL, 1.1 deg mtr, HTC bit) DPRB RUNCMP RIH with BHA #35, to make dummy drift. BHA: STR-324 PDC bit - 1.1 deg WF motor - xlo - 2 jts of solid 2-318' STL liner - BHI MWD tool. Following pressure schedule. DPRB RUNCMP Log tie in pass over GR charecter at 7760'. Make -13' correction. DPRB RUNCMP RIH dry, at 30 fpm, with TF at 135R, the 'as drilled' TF for the L 1 lateral. Slick thru window. Kick on pumps to 1 bpm, 3080 psi (Same rate we will be able to achieve with liner and an inner work string.). Continue RIH. Rotating orienter to match "as drilled" toolface as we RIH. Set down at 8069'. Had motor work. PU, ease on back down slowty. DPRB RUNCMP Work interval at 8069'. Finally got thru it. Continue to bottom holding as drilled tool face the entire way. Holding 4300 Ibs BHP. Set down at 8685'. PU, made it thru on 2nd attempt. Clean rest of the way to TD. DPRB RUNCMP Bring pump rate up to 1.5 bpm, to provide best hole cleaning. PUH holding 4300 psi on annular BHP gauge. PU off bottom at 19 klbs. Pulling at 30 fpm. Slick up hole thru open hole interval. DPRB RUNCMP POOH following pressure schedule. DPRB RUNCMP Tag up at surface. No flow test. Stand back injector and lay down BHA. Date From- To 10/16/2004 23:40 - 00:00 10/17/2004 00:00 - 01:00 1.00 RUNCO 01 :00 - 01 :30 0.50 RUNCO DPRB 01 :30 - 02:30 1.00 RUNCO DPRB 02:30 - 03:30 1.00 RUNCO DPRB 03:30 - 05:00 1.50 RUNCO 05:00 - 06:30 1.50 RUNCO 06:30 - 07:50 1.33 RUNCO 0.33 RUNCO 07:50 - 08:10 0.25 RUNCO 08:10 - 08:25 08:25 - 09:20 0.92 RUNCO 09:20 - 10:20 1.00 RUNCO 1.42 RUNCO 0.50 RUNCO 10:20 - 11 :45 11:45 -12:15 Printed: 11/1612004 2:57:54 PM BP EXPLORATION Operations Summary Report Legal Well Name: 1 Y-24 Common Well Name: 1Y-24 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Dat~_~_JFrom -To Hours Task éo.(j.eNPT I 10/17/2004 ¡ 12:15 - 12:30 112:30.16:30 ! 0.25 RUNCO 4.00 RUNCO 16:30 - 18:00 1.50 RUNCO 18:00 - 20:00 2.00 RUNCO 20:00 - 22:00 2.00 RUNCO 22:00 - 23:45 1.75 RUNCO 23:45 - 00:00 0.25 RUNCO 10/18/2004 00:00 - 02:30 2.50 RUNCO 02:30 - 03:00 0.50 RUNCO 03:00 - 04:00 1.00 RUNCO 04:00 - 06:00 2.00 RUNCO 06:00 - 06:15 0.25 RIGD P 06:15 - 07:15 1.00 RIGD P 07:15 - 07:50 0.58 RIGD P 07:50 - 09:00 1.17 RIGD P 109:00 - 10:20 1.33 RIGD P I DPRB DPRB DPRB DPRB DPRB Page 33 of 34 Spud Date: 6/10/1993 End: 8/28/2004 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Pha~____ DescriptionofQþeratiøn$ RUNCMP I Safety meeting prior to making up liner BHA. RUNCMP I Make up liner for L 1 lateral for the 4th time. MU STR-324 2.73" OD bicenter bit - WF mud motor at 1.1 degrees - x/o - 7' I spaceout pup - 0 ring sub - 59 jts of predrilled liner. Running 1" I CSH inner work string and space out. Make up deployment ¡sleeve and BHI MWD tools. ! ! Note - Made a crude scribe when running liner. Pointed motor I bend away from drawworks, tried to keep liner straight when running it, and scribed MWD to a point facing away from the drawworks. It is crude, but the best we can do. RUNCMP I RIH with liner BHA. (BHA #36). Follow pressure schedule. Mostly surging fluid away. RUNCMP I' Orient TF to HS to pass through window 7855. Orient to 135 to pass billet at 7906. Orient back to HS to continue in hole. 30 I fpm. no pumps. Set dn at 8710. Work through. Several more set dns. PU and run through ok. Work to 9104. Lots of set dns. Close EDC to drill ahead. RUNCMP I Shut dn pumps. PU liner. Free at 27k# up wt. Orient to HS. RIH. PU and tag hard several times at 9350. Set max dn wt. Bleed WHP from 1000 to 100 psi. Make 10-15 ft. Repeat WHP pressure cycle process until reaching liner TD of 9500'. RUNCMP Clrc at 1.05 bpm @ 4000 psi with zero WHP. PU and release from liner no problem. POOH as per pressure schedule. CLose SSSV with 1200 psi on well. POOH to surface. RUNCMP At surface. Get off well. Unstab coil. LD Inteq mwd tools. Stand back 1" CSH in derrick. Continue to stand back CSH in derrrick. MU nozzle assembly. Stab coil. Get on well. RIH to 7500. POOH displacing tbg to seawater. Take rtns to tiger. Stop at sssv. FP tbg with diesel to surface. Safety meeting to discuss fluid pumping order for remainder of rig down Pump diesel and FP well from 2000' to surface. Safety meeting prior to pumping N2 to blow down coil. Blow down reel with N2, taking returns to the tiger tank. Driller blew lines to pits clear with last bit of N2 from blowdown. Personnel H2S detectors for several individuals went off. All personnel evacuated to the rig camp. Highest reading recorded was 60 ppm. No rig H2S alarms went off, and they were checked and calibrated yesterday. No personnel H2S alarms went off other than the new Rattler style. There were still several old style personnel H2S monitors in service, and individuals in the area with the old style alarms did not get an alarm activation. Call BP safety, and discuss the situation. Call CPAI pad operator for assistance. A 2 man team consisting of the pad operator and BP company man sniffed the rig. They were equiped with 2, 4 gas monitors. No H2S, Carbon Monoxide, or Methane gasses were detected. Oxygen levels were good throughout the rig, including below deck level in the pits. After the entire rig was sniffed, a post incident safety meeting was held with the rig crew to discuss the RUNCMP RUNCMP RUNCMP RUNCMP POST POST POST POST POST Printed: 11/1612004 2:57:54 PM BP EXPLORATION Operation~.Summary Report Page 34 of 34 Legal Well Name: 1Y-24 Common Well Name: 1 Y-24 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date J~~~~~ To Hours Task Code 10/18/2004 109:00 - 10:20 1.33 RIGD P ¡ I Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 Description of Operations POST situation. The rig crew then returned to work. 10:20 - 13:00 I 2.671 RIGD P Note - The suspected cause of the false alarms is sensitivity of the new rattler H2S personnel monitors to a mixture of N2 gas and methanol vapor. Methanol was used to flush the coil ahead of the N2. Further investigation should be done to avoid this situation in the future. POST Resume rigging down. Clean pits. Unstab injector. 13:00 - 16:00 3.00 RIGD P POST Drop reel down from reel house. Nipple down BOP stack, and NU tree cap. PT tree cap to 3500 psi. Continue prepping for move to 1 D pad. Rlease rig at 1800 hrs on 10-18-2004 16:00 - 18:00 2.00 RIGD P POST Printed: 11/1612004 2:57:54 PM · ConocoPhilUps Alaska, Inc. .KRU 1Y-24AL 1 1N!!+2IAIL1 //i ........./ .·..·......//.·i i./ ./ ....·X</i.·/.... /i /.......... i/. .../....XII API: 500292237160 Well Type: PROD Anale (ã) TS: de!:! (àJ TUBING SSSV Type: TRDP Orig 10/18/2004 Angle @ TD: deg@ (0-7180, Completion: OD:3.500, ID:2.992) Annular Fluid: Last W/O: 10/18/2004 Rev Reason: CTD SIDETRACK Leo AL 1 Reference Loa: Ref Loa Date: Last UDdate: 10/22/2004 Last Taa: TD: 9500 ftKB Last Ta!:! Date: Max Hole An!:!le: o decl (ã) SURFACE (:iäsini:l··Stìil¡¡¡ø...(:iO"MØt¡IS1liB:llíI.~S.".·..'.'D'.".'.."".'. )) ·...Pi ip···...i .i........ (0-4599, DescriPtion Size Top Bottom TVD Wt Grade Thread OD:9.625, CONDUCTOR 16.000 0 121 121 62.50 H-40 Wt:36.00) SURFACE 9.625 0 3041 3041 47.00 L-80 SURFACE 9.625 0 4599 4599 36.00 J-55 PRODUCTION 7.000 0 8372 8372 26.00 L-80 'RODUCTION WINDOW 6.156 7858 7868 7868 0.00 (0-8372, ~¡íšinâ~il'Ìl:i~ LIIíIEB: ·LlEG~1L1'···.>iii .. i......·....... ii i" .. ii ........... ..........". OD:7.000, Description Size Top I Bottom TVD Wt Grade Thread Wt:26.00) SLOTTED LINER AU 2.650 7600 I 9004 9004 4.70 L-80 STL SLOTTED LINER AL 1 2.375 9004 I 9500 9500 4.70 L-80 STL Ï1ul)il'ÌšStririå· .Tí.JBIN~i.'·.'... .·..··................i ............. .. D.·DI.·.· II. "i..> ··D/..·.·... ............ ........... I·...··II. ..····...···I "'IXI;, Gas Lift Size I Top I Bottom TVD I Wt I Grade Thread MandrelNalve 3 3.500 0 I 7180 7180 I 9.30 I L-80 EUE8rd (5811-5812, 3.500 I 7180 I 7682 7682 I 9.20 I L-80 EUE8rdMOD Pel1'c:irä~lc:ibs·i$liIlTlfuåt:'i. ii........ xx ii.· .. i< ..·.·.·....I........ .... Interval I TVD Zone Status Ft SPF Date TVDe Comment Gas Lift 7603 - 9480 7603 - 9480 1877 8 110/15/2004 IPERF Slotted Liner, 3/8" holes, 90 MandrelNalve de!:! orient 4 (6579-6580, Gãs LiJtMãndréUW'alves .....·..·Ii.·..···..· 'I ..I ... .....·..·i·..I St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt Gas Lift 1 3176 3176 CAMeo MMG GLV 1.5 RK 0.188 1337 1 0/21/200 MandrelNalve 2 4700 4700 CAMeo MMG GLV 1.5 RK 0.188 1314 1 0/21/200< 5 3 5811 5811 CAMeo MMG GLV 1.5 RK 0.188 1293 10/21/200 (7110-7111. 4 6579 6579 CAMeo MMG GLV 1.5 RK 0.250 1311 M 0/21/200< 5 7110 7110 CAMeo MMG OV 1.5 RK 0.250 0 10/21/200 G.tlîertllûâsê âui D;éte~l·GC)'MMÆ1N¡JEWEItR¥' I······ I>' 'IP NIP Depth TVD Type Description ID (7161-7162, 28 28 HANGER FMC TUBING HANGER 10/3/2004 3.800 00:4.500) 1966 1966 SSSV CAMBO TRM-4E SSSV #HVS-379 set 1 0/3/2004 2.812 7161 7161 NIP HALLIBURTON 'X' NIPPLE 10/3/2004 3.812 7172 7172 SEAL BOT 80-40 SEAL ASSEMBLY STABBED INTO ORIGINAL COMPLETION 3.000 SEAL PBR (ã) 7180 1 0/3/2004 (7172-7173, 7180 7180 PBR BAKER PBR (ORIGINAL COMPLETION) 3.000 OD:4.500) 7193 7193 PACKER BAKER 'FHL' PACKER (ORIGINAL COMPLETION) 2.937 7211 7211 NIP CAMeO 'D' NIPPLE NO GO (ORIGINAL COMPLETION) 2.750 7681 7681 SOS ORIGINAL COMPLETION) 2.992 7870 7870 TTL BAKER (ORIGINAL COMPLETION) 2.992 TUBING t:)tftêr:(i·ilûOsi.e ãUlþ¡······êtdi}.~LlINEB:·AL1·¡EWELB:N!! ).'p "'p, .....·D. Ii PI .). .............·i.·.··.·.... .·.....iI....'...... (7180-7682, Depth TVD Type Description ID OD:3.500, ID:2.992) 7600 7600 SLEEVE SHORTY BAKER DEPLOYMENT SLEEVE FROM MAIN LEG TO LOWER 2.250 LATERAL LEG AL 1 GenêrålINotes··IIX..·..i i......·i i.·...... i......... ini;;.··.·..··. I,,'ii" >.. »I,; .......i .........·......··i> .. PACKER Date I Note (7193-7194, n 0/18/2001 CTD DUAL LATERAL WELL: LEG AU DEPLOYED FROM MAIN LEG OD:6.156) "'ACCESSIBLE FOR WELLWORK'" NIP (7211-7212, OD:3.500) SLEEVE (7600-7601, OD:2.650) SOS (7681-7682, OD:3.500) WINDOW (7858-7868, ~ ... OD:6.156) SLOTTED LINER AL 1 - (7600-9004, OD:2.650, - Wt:4.70) . BP-GDB Baker Hughes INTEQ Survey Report . ... .... 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: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1Y Pad North Slope Site Position: Northing: 5974755.95 ft Latitude: 70 20 31.499 N From: Map Easting: 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.24 deg Well: 1Y-24 Slot Name: KRU 1Y-24 Well Position: +N/-S 0.00 ft Northing: 5974755.95 ft Latitude: 70 20 31.499 N +E/-W 0.00 ft Easting : 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft Wellpath: 1Y-24AL 1 Drilled From: 1Y-24A 500292237160 Tie-on Depth: 7902.00 ft Current Datum: SITE Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/11/2004 Declination: 24.51 deg Field Strength: 57571 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 185.00 Survey Program for Definitive Wellpath Date: 11/1/2004 Validated: Yes Actual From To Survey ft ft 35.00 7841.40 7855.00 7879.44 7902.00 9678.00 Version: 15 Toolcode Tool Name Survey #1 (35.00-8375.00) (0) MWD (7855.00-9785.00) (1) MWD (7902.00-9678.00) MWD MWD MWD MWD - Standard MWD - Standard MWD - Standard Annotation 7855.00 7879.44 7902.00 9678.00 5965.89 5985.96 6002.07 6063.70 Window TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 10/14/2004 Engineer: Tied-to: From: Definitive Path . BP-GDB Baker Hughes INTEQ Survey Report . ... ..... INTEQ 7855.00 30.78 160.06 5965.89 5859.89 -4635.79 1256.22 5970125.93 532707.15 4508.66 0.00 0.00 7879.44 38.85 171.35 5985.96 5879.96 -4649.28 1259.52 5970112.45 532710.50 4521.82 42.14 43.38 7902.00 49.85 174.29 6002.07 5896.07 -4664.91 1261.44 5970096.83 532712.49 4537.21 49.59 11.66 7931.43 47.20 180.48 6021.57 5915.57 -4686.91 1262.47 5970074.84 532713.62 4559.04 18.14 121.77 7962.10 47.77 186.56 6042.30 5936.30 -4709.45 1261.08 5970052.29 532712.32 4581.62 14.73 84.81 7996.26 51.69 192.87 6064.39 5958.39 -4735.11 1256.65 5970026.62 532707.99 4607.57 18.17 52.92 8027.70 57.13 198.29 6082.69 5976.69 -4759.70 1249.75 5970002.00 532701.20 4632.67 22.26 40.63 8068.44 64.94 204.82 6102.42 5996.42 -4792.77 1236.60 5969968.88 532688.19 4666.76 23.74 37.82 8098.83 71.18 205.49 6113.77 6007.77 -4818.27 1224.62 5969943.33 532676.32 4693.21 20.63 5.82 8122.82 76.50 204.91 6120.45 6014.45 -4839.12 1214.82 5969922.45 532666.60 4714.82 22.30 353.94 8150.89 83.17 204.88 6125.40 6019.40 -4864.16 1203.19 5969897.35 532655.08 4740.79 23.76 359.74 8177.62 86.73 209.35 6127.75 6021.75 -4887.85 1191.06 5969873.62 532643.05 4765.44 21.33 51.57 8210.88 88.42 216.43 6129.16 6023.16 -4915.74 1173.02 5969845.66 532625.14 4794.79 21.87 76.73 8239.42 89.03 222.05 6129.80 6023.80 -4937.83 1154.98 5969823.50 532607.19 4818.37 19.80 83.87 8268.17 90.32 216.72 6129.96 6023.96 -4960.04 1136.75 5969801.21 532589.05 4842.09 19.07 283.58 8298.69 92.41 209.15 6129.23 6023.23 -4985.63 1120.17 5969775.56 532572.58 4869.02 25.72 285.51 8330.79 90.63 201.75 6128.38 6022.38 -5014.58 1106.39 5969746.55 532558.93 4899.07 23.70 256.59 8361.95 89.95 194.95 6128.22 6022.22 -5044.14 1096.59 5969716.95 532549.25 4929.37 21.93 264.31 8389.77 89.77 186.50 6128.29 6022.29 -5071 .45 1091.42 5969689.63 532544.19 4957.02 30.38 268.77 8418.21 89.52 184.26 6128.47 6022.47 -5099.76 1088.75 5969661.30 532541.64 4985.46 7.92 263.63 8448.04 91.98 189.25 6128.08 6022.08 -5129.37 1085.24 5969631.68 532538.26 5015.26 18.65 63.74 8480.07 93.67 196.62 6126.49 6020.49 -5160.52 1078.09 5969600.50 532531.24 5046.93 23.58 76.91 8507.15 92.72 203.05 6124.98 6018.98 -5185.94 1068.92 5969575.05 532522.17 5073.05 23.97 98.23 8539.51 93.37 209.20 6123.26 6017.26 -5214.94 1054.70 5969545.99 532508.08 5103.18 19.08 83.80 8568.22 94.29 216.81 6121.34 6015.34 -5238.95 1039.11 5969521.92 532492.59 5128.45 26.64 82.85 8598.17 96.35 216.35 6118.57 6012.57 -5262.89 1021.33 5969497.90 532474.92 5153.85 7.05 347.49 8629.16 96.73 207.19 6115.03 6009.03 -5289.04 1005.14 5969471.69 532458.84 5181.31 29.39 272.91 8658.76 92.75 204.34 6112.58 6006.58 -5315.60 992.32 5969445.08 532446.13 5208.89 16.52 215.64 8694.19 93.03 193.90 6110.79 6004.79 -5348.99 980.75 5969411.65 532434.70 5243.15 29.44 271.80 8726.06 95.68 189.04 6108.37 6002.37 -5380.12 974.43 5969380.50 532428.51 5274.72 17.33 298.84 8757.47 96.10 184.19 6105.15 5999.15 -5411.14 970.83 5969349.46 532425.04 5305.94 15.42 275.22 8795.83 96.17 176.17 6101.04 5995.04 -5449.25 970.71 5969311.36 532425.08 5343.91 20.79 270.93 8827.96 98.36 170.68 6096.97 5990.97 -5480.90 974.36 5969279.73 532428.86 5375.12 18.27 292.24 8856.51 97.52 165.22 6093.03 5987.03 -5508.54 980.26 5969252.11 532434.88 5402.14 19.17 261.55 8889.52 95.77 159.32 6089.20 5983.20 -5539.76 990.24 5969220.94 532444.99 5432.37 18.53 253.73 8923.38 96.01 163.74 6085.73 5979.73 -5571.69 1000.91 5969189.05 532455.79 5463.26 13.00 86.65 8953.55 95.31 167.08 6082.75 5976.75 -5600.74 1008.47 5969160.04 532463.47 5491.54 11.26 101.73 8983.26 91.74 170.86 6080.92 5974.92 -5629.84 1014.14 5969130.97 532469.26 5520.03 17.48 133.29 9016.05 90.48 175.07 6080.29 5974.29 -5662.37 1018.15 5969098.46 532473.41 5552.09 13.40 106.62 9052.28 93.21 180.61 6079.12 5973.12 -5698.54 1019.52 5969062.30 532474.93 5588.00 17.04 63.69 9084.05 93.73 185.50 6077.20 5971.20 -5730.19 1017.83 5969030.64 532473.37 5619.68 15.45 83.77 9120.44 92.56 186.51 