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Home My WebLink About204-1947. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU F-11B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-194 50-029-20424-02-00 10969 Conductor Surface Intermediate Liner Liner 9062 80 2622 8785 641 2639 7000 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 6683 34 - 114 33 - 2655 30 - 8815 8307 - 8948 8330 - 10969 34 - 114 33 - 2655 30 - 8375 7894 - 8502 7916 - 9062 None 2670 4760 7020 10530 7000, 9995 5380 6870 8160 10160 9610 - 10920 7" 26# x 4-1/2" 12.6# L80 28 - 8367 9048 - 9056 Structural 4-1/2" Baker SAB Packer 8526 7847 Torin Roschinger Operations Manager Andy Ogg andrew.ogg@hilcorp.com 907.659.5102 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028280 28 - 7951 N/A N/A 0 300 0 850 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8256, 7847 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 7:56 am, Aug 13, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.13 07:49:24 - 08'00' Torin Roschinger (4662) JJL 9/5/25 DSR-9/11/25 RBDMS JSB 081825 ACTIVITY DATE SUMMARY 7/30/2025 T/I/O = 850/300/300. Temp = SI. AOGCC SU well Inspection Witnessed by Austin McLeod. Pictures taken. SV = C, WV = LOTO, SSV = C. MV = O. IA, OA = OTG. 10:30 Daily Report of Well Operations PBU F-11B F-11B Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/09/2025 InspectNo:susSAM250730123523 Well Pressures (psi): Date Inspected:7/30/2025 Inspector:Austin McLeod If Verified, How?Other (specify in comments) Suspension Date:5/27/2012 #322-133 Tubing:850 IA:300 OA:300 Operator:Hilcorp North Slope, LLC Operator Rep:Andrew Ogg Date AOGCC Notified:7/25/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT F-11B Permit Number:2041940 Wellhead Condition Good. All valves operable. SSV opened to get tubing pressure. Surrounding Surface Condition Good/clean. Typical pad gravel. Condition of Cellar Good. Damp gravel. Comments Pad map used. Supervisor Comments Photos (6) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, September 9, 2025 9 9 9 9 9 9 9 9 9 9 9 9 9 9 2025-0730_Suspend_PBU_F-11B_photos_am Page 1 of 3 Suspended – PBU F-11B (PTD 2041940) AOGCC Inspection #susSAM250730123523 Photos by AOGCC Inspector A. McLeod 7/30/2025 Wellhouse Well Cellar 2025-0730_Suspend_PBU_F-11B_photos_am Page 2 of 3 Production Tree 2025-0730_Suspend_PBU_F-11B_photos_am Page 3 of 3 Surface Safety Valve and Master Valve Production Tree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[ / 6WUXFWXUDO %DNHU6$%3HUP3DFNHU 1R6669,QVWDOOHG 1R6669,QVWDOOHG 'DWH 6WDQ*ROLV 6U$UHD2SHUDWLRQV0DQDJHU 2OLYHU6WHUQLFNL 2OLYHU6WHUQLFNL#KLOFRUSFRP 358'+2(%$<358'+2(2,/ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& &RPP &RPP6U3HW(QJ 6U3HW*HR 6U5HV(QJ )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 11:55 am, Mar 15, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV ;1RQHDWWKLVWLPH '/% '650*50$5 GWV Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.17 12:47:34 -08'00' RBDMS SJC 032322 +LOFRUS1RUWK6ORSH//& 6WDQ*ROLV 3%: 2SHUDWLRQV0DQDJHU &HQWHUSRLQW'U6XLWH $QFKRUDJH$ODVND -HUHP\03ULFH&KDLU $ODVND2LODQG*DV&RQVHUYDWLRQ&RPPLVVLRQ :HVWWK $YHQXH $QFKRUDJH$ODVND 6XEMHFW 3UXGKRH%D\ :HOO)%37' $SSOLFDWLRQIRU5HQHZDORI([LVWLQJ6XVSHQVLRQ 'HDU&KDLUPDQ 3ULFH $Q $2*&&ZLWQHVVHGVXVSHQGHGZHOOLQVSHFWLRQRI3UXGKRH%D\ZHOO)% ZDVFRQGXFWHGRQ $$&K7KH VXEPLWWHGVXVSHQGHGZHOOLQVSHFWLRQUHIOHFWVWKHFXUUHQW 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perator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-194 6.50-029-20424-02-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10969 7000 6683 8256 None 7000, 9995 7847 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 34 - 114 34 - 114 Surface 2622 13-3/8" 33 - 2655 33 - 2655 5380 2670 Intermediate 8785 9-5/8" 30 - 8815 30 - 8375 6870 4760 Liner 641 7" 8307 - 8948 8794 - 8502 8160 7020 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth)7" 26# x 4-1/2" 12.6# L-80 28 - 8367 28 - 7951 8256 7847Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker SAB Perm Packer Liner 2639 3-1/2" x 3-3/16" x 28330 - 10969 7916 - 9062 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Sternicki, Oliver R Oliver.Sternicki@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4301 Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9062 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Suspend Inspection Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028280 PBU F-11B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Jody Colombie at 2:41 pm, Jun 26, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.24 09:55:42 -08'00' MGR26JUN20 RBDMS HEW 6/29/2020 SFD 6/30/20206/26/2020 ACTIVITYDATE SUMMARY 6/4/2020 T/I/O = 0/Vac/210. Temp = SI. Pre AOGCC SU Inspection. No AL. Area around well is clean and free of debris. Temporary scaffolding installed in wellhouse. Wellhead is clean and dry. Cellar is clean with ~1' of what appears to be snow melt water. Well ID sign installed on front of wellhouse. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:25 6/9/2020 T/I/O = 0/0/230. Temp = SI. SU well inspection (AOGCC witnessed by Bob Noble). No AL. Temporary scaffolding in wellhouse. Pictures taken. SV, WV, SSV = C. MV = O. IA, OA = OTG. 0930. Daily Report of Well Operations PBU F-11B Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Prudhoe Bay Unit F-11B Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 204-194 API Number: Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 5/27/2012 Surface Location: Section: 2 Twsp: T11N Range: 13E Nearest active pad or road: F Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: OK Pad or location surface: OK Location cleanup needed: None Pits condition: OK Surrounding area condition: OK Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): See Pictures in folder Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: See Pictures in folder Cellar description, condition, fluids: Dry / Clean Rat Hole: Wellhouse or protective barriers: Yes Well identification sign: OK Tubing Pressure (or casing if no tubing): 0 Annulus pressures: 0 / 230 Wellhead Photos taken (# and description): See Pictures in folder Work Required: None Operator Rep (name and signature): Ryan Moore AOGCC Inspector: Bob Noble Other Observers: Randy Mork / Jeff Curren Inspection Date: 6/9/2020 AOGCC Notice Date: 6/8/2020 Time of arrival: 9:15 AM Time of Departure: 9:20 AM Site access method: Truck 50029204240200 Re- Inspection Suspended Well Inspection Review Report InspectNo: susRCN200609163050 Date Inspected: 6/9/2020 Inspector: Bob Noble Type of Inspection: Well Name: PRUDHOE BAY UNIT F -11B Permit Number: 2041940 Suspension Approval: Sundry # 312-010 Suspension Date: 5/27/2012 Location Verified? W If Verified, How? Other (specify in comments) Offshore? ❑ Subsequent Date AOGCC Notified: 6/7/2020 Operator: BP Exploration (Alaska) Inc. Operator Rep: Ryan Moore Wellbore Diagram Avail?❑ Photos Taken? ❑� Well Pressures (psi): Tubing: 0 Fluid in Cellar?❑ IA: 0 BPV Installed? ❑ OA: 23 VR Plug(s) Installed? ❑ Wellhead Condition Flow line was attached. Wing was locked out. Everything else was blinded. SSV had to be pumped open. Condition of Cellar Clean melt water in cellar. Surrounding Surface Condition Good clean gravel. ' Comments Location verified with a pad map. ' Supervisor Comments Photos (3) I/ �(let Izazo Friday, June 19, 2020 O LO 00 4t CO 0) r � N 0 O Q N O O Z (L L U O Q 1L N C M U M.9 L) a () CD CD QO V O O GU p O (� N �0r0) NQac0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM )N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspend Well Inspection m 2. Operator Name. BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-194 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6 API Number: 50-029-20424-02-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number: PBU F-11 B 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 10969 feet Plugs measured 7000/9995 feet ) j G 2 7 2015 true vertical 9062 feet Junk measured feet Effective Depth: measured 7000 feet Packer measured 8255 feet 4O0CC true vertical 6683 feet Packer true vertical 7845 feet �j Casing: Length: Size. MD. TVD. Burst: Collapse: Structural Conductor 80 20"x 30" 32-112 32-112 0 0 Surface 2622 13-3/8"72#L-80 32-2653 32-2653 4930 2670 Intermediate 8785 9-5/8"47#L-80 29-8813 29-8374 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9610-9640 feet 9650-9680 feet 9710-9740 feet 9790-9910 feet 10100-10420 feet 10580-10920 True vertical depth: 9048-9049 feet 9049-9049 feet 9049.9051 feet 9056-9059 feet 9052-9051 feet 9049-9056 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"Baker SAB Perm Packer 8255 7845 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: NifiL t SCA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI Subsequent to operation: SI 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development lI Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature " " Phone +1 907 564 4424 Date 8/27/15 Form 10-404 Revised 5/2015 i / L-!