6075.20 5969.20 -5766.33 1014.03 5968994.49 532469.72 5656.01 4.24 139.21 9154.28 90.20 181.00 6074.38 5968.38 -5800.07 1011.82 5968960.74 532467.65 5689.82 17.71 246.89 9190.11 91.95 176.65 6073.71 5967.71 -5835.88 1012.55 5968924.95 532468.54 5725.42 13.08 291.95 9220.51 91.33 169.30 6072.84 5966.84 -5866.02 1016.26 5968894.83 532472.38 5755.12 24.25 265.29 9246.32 92.35 163.90 6072.01 5966.01 -5891.10 1022.24 5968869.77 532478.46 5779.59 21.28 280.78 9280.39 92.01 158.15 6070.71 5964.71 -5923.28 1033.31 5968837.64 532489.66 5810.68 16.89 266.73 9311.04 92.84 152.69 6069.42 5963.42 -5951.12 1046.04 5968809.86 532502.50 5837.31 18.00 278.76 9340.23 92.53 147.20 6068.05 5962.05 -5976.35 1060.64 5968784.69 532517.21 5861.17 18.82 266.90 9367.04 90.05 144.73 6067.44 5961.44 -5998.56 1075.64 5968762.55 532532.30 5881.98 13.05 224.91 9398.09 87.25 146.28 6068.18 5962.18 -6024.14 1093.21 5968737.05 532549.98 5905.93 10.31 151.05 9431.08 86.64 150.88 6069.94 5963.94 -6052.24 1110.38 5968709.02 532567.26 5932.43 14.05 97.68 9462.02 87.31 155.28 6071.57 5965.57 -6079.78 1124.37 5968681.54 532581.36 5958.65 14.37 81.45 . BP-GDB Baker Hughes INTEQ Survey Report . ... ..... lNTKQ 9491,95 88.73 159.26 6072.60 5966.60 -6107.37 1135.92 5968654.00 532593.03 5985.12 14.11 70.43 9519.96 89.25 159.45 6073.10 5967.10 -6133.57 1145.80 5968627.84 532603.02 6010.37 1.98 20.07 9555.15 94.10 158.68 6072.07 5966.07 -6166.42 1158.36 5968595.05 532615.72 6041.99 13.95 350.99 9586.21 93,24 153.93 6070.08 5964.08 -6194,79 1170.81 5968566.74 532628.29 6069.17 15.51 259.87 9623.36 93.49 149.08 6067.90 5961.90 -6227.37 1188.50 5968534.23 532646.11 6100.09 13.05 273.10 9630.00 94,00 146.57 6067.46 5961.46 -6232,98 1192.03 5968528.64 532649,66 6105.37 38.49 281.59 , 9678.00 95,00 142.00 6063.70 ( 5957.70 -6271.82 1219.95 5968489.92 532677.74 6141.63 9.72 282.55 -- WELLPATH DETAILS 185.00· 0.00 0.00 0.00 REFERENCE INFORMATION r Survey: MWD (1Y~24f1Y~24Al Created By: Brij Potni: Date: 1 i /212004 '4' v:· Re: CTD BOP Testing at KRU . - Subject: Re: CTD BOP Testing at KRU From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 20 Aug 2004 11 :58:50 -0800 To: "Kara, Danny T" <KaraDT@BP.com> cc: Jim Regg <jimJegg@admin.state.ak.us>, AOGCC North Slope Office <aogcc -prudhoe _ bay@admin.state.ak.us> Dan, As I understand, the regulation change has been formally adopted by the Commissioners and will soon be signed off by the Lt. Governor. I have been advised that the Commissioner's action is sufficient to be able to grant your request. By copy of this email, the coil drilling activities of 1Y-24A and 1Y-24AL1 may use the 14 day interval. Please call with any questions. Tom Maunder, PE AOGCC Kara, Danny T wrote: Thanks for your time. Dan Kara BP Coiled Tubing Drilling 564-5667 (office) 240-8047 (cell) 564-5510 (Fax) karadt@bp.com 10fl 8/20/2004 11 :59 AM 1 a. Type of work o Drill II Redrill r b. Current Well Class o Exploratory II Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Number: Conoco Phillips Alaska Inc. Bond No. 2S100302630-277 Kuparuk 1Y-24AL 1 3. Address: 6. Proposed Depth: ,¡ 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10225 ,¡ rvD 5958ss Kuparuk River I Kuparuk River Oil 4a. Location of Well (Governmental Section): 7. Property Designation: ,/ Pool Surface: ADL 025646 570' SNL, 1762' EWL, SEC. 01, T11 N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 5114' SNL, 2986' EWL, SEC. 01, T11N, R09E, UM August5,2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1697' SNL, 3254' EWL, SEC. 12, T11N, R09E, UM 2560 25,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-531432 y- 5974756 Zone- ASP4 (Height above GL): 106 feet 2Z-05 is 815' away ,/ 16. Deviated Wells: Kickoff Depth: 8140 ' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 dearees Downhole: 3155 v Surface: 2535 v 18. ",;:Sljlnl:! ~...,... . ~...ttinnl'b:>""th ..: .,...( iSizA TliÓ .... ..... i'(' Hole Casina Weiaht Grade Coupling Length MD rvD MD rvD (including staae data) 3" 2-3/8" 6.2# L-80 STL 2625' 7600' 5757' 10225' 5958' Uncemented Slotted Liner '.19.. PRESENTWELLCOND(flQN$QMMARY(To .b~ ,comp/éteqfor~edríUANORe..e¡'ttYOpératiôns) Total Depth MD (ft): Total Depth rvD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth rvD (ft): Junk (measured): 8375 6420 None 8282 6338 None l".",¡¡¡¡...k ': ..( l'øni'lth :i ijiii:,y'.i.Sizêiiii'i :i iii'>"; (¡,iiii?' iii iYii;·""l':!I'·¡¡I;·;( ~trIIMllr~1 r.nnrllJdnr 121' 16" 218 sx Permafrost 'C' 121' 121' - . 4599' 9-5/8" 800 sx PF 'E', 480 sx 'G', Top Job: 105 sX PF 'C' 4599' 3600' IntAr Prnrh ,Minn 7568' 7" 750 sx Class 'G' 7568' 5733' I inAr 1108' 5" 175 sx Class 'G' 7264' - 8372' 5501' - 6417' Liner 1965' 2-3/8" Uncemented Slotted Liner 7885' - 9850' 9850' - 6006' Perforation Depth MD (ft): None perfOration Depth rvD (ft): None 20. Attachments o Filing Fee, $100 1m BOP Sketch 1m Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 1m Drilling Fluid Program 1m 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Thomas McCarty, 564-4378 Printed Name Thomas McCarty Title CT Drilling Engineer Signature "2....~ Prepared By Name/Number: /~.A. "? Phone 564-4378 Date "7/ Æ I ') V Terrie Hubble, 564-4628 (!: ..,if..: i'y.':..., (...i:"'}!(: :~:.ii·:; ..:!:(::;;:.'(.;;';:: ?:t((m( .i..(;;::.:~..::;.W:!;i:>.i;: ..:: Permit To Drill " I API Num?:r: ~ /? 7. ,i;.;J Permit APp~ay 0- c¡ See cover letter for Number: ~ - /4 50- 029-22371- -00 'I· /""'\ D~: //3 tJ other requirements Gondman. of Appmvalo Samples Required IJ Yes~ Log Req(.lred o Yes .~o Hydrogen Sulfide Measures <\~ es 0 0 irectional Survey Required ,grYes ·0 No Other 'i'ÁD~s \ \>,\) V * S'y GS \'(/) ~/3;;t/ / J-~ ~BY 1!3/t;C;' v V ADDroved Bv: 7 ~ _ I !'. ~ COMMISSION Date Form 10-401 RevisfJ 06/201 ! '-'lJK~I\JA _ Submit In Duplicate I STATE OF ALASKA . ALASKA I AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 .JÞ'~ - hiÇ; Ä , 'ì/r,? K.V-24A & V1-24AL 1 Sidetrack - col Tubing Drilling ,'Z. .01.( Summary of Operations: ,6Þ l' v Coiled tubing drilling will sidetrack KRU I Y-24 using the dynamically overbalanced;;~led tubing drilling (DOCTD) technique (see description below). This horizontal laterals (1 Y-24A/IJ &pz,) will target Kuparuk A sand reserves for production. The Kuparuk A Sand perforations in the existing well, I Y-24 will be isolated with cement pumped past the whipstock. CTD Drill and Complete 1 Y -24A & Yl-24ALl prol!ram: Planned for AUl!ust 5. 2004 1. Pre CTD No flow test on SSSV, MIT-IA, MIT-OA 2. Pre CTD install mechanical whipstock at approx 7885' 3. Pre CTD pump approx. 15bbls 15.8ppg cement past whipstock 4. MIRU Nordic 2. NU 7-1/16" BOPE, test. 5. Mill 3.80" window at 7885' md and 10' of openhole. v 6. Drill 3" bicenter hole horizontal sidetrack 1 Y -24A from window to -9850' TD targeting Kuparuk A sand interval. 7. Run and drop a 2-3/8" slotted (pre-drilled) liner from TD of 9850', up to 8140' md. 8. Openhole sidetrack at 8140', above the 2-3/8" liner. ".-/ 9. Drill 3" bicenter horizontal sidetrack lY-24ALl from open-hole side track to - 10225' TD targeting v Kuparuk A sand interval. 10. Complete with 2 3/8" pre-drilled liner from the TD of L2 at 10225', up into the 3-1/2" tubing to -7400 '. 