/?j�1RBDMSr� .,,,4UG 2 8 2015 Submit Ongmal Only m Q. 000o 0) 0 0 a t- O N U) c CD O U) U 4-, O O L.0 OV coO • 6) CO O , N CO v O CO CO CO N N 6) N 0 O N N O CD cr CO V C1) CO M U) 6) O O a) 6) N CO 00 6) 6) N N- H CO CO N 6) 00 (NI (\I 6) 6) co V 6) U) CO CO N CO (3) 6) O N co N- t` 6) N- C C`7 Cr) 00 OO C`') 0 U) U) CO CO 6) CO CD N CO N CO CO CO 0) CO CO V • CO QLO CO CO N N O O C) CO V 6) CO COCD I CO N COCO CO CO Cb CX) CO N N CO C W I- 0 p O O O CO 00 00 co 00 - co —) J J a) 0,) OM N * J N Cep J (O •N x t— (p CV fn - - O O _ CO CO O a0 N = _ N _ U co f� o N 6) C) Ch i Ch N 4 L O)O N (b CO CD N N N- C CO CO N- V N CO N 6) lv N CO O 1— CO J W — • W W .N U U cts U O u_ cCccrxectx0 Z Z Q W W W W W Ep m O I Z Z Z Z j j U (n Z J J J J F I-- • a) o U O N L L L a) " -0 m ca c13 o m � L ca n.� ca a) (13c U o O C 7 N -o C N L (6 O o• > N E ) a) a) cc L 2 oU a) Q U 02 U C1 r a) CJ 1 -6 LL > c (13 d o m Q. aa)) a) �+CD CL = o (7) W> • -0 2 O -o C CO a) O O r Q V c 0_ O ; (D O " O C7) Q .E H Z W I- Q u) D >- O � N � 5 Co m 0 Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name PRUDHOE BAY UNIT F-11 B Field/Pool: PRUDHOE BAY/PRUDHOE OIL Permit#(PTD): 204-194 API Number: 50029204240200 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 5/27/2012 Surface Location: Section 2 Twsp: 11N Range: 13E Nearest active pad or road: F pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean, active pad Pad or location surface: graded gravel Location cleanup needed None Pits condition clean rain/snow water Surrounding area condition: Clean Water/fluids on pad: Rain water Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (#and description) (3)well, flow line, and row Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition McEvoy wellhead, CIW tree, all casing valves open to gauge Cellar description, condition, fluids backfilled wood cellar box, clean Rat Hole: N/A Wellhouse or protective barriers well house Well identification sign: Yes, correct Tubing Pressure (or casing if no tubing) N/A SSV closed Annulus pressures: IA= 140 psi OA= 130 psi Wellhead Photos taken (#and description): (2)wellhead and tree Work Required. None Operator Rep(name and signature) Whitney Pettus ._- AOGCC Inspector: Waived by Chuck Scheve Other Obse rs: Ryan Hayes Inspection Date: 8/3/2015 AOGCC Notice Date: 8/2/2015 Time of arrival: 12:45 PM Time of Departure' 1:10 PM Site access method Truck -a E m o v ca = a c? o = ., ow _ O. oN a V) L •- 0 21 _ a� ( 5 5 v o E aI IIIII ! 1 .. a 73 o! Lri Ln rt - o m u_ 4 0 73aow 0 \ \ 4--.4N ' a.m CO o m o D_ r - 4- t `o c 0 r / c d tN v0 � 1110444 _ V I4\4Nv w 0 mc> 2 uoni C JO�N2o 1111 Illikil‘ 41114 \ , cE w o d U . U ijj} N - i U ' N Q w N 0 m m L p CO a_ 0 ""'..� _�11.� .rr^"/ ` LL L.L. M N N u. U CO V LL`fit Q v X.it U1 .4 01 Im lr+)Q r4<<< fir._.. Y N X m) r1 N .-1 'Q O r•O7.LD[L!) l. ti 0..Nl. l. u._ L.i 1 ti"{N LL:-1[.i m �'rQ1� 11LUJ.LLm;Li ULL Q Q "' Li ll .-� li CO u_ 1s1 <1.1_°: lipr : 0 n r U) N w 4111111... 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X / /. /ff. .0.:,,44/".+4.-4"4.-.41:4'.•Zre.......e...„4.-17.4'.4.4" ..0,!.... ."...r.r. ...Ir.:40:y •••-••. , er e ,, 4 if. =fit �\ �,��♦�� jr rz j t d '7 wn U •,, '' T ..' c F- f'' - -•_t'a'rt•1` ';;/— "' � Ott !. ., ^pm''-'+a ' _'... t ._. ..:4s :..„77 - la c'` ` \ �'`... ��r ift., . , i E{.^ 's, . ., -.' .''I4 '*,.z,_ : V Niii 8.'-, ',.',':.• a. \ /1, tr al r. N . A ' -R 7 ail N t sj ..- s t. I tky w 1 i ....T., • • . •.4C:..:. 4 orip,..07•:*4:: otit* ih t Ant s : s • * , : 4 74 i * 'r'''''' 4' ' , , ---j4z-ia.:---W„.r.. -_44.4.17,-,T-'=„-'-',:'---. h y •.z- -V740&44".5,--- — : .-,...., ,......_, e 8 m • . I x v alep.0111011 . . _ so orivi,�.• • K • #ON, ham , " -x , 6'CSN ,FETY NOTES: INITIAL WELLBORE NOT SHOWN ' W ELLi EAD= MoEVOY F-1113 ON DIAGRAM. MARKER JOINT @ 9265"ON ACTUATOR= OTIS SUSPENDED ORIGINAL RE5T1aCT10N CTD SIDETRACK-70"@ 9569' a KB. EV= 66.76' (ID)PIM 10/20/04 DIMS BF.ELEV= 38.16' r KOP I 2008' —7'OTIS RPB SSSV M.D=5.963- Max Angle= 96°Q 9997 Datum MD= 9339' w/T x 41/2'MEM-(SET-1985),D=3.813" Datum TVD= 8800'SS 13-3/8-CSC,72#,L-80,D=12.347" H 2655' -7000' I—EST TOC(05/18/12) ---------------------- Ilillili Minimum ID = 3.813" @ 2008' i�ri,rii 8033'-8038' —15-TBG (04/23/12) 7" X 4-1/2" INSERT IN SSSV NIP I.��, ,.4k•S ii.A.• 8256' HTOP OF CEI IBVT(04/11/12) 7'TBG,26#,L-80,AB-IJ4S, --j 8256' ►``I`Is .F 8256' H 7'X 4-1/7'XO,D=3.958- .0383bpf,D=6.276' MIt I 8256' H9-5/8"X 41/2'BKR SAB F#R,13=4.00" I; · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a 0 !J - J c¡ l.} Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. 1 o Other, Noffype: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: lJ 130lob I I 151 Project Proofing 1111111111111111111 û1P BY: ~ ~ + a Lf:- = TOTAL PAGES òLf (Count does not include cover sheet) 151 151 Scanning Preparation BY: ~ Date: Production Scanning Stage 1 Page Count from Scanned File: 5.5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~Maria~ Date: II /30/ 0 Þ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111I1111111 NO 151 V\;1-P NO BY: Maria Date: 151 11111111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111I111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/01/12 Inspector: Bob Noble Operator: BPX Well Name: PBU F -11B Oper. Rep: Jon Arend PTD No.: 2041940 Oper. Phone: Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 05/27/12 Date AOGCC Notified: 08/30/12 Sundry No.: 312 -010 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 200 Photos Taken? Yes IA 5 SCANNED APR 1 7 2613 OA 0 Condition of Wellhead: Wellhead in good condition. IA and OA were blinded with gauges. FL just had the wing closed. SSV was opened to get pressure and closed again. Wellhead protected with a wellhouse. Cellar was dry and clean. Location was verified with plot plan. Condition of Surrounding Surface Location: Good clean gravel. Follow Up Actions Needed: None Comments: None Attachments: Photos (2) REVIEWED BY: Insp. Supry JC S 104 (t Comm PLB 10/2011 2012- 0901_Suspend_PBU_F- 11B_bn I. Suspended Well Inspection — PB F -I lB PTD 2041940 Photos by AOGCC Inspe B. No ble 9/1/2012 1 t. f y S y fir. « _ i rip Ilir III 41 ' -, fr 7 itii. i '''' ' ". : s ■ A 4 , , .,, y y, h s..,fi. { �,'k K w a s " � ';6 i .,.. +.s . C + -Pik —. y . �q� S 5 Rne J •KA OIL AND G STATE OF ALASKA AS CONSERVATION COMMION RECEIVED REPORT OF SUNDRY WELL OPERATIONS SEP 1 9 2012 F . j'� 1. Operations Abandon U Repair WeIIU Plug Perforations U Perforate U Othe) O II ins Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extensioi Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wee 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory ❑ 204 -194 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ S. API Number: Anchorage, AK 99519 -6612 50- 029 - 20424 -02 -00 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADL0028280 PBU F -11 B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10969 feet Plugs measured 7000 feet true vertical 9061.96 feet Junk measured None feet Effective Depth measured 7000 feet Packer measured 8256 feet true vertical 6682.6 feet true vertical 7846.15 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 2626 13 -3/8" 72# L -80 29 - 2655 29 - 2654.94 4930 2670 Intermediate None None None None None None Production 8787 9 -5/8" 47# L -80 28 - 8815 28 - 8375.31 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9610 - 9640 feet 9650 - 9680 feet 9710 - 9740 feet 9790 - 9910 feet 10100 - 10420 feet 10580 - 10920 feet True Vertical depth 9047.79 - 9049.27 feet 9049.25 - 9048.69 feet 9049.21 - 9051.21 feet 9056.38 - 9059.32 feet 9052.02 - 9051.34 feet 9049.3 - 9055.72 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker SAB Packer 8256 7846.15 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 16 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 527 30102 21 0 1176 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator10 Development Q -- Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDAPIU GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 < SUSP 0 SPLUC,0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature k,'. " Phone 564 -4424 Date 9/19/2012 RBDMS SEP 2 0 iii1 - e ;, 1. z S f Form 10-404 Revised 11/2011 (6 / 7 /y Submit Original Only Casing / Tubing Attachment ADL0028280 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470 LINER 641 7" 29# L -80 8307 - 8948 7894.38 - 8501.54 8160 7020 LINER 48 3 -1/2" 9.3# L -80 8330 - 8378 7916.16 - 7961.61 10160 10530 LINER 1265 3- 3/16" 6.2# L -80 8378 - 9643 7961.61 - 9049.28 LINER 1326 2 -7/8" 6.16# L -80 9643 - 10969 9049.28 - 9061.96 13450 13890 PRODUCTION 8787 9 -5/8" 47# L -80 28 - 8815 28 - 8375.31 6870 4760 SURFACE 2626 13 -3/8" 72# L -80 29 - 2655 29 - 2654.94 4930 2670 III TUBING 8234 7" 26# L -80 26 - 8260 26 - 7849.93 7240 5410 TUBING 111 4 -1/2" 12.6# L -80 8256 - 8367 7846.15 - 7951.19 8430 7500 • Daily Report of Well Operations ADL0028280 ACTIVITYDATE SUMMARY • = •• I. emp= £ ssis ►V 'rojec s a e nspec ion - U nesse. •y :o• lo• e . to AL. 9/1/2012 SV,WV,SSV= Closed. MV =Open. IA,OA =OTG. NOVP. (1130 hrs) • • • • Prudhoe Bay Unit / Prudhoe Oil Pool Well F -11 B, PTD 2041940 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of F -11 B on 9/1/2012. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). o Report of Sundry Well Operations (10 -404) o Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Bob Noble witnessed the inspection. o Wellbore diagram illustrating the current configuration of the well. o Pad map showing the well location and other wells within one - quarter mile radius of the surface location. o Photographs showing the condition of the wellhead and the surrounding location. 7 .— Additional pertinent information: L • F-11B was suspended on 5/27/2012. The work was documented in a completion report (form 10 -407) submitted 06/19/2012. • F -11 B is located on an active maintained pad and is accessible by the Prudhoe Bay road system. • Top of cement was tagged at 6752' SLM on 5/27/2012. John Crisp (AOGCC) witnessed. MS /MLB 09/18/12 • • Suspended Well Site Inspection Form 'Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: F -11 B Field /Pool: Prudhoe Bay /Prudhoe Oil Permit # (PTD): 2041940 API Number: 50- 029 - 20424 -02 -00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 5/27/2012 Surface Location: Section: 2 Twsp: 11N Range: 13E Nearest active pad or road: F -Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, Clean Pad or location surface: Level gravel pad Location cleanup needed: None Pits condition: Meltwater, No sheen Surrounding area condition: Good Water /fluids on pad: Rainwater Discoloration, Sheens on pad, pits or water: None Samples taken: N/A Access road condition: Spine, Good Photographs taken (# and description): (2) Front wellhouse, Back wellhouse Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Cameron wellhead, McEvoy tree and annular valves Cellar description, condition, fluids: Clean gravel cellar, 3' deep Rat Hole: None Wellhouse or protective barriers: Wellhouse,Good condition Well identification sign: Yes, Needs to be corrected to F -11 B and new permit number Tubing Pressure (or casing if no tubing): 200 psi Annulus pressures: IA =5, OA =0 Wellhead Photos taken (# and description): (2) Tree, Wellhead and annular valves Work Required: Order and install new Wellhouse sign Operator Rep (name and signature): Gerald Murphy 411111111101 AOGCC Inspector: Bob Noble Other Observers: Jon Are Inspection Date: 9/1/2012 AOGCC Notice Date: 8/31/2 j Time of arrival: 10:40 AM Time of Departure: 11:25 AM Site access method: Pickup 0 0 . . . -- TREE A V ChV • F -1 1 OT HOW B NE& L LO WELBRE NT SH OOWN Y" INEVOY ALAIN, NAPIER JOINT a 0205' ON AaTLIA TOR = '----01-hi Wi StJ$PENE)ED OIROINAL r ua CM SIDET 70 RACK - ° fa 95617 ks alv . . - Dim BF BIN = — " [ m i GU' RI3TRICTION(14JD) PER 101201111 OITAS 2000 I— r oils FR) SSSY NV, 0 • 5.ssr ICOP A 3400' 11u ATO = 95* (5 9967 0 or Fr la 4-17 PISART (SET -1905), 10 . 3.111V Daum LET = 93.19' i ()Nu IVO= WRY SS L113/71 CSC, 721. L-80. o -12 3±7.-LIsser ,...29 40-_ -iis I WC pviivi Mire Irnu m 10 0 3.813" © 2008' `e` N`,`,%., N 4, ,,.• NV. • .• 1 ■ 8033' - 110377 -i 5' TOG PLECH (0472:V12) i 7" X 4-1/2" INSERT IN sssv Nip I .,,v..N., to" ■?".;•ite`0. °° . --L.seer Toe cc cadENT owt inn `••• N'oso.V. NI •■• ;`..`;`.7';')%e r TOG. 201, 1 ao, ke easy :•",%,-`,-"=-", 82.51V r x 4- isr xo, D. assr I 0353 bp!. V - 027W li t:: 4 ''• 11 VW 9-SW X 4-117 SKR SAB ROt IDT . isor 4-1/2" OTIS X NP, 0 • 3.813 l `,"Ze ..". `," .../ • ./ ITOPOF r um. 290, L-II0, ID • 0 1114' POT '',e.e'V'o 11 1 ',MI 1123, gi a.nr es anal sty. o = 3.00 ..:;<;:,..").:.....:(n■II — . j i .1 1 TLIPOT LEER ( W ? %.*‘,/, 1 „..., . , ..,.; .. .ar wr CllB DI RIP, /ELLS) 0* EIR - 111:::5.1 VIEVPIEIS X PP, ID = 281 4-17 7BG, 12 7511, Lao. 0152 bpT, VA low SNIT 1 -... .: e A V' ' ..; is ais7' Ur SKR WS TRIO TAL MOD PPE) ., .:•: .;•: .,•, wow OM TT UXias 1117101 3-1:2” LM s81st-So sn,, ow? VI, D. zwr —■ sir , `,N ZeliA. III 1 A. s e,...' A', ; gm 3.172 X 3-3114W X0, 11:1- 27W Inly or amen 0 cywo -- --nificr _ I &Mr COG, 419, LAO, to = a WI' Ilral:M : Z :::: 1 Int l OuT WINDOW 1F-118): ta... SOW' (NO RA TAG) Fomocsc (ao/14,04) I IOW CTD I .....„......,,,V.. \ •• -. N ■ • • • IV&IMITMI (I1 3104 ) nor . 441 c',• I ' N „•,.. ,•• lk,:•,,•;, — V•r , ' 9643 * I 3 ic z. tar PERFORAmOn %MUM • ..,,,,,,, '4 ,r . XO, O. 2,44' REF LOG SWS MEN c41./Ga. C01 19 20101 ANGLE AT TOP PEW: 55 • 97117 , "4;4 PPM Raw* PAAAA1o1 OB tr histaTTAI . , 011s stI ,. III ..1 PITERVAL • . Sqa 111.1 V tow 2.30 CEP go*. ' Noe , WM $ , • • P sus - sum , S warm 3-3nr Lon. 6.20, Leo To .00re bpl, 0.2.80 96ar Doe -9733 1 S mans I 979D :- 9910 ' S 1 0412 10103 - 10‘.20 C Magi ■0; 1 1485711 C 71 M+ < r (WO O mom.) leasf ' s' •■ lwnt°7) cai isu=s , sm 101120 C ' 10122106 H .•„ I 2-7 r LIR Liss, sn., 140, .01358 be. D. 2.441' 1111M OM REV ST =OEM bAla , RE v fly CONNIPEPITS PFtUDHOE awe UNIT SII$ ORNINAL 0011PUITION 4/07 JRA/Sv SET COSPADPERF g17131107) WELL 711111 Mall a 0 I ciDtalwarionesmac 0141012 MP PJC PIA (OS I 1112) 1 PERIAR No 104 4940 WOW 11001E1c v Cm S1)E1RAOR . °NUM ,JIGAID TOG PUNO1 (04/23,12) , API No 50.021.21)(24412 01/21110 .MFITLH ORLG ORA:- I COPIRECTICWS 0412112 : P.IC PERT CORRECTION „V/ 1407 CJIPPAG *17412 tSET P X P.,,,LIC 0 MC? 7 otygni2 2306(0/ 7 Jowly() ip&A owe/12) 0TATT CAPPTIM PKPLUG 1 17412 .! P. 'OUT COARECTN O ' 54/C 2 TIM RISE ! op Explwallon (MIAs) • • F Pad ikil July 11, 2012 ' 1 } Approximate Scale: 1"=300' * . ,, 40,444 - ,e K' 2012- DMC0157 -6 -54 derometric a 1 s i , h. 1 1 1 1,/, 1 �r . .. a u ''''''.....:, ' :1: '' . i A ■ 1 , 1 1 1 _ 1 1 r1/4 x x k s , . ..... ':' - -', A l '''. .--*■ ' ' 7 --. .....,.1. 