11. Post CTD rig -Run GL V s. Bring on production. Mud Program: · Steps 1-2: 9 ppg Potassium-Formate biozan brine · Steps 3-10: Potassium-Formate based PIo-Pro (9 ppg) v' Disposal: · No annular injection on this well. v · Class II liquids to KRU lR Pad Class II disposal well · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · lY-24A: 23/8",6.2#, L-80, STL slotted liner from 9850' md to 8140' md · lY-24ALl: 23/8",6.2#, L-80, STL slotted linerfrom 7600' md to TD at 10225' 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 4500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 1 Y -24A & 1 Y -24A Ll · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · The nearest well to lY-24A is lY-16 which is offset by 537'. The nearest well to lY- 24ALl is 2Z-05 815' away. / Logging · A Gamma Ray log will be run over all of the open hole section. J Thomas McCarty 564-4378 office, 748-2598 cell 1/2 K.1V-24A & V1-24AL1 Sidetrack - co. Tubing Drilling Hazards i-/ }" '1' ,'I, ,¡;;J · One mapped fault in the planned k1well path; lost circulation risk is lo~. )J 'I' 17-' ,,,>"¡ · Reservoir pressure is estimated to be 9.8 ppg in the existing well. 1.Z' ~Il penetrate a potentially over- pressured fault block (hence DOCTD). Best estimate is IOppg in/the fault block. ,/ . Well 1 Y-24 has a H2S reading of 60 ppm (measured 08/05/02). 1 Y is an H2S pad. All H2S monitoring equipment will be operational. ,/ Reservoir Pressure 0/ . Reservoir pressure is approx. 3] 55psi at 6200' TVD 9.8 ppg EMW. Max. surface pressure with gas (0. I psi/ft) to surface is 2535 psi. ./ Dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high ./ reservoir pressure. Plans are to use 9 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 BHA 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 hole volume of kill weight fluid will be on location as a contingency. Both production liners (Ll & L2) will be deployed into the wellbore after killing the well with kill weight fluid. Estimated reservoir pressure: 3155 psi at 6200' TVD, 9.8 ppg EMW. ,/ Expected annular friction losses while circulating (ECD): 500 psi Planned mud density: 9 ppg equates to 2902 psi hydrostatic bottom hole pressure. While circulating 9 ppg fluid, bottom hole circulating pressure is estimated to be 3400 psi When circulation is stopped, a minimum of 500 psi surface pressure will be applied to balance the reservoir. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling. Thomas McCarty 564-4378 office, 748-2598 cell 2/2 . . ConocoPhlllips Alaska. Inc. . KRU 1Y-24 1Y -24 API: 500292237100 Well Tvpe: PROD Anale (éj) TS: 31 dea (éj) 7765 - SSSV Type: TRDP Orig 6/28/1993 Angle @ TD: 28 deg @ 8375 sssv ComDletion: (1793-1794. Annular Fluid: last W/O: 3/21/1994 Rev Reason: TAG FILL 00:4.000) Reference Loa: Ref Loa Date: Last Update: 2/27/2004 Last Tag: 8240 TD: 8375 ftKB Last Taa Date: 2/22/2004 Max Hole Anale: 47 dea (éj) 2431 Gas lift Casino Strino - ALL STRINGS MandreWalve ~ DescriDtlon Size Too Bottom TVD Wt Grade Thread 1 CONDUCTOR 16.000 0 121 121 62.50 H-40 (3066-3067. SUR. CASING 9.625 0 3041 2506 47.00 L-80 [, PROD. CASING 7.000 0 7568 5733 26.00 L-80 SUR. CASING 9.625 3041 4599 3600 36.00 J-55 Gas lift . LINER 5.000 7264 8372 6417 18.00 L-80 Indrel/Dummy Tubino Strina - TUBING Valve 2 (4899-4900 . Size TOD Bottom TVD Wt Grade Thread 00:5.968) 4.000 0 4893 3807 11.00 J-55 DSSHTC I 3.500 4893 7223 5470 9.30 J-55 EUE 8RD MOD ¡ Gas lift 3.500 7223 7681 5819 9.20 L-80 EUE 8RD MOD MandrelNalve ..~. Perforations SummarY 3 Interval TVD Zone Status Ft SPF Date Tvpe Comment (5658-5659. 8014 - 8016 6103 - 6105 A-5 2 4 919/1993 IPERF 33/8" SWS Guns; 180 deg. Phasina 8016 - 8022 6105 - 6110 A-5 6 10 12/22/1996 RPERF 2 118" Ener Jet DP Gas lift ... 8022 - 8030 6110-6117 A-5,A-4 8 4 919/1993 IPERF 33/8" SWS Guns; 180 deg. mdrel/Dummy Valve 4 Phasing (6420-6421. .1 8030 - 8038 6117-6124 A-4 8 10 12/22/1996 APERF 2 1/8" EnerJet DP I 00:5.968) 8038 - 8039 6124 - 6125 A-4 1 4 9/9/1993 IPERF 33/8" SWS Guns; 180 deg. Phasino Gas lift 8060 - 8074 6143 - 6155 A-3 14 6 12/22/1996 APERF 2 1/8" EnerJet DP MandreWalve 8101 - 8107 6179 - 6184 A-3 6 6 12/22/1996 APERF 2 1/8" EnerJet DP 5 Gas lift ManclrelslValves (7126-7127. St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt NIPPLE 1 3066 2523 Merla TMPD GLV 1.0 BK 0.156 1342 4/20/1997 (7171-7172. 2 4899 3811 Camco MMG2 DMY 1.5 RK 0.000 0 3/21/1994 00:3.500) 3 5658 4340 Cameo MMG2 GLV 1.5 RK 0.188 1292 4/20/1997 4 6420 4878 Cameo MMG2 DMY 1.5 RK 0.000 0 3/21/1994 5 7126 5398 Cameo MMG2 OV 1.5 RK 0.250 0 4/20/1997 I Other (I luas e ~ul D. eteJ - JEWELRY PBR DeDth TVD TVDe DescriDtion ID (7180-7181. 1793 1645 SSSV Cameo 4" TRDP-4 3.312 00:3.500) 7171 5431 NIPPLE Cameo W-1' Landino 2.812 7180 5438 PBR Baker 3.000 7193 5448 PKR Baker 'FHl' 2.937 PKR 7211 5461 NIP Camco 'D' Nipple NO GO 2.750 I (7193-7194. 7680 5819 SOS Baker 2.992 00:6.156) 7681 5819 TTL 2.992 General Notes Date Note 1/17/1997 Under-reamed HARD ASPHAL TENES out of Liner from 7930'-7993'; Underreamed remainder of Liner to NIP D PBTD with No Obstructions. NOTE: Under-reamer blades were severely worn on top side of blades (7211-7212. 00:3.500) (indicates oossible Csa Damaoe) See WSR 1/17/97 I TUBING (7223-7681. ~ 00:3.500. 10:2.992) - - Perf - - (801&-8022) - - - - - - Perf - - (8014-8039) - -- - - - - Perf - - (8030·8038) - - - - - - Perf - - (806Q..8074) - - - - - - - - Perf - - (8101-8107) - - - - - - -- KRU 1 Y -24A & -24AL 1 Producer Proposed CTD Completion ¥ Conoco UIi Alaska,lnc 9-5/8" 36# J-55 casing @ 4599' 5" liner top @ 7264' MD 7" 26# L80 @ 7568' MD 2-3/8" liner top @ +/-7600' MD Top of Whipstock +1-7885' MD Cemented in Place 5"18# L-SO @ 8372' MD H. 4" 11.0# J-55 DSS-HTC tubing to surface. G. 4" Cameo 'TRDP-4' SSSV set at 1793' MD, 3.312" ID I. 4" x 1" Merla TMPD mandrel at 3066' MD I. 4" x 3-%" crossover at 4893' MD F. 3-1/2" 9.3# J-55 EUE 8rd Mod tubing to crossover wI 3-1/2" x 1-1/2" Cameo 'MMG2' mandrels C. Baker 3-1/2" FHL packer at 7193' MD with PBRlseal assembly B. 3-W' Cameo 0 nipple with 2.75" 10 at 7211' MD (may be milled out to 2.80" for CTO bits) A. 3-1/2" tubing tail at 7681' M D Window in 5" 3" open hole Lateral (1Y-24AL 1), TO @ 10225' md 0 0 0 0 0 0 0 0 0 0 0 0 -- 0 0 0 0 0 0 0 0 0 0 0 0 1Y -24A, TO @ 9850' md 2-3/8" pre-drilled liner ConocoPhmips Alaska, Inc. WELLPATH DETAILS Phrt..,tt11'(w2,4A1.1 50029223'f'i6Ð P;S:l"INIt W.tlpati!: Pbm#S 1Y.24A Tie on MO¡ 8140.00 ...' NtUdiç,2 16G.ooft FI..f.Datum: SITE V.hcth:l-fiI o+~~~ 0riS"1 :=~ Mgle ....W 171.0(V .... D.Ge .... REFERENCE INFORMA nON k, Mil ·$nc Plan: Plan #7 (1Y-24/P!an#7 1Y-24AL Created By: Digita! Business Clìènt UserDate: 7/812004 Azimuths to True North Magnetic North: 24.67' at ,..-; ¡: æ -41 Q Q -4: £! +,-5' - ,¡: 1:: -5: o ~ -5400- - . - ,¡: .. :s 0- ~ TAI'WËTùETN15 +NI~<; sm.!", ANN.OTATIONS TV!) NlD ¡!u"t(fÞ:¡tføa 'æ' ~ 12. ,¡: 51 .. C3. Gl5 a 15750 1: 5: GI )05: GI ih ... BP-GDB Baker Hughes INTEQ Planning Report . . ..