4 I.,,,,41 . ., if ............. ,,b( ._ , _ .,.. .. ...,.. _ ,............. ... t t 1 • • — - - - -- I i + a) Enter /Exit / I 4 fri \ 1 j I • 24 48 • I I • 39 • ■ 33 13• j I I � • 23 41 ■ I 37 • I , I I • 22 12 • ! I I I 40' 34 to i • 35 i a • I j ! •2i • 31 • 29 • __ 9 • I C0 I l 8■ I i 3$ • 38■ i 7 43 • 6• i 135' 19 5 s • 47 • 28 ■ 18 4• I a 4 i 40 • I • 27 3• I I •17 I i • 45 11 I I 97' , • 26 2• I I •16 i I ■ $ 44 1 I i • 15 I I I I I - -_ I r - - -.,.' I — ____ . i I I (1� 1 I I I— I - -`∎� 940' 1 I 1- - 1�" - -m-:1 I , ‘. s 1 Enter Exit .. � \ j 1 -) �1 1 4y f ` - - - , — - - - - -- - -- \\ Enter /Exit \,. -- - - =_.% 1 WELL PRODUCER • Or ❑ ' WELL INJECTOR A DATE : 5/30/2012 SCALE .1" = 250' MAP DATE 2011 PBU - F PAD WELL SLOT UV/CONDUCTOR • • • • a ltttfltl • : ' uuu Al I F_11 F -li d UM. — • _ OM Alllliir r ��' �� • • • s 4s Q. p tr j p , , * xa ir 'f aft �� s t 3 K :1 • c 7 , .. .� �i . l , ' • ,,, 4 : , , • ,o`;�.,.Y#S.Y!- a ". rt -,� .,,,,,.,,,,... .*.. . ., ,. ..,..., . , .., . , ..,.. , , ... ' ' #ii ' ' ''''' 4 ' ... ' ' ' ' '''' '''' '''''.1.',...••',11•4°'•'!'.4.; r ,. . ,,, , , . ii r • • • • . • • \ r% ' e I \ 1 \ 1 I i I fl . , . lb* ..______----- c Vi m. t `y ♦ ek • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned IS Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. '• 5/27/2012 204 - 194 312 - 010 a ' 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/15/2004 50 029 - 20424 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/19/2004 PBU F -11B 2208' FNL, 2869' FEL, SEC. 02, T11 N, R13E, UM g. KB (ft above MSL): 66.76' 15. Field / Pool(s): Top of Productive Horizon: 1057' FNL, 938' FEL, SEC. 02, T11 N, R13E, UM GL (ft above MSL): 38.16' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1934' FNL, 1812' FEL, SEC. 02, T11 N, R13E, UM 10934 9057 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 651958 y- 5974592 Zone- ASP4 10969 9062 ADL 028280 TPI: x- 653865 y- 5975782 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 653010 y- 5974888 Zone ASP4 None 18. Directional Survey: ❑ Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD GR / EWR, MGR / CCL / CNL 8948' 8502' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 7.5 cu vds Concrete 13 -3/8" 72# L -80 Surface 2655' Surface 2655' 17 -1/2" 3153 cu ft Arcticset 11 9 -5/8" 47# L -80 Surface 8815' Surface 8375' 12 -1/4" 1193 cu ft Class 'G'. 130 cu ft AS 1 7" 29# L -80 8307' 8948' 7894' 8502' 8-1/2" 401 cu ft Class 'G' 3 -1/2" x x 2 8.81M2# 6.2# / L -80 8330' 10969' 7916' 9062' 4-118x3-3/4' 230 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 7 ", 26#, L -80 8256' 8256' / 7846' MD TVD MD TVD 4 -1/2 ", 12.75#, L -80 8256' - 8367' 26. REOEIV ED DEPTH INTERVAL C (MD)I FRACTURE, AMOUNT AND KIND OF MATERIAL USED 9 1 8048' 15.6 Bbls Class 'G' SUN 1 6752' 72 Bbls Class 'G' AOGGC 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL - BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes IS No Sidewall Core(s) Acquired? ❑ Yes El No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None z.°14 .Mtigi,� JUN 2 RBDMS JUN 2 0 2012 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Original Only r, ` 6.z6,.12.- ,d�0 ubmit (_:/ 29. GEOLOGIC MARKERS (List all formations an encountered): 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes C No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Shublik 8978' 8530' None Sadlerochit 9057' 8603' Top CGL 9197' 8733' Base CGL 9265' 8797' 25N 9334' 8862' 22N 9408' 8931' 21N 9464 8981' Zone 1B / 14N 9545' 9032' 14P 9547' 9032' Formation at Total Depth (Name): 31. List of Attachments: Summary of Work, Well Schematic Diagram 32. I hereby certify that the oing L ue correct to the best of my knowledge. /� Signed: Joe Lastufk Titl Drilling Technologi Dat (0 IN j1� PBU F -11 B 204 -194 312 -010 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Aras Worthington, 564 -4102 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • F -11 B, Well History Date Summary 04/10/12 T /I /O = ? ?/10 /vac. Temp= SI P &A ( Reservoir Abandonment) Heated 2 Diesel transports to 75 *. Pumped 27.1 bbls 75* diesel down IA to liquid pack. Job postponed due to valve positions on pump -in sub. FWHP= ? ?/0/0. Swab, SSV, & wing shut. Master, IA, & OA open. 04/11/12 P &A Stage 1 of 2( Reservoir Abandonment) LRS and SLB . LRS load IA w/ 20 bbls hot diesel. Spear in tbg w/ 20 bbls neat meth, 500 bbls 1% KCL FW, and 10 bbls neat meth spacer. SLB pumped 5 bbls fresh water, 10 bbl chemical wash, 15.6 bbls of 15.8 ppg class G cement, 2 bbls fresh water down TBG. SLB pumped 5 bbls fresh water to launch wiper plugs. LRS displace with 309 bbls 70* diesel down TBG. Est TOC @ 8256' (1350' above top perf) Estimat 1.5 bbls into formation. LRS not in control of well upon departure. FWHP's= 3100/3056/0. 04/12/12 T /I /O = 1780/1780/20. Temp = SI. Bleed TP to 1000 psi (P &A screen). No AL. T & IA FL @ surface. Bled TP to 950 psi though flowback tank in 2 min. During bleed IAP decreased 100 psi. Bled IAP to 940 psi through flowback tank in 1 min. Monitored for 30 min. TP decreased 30 psi, IAP increased 20 psi. Job complete. Final WHPs = 920/960/20. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 1030. 04/13/12 T /I /O = 800/850/20. Temp = SI. WHPs (Post T bleed). TBG pressure decreased 120 psi. IAP decreased 110 psi since 4/12/12 10:30 am. SV, WV =C. SS V, MV =O. IA, OA =OTG. NOVP. 02:10 04/17/12 TAG CEMENT C© 8048' SLM w/ 1.75" S- BAILER - FULL OF CEMENT. TAG CEMENT w/ 2.25" CENTRALIZER & 1.75" SAMPLE BAILER © 8048' SLM - FULL OF CEMENT . 2ND TAG WITNESSED BY AOGCC REP JEFF JONES. PERFORMED AOGCC WITNESSED CMIT TxIA TO 2500# - PASS. 04/23/12 (SLB E -LINE - TUBING PUNCHER). INITIAL T /I /O = 400/1050/0 PSI. RAN 5' x 1- 11/16" TBG PUNCH -- TBG PUNCH INTERVAL C© 8033'- 8038'. FINAL T /I /O = 750/730/0. 05/17/12 (Obj: Reservoir Abandonment) Down TBG Pumped 5 bbls 30* meth followed by 316 bbls 80* 1°/0 KCL for injectivity test 5 bbls meth spacer followed by 84 bbls of 75* diesel for f- protect followed by 98 bbls 1% KCL SLB pumped down TBG 5 bbls of fresh H2o followed by 10 bbls of chemical wash followed by 2 bbls of fresh H2o spacer followed by 72 bbls of 15.8 ppq class G cement followed by 21hls of fresh H2o spacer Line up valves to launch wiper balls pump 5 bbls of fresh H2o to launch wiper balls LRS line up valves to pumped down both sides of ball launcher down TBG 159 bbls of 90* 1% kcl followed by 96 bbls of 85* diesel to f- protect TxIA. Estimated TOC I@ 7000' on TBG and IA. Freeze protect hard line w/2 bbls of diesel and 3 bbls of meth Wing shut swab shut ssv shut master open casing valves open to gauges FinalWhp's= vac /10/201. 05/24/12 GREASE CAPS VERIFIED SERVICE W /AS SLICK LINE SVC AND CYCLE VALVE SWAB 100% GOT ALL TURNS 33 1/4. 05/27/12 RAN 3.51 CENT, 3 " SAMPLE BAILER. TAGGED TOC © 6752' SLM. JOHN CRISS (AOGCC) ON LOCATION AND WITNESSED TAG OF CEMENT AND SAMPLE. MIT -T PASSED.1QHN CRISS (AOGCC) WAIVED WITNESS. MIT -IA PASSED. JOHN CRISS (AOGCC) WAIVED WITNESS. Page 1 of 1 IR= 6" CAN • F —1 1 B s NOTES: 11111AL VVELLBORE NOT SHOWN VVELLI McEVOY , 0 GRAM, MARKER JOINT @ 9265" ON ACTUATOR= 0115 ORIGINAL 7" LNR. CTD SIDETRACK - 713° (:-, 9569' KB. ELB/ = 66.76' SUSPENDED <2 . RESTRICTION (1413) PER 10/20104 CiNIS BF. ELEV = 3816' KOP= 3400' 1 RPB l'4I Max Angle = 96" © 9992 0 w /7' x 4-1/2" WERT (SET -1985), D = 3.813" DtumM0= 9339' Datum WD 8800SS . = ' Col5 2" 1 13-3/8" CSG, 72#, L-80, 0=12.347' H 2655' 1 2008' 7" OTIS SSSV P, 0=5.963' - ,,—IEST TOC (05/18/12) Minimum ID =3.813" @ 2008' -iiilrigivirvic, lf.4 ,4"" . ." INV.' 8033' - 8038' -- 16 MG PUNCH (04/23/12) 1 7" X 4 INSERT IN SSSV NIP eir dik 4+.40 0045 ' A, los iii, 1.1 ieir 4 .P.0. iiii% 1,1,41, 1 ,82er --1TOP OF CEMENT (04/11/12) 1 .1".0"4//fr 41Pe it ill 111 1% ill AY 1 4 1 7" TBG, 26#, L-80, A B-U4S, 8256' 16%%10406 i .t.t.e...".....#.0 8256* H 7" X 4-1/2" X0, 0= 3.958" - 3kNig.igrivicr...ai....1 .0383 bpf, ID = 6.276" M ' '' ■T,1, 8256' 1--19-5/8" X 4-1/2" BKR SAB FKR, ID= 4.00" kiNso. 'II ' ...%%%. 8302' — 14 - 1/2" OTIS X NIP, 0 = 3_813" Iiilb% see," lir lik: ifr 4! 100 'TOP OF 7" LNR, 29#, L 0 = 6.184" 1 8307" 2,1 e 0, 4 m lip % "4 • 8330' — 13.70 - BKR DEPLOY SLV, 0 = 3.00" 5 Ai Fa • I. ....% . . 8323' ELM -- 1TOP OF LIVER (10/21/04) 1 0 ifr .0 0 tO 11 11 I 8334 — 4 OTIS XN NIP, MLLE) 4 e JP ill 0= 3.80 (BEHIND PIPE) IF klki .. 1 8349' —13-1/2" HES X MP, 0= 2.81" 4 I 4i e 41 i i, ‘• 0 p -1 /2' TEG, 12.75#, L-80, .0152 bpf, 0 = 3.958" H 8367' 4 4, 41P 411 11 0 8367' H4 BKR SOS TBG TAL (BEHIND PIPE) ook. vv.% , 40 ill 0! 3-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.99" —1 8378' 8361' H ELMD TT LOG an ??177 f?? li% p% e A 4fie 4 lip 1 4 1 1.'41b: 8378' —13-1/2" X 3-3/16' X0, 0= 2.79 1 404/P.if .04/ hi. ki. 4/Pft 4/0 4/P41 kik* 'kV 411',4/0 41* 41! 1TOP OF CEMENT (10/14/04) -- I 8740' ewseff4 • 4P 1\ 1 9-5/8" CSG, 47#, L-80, 0 = 8.681' — 8815' — tiedm • v 1 Vivitplip'j...4 MILLOUTI/VMD0171/ (F lip 4. 0. 1 4 1 "4# diti/Vioil# 8948' - 8956' (NO RA TAG) WHIPSTOCK (10/14/04) 1 — 8948' CID '417014 N; , -2 ' WIIIPSTOCK (10/13/04) 8965' 4 N. i ll i r i i r N. 9643' 3-3/16" X 2-7/8" o'..4//fr 4 • PERFORATION SUMMARY Ilipilvs. REF LOG: SWS MEM CNUG X0, 0 = 2.44" FUCCL ON 10/20/04 4 4. NA% ANGLE AT TOP PERF: 85' @ 9790' NA.% 411. %It Note: Refer to Production 08 for historical pert data *An llis. 9995' —2.30 CEIP SIZE SPF INTERVAL I Opn/Sqz DATE ` .... 'VS. 2" 6 9606 - 9636 1 S 04/20/12 ' 1: ••••• 2" (07/31/07) 6 9646 - 9676 S 04/20/12 3-3/16" LNR, 6.2#, L-80 TCII .0076 bpf, Ir.2.80" 1 9643' 2" 6 9706 - 9736 S 04/20/12 IO '' ' (4 2" 6 9790 - 9910 S 04/20112 RESTRICTION <2.3" (HUD, DIMS 10/20/04) 1 10809' 2" 6 10100 - 10420 C 10/22/04 2" , 6 10580 - 10920 j C 10/22/04 1PBTD H 10934' All, Aliftb , 'Nu 2-7/8' LNR, 6.16#, STL, L-80, .0058 bpf, 0 = 2.441" —{ 10969' I DATE REV BY COMMENTS 1 DATE i REV BY 1 COMMENTS I PRUDHOE BAY UNIT 01/14/80 ORIGINAL COMPLETION . 08/04/07 I JRA/SV SET CIBP/ADPERF (07/31/07) I WELL: F-11B 05121/00 CRM CID RORIZ SIDETRACK 1 04/20/12 'REM/ pJCIP&A (04/11112) I PERMIT No: '2041940 , f 10/23/04 NORDIC1 CID SIDETRACK 04/26/12 JMC/JMD TBG PUNCH (04/23/12) API No: 50-029-20424-02 01/29/06 JAF/TLH DRLG DRAFT CORRECTIONS ' 04/29/12 PJC : PERF CORRECTION I SEC 2, T11N, R13E 02/14/07 CJN/PAG SET PXPLUG @ 8302' I 06/07/12 i JLW/JMD P&A (05/18/12) 03/06/07 CJN/ILH PXPLUG PULLED I 06/17/12 PJC ICMT CORRECTION 1 BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ` DATE: May 27, 2012 P. I. Supervisor ( ( ( ( FROM: John Crisp, SUBJECT: P &A PBU F -11 B Petroleum Inspector BPX Prudhoe Bay PTD 204 -194 May 27, 2012: I tr aveled to PBU F Pad to witness RIH with sample bailer on v p wire line to verify TOC on F -11 B. BPX Wells Group Ryan Thompson was in charge of this TOC wire line tag. Proposed TOC for this Risk Mitigation Reservoir Abandonment plug was 7100' MD. TOC was found at 6752' MD. I witnessed POOH with sample bailer on wireline & the bailer dumped to verify cement sample was recovered. Summary: I witnessed the tag of a reservoir abandonment plug on PBU F -11 B. TOC found at 6752" MD WL. Attachments: none - Non - Confidential 44 lL D JUL �` 8 P &A BPX PBU F -11B • • IMITE ird SEAN PARNELL, GOVERNOR ��11 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATI ON COMMISSION ORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Aras Worthington Wells Intervention Team Lead j lt BP Exploration (Alaska), Inc. (� �- +' P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, F -11 B Sundry Number: 312 -010 Dear Mr. Worthington: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. i -,4, Chair DATED this / day of January, 2012. Encl. STATE OF ALASKA (Z `''' 0 VED ALASKA* AND GAS CONSERVATION COMMISSION � At 9-/°1 APPLICATION FOR SUNDRY APPROVALS 1,q -t"L/ a 8 5 2012 20 AAC 25.280 • • ' - r E t° as �;Qfl3. Common 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ " ''Cfiange /Approved Program ❑ Suspend IS < Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Ari � ztension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 Exploratory ❑ 204 -1940 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20424 -02 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ F -11B - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028280 - PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10969' 9061.96 • 10934 ' 9057.33 - 9995 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 30 110 30 110 1490 470 Surface 2616' 13 -3/8" 72# L -80 29 2655 29 2655 4930 2670 Production 8787' 9 -5/8" 47# L -80 28 8815 28 8375 6870 4760 Liner 641' 7" 29# L -80 8307 8948 7895 8502 8160 7020 Liner 2639' 3- 1/2X3 - 3/16X2 -7/8 8330 10969 7916 9062 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# L -80 26 8256 - 4 -1/2" 12.6# L -80 8256 8367 Packers and SSSV Tvoe: 4 -1/2" Baker SAB PKR Packers and SSSV MD and TVD (ft): 8256 7846 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/18/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended El 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington Printed Name Aras Worthington Title Wells Intervention Team Lead Signature / Phone Date 564 -4102 1/4/2012 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 2"(NO Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: it 11 I f i v/V . pA e , , -eQ 20 414Czs - / a ( ) Subsequent Form Required: / _ Li / Date: ' APPROVED BY i hol Approved by: J COMMISSIONE THE COMMISSION f z____ Ra A 1012 G � Form 10 403 R ► 1 n Submit in Duplicate F -11 B _ 204 -194 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F -11 B 10/22/04 PER 9,790. 9,910. 9,056.38 9,059.32 F -11 B 10/22/04 PER 10,100. 10,420. 9,052.02 9,051.34 F -11 B 10/22/04 PER 10,580. 10,920. 9,049.3 9,055.72 F -11B 7/31/07 BPS 9,995. 10,969. 9,052.4 9,052.31 F -11B 8/1/07 APF 9,610. 9,640. 9,047.79 9,049.27 F -11B 8/1/07 APF 9,650. 9,680. 9,049.25 9,048.69 F -11 B 8/1/07 APF 9,710. 9,740. 9,049.21 9,051.21 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE IIII 1 • • Summary of Proposed Work BP Exploration Alaska Inc (BPXA) Reservoir Abandonment Well F -11 B PTD: 204 -194 API: 50- 029 - 20424 -02 -00 As part of BP's risk mitigation program to minimize the number of unsecured non - operable wells across its area of operation, well F -11 B has been targeted for reservoir abandonment. As per AOGCC definitions, the proposed work will be for suspending the well. This will isolate the reservoir but still allow access to the wellbore for re -entry or sidetrack in the future. F-11B has been shut in since March 2010 due to high GOR. In April 2010 collapsed tubing was found and confirmed at 8180' SLMD. In July 2011 a 24 arm caliper showed that the tubing is damaged from 8213' -8221' ELMD with a minimum restriction of 1.80 ". Injectivity through the TxIA through this hole has been successful at 2 BPM. The abandonment will require cement to be pumped in two -sta g the first stage we will bullhead cement from PBTD to the 9 -5/8" by 4 -1/2 production packer at 8256'. After waiting on cement and tagging the top of cement we will circulate the T x IA with diesel and pump a cement plug with the top of cement in the T and IA at 7100'. This will provide a -1156' column of cement above the Sag River in the tubing and all annuli. Well History F -11 was a conventional GD well drilled in 1980. • 17.5" hole drilled to 2655' o 13 -3/8" 72# casing cemented with 3069 cu ft of 15.2 PPG Arcticset II, bumped plug ok with no returns o Top job performed with 84 cu ft Arcticset II with 1.25" tubing hung at 60' below GL, full returns • 12.25" hole drilled to 8815' o 9 -5/8" 47# casing cemented with 1196 cu ft Class `G' • Calculated top of cement Tess 30% is 6142' o 130 cu ft Arcticset I cemented through DV tool at 2568' • Calculated top of cement is 2170' with Arcticpack to surface • 8.5" hole drilled to 9671' o 7" 29# casing cemented with 402 cu ft Class `G' • Calculated top of cement less 30% is to liner top at 8307 plus 108 cu ft excess • CBL initially showed free pipe, pressured up and re -ran CBL u nable to find results � ctir. 4e. I.vC1S (Q1� v,��I 61 7O 71' p0o�/ ®� je, /31 4'1i1 4 4/ C U If rh, Wef" , ( , arnl f ec /ciyye gNrl i'cf44 Cic /,' . for .7,[ f �5/' "" C G cW/'eir l eIC/icre * 1145 ' �, /g5 her 445 5404,4 f� #fe r a • `eserv -7v r4 r eta, / /y � D 1 � � iy RNs` Vq /,C, p /I� r °'1 r4 c&' !I?