-: lNTEQ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 GeoDatum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: KRU 1Y Pad Alaska, Zone 4 Well Centre bggm2003 North Slope Site Position: Northing: 5974755.95 ft Latitude: 70 20 31.499 N From: Map Easting: 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.24 deg Well: 1Y-24 Slot Name: KRU 1Y-24 Well Position: +N/-S 0.00 ft Northing: 5974755.95 ft Latitude: 70 20 31.499 N +E/-W 0.00 ft Easting : 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft Wellpath: Plan#7 1Y-24AL 1 500292237160 Current Datum: SITE Magnetic Data: Field Strength: Vertical Section: Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 106.00 ft 7/8/2004 57548 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Plan#51Y-24A 8140.00 ft Mean Sea Level 24.67 deg 80.77 deg Direction deg 171.00 Annotation 8063.35 8140.00 8160.00 8200.00 8450.00 8625.00 8708.26 8868.26 8947.26 9173.26 9523.26 10023.26 10225.00 6007.80 6027.71 6028.58 6026.40 6011.04 6011.01 6003.76 5976.49 5970.03 5966.52 5959.99 5958.14 5957.70 TIP KOP 3 4 5 6 7 8 9 10 11 12 TO Plan: Plan #7 Identical to Lamar's Plan #7 Principal: Yes Date Composed: Version: Tied-to: Plan Section Information 7/8/2004 1 From: Definitive Path 8063.35 J 8140.00 8160.00 8200.00 65.00 85.09 89.92 96.33 231.16 253.13 251.84 244.15 6007.80 6027.71 6028.58 6026.40 0.00 38.00 25.00 25.00 0.00 26.21 24.15 16.02 -4760.54 -4794.13 -4800.14 -4815.08 1222.52 1157.52 1138.48 1101.49 0.00 28.67 -6.46 -19.23 0.00 49.99 345.00 310.00 . . -tit: INTßQ BP-GDB Baker Hughes INTEQ Planning Report 8450.00 90.01 181.83 6011.04 -5014.36 972.67 25.00 -2.53 -24.93 266.70 8625.00 90.01 160.83 6011.01 -5186.39 998.90 12.00 0.00 -12.00 270.00 8708.26 100.00 160.83 6003.76 -5264.64 1026.11 12.00 12.00 0.00 0.00 8868.26 99.44 180.30 5976.49 -5419.42 1051.81 12.00 -0.35 12.17 90.00 8947.26 89.96 180.30 5970.03 -5498.07 1051.39 12.00 -12.00 0.00 180.00 9173.26 91.79 207.36 5966.52 -5715.44 997.88 12.00 0.81 11.97 86.00 9523.26 90.26 165.38 5959.99 -6055.49 959.92 12.00 -0.44 -11.99 268.40 10023.26 90.13 105.38 5958.14 -6395.36 1295.27 12.00 -0.03 -12.00 270.00 10225.00 90.12 81.18 5957.70 -6406.81 1495.18 12.00 -0.01 -12.00 270.00 Survey 8063.35 65.00 231.16 6007.80 -4760.54 1222.52 5970001.05 532673.98 4893.17 0.00 0.00 TIP 8075.00 67.89 234.81 6012.46 -4766.96 1214.00 5969994.59 532665.48 4898.18 38.00 49.99 MWD 8100.00 74.34 242.19 6020.55 -4779.28 1193.84 5969982.19 532645.38 4907.20 38.00 48.53 MWD 8125.00 81.02 249.11 6025.89 -4789.32 1171.61 5969972.06 532623.19 4913.63 38.00 46.14 MWD 8140.00 85.09 253.13 6027.71 -4794.13 1157.52 5969967.19 532609.13 4916.18 38.00 44.65 KOP 8150.00 87.51 252.48 6028.35 -4797.08 1147.99 5969964.20 532599.61 4917.61 25.00 345.00 MWD 8160.00 89.92 251.84 6028.58 -4800.14 1138.48 5969961.10 532590.11 4919.14 25.00 345.04 3 8175.00 92.33 248.96 6028.28 -4805.17 1124.35 5969956.01 532576.00 4921.90 25.00 310.00 MWD 8200.00 96.33 244.15 6026.40 -4815.08 1101.49 5969946.00 532553.19 4928.11 25.00 309.94 4 8225.00 95.93 237.87 6023.72 -4827.13 1079.76 5969933.87 532531.51 4936.61 25.00 266.70 MWD 8250.00 95.47 231.61 6021.24 -4841.48 1059.46 5969919.43 532511.27 4947.61 25.00 266.03 MWD 8275.00 94.93 225.36 6018.97 -4857.97 1040.83 5969902.86 532492.71 4960.99 25.00 265.41 MWD 8300.00 94.34 219.11 6016.95 -4876.42 1024.08 5969884.35 532476.05 4976.58 25.00 264.84 MWD 8325.00 93.70 212.88 6015.19 -4896.58 1009.44 5969864.13 532461.48 4994.21 25.00 264.33 MWD 8350.00 93.02 206.66 6013.72 -4918.23 997.05 5969842.43 532449.19 5013.66 25.00 263.90 MWD 8375.00 92.30 200.44 6012.56 -4941.12 987.08 5969819.50 532439.32 5034.70 25.00 263.53 MWD 8400.00 91.55 194.23 6011.72 -4964.95 979.64 5969795.64 532431.97 5057.08 25.00 263.24 MWD 8425.00 90.78 188.03 6011.21 -4989.47 974.81 5969771.11 532427.25 5080.53 25.00 263.03 MWD 8450.00 90.01 181.83 6011.04 -5014.36 972.67 5969746.21 532425.21 5104.79 25.00 262.91 5 8475.00 90.01 178.83 6011.04 -5039.36 972.52 5969721.21 532425.17 5129.45 12.00 270.00 MWD 8500.00 90.01 175.83 6011.03 -5064.33 973.69 5969696.25 532426.44 5154.30 12.00 270.00 MWD 8525.00 90.01 172.83 6011.03 -5089.20 976.16 5969671.39 532429.02 5179.25 12.00 270.00 MWD 8550.00 90.01 169.83 6011.02 -5113.91 979.93 5969646.69 532432.89 5204.25 12.00 270.00 MWD 8575.00 90.01 166.83 6011.02 -5138.39 984.98 5969622.24 532438.05 5229.22 12.00 270.00 MWD 8600.00 90.01 163.83 6011.02 -5162.58 991.32 5969598.08 532444.48 5254.09 12.00 270.00 MWD 8625.00 90.01 160.83 6011.01 -5186.39 998.90 5969574.30 532452.17 5278.80 12.00 270.00 6 8650.00 93.01 160.83 6010.35 -5210.00 1007.11 5969550.74 532460.47 5303.40 12.00 0.00 MWD 8675.00 96.01 160.83 6008.39 -5233.53 1015.29 5969527.24 532468.76 5327.93 12.00 0.00 MWD 8700.00 99.01 160.83 6005.12 -5256.94 1023.43 5969503.86 532476.99 5352.32 12.00 0.00 MWD 8708.26 100.00 160.83 6003.76 -5264.64 1026.11 5969496.18 532479.70 5360.34 12.00 0.00 7 8725.00 99.99 162.87 6000.85 -5280.30 1031.24 5969480.54 532484.90 5376.62 12.00 90.00 MWD 8750.00 99.96 165.91 5996.52 -5304.01 1037.87 5969456.86 532491.62 5401.07 12.00 90.35 MWD 8775.00 99.90 168.96 5992.21 -5328.05 1043.22 5969432.85 532497.08 5425.64 12.00 90.88 MWD 8800.00 99.81 172.00 5987.93 -5352.33 1047.30 5969408.58 532501.25 5450.27 12.00 91.41 MWD 8825.00 99.70 175.04 5983.69 -5376.81 1050.08 5969384.12 532504.13 5474.88 12.00 91.93 MWD 8850.00 99.56 178.08 5979.51 -5401.41 1051.55 5969359.53 532505.71 5499.41 12.00 92.44 MWD 8868.26 99.44 180.30 5976.49 -5419.42 1051.81 5969341.52 532506.04 5517.24 12.00 92.95 8 8875.00 98.63 180.30 5975.43 -5426.08 1051.77 5969334.87 532506.04 5523.81 12.00 180.00 MWD 8900.00 95.63 180.30 5972.33 -5450.88 1051.64 5969310.07 532506.01 5548.28 12.00 180.00 MWD 8925.00 92.63 180.30 5970.53 -5475.81 1051.51 5969285.14 532505.98 5572.89 12.00 180.00 MWD 8947.26 89.96 180.30 5970.03 -5498.07 1051.39 5969262.88 532505.96 5594.85 12.00 180.00 9 . . B.. ..... INTßQ BP-GDB Baker Hughes INTEQ Planning Report 8950.00 89.98 180.63 5970.03 -5500.80 1051.37 5969260.15 532505.95 5597.55 12.00 86.00 MWD 8975.00 90.19 183.62 5969.99 -5525.78 1050.44 5969235.17 532505.13 5622.08 12.00 86.00 MWD 9000.00 90.40 186.62 5969.86 -5550.68 1048.21 5969210.26 532503.00 5646.32 12.00 86.00 MWD 9025.00 90.61 189.61 5969.64 -5575.43 1044.69 5969185.50 532499.58 5670.21 12.00 86.02 MWD 9050.00 90.81 192.60 5969.33 -5599.95 1039.87 5969160.96 532494.87 5693.68 12.00 86.05 MWD 9075.00 91.02 195.59 5968.94 -5624.19 1033.78 5969136.69 532488.88 5716.67 12.00 86.08 MWD 9100.00 91.22 198.59 5968.45 -5648.08 1026.44 5969112.78 532481.64 5739.12 12.00 86.13 MWD 9125.00 91.42 201.58 5967.87 -5671.55 1017.86 5969089.27 532473.15 5760.96 12.00 86.19 MWD 9150.00 91.61 204.58 5967.21 -5694.54 1008.06 5969066.25 532463.45 5782.13 12.00 86.26 MWD 9173.26 91.79 207.36 5966.52 -5715.44 997.88 5969045.30 532453.36 5801.18 12.00 86.34 10 9175.00 91.78 207.16 5966.47 -5716.99 997.08 5969043.76 532452.57 5802.58 12.00 268.40 MWD 9200.00 91.69 204.16 5965.71 -5739.51 986.27 5969021.19 532441.85 5823.13 12.00 268.39 MWD 9225.00 91.60 201.16 5964.99 -5762.57 976.64 5968998.10 532432.32 5844.40 12.00 268.30 MWD 9250.00 91.51 198.16 5964.32 -5786.10 968.23 5968974.53 532424.02 5866.33 12.00 268.22 MWD 9275.00 91.41 195.16 5963.68 -5810.04 961.07 5968950.56 532416.96 5888.85 12.00 268.13 MWD 9300.00 91.30 192.16 5963.09 -5834.32 955.17 5968926.26 532411.16 5911.92 12.00 268.06 MWD 9325.00 91.20 189.16 5962.54 -5858.88 950.55 5968901.68 532406.64 5935.45 12.00 267.99 MWD 9350.00 91.09 186.16 5962.05 -5883.65 947.22 5968876.90 532403.41 5959.39 12.00 267.92 MWD 9375.00 90.97 183.16 5961.60 -5908.56 945.19 5968851.98 532401.48 5983.68 12.00 267.86 MWD 9400.00 90.86 180.16 5961.20 -5933.55 944.46 5968827.00 532400.86 6008.24 12.00 267.81 MWD 9425.00 90.74 177.17 5960.85 -5958.54 945.04 5968802.02 532401.55 6033.01 12.00 267.76 MWD 9450.00 90.62 174.17 5960.55 -5983.46 946.93 5968777.10 532403.54 6057.93 12.00 267.72 MWD 9475.00 90.50 171.17 5960.31 -6008.25 950.12 5968752.33 532406.84 6082.91 12.00 267.68 MWD 9500.00 90.37 168.17 5960.12 -6032.84 954.60 5968727.76 532411.42 6107.90 12.00 267.65 MWD 9523.26 90.26 165.38 5959.99 -6055.49 959.92 5968705.14 532416.83 6131.10 12.00 267.63 11 9525.00 90.26 165.18 5959.99 -6057.17 960.36 5968703.46 532417.28 6132.83 12.00 270.00 MWD 9550.00 90.26 162.18 5959.87 -6081.16 967.39 5968679.50 532424.41 6157.62 12.00 270.00 MWD 9575.00 90.26 159.18 5959.76 -6104.74 975.66 5968655.95 532432.78 6182.21 12.00 269.99 MWD 9600.00 90.25 156.18 5959.65 -6127.87 985.16 