�`P/ , j k' / G e G 4 l • f, o terc,a i tic welt r,, r6 P i rW , is 1A,Z • • • In May 2000 F -11A was drilled as a horizontal CT sidetrack. • 3 -3/4" hole drilled from 8312' to 10875' o 2 -7/8" 6.16# casing cemented with 107 cu ft Class 'G', bumped plug ok In October 2004, F -11 B was drilled as a horizontal CT sidetrack. • 4 -1/8" x 3 -3/4" hole drilled from 8330' to 10969' o 3.5" 8.81# x 3- 3/16" 6.2# x 2 -7/8" 6.16# casing cemented with 230 cu ft Class `G' For questions or comments: Contact Office Cell Todd Sidoti 907 564 -5113 907 632 -4113 w /a: Well File 2 • • Volumes Tubing OD ID bbl /ft 2 -7/8 ", 6.16# 2 -7/8" 2.441 0.0058 3- 3/16 ", 6.2# 3- 3/16" 2.80" 0.0076 3-1/2", 8.81# 3-1/2" 2.99" 0.0087 4-1/2", 12.75# 4-1/2" 3.958" 0.0152 7 ", 26# 7 6.276 0.0383 Casing OD ID bbl /ft 9 -5/8 ", 47# 9 -5/8" 8.681 0.0732 13 -3/8 ", 72# 13 -3/8" 12.347 0.148 Annular Capacity 9 -5/8" x 7" 0.0256 First Cement Plug: Tbg volume from packer (8256') to bottom perf 12.5 bbl (9910') �� GJi 7.5 Second Cement Plug: .J Tbg volume from 8256' -7100' 44 bbl z a1� IA volume from 8256' -7100' 30 bbl Total Cement Volume 74 bbl Steps: 1 0 Service Tree valves and annular valves. PT all valves. PPPOT -T and IC. Shoot fluid levels in Tubing, IA, and OA. 2 F Bullhead cement from 9995'- 8256'. WOC. Pre-ss. 3 S Tag TOC. (AOGCC 24 -hr notification to witness required) 4 F Establish circulation, circulate cement to 7100' in the T and IA. WOC. 5 S Tag TOC. - - - • - . 'c - e - - . . pet- re ...:.o,.0 6 F PT cement plug (Tbg and IA) to 2500 psi. : " - . - r no i . • • ) rress- 3 �b k COA01 , • l• /L 3 • • TREE= 6" CIW SAFETY NOTES: ORIGINAL PARENT WELL NOT WELLHEAD= McEVOY Current ,� ,� B SHOWN ON DIAGRAM. MARKER JOINT@ 9265" ON ACTUATOR = OTIS ORIGINAL 7" LNR. CTD SIDETRACK- 70° @ 9569' KB. REV = 68.76' Q.3" RESTRICTION (HUD) PER 10/20 /04 DIMS BF, ELEV = 38.16' KOP = 3400' Max Angte = 96 @ 9992' 2008' 17' OTIS RFS SSSV NP, ID= 5.963" Datum ND= 9339' w(7" x 4 -1/2" 4$ERT (SET - 1985), ID= 3.813' C.fatumTVO. 8800' SS 1 13-3/8' CSG, 72 #, L -80, ID = 12.347" H 2655' Minimum ID = 2.377" @ 9643' TOP OF 2 -7J8" LINER 1 7" TBG, 26 #, L -80. AB -U4S, 8256 8256 7' x a -112 xo' 0383 bpf, D = 6 276 1'/ ►�4 Ma 6266' , 9 -5/8" X 4-1/2" BAKER SAB PKR [) = 4.00" I 111: 8302' H4 -12' OTIS X NP, op= 3.813" I (TOP OF 7" LNR 29#, L -80, ID = 6.184" H 8307' 8330' H 3.70" BKR DEPLOY SLV , D = 3.00" I 'a 8323' B_M H TOP OF LINER (10/21/04) I I 1r 8334• H 4-I/2" 3.80 OTIS XN ( BEHND NP. WN LLED = / i) I 8349' H3- 1 /2 "IESXNIP,D =281" I 1 I .. 4-1/2" TBG, 12 75#, L -80, .0152 bpi, D = 3.958" H 8367' I r t 1 � If D 8 367' 4.1/2" BKR SOS TBG TAIL (BEHIND PIPE) #4 0 V V II I 8361' H H- MDTT LOG DATE NOT AVALABLE I 13- 1/2' LNR 8.81 #, L -80 STL, .0087 bpf, ID = 299" H 8378' A . 1'11'1 1 1 8378' H3 D X 3.3!16" XO, = 2.79" I ,/./, 0 1.11 ITOPOF CEMENT (10/14 1 04) 8740' ii• ii •.•1• /111 9 - 5/8" CSG, 47 #. L - 80, D = 8.681" 8815' 114 1111' I - 11 1 1 1 i � 1 1 1 1 1 1 IW STOCK (10174104) H 8948' CTD I ♦4 p1��1 M�LOUr WINDOW (F -1181: I I 8948'- 8 956 ' (NO RA TAG) 1 WHPSTOCK (10 /13/04) H 8965' I 9643' I-- 3 -3/16" X 2 -7/8" I CHEM CUT (10105104) H 9010' W 44 xo, D =2.44' 1 2 -7/8" LNR 6 16#, STL, L -80, D= 2.441" 10875' S I , 9995' I 2.30 COP PERFORATION SUMMARY t REF LOG SWSMEMCM /GRCCLON10 /20/04 1 , (07;31/07) 3.3/16 LNR 6.2#. L -80 TC11.0076 bpf, D=280 9643' ANGLE AT TOPPERF: 85@9790' r , Note. Refer to Production DB for historical pert data , SIZE SPF INTERVAL Opn ?Sqz DATE (RESTRICTION s2.3" (IED. 016S 10 /2004) H 10809' 2" 6 9606 - 9636 0 08 /01/07 2' 6 9646 - 9676 0 08/01/07 'MID — 10934' ., 6 9790 - 9910 0 10/22/04 2" 6 9706 - 9736 0 08/01/07 �� 2" i 2 -7 ?8 "LNR 6.16#. S TL. L- 80..0058 bpf. D = 2441" I--I 10 969' 2' 6 10100 - 10420 C 10/22/04 2' 6 10580 - 10920 C 10/22/04 DATE REV BY COMMENTS DATE REV BY COW/ VENTS PRUDHOE BAY UNIT 01/14/80 ORIGINAL COMPLETION 08 /04/07 JRAJSV SET CIBP'ADPERF(07'31 /07) WELL: F-118 05121100 CRM CTD HORIZ SIDETRACK PERMIT No: t041940 10/23/04 NORDIC1 CTD SIDETRACK API No: 50-029-20424-02 01'29/06 JAETLH DRLG DRAFT CORRECTIONS SEC 2, T11N, R13E 02/14/07 CJNYPRG SET PX PLUG @ 8302 03/06/07 CJNITLH PX PLUG PULLED BP Exploration (Alaska) • 4 • . 0 I TREE - 6" CV SAFETY NOTES: ORIGINAL PARENT WILL NOT WELLHEAD - Mc 0/0Y ACTUATOR - 07t5 SHOWN ON DIAGRAM MARKER JOINT 9265" ON Proposed F -� B c ORIGINAL T "LNR GTDSIDETRACK -7O' § 9569' KB ELEV = 66 76' '2.3" RESTRICTION (HUD) PER 10120104 DIMS BF ELEV = 38.16' I KOP - 3400 2008' {--� 7' OTIS. RFB SSSV NP D 5963' Ma. Angie - 96 �! 9592' ^ , Datum f40- 9339' (w✓ w rTx4- 'r2' INSERT (SET -t985) U =3.8'3" Datum TVD - 8800' SS I13- 3:8' 2 34r I 2655' li Yt 1'100 - TOO Minimum ID = 2.377" @ 9643' P TOP OF 2 -7/8" LINER �` 7 TBG. 260.1-80 AB -1145 8256' ; °a 8256' a 7' X 4 XO 0383 bpf D - 6 276 - B256' y 51 X 4-112' BAKER SAB PKR L, - 4 00' 1 ey s,„4 ....._ _1 8302' H4 *J2'' OTIS X NP D - 3.8' 3 J r IT_,f _iF '"121 290 L•80 0 - 6 184' 830T a ■ f j _ - -- $ 330' 3 7d' BKR DEPLOY SLV ID 3 0(r i — 8 ELM TOP OF LINER ('0/21!04iJ I • 8334' - 2' OTIS xN NP MLLED - i ' ' C- 380 (861AAPIPE) r 8349' 2' HES X NIP. 0 - 2 8" I 14 ' 2 TBG '2 15x L 8C, 0 bpi 0 - 3 65,4" 836T • r ' - - - -I 8367' H4 BKR SOS TBG TA (BE}RND PIP E) I ' 1 8361' H&MD LOG DATE NOT AVALA.BLE L 01 STL 0067 bpf iD " � t 2 ' 8378' i�� *•� - -___1 3, X J D 79 9 � '.. 8378' I' _ z - - 2 " I N TOP OFCEhET�i 8740' ..1 • `' •, ; 0 ' VA t .q • 1 I COG 470 L - 80 D- 8.68 8815' •• ∎v• `:: I'WHPSTOCK x0. 1a +•' '4'04 - H 8948' CTD tti: , :•••: MILLOUT WINDOW(F -118): • pP A ��, :i: 8948' - 8956' { NO RA TAG) I'WHPSTOCK i `0 1- Jo , . H 8965' '0•: i hhh... • ' • Z • 9643' I-- 3.3!'6" X 2-7!8• ICHB:1 CUT ;'0:05:'04: H 9010' � XO. D = 2 44 ti�� I2T'8'LNR6'6 STL. L-80.D - 244' H 10875' ?:••, PERFORATION SUS/WARY I [ , • 1 , 9995' I — 2.30 CEP REF LOG S`NS MEMCNL'GRCCL ON'0,2(004 OT .* (07'3" 0T. X3'`6" LNR. 6.2X. L -80 Tail 3076 bpf C -2 -8i" 9643' j ANGLE AT TOP PERF. 85 C 9790' Note Refer to Production DB for historical pert data SIZE OFF NTERVAL Opn;Syz DATE 'RESTRICTION r2 3 tHUD DILU ' :: 2. - H 10809' 1 — , 6 9606 9636 O 08.0107 WE 6 9646 9676 O 08;01.07 10934' • NA" 2" 6 9706 - 9736 0 081 0110, 7'8' LW. 6 '64 SR . L 80 0058 bpf 10 - 2.44- H 10969' I 2' 6 9790 -9910 0 10;22 : :04 I 2 6 10100.10420 C 10122104 '058C '0920 C '0/22!04 DATE EE: 0 COb,f.lE/TS DATE REV BY CO6LENTS PRUDHOE BAY UNR 01114/80 ORIGINAL COMPLETION _6.'04,07 JRAISV SET CEP'ADFERF ft .1 `_ 'WELL. F -11B 05/21!00 CRM CT HORIZ SIDETRACK PERMIT No ( 2041940 10/23/04 NORDDC1 CT SIDETRACK API No 50-029-20424-02 ::129106 JAF'TLH DRLG DRAFT CORRECTIONS SEC2 T'1N. R13E 021'4'07 CJN'F1a G SET PX PLUG 1 8307 03.06107 CJhaTLH PX PLUG FULLED BP Exploration (Alaska) • 5 Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 15, 2007 8:58 AM To: 'Preble, Gary B (SAIC}' Cc: 'Arthur C Saltmarsh ;'Stephen F Davies' Subject: PBU F-11A (204-194) Gary, 1 am reviewing the 404 you submitted for the additional perforations on this welt. The information on the 4d4 does not include any of the new work detailed on the operations summary. The new bridge ptug at 9995 has isolated the fwo perforation sets below it and the new perforated intervafs are not listed. Would you please resubmit the 404 sheet including the new intarmatian. Catl or rr~ssage with any questians. Tom Maunder, PE AOGCC ~;;~ " +~ , :•, , \ l ~~ F ll l) ~..~ , . e.~'M.~~~~ ~~..i . . ~l `a 8/15I2007 _ 7. . .- !" ' ~ ~ STATE OF ALASKA ~~3-~Y ` ' ALAS~OIL AND GAS CONSERVATION COMM~ON ''~1~,~ F~PORT OF SUNDRY WELL OPERATIONS ao~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ q 0~ C~ ~~ Change Approved Program ~ Opera Shutdown~ ~'~ '~ ~+ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: ~~ Name: Development ~' Exploratory ~ 204-1940 ~ s 3. Address: P.O. Box 196612 Stratigraphic ~ Ser~nce ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20424-02-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 66J6 KB PBU F-11A ' 8. Property Designation: 10. Fieid/Pool(s): ADLO-028280 PRUDHOE BAY Field/ PRUDHOE OIL Pool - 11. Present Well Condition Summary: Total Depth measured 10969 ~ feet Plugs (measured) None ~~~5 true vertical 9061.96 - feet Junk (me re~) _ None ~~~,~~~~~~~ ~~~ Effective Depth measured 10934 ' feet true vertical 9057.33 ' feet ~ t~ '~~ ~~ - ~,~ _ _~_, - ~.•.~.Y,.ti.->..-,~:_,.w.@.... 4 Casing Length Size ... _ ~.~-;.. M TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 1 30 - 110 1490 470 Liner 48 3-1/2" 9.3# L-80 8330 - 8 78 7916.16 - 7961.61 10160 10530 Production 8787 9-5/8" 47# L-80 28 - 881 28 - 8375.31 6870 4760 Liner 641 7" 29# L-80 8307 - 894 7894.38 - 8501.54 8160 7020 Liner 1265 3-3/16" 62# L-80 8378 - 9643 7961.61 - 9049.28 Liner 1326 2-7/8" 6.16# L-80 9643 - 10969 9049.28 - 9061.96 13450 13890 Perforation depth: Measured depth: 9790 - 9910 1 0- 10420 105fl0 - 10920 \ --, ``~., ~jc jpv,3 4~,\_> True Vertical depth: 9056.38 - 9059.32 9052.02 - 34 49.3 - 9 72 Tubing: (size, grade, and measured depth) 7" 26# L-80 26 - 8256 4-1/2" 12.75# L-80 8256' - 8367' Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BAKER SAB 8526' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Productio or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 890 35698 49 0 1614 Subsequent to operation: 522 25701 51 0 188 14. Attachments: 15. Well Class after ~roposed work~ Copies of Logs and Surveys Run Exploratory ~ Development , Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~,, ^''"~ " Phone 564-4944 Date 8/7 007 ~~` ~ ~'1 qG~, ~`j~ o O Form 10-404cRevised 04/2006 Submit Ori inal Only ~RIGONAL ~ ~ DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/30/2007'; CTU #8, Set CIBP / Add Perf; MIRU unit. ... Cont' on WSR 07/31/07 7/31/2007 CTU #8. Set CIBP / Add Perf; ... Cont' from WSR 07/30/07 ... MU and RIH with i SLB gamma ray / ccl and 2.3" OD JSN. Drift liner down to 10100' ctmd. Log ' interval 9550'-10100' and flag pipe at 9550' ctmd. POOH. Confirmed good data. ', (Tie into SLB PPROF 03f22107). MU and RIH BKR 2-7/8" CIBP. Correct depth at 'flag and set CIBP at 9995' elmd. POOH. MU and RIH with first set of perf guns; 30' of 2" HSD PJ 2006 HMX, 6 spf. Tag CIBP and correct depth. Perforate ' interval 9710'-9740' elmd. POOH. All shots fired. Standby unit due to no night 'crew available because of flight cancellations. ... ConY on WSR 08/01/07 ... ~. .__....... ..........._.. .___....... ..~_.. .. .... . _.. 8/1/2007 CTU #8, Set CIBP / Add Perf; ... ConY from WSR 07/31/07 ... MU and RIH with second set of guns; 30' of 2" HSD PJ 2006 HMX, 6 spf. Tag CIBP and correct depth. Perforate interval 9650'-9680' elmd. POOH. All shots fired. MU and RIH with third set of guns; 30' of 2" HSD PJ 2006 HMX, 6 spf. Tag CIBP and correct ' depth. Perforate interval 9610'-9640' elmd. POOH. All shots fired. MU 2.5" JSN. ' Blow down coil with N2 and RIH pumping N2 at 700 scfpm taking returns to LP. RIH parking coil at various intervals and letting fluid unload. ... ConY on WSR 08/02/07 ... 8/2/2007 CTU #8, Set CIBP / Add Perf; ... Cont' from WSR 08/01/07 ... Cont' unloading well at 7800' ctmd. Verify with PCC that well is flowing at low GOR and 0% WC. Cut N2 and POOH. Monitor well at surface and verify well is flowing on its own. Turn well over to pad operator. RDMO. '`** Job Complete *"" FLUIDS PUMPED BBLS 76 1% KCL 70 TOTAL • • E y.~ arS.~~ ~~ MICROFILMED 03/01/2008 DO NOT PLACE ~,~ J~~_ ;fF- ~~ ~~~ ANY NEW MATERIAL UNDER THIS PAGE F:1L,aserFichelCvrPgs_Inserts~Microfilm Marker.doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well F-48 G-19A NGI-13 MPE-30A F-11B W-12A 11-27 02-22A 01-16 01-14 L5-05 D-21 14-15 D-18A 14-0SA 1-23/0-15 S-03 1-09A1L-21 P2-19A OWDW-NW K-01 11-32 3-25B/L-27 Job# 11846815 11890315 11890313 11855817 11649954 11418301 11637127 11216214 11630486 11801086 11767129 11626119 11221550 11695074 11813055 11846802 11223120 11849930 11649963 11211370 11695073 11630498 11630490 S~NED OCT S 1 2007 Lo!! Description USIT 1'1/- (): J., USIT 1'1'1- t()' ~ USIT 1 YTf' I ~... -rH 1 USIT :;)01 - 0 ( MCNL ;) ~I- 10'-(. IQ::> 1:..) MCNL ) 'ì~ -I"X g .. tÇ~':1L( RST j/z( 6,- Il.../?í ~ I ·"....s-~(." MCNL ;ON) _ ("",\ 1t ...... RST 1~"ír-t)O$r"'"' ¿;;-!;-j.-:;r RST ..-¡ ~ _ "''''J. ~ tt I ~-~ +'-i MCNL /7r "":} -t)<r,q ti:' , ""'~ 0 RST I '?r;::) - I'\~~ ... '~>t' RST I"';{ I - ó"ð'-/ ." ,55$(;:) RST :::)/..,/- In ~ 1t- ,~~ ?5 RST I D,:) - ("\C) / .. 1 ~ l5 RST d "-.1' _ tQ£.1 i.....J;)~ 'It I<=: '5155 RST /"lel - 10", 1!t t""<\~'-( RST I A q.. - ('If:) q 11: I S-S- ... - '5 MCNL ~1()+- Aid ~ 15""5~ d RST I J,." ,-" -VJ^ $:l/5.<;-=+/ RST 1~3- 1;:)/ ..../001-6 RST 1D¡4- I~ *"1~S("''9 RST ~'\~ - ^~ I ..., :Ç.,S"ï., 'j{ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Date 10/12/07 09/30/07 09/30/07 10/01/07 03/22/07 09/10/06 06/05/07 10/02/06 06/28/07 07/07/07 06/17/07 09/12/07 03/07/06 08/28/07 06/11/07 08/11/07 06/13/06 08/04/07 04/22/07 02/28/06 08/27/07 09/03/07 07/26/07 NO. 4459 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milnl! Pt.,Lisburm BL Color 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Aoch_. AK 9950~2838L ATTN: Beth ~ Received by: G ". 1 0/23/07 . . ",ø: I STATE OF ALASKA . T~P¡' ALA A Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull TubingD Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 66.76 KB / 8. Property Designation: ADLO-028280 11. Present Well Condition Summary: Total Depth measured 10969 / feet true vertical 9061.96 feet Effective Depth measured 10934 feet true vertical 9057.33 , feet Casing Length Size Conductor 80 20" 91.5# H-40 Liner 48 3-1/2" 9.3# L-80 Production 8787 9-5/8" 47# L-80 Liner 641 7" 29# L -80 Liner 1265 3-3/16" 6.2# L-80 Liner 1326 2-7/8" 6.16# L-80 Perforation depth: Measured depth: 9710 - 9740- True Vertical depth: 9049 - 9051 Measured depth: 9790 - 9910 True Vertical depth: 9056 - 9059 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 890 522 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic RECEIVED AUG 2 2 2007 Stimulate 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: , sion Exploratory Service 9. Well Name and Number: 204-1 940 ' 6. API Number: 50-029-20424-02-00 / PBU F-11B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) 9995' CIBP SET Junk (measured) None SC.P\NNED AUG 2 82007 MD 30 - 110 8330 - 8378 28 - 8815 8307 8948 8378 - 9643 9643 - 10969 9610 - 9640 - 9048 - 9049 9650 - 9680 - 9049 - 9049 7" 26# TVD 30 - 110 7916.16 - 7961.61 28 - 8375.31 7894.38 - 8501.54 7961.61 - 9049.28 9049.28 - 9061.96 9606 - 9636 9047 - 9049 [10580 -10920 C 9049 - 9056 C L-80 9-5/8" X4-1/2" BAKER SAB PKR o o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 35698 49 0 25701 51 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P' Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Signature Burst Collapse 1490 470 10160 10530 6870 4760 8160 7020 13450 13890 9646 - 9676 9706 - 9736 9049 - 9049 9049 -9051 10100 - 10420 C "}-? ~c;.CL "Q::~ S 9052 - 9051 C b~ \0\0.,;) \'> ~ <;C\ S' 26 - 8256 1 (') rYV\ {4Y ~J ~ 8256' o o o RBDMS 8Ft AUG 2 7 Z007 Tubing pressure 1614 188 Service WINJ WDSPL Title Data Management Engineer Phone 564-4944 Date 8/17/2007 . . F-IIB DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/30/2007 CTU #8, Set CIBP / Add Perf; MIRU unit. ... Cant' on WSR 07/31/07 ... 7/31/2007 #8. Set CIBP / Add Perf; ... Cant' from WSR 07/30/07... MU and RIH with SLB gamma ray / ccl and 2.3" OD JSN. Drift liner down to 10100' ctmd. Log interval 9550' -10100' and flag pipe at 9550' ctmd. POOH. Confirmed good data. (Tie into SLB PPROF 03/22/07). MU and RIH BKR 2-7/8" CIBP. Correct depth at flag and POOH. MU and RIH with first set of perf guns; 30' of 2" Tag CIBP and correct depth. Perforate interval 9710'-9740' - elmd. POOH. All shots fired. Standby unit due to no night crew available because of cancellations.... Cant' on WSR 08/01/07 ... 