5968632.87 532442.37 6206.54 12.00 269.97 MWD 9625.00 90.25 153.18 5959.54 -6150.46 995.85 5968610.32 532453.16 6230.53 12.00 269.96 MWD 9650.00 90.25 150.18 5959.43 -6172.47 1007.71 5968588.37 532465.11 6254.11 12.00 269.95 MWD 9675.00 90.24 147.18 5959.33 -6193.82 1020.70 5968567.08 532478.19 6277.24 12.00 269.93 MWD 9700.00 90.24 144.18 5959.22 -6214.46 1034.80 5968546.49 532492.37 6299.83 12.00 269.92 MWD 9725.00 90.23 141.18 5959.12 -6234.34 1049.96 5968526.68 532507.61 6321.84 12.00 269.91 MWD 9750.00 90.23 138.18 5959.02 -6253.40 1066.13 5968507.69 532523.86 6343.19 12.00 269.89 MWD 9775.00 90.22 135.18 5958.92 -6271.58 1083.28 5968489.58 532541.09 6363.83 12.00 269.88 MWD 9800.00 90.21 132.18 5958.82 -6288.85 1101.36 5968472.40 532559.24 6383.71 12.00 269.87 MWD 9825.00 90.21 129.18 5958.73 -6305.14 1120.32 5968456.19 532578.26 6402.77 12.00 269.86 MWD 9850.00 90.20 126.18 5958.64 -6320.42 1140.10 5968440.99 532598.11 6420.95 12.00 269.85 MWD 9875.00 90.19 123.18 5958.56 -6334.64 1160.66 5968426.86 532618.72 6438.22 12.00 269.84 MWD 9900.00 90.18 120.18 5958.48 -6347.76 1181.93 5968413.82 532640.05 6454.51 12.00 269.83 MWD 9925.00 90.17 117.18 5958.40 -6359.76 1203.87 5968401.92 532662.03 6469.79 12.00 269.82 MWD 9950.00 90.16 114.18 5958.33 -6370.59 1226.39 5968391.19 532684.60 6484.01 12.00 269.81 MWD 9975.00 90.15 111.18 5958.26 -6380.23 1249.46 5968381.65 532707.70 6497.13 12.00 269.80 MWD 10000.00 90.14 108.18 5958.20 -6388.64 1273.00 5968373.33 532731.27 6509.13 12.00 269.79 MWD 10023.26 90.13 105.38 5958.14 -6395.36 1295.27 5968366.71 532753.57 6519.24 12.00 269.78 12 10025.00 90.13 105.18 5958.14 -6395.82 1296.94 5968366.26 532755.25 6519.96 12.00 270.00 MWD 10050.00 90.13 102.18 5958.08 -6401.73 1321.23 5968360.45 532779.56 6529.60 12.00 270.00 MWD 10075.00 90.13 99.18 5958.03 -6406.36 1345.80 5968355.93 532804.14 6538.01 12.00 269.99 MWD 10100.00 90.13 96.18 5957.97 -6409.69 1370.57 5968352.69 532828.92 6545.18 12.00 269.99 MWD 10125.00 90.13 93.18 5957.92 -6411.73 1395.48 5968350.76 532853.84 6551.09 12.00 269.98 MWD 10150.00 90.12 90.18 5957.86 -6412.46 1420.47 5968350.13 532878.83 6555.73 12.00 269.97 MWD 10175.00 90.12 87.18 5957.81 -6411.89 1445.46 5968350.81 532903.81 6559.06 12.00 269.97 MWD . . ..rr: INTEQ BP-GDB Baker Hughes INTEQ Planning Report 10200.00 90.12 ./ 10225.00 90.12 84.18 5957.76 -6410.00 1470.39 5968352.80 532928.73 6561.10 12.00 269.96 MWD 81.18 5957.70 ./-6406.81 1495.18 5968356.09 532953.51 6561.83 12.00 269.95 TO , . . BOP- Tree . Well KB Elevation Rig Floor ,.................... ~8~PQ.þ$' Œ;)ÆM1Bmb¥êlªig~wMe~:a@D¡:¡tØ~M _ WJ!!I'ÎMi!!!!\!~!IB!4i/ð~ci:1 >1 IMtI9.fuJ:;:¡;V~IjI.~' ~~~~i~!I¡~;II~r.}0::::;·::j ~ Swab Valve Tree Size SSV I Master Valve Base Flange Page 1 -- KRU 1Y..24A paruk ·'An P1D 2 1 1/12/2004 Proposed ucer . . . 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 LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡¿e¿{, 1'I"Zc!/! L/ PTD# 2Dlf - fU ~. Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlboresegment of LATERAL existing well , Permit No, API No. . (Jf API number Production. sbould continue to be reponed as last two (2) digits a function ·of tbe original API number. stated are between 60-69) above. P~OT BOLE In accordance witb 20 AAC 25.005(1), aU (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated În botb name (name on permit plus PH) .. and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to full EXCEPTION compliance witb 20 AAC 25.055. Approval to ,. perforate and produce is contingent upon / issuance of a conservation order apf!l.."1?,g a ¿/. spacing· exception. CtrH.&£'<> t.-. 'f'J. (Companv Name) assumes tbe liability of any protest to tbe spa cing . ex ception tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample iIitervals through target zones. ~ o Well bore seg Annular Disposal On Program DEV On/Off Shore 11160 Name: KUPARUK RIV UNIT 1Y-24AL1 GeoArea 890 Unit Multilat~ral weU~ f~e waiv~dper 20AAC 25.. Q05{e) El1tire. hori~Qnta! wellb9re.lies within ADL 025646. Wel 1-QIL DEV No.4326 be Jess than 1 000 feet from2Z-05. io NEl4S. "12,T11N~ R9E. . NA Yes Yes Yes Yes No No. Yes Yes Yes No. Yes Yes NA NA NA NA Initial ClassfType 490100 KUPARUK RIVER, KUPARUK RV OIL ING Field & Pool Administration KRU KURarukRilœr OiJ PooJ WelJ bQre is .situate~ .more than 50.0 Jee1 from lease bouodary~ SPACING .EXCEPTION REQUJREQ: j-\orjzootalsidetrack~ w~U .bor.e will SPACING EXCEPTIONREQUJREQ: .WiJI be 2l1d.weJlbQre ORentQ R091 governed þy COl1s~rvationOrder b.oUl1dary .V_··t..,~~!.·,<!!,"II. W~I W~II Well 2 3 4 5 6 7 8 9 is weJlbQre plat .Op~rator onl~ affected party øperator bas. appropriate. bond inJorc~ Permil cao be issued witbQut conservation order Permil cao be issued witbQut ad.mil1istrati-.:e.approvaJ Can permit be approved before 15-day wait .W~II'nn~.n'" u,:."'" ~'ð~ ~"... n..~.n n"·"n':~ð'" .." In'ð # (PullO# .AJI w F service w.el onl~). _ Pr~-I s than 3 mOl1ths (for in. commeots) (for "Jyctioo Order 1~"",!>"Ly"" !,.I__"I~lr! ~.....~ .....~\"I ...._...r;,.oL~ _","~Lll"""l..v\4 L/J- service well onJy) o 11 12 13 14 15 6 7 Date Appr SFD 7/13/2004 Itilater.al welLbor.e Conductor JnstaJled. io .:1 Y -24 (193-072). All aq.uif~rs eKempled 40 CfR .:147.102(b)(3) instalJe_dJn Mu )'-24. jn.1Y~24, lioer .completion plaoned. Surface ca.sing Production casiog installed Slotte.d 1)'-24. Production ca.sing alJd.lln~r c.ern~oted as r~quir~d on wells.. NQ r~se""epjtplanoed, All waste to.Class Rig is.:quippe.d.w:ith ste~'-pits. 304-261 Pro~imit~ analysis performe.d, 2Z-05 815: distant. . PlalJ to use dynarnic_overbalan.ce with 9 PR9Jlui~.and 500p.si at surfaœ. 450.0 psi.BØP. t~st planne~.. MAßPcircuJatiog 3400 psi.. MASP calcuJated.at2535psi Rig.eJ:uippe~wjtb sensors alJd alarms. Mud should preclude H2.S. Qn.rig Ypad 60. RPm. H2S. Rrod.uœd. Qn measured ßO ppm H2S on 8/5102. Þe drj~d with coiled. tubil1g. and. 9.0 ppg.mu.d, w~1l bore (KRU 1Y-24) re$~""oir pre.s$ure is .9,8 Parent Exp~cted -10.0ppg EMW; wi NA NA NA NA No. Yes Ye$ Ye$ _Ye$ NA Yes Ye$ Yes Ye$ Ye$ Yes NA No. Yes NA NA Ye$ AÇMP F'indjngof Consistency has been Js.sued. for. tbis pr.oiect .C.oodu.ctor .S.urface .casil1g. protects al string.prov¡d~d & $urf.csg long string tosud csg CMT v.ol ad~quate. to tie-in .CMT will covera]l kl1ownproductiye borizons C,T, B&. Rermafr.ost A~equate.tan.kage.or re.serve pit. Jf.aJe-~riIL has a 100403 for abandonment C_asiog designs ad_eQuate for beeo approv~d .A~equale.w:ellbor~ separatjonpropose~ t .B.OPEs, do they me~l reguJatiol1 Dr\n~ nrðr>C! r~"':I"'I" ""!InrU"^I\I"=<"'!I.&.ð" Jest lo_(pu_t '( I Rf>-53 (May 84) c me~l r~guJatiol1s Ii$tadequate If.djv~rter req.uir~d, dQes BI:IP exp~cted at .9,8.EMW. Res.ervoir Permit fee attache~ .L~as.e .number .apprORriale I '";ro"ð '.'ð" n.arn~.aod oumb.er I in.a d.efinepppol. I proper .distance from driJling unit I prpp~r distance from Qth~r wells :r~ag.e.aYailable in.drilliog. unit il1cJuded .known USDWs .CMT. vol. ad~quate. to circulate oncol1d_uctor .Drilliog fluid. Rrog.ram schematic & ec¡.uip 8 19 20 21 22 23 24 25 26 27 28 29 30 31 Engineering Date 7/13/2004 f ~v v... t7 Appr TEM in_commel1t$) psig !~}.lt'::J ~...........t"".f""t.I~LII;;õI L.I'_""'J- ~ ,...!'''~''"JI'JOI' ~S,~ì operation shutdown 32 33 34 H2S gas. RrQbabl~ W~II$ withil1 AOR verified (for.s.ervj~ w~1I only) c.ao be issued wlo hydrogen s.ulfide meas.ures Permit .D_ata.pres~lJted on. Rote.ntial pverpres.sure .zones 35 36 37 38 39 Geology .Setsrnic.analysjs. Qf shaJlow gas.zoo~s Date 7/13/2004 Appr SFD _SeabedcOl1ditioo survey .(if off-shore) CQnta.ct l1am.elphOl1eforw:eelsly progressreRorts [exploratpry .only]. Date Engineering Commissioner Date: ? J J3/4 Geologic Commissioner fJTS 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. REViSED COpy . **** REEL HEADER **** MWD 06/11/03 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 23/03/06 737190 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7881.5000: STOP.FT 9918.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD FIELD: LOC . LOCATION: W CNTY. STAT. SRVC. TOOL. DATE. API . -Parameter #MNEM.UNIT #--------- . Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: COUNTY: STATE: SERVICE COMPANY: TOOL NAME & TYPE: LOG DATE: API NYUMBER: Information Block Value CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. 1Y-24APB1 Kuparuk River Unit 70 deg 20' 31.499" N 149 deg 44' 41.698" North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 20-Aug-04 50-029-22371-71 ------------------------------- ------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . f)(:t.1-1;)(¿, d Ii.{d/( 01 11N 09E MSL o RKB 52 KB 52 N/A o 7881. 5 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 . . -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 are 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 Locator( a Electrical Disconnect and Circulating SubIa Drilling Performance Sub (Inner and Outer Downhole Pressure( and 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 the Integ MWD GR is the primary depth control data for this well. (7) The sidetrack was drilled from 1Y-24 through a milled window in 5" liner. Top of Window 7874 ft. MD (5876.2 ft TVD) Bottom of Window 7881.5 ft. MD (5882.7 ft. TVD) This wellbore( 1Y-24APB1( was drilled through a casing window approximately 18 ft MD deeper than the casing window used for the final wellbore( 1Y-24A. (8) The interval from 9890 ft. to 9918 ft. MD (5999.8 ft. to 5995.9 ft. TVD) was not logged due to bit to sensor offset. (9) Tied to 1Y-24 at 7678 ft. MD (5711 ft. TVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration( feet/hour TVD -> Subsea True Vertical Depth( feet CURVE SHIFT DATA BASELINE ( MEASURED ( DISPLACEMENT Tape Subfile: 1 70 records _ . . Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 ConocoPhillips Alaska Inc. 1Y-24APB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !! !!!!!!!!!!!!!!!!! Remark File Version 1.000 Data presented here is final and the Integ MWD GR is the primary depth control data for this well. . . *** 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: 49 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7881.500000 9918.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 58 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC raw.xtf 150 . . CN WN FN COUN STAT ConocoPhillips Alaska In 1Y-24APB1 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 ROPS GRAX ROPS 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 GRAX MWD ROPS MWD 68 68 1 1 AAP I F/HR 4 4 4 4 ------- 8 Total Data Records: 97 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7881.500000 9918.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 106 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 23/03/06 737190 . 01 **** REEL TRAILER **** MWD 06/11/03 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . Tape Subtile 2 is type: LIS DEPTH 7881.5000 7882.0000 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 9200.0000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 9918.0000 GR 105.9400 109.2100 102.3300 121. 8600 87.5200 101.8300 88.2400 94.6200 63.0100 103.8700 140.9200 97.6700 64.1700 73.2900 79.3500 90.7100 85.0700 74.9600 124.9700 122.1400 77.5900 72.0300 -999.2500 -999.2500 Tape File start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROP -999.2500 -999.2500 78.4000 16.9900 51.1000 106.5200 114.5500 112.4400 126.1100 102.8200 39.1000 92.2900 96.5900 98.5800 93.8400 126.9300 95.4200 132.8000 100.9700 68.5300 143.8700 119.3800 76.3400 -999.2500 7881.500000 9918.000000 0.500000 teet . . Tape Subfile 3 is type: LIS DEPT!! GRAX ROPS 7881. 5000 105.9400 -999.2500 7881.7500 107.5750 -999.2500 7900.0000 102.3300 78.4000 8000.0000 121. 8600 16.9900 8100.0000 87.5200 51.1000 8200.0000 101.8300 106.5200 8300.0000 88.2400 114.5500 8400.0000 94.6200 112.4400 8500.0000 63.0100 126.1100 8600.0000 103.8700 102.8200 8700.0000 140.9200 39.1000 8800.0000 97.6700 92.2900 8900.0000 64.1700 96.5900 9000.0000 73.2900 98.5800 9100.0000 79.3500 93.8400 9200.0000 90.7100 126.9300 9300.0000 85.0700 95.4200 9400.0000 74.9600 132.8000 9500.0000 124.9700 100.9700 9600.0000 122.1400 68.5300 9700.0000 77.5900 143.8700 9800.0000 72.0300 119.3800 9900.0000 -999.2500 76.3400 9918.0000 -999.2500 -999.2500 Tape File Start Depth 7881.500000 Tape File End Depth 9918.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . Tape Subfile 4 is type: LIS ¿;)Q(1- t d<O if~'i. .~.C'.~:'¡ . **** REEL HEADER **** MWD 06/04/05 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 23/03/06 737190 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7863.0000: STOP.FT 9677.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. 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 #--------- ------------------------- SECT. 01 TOWN. N llN RANG. 09E PDAT. MSL EPD . F 0 LMF . RKB FAPD. F 106 DMF KB EKB .F 106 EDF .F N/A EGL .F 0 CASE.F 7863 OSl . DIRECTIONAL -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 are 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 Locator, a Electrical Disconnect and Circulating Sub,a Drilling Performance Sub (Inner and Outer Downhole Pressure, and 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. 1Y-24AL1 Kuparuk River Unit 70 deg 20' 31.499" N 149 deg 44' 41.698" W North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 14-0ct-04 50-029-22371-60 Description ------------------------------- 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 1t 1(.[ c9/ b . . 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 the Integ MWD GR is the primary depth control data for this well. (7) The sidetrack was drilled from IY-24 through a milled window in 5" liner. Top of Window Bottom of Window (8) The interval from 9649 ft. (5959.6 ft. to 5956.9 ft. bit to sensor offset. (9) Tied to 1Y-24 at 7760 ft. MD (5778 ft. TVD). (10) This wellbore, 1Y-24AL1, was sidetracked off 1Y-24A @ 7913 ft. MD (5903.2 ft. SSTVD) on MWD run 9. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 7858 ft. MD 7863 ft. MD to 9677 ft. TVD) was not (5859.9 (5866.7 MD logged ft TVD) ft. TVD) due to DISPLACEMENT Tape Subfile: 1 70 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 ConocoPhillips Alaska Inc. 1Y-24AL1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!! !!!!!!!!!!! Remark File Version 1.000 Data presented here is final and the Integ MWD GR is the primary depth control data for this well. *** 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: 44 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7863.000000 9677.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 53 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 raw.xtf 150 ConocoPhillips Alaska In lY-24ALl 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 ROPS GRAX ROPS 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 ROPS MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 87 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7863.000000 9677 . 