8/1/2007 #8, CIBP / Add Perf; ... Cant' from 07/31/07... MU and RIH with second set of guns; 30' of 2" HSD PJ 2006 HMX, 6 spf. Tag CIBP and correct depth. PArfor;:¡tA interval 9650'-9680' elmd. POOH. All shots fired. MU and RIH with third set of guns; 30' of 2" HSD PJ 2006 HMX, 6 spf. Tag CIBP and correct depth. Perforate interval 9610'-9640' elmd. POOH. All shots fired. MU 2.5" JSN. Blow down coil with N2 and RIH pumping N2 at 700 scfpm taking returns to LP. RIH parking coil at various intervals and letting fluid unload. ... Cant' on WSR 08/02/07 ... 8/2/2007 CTU #8, Set CIBP / Add Perf; ... Cant' from WSR 08/01/07 ... Cont' unloading well at 7800' ctmd. Verify with PCC that well is flowing at low GOR and 0% WC. Cut N2 and POOH. Monitor well at surface and verify well is flowing on its own. Turn well over to pad operator. RDMO. *** Job Complete *** FLUIDS PUMPED BBLS I 76 .1% KCL 76 TOTAL ;t :1 Na t/ À~~ '-P DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041940 Well NamelNo. PRUDHOE BAY UNIT F-11B Operator BP EXPLORATION (ALASKA) INC 5p uJ I.,C aJ)~ Co API No. 50-029-20424-02-00 MD 10969 V"" TVD 9062 /Completion Date 10/23/2004 / Completion Status 1-01l Current Status 1-01l UIC N REQUIRED INFORMATION Mud log No DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, MGR / eel/ CNl Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc Name Directional Survey Samples No Directional Survey Yes (data taken from logs Portion of Master Well Data Maint . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 8900 10969 Open 11/9/2004 IIFR .. 8900 10969 Open 11/9/2004 IIFR 2 Blu 8137 10721 Case 11/24/2004 COMPENSATED NEUTRON/MEM GR/CCUNEUTRON I I 8126 10723 Case 11/24/2004 COMPENSATED ! NEUTRON/MEM GR/CCLlNEUTRON I 8921 10929 Open 3/11/2005 GRlEWR4/ROP I 8921 10929 Open 3/11/2005 GR/EWR4/ROP I ~ Sample Set Sent Received Number Comments . Directional Survey Neutron Vc Pd, ~ I J g rJ Neutron 13088 Induction/Resistivity 13088 LIS Verification Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? ~ Chips Received? .~ Daily History Received? eDN (j)N Formation Tops Analysis Received? ~ Comments: Permitto Drill 2041940 MD 10969 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Well Name/No. PRUDHOE BAY UNIT F-11B Operator BP EXPLORATION (ALASKA) INC TVD 9062 Completion Date 10/23/2004 Completion Status 1-01L Current Status 1-01L Date: API No. 50-029-20424-02-00 UIC N . . 11/16/04 Schlumberger NO. 3256 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . WII J b# L D ·f D t BI r Color p. t CD .~ e 0 OQ escrlPlIon ae ue me rm s ~O ~ E-39A 10715430 MEMORY IPROF & WARMBACK 09/13/04 1 "':¡tf-o} .. D.S. 15-25A 10715428 MEMORY PPROF & IPROF 09/11/04 1 c:Ø'q; " C-25A 10928596 MEMORY LDL 09/27/04 1 C-25A 10928598 MEMORY LDLIIPROF 10/04/08 1 \ ., ..-. L2-14B 10670029 PRODUCTION PROFILE 08/20/04 1 Zl;.'-~"" F-11 B 10928600 MCNL 10/20/04 1 1 IP;¡ ~Ç? ð't_".a.t ~'.~ L2-07A 10861911 MCNL 05/31/04 1 1 -07A 10715409 MCNL 06/07/04 1 1 ~w/ F-28A 10670015 MCNL OS/22/04 1 1 L3-05 10724368 RST-SIGMA 04/02/04 1 1 L3-05 10662981 RST-SIGMA 01/08/04 1 1 ~/~ L3-05 10866588 RST-SIGMA 09/03/04 1 1 " \. L3-05 10672320 RST-SIGMA 09/28/03 1 1 ¡?£. - /5 if. L3-02 10560313 RST-SIGMA 10/16/03 1 1 (ø()" < OWDW-NW 10563037 RST-SIGMA & BORAX 03/29/03 1 1 OWDW-NW 10672361 RST -BORAX 03/28/04 1 1 ;Z; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, 99503-2838 A TTN: Bet Date Delivered: /(-:2c{- otf ",../' . .. .. STATE OF ALASKA I ALASKA~L AND GAS CONSERVATION COMM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ~ Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/23/2004 204-194 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/15/2004 50- 029-20424-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/19/2004 PBU F-11B 2208' SNL, 2869' WEL, SEC. 02, T11N, R13E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1057' SNL, 938' WEL, SEC. 02, T11N, R13E, UM 66.76' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1934' SNL, 1812' WEL, SEC. 02, T11 N, R13E, UM 10934 + 9057 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 651958 y- 5974592 Zone- ASP4 10969 + 9062 Ft ADL 028280 TPI: x- 653865 y- 5975782 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 653010 y- 5974888 Zone- ASP4 (Nipple) 2008' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost ~Yes ONo NIA MSL 1900' (Approx.) 21. Logs Run: MWD GR / EWR, MGR / CCL / CNL 2. CASING, LINER AND CEMENTING RECORD CA$ING ::>ETnNG OEPTHMD ::>ml/llGPEPTH TVD HQi..!; . ;utÐ~ð SIZE Wr. PER FT. GRADE TOP BOTTOM TOp BOTTOM SIZE 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 7.5 cu yds Concrete 13-3/8" 72# L-80 Surface 2655' Surface 2655' 17-1/2" 3153 cu ft Arcticset " 9-5/8" 47# L-80 Surface 8815' Surface 8375' 12-1/4" 1193 cu ft Class 'G', 130 cu ft AS I 7" 29# L-80 8307' 8948' 7894' 8502' 8-1/2" 401 cu ft Class 'G' 3-1/2" x 3-3/16" x 2-7/6" 8.81# / 6.2# / 6.16# L-80 8330' 10969' 7916' 9062' 4-1/8" x 3-3/4" ;>30 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. T Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 7", 26#, L-80 8256' 8256' MD TVD MD TVD 4-1/2", 12.75#, L-80 8256' - 8367' 9790' - 9910' 9056' " 9059' 25. ACID,....· CEM~~" C"'I.,r=r=.,.i:: . r=Tr- ....... 10100' - 10420' 9052'" 9051' ... 10580' " 10920' 9049' - 9056' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protected w/ MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 30,2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oil-Bel GAs-McF WATER-Bel CHOKE SIZE I GAS-Oil RATIO 10/31/2004 4 TEST PERIOD ... 171 197 11 960 1,151 Flow Tubing Casing Pressure CALCULATED ... Oil -Bel GAs-McF WATER-Bel Oil GRAVITY-API (CORR) Press. 241 420 24-HoUR RATE 1,028 1,184 66 25.3 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SUbm~~Jf,oooe, state "oooe" GO¡'i!¡-JLè'::; ¡UN ~ None . . ~ 4 ì RBDMS 8FL NOV 1 2 ZOO4 /J' 3 ~v ORIGINAL J .~I Gr/ t'''''Oj'''I:...,,,,,~....,..l Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS NAME MD Shublik 8978' Sadlerochit 9057' Top CGL 9197' Base CGL 9265' 25N 9334' 22N 9408' 21N 9464 Zone 1B 114N 9545' 14P 9547' 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8530' None 8603' 8733' 8797' 8862' 8931' 8981' 9032' 9032' 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 Technical Assistant Date I (-ocr..O PBU F-11B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Mary Endacott, 564-4388 204-194 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/12/2004 Rig Release: 10/23/2004 Rig Number: N1 Spud Date: 12/27/1979 End: 10/23/2004 1 0/12/2004 01 :00 - 02:30 1.50 MOB P PRE PJSM on moving rig off well Move Nordic1 off of C-25b 02:30 - 04:30 2.00 MOB P PRE Scope derrick down make ready to mob to F-11 04:30 - 08:30 4.00 MOB P PRE Trave C-Pad to F-Pad 5.1 miles 08:30 - 10:20 1.83 MOB P PRE On F-Pad at 0830 hrs, Tool Service leveling F-11 area, Scope up derrick, NC Machinery Mechanic is working on Generator 10:20 - 10:30 0.17 MOB P PRE PJSM on moving over well. 10:30 -11:00 0.50 MOB P PRE Install SV platform, remove tree cap and move over well 11 :00 - 15:00 4.00 RIGU P PRE Rig Accepted at 1100 hrs 10/12/2004 Removed diesel from tree cap. Remove tree cap bolts and installing BOP's 15:00 - 20:00 5.00 BOPSU P PRE PT BOP's as per APD # 204-194 to 3500 psi/ 300 psi. John Crisp AOGCC inspector waved witnessing BOP Test IA = 32 psi, OA 138 psi 20:00 - 21:15 1.25 BOPSU P PRE Fill coil, circulate dart, Dart on seat at 56.4 bbls. press test inner reel valve. Open well, well is dead. Re-grease leaking Master valve. 21 :15 - 21 :30 0.25 PULL P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation to M/U Baker fishing BHA. 21 :30 - 23:00 1.50 PULL P DECOMP M/U Baker fishing BHA #1 with 4" GS Spear, Hyd Disc, Jars, 2 x 3-1/8" drill collars, Accelerator, Swivel, Check valves and eTC. OAL = 80.8 ft. 23:00 - 00:00 1.00 PULL P DECOMP RIH with liner fishing BHA. Circ at min. rate. 10/13/2004 00:00 - 01 :00 1.00 PULL P DECOMP RIH with liner fishing BHA. Stop at 8000 ft. 01 :00 - 01 :30 0.50 PULL P DECOMP Continue to circulate 2# Biozan and displace diesel out of well. 2.2 bpm, 1660 psi. Divert diesel to tiger tank. 01 :30 - 01 :45 0.25 PULL P DECOMP Stop pump, Up wt = 30.5 Kat 8250', Dwn wt. = 19.5K. RIH and tag fish