000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 96 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 23/03/06 737190 01 ,**** REEL TRAILER **** MWD 06/04/05 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . Tape Subfile 2 is type: LIS DEPTH 7863.0000 7863.5000 7900.0000 7950.0000 8000.0000 8050.0000 8100.0000 8150.0000 8200.0000 8250.0000 8300.0000 8350.0000 8400.0000 8450.0000 8500.0000 8550.0000 8600.0000 8650.0000 8700.0000 8750.0000 8800.0000 8850.0000 8900.0000 8950.0000 9000.0000 9050.0000 9100.0000 9150.0000 9200.0000 9250.0000 9300.0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650.0000 9677.0000 GR 248.5200 82.1600 128.8850 121.6100 133.8100 118.2000 141. 5100 53.3700 84.9333 93.6480 68.7522 58.5200 79.8300 63.2343 53.5900 120.4300 84.6200 122.9300 139.1800 134.3000 129.8500 119.0900 90.5300 57.2500 87.3500 99.2567 61.8400 69.5100 73.1567 76.7800 88.0315 65.5200 63.8300 57.7050 71.8000 69.0200 83.0800 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROP 4.9100 5.3500 54.7300 53.3700 47.3600 43.9100 43.8000 154.4600 91.4800 165.3700 169.6100 161.9600 193.1400 180.0000 175.6100 164.3500 171. 4900 126.5800 36.9900 104.8800 90.7200 85.8800 119.4600 174.7600 160.6600 160.2200 140.8800 107.5100 122.4000 108.2900 103.2000 109.9000 104.3900 163.1000 149.0300 76.1300 110.6000 19.4300 -999.2500 7863.000000 9677.000000 0.500000 feet . . 'ape Subfile 3 is type: LIS DEPTH GRAX ROPS 7863.0000 248.5200 4.9100 7863.2500 165.3400 5.1300 7900.0000 128.8850 54.7300 7950.0000 121.6100 53.3700 8000.0000 133.8100 47.3600 8050.0000 118.2000 43.9100 8100.0000 141.5100 43.8000 8150.0000 53.3700 154.4600 8200.0000 84.9333 91.4800 8250.0000 93.6480 165.3700 8300.0000 68.7522 169.6100 8350.0000 58.5200 161. 9600 8400.0000 79.8300 193.1400 8450.0000 63.2343 180.0000 8500.0000 53.5900 175.6100 8550.0000 120.4300 164.3500 8600.0000 84.6200 171. 4900 8650.0000 122.9300 126.5800 8700.0000 139.1800 36.9900 8750.0000 134.3000 104.8800 8800.0000 129.8500 90.7200 8850.0000 119.0900 85.8800 8900.0000 90.5300 119.4600 8950.0000 57.2500 174.7600 9000.0000 87.3500 160.6600 9050.0000 99.2567 160.2200 9100.0000 61.8400 140.8800 9150.0000 69.5100 107.5100 9200.0000 73.1567 122.4000 9250.0000 76.7800 108.2900 9300.0000 88.0315 103.2000 9350.0000 65.5200 109.9000 9400.0000 63.8300 104.3900 9450.0000 57.7050 163.1000 9500.0000 71.8000 149.0300 9550.0000 69.0200 76.1300 9600.0000 83.0800 110.6000 9650.0000 -999.2500 19.4300 9677 . 0000 -999.2500 -999.2500 Tape File Start Depth 7863.000000 Tape File End Depth 9677.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ~ . . Tape Subfile 4 is type: LIS . . **** REEL HEADER **** MWD 06/04/05 BHI 01 1d\ *' \)1 LIS Customer Format Tape **** TAPE HEADER **** MWD 23/03/06 737190 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7863.0000: STOP.FT 9677.0000: 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 #--------- ------------------------- SECT. 01 TOWN.N IIN RANG. 09E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 106 DMF KB EKB .F 106 EDF .F N/A EGL .F 0 CASE.F 7863 OSI . DIRECTIONAL -Remarks (I) All depths are Measured Depths (MD) unless otherwise noted. 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. lY-24ALl Kuparuk River Unit 70 deg 20' 31.499" N 149 deg 44' 41.698" W North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 14-0ct-04 50-029-22371-60 Description ------------------------------- 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 ~ Ò v{ - J ~fp . . All depths are Bit Depths unless otherwise noted. All Gamma Ray data are realtime data. 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 Locator, a Electrical Disconnect and Circulating Sub,a Drilling Performance Sub (Inner and Outer Downhole Pressure, and 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 the Integ MWD GR is the primary depth control data for this well. (7) The sidetrack was drilled from lY-24 through a milled window in 5" liner. Top of Window Bottom of Window (8) The interval from 9649 ft. (5959.6 ft. to 5956.9 ft. bit to sensor offset. (9) Tied to lY-24 at 7760 ft. MD (5778 ft. TVD). (10) This wellbore, lY-24ALl, was sidetracked off lY-24A @ 7913 ft. MD (5903.2 ft. SSTVD) on MWD run 9. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, (2) (3) (4) 7858 ft. MD 7863 ft. MD to 9677 ft. TVD) was not (5859.9 (5866.7 MD logged ft TVD) ft. TVD) due to DISPLACEMENT Tape Subfile: 1 70 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 ConocoPhillips Alaska Inc. lY-24AL1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 Data presented here is final and the Integ MWD GR is the primary depth control data for this well. *** 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 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 44 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7863.000000 9677.000000 0.500000 feet **** FILE TRAILER **** Tape Sub file: 2 53 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 raw.xtf 150 ConocoPhillips Alaska In 1Y-24AL1 . . FN COUN STAT 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 ROPS GRAX ROPS 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 GRAX MWD ROPS MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 87 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7863.000000 9677.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 96 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 23/03/06 737190 01 . **** REEL TRAILER **** MWD 06/04/05 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 7863.0000 7863.5000 7900.0000 7950.0000 8000.0000 8050.0000 8100.0000 8150.0000 8200.0000 8250.0000 8300.0000 8350.0000 8400.0000 8450.0000 8500.0000 8550.0000 8600.0000 8650.0000 8700.0000 8750.0000 8800.0000 8850.0000 8900.0000 8950.0000 9000.0000 9050.0000 9100.0000 9150.0000 9200.0000 9250.0000 9300.0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650.0000 9677.0000 GR 248.5200 82.1600 128.8850 121.6100 133.8100 118.2000 141.5100 53.3700 84.9333 93.6480 68.7522 58.5200 79.8300 63.2343 53.5900 120.4300 84.6200 122.9300 139.1800 134.3000 129.8500 119.0900 90.5300 57.2500 87.3500 99.2567 61.8400 69.5100 73.1567 76.7800 88.0315 65.5200 63.8300 57.7050 71.8000 69.0200 83.0800 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROP 4.9100 5.3500 54.7300 53.3700 47.3600 43.9100 43.8000 154.4600 91.4800 165.3700 169.6100 161.9600 193.1400 180.0000 175.6100 164.3500 171.4900 126.5800 36.9900 104.8800 90.7200 85.8800 119.4600 174.7600 160.6600 160.2200 140.8800 107.5100 122.4000 108.2900 103.2000 109.9000 104.3900 163.1000 149.0300 76.1300 110.6000 19.4300 -999.2500 7863.000000 9677.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 7863.0000 248.5200 4.9100 7863.2500 165.3400 5.1300 7900.0000 128.8850 54.7300 7950.0000 121.6100 53.3700 8000.0000 133.8100 47.3600 8050.0000 118.2000 43.9100 8100.0000 141.5100 43.8000 8150.0000 53.3700 154.4600 8200.0000 84.9333 91.4800 8250.0000 93.6480 165.3700 8300.0000 68.7522 169.6100 8350.0000 58.5200 161.9600 8400.0000 79.8300 193.1400 8450.0000 63.2343 180.0000 8500.0000 53.5900 175.6100 8550.0000 120.4300 164.3500 8600.0000 84.6200 171.4900 8650.0000 122.9300 126.5800 8700.0000 139.1800 36.9900 8750.0000 134.3000 104.8800 8800.0000 129.8500 90.7200 8850.0000 119.0900 85.8800 8900.0000 90.5300 119.4600 8950.0000 57.2500 174.7600 9000.0000 87.3500 160.6600 9050.0000 99.2567 160.2200 9100.0000 61.8400 140.8800 9150.0000 69.5100 107.5100 9200.0000 73.1567 122.4000 9250.0000 76.7800 108.2900 9300.0000 88.0315 103.2000 9350.0000 65.5200 109.9000 9400.0000 63.8300 104.3900 9450.0000 57.7050 163.1000 9500.0000 71.8000 149.0300 9550.0000 69.0200 76.1300 9600.0000 83.0800 110.6000 9650.0000 -999.2500 19.4300 9677.0000 -999.2500 -999.2500 Tape File Start Depth 7863.000000 Tape File End Depth 9677.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . Tape Subfile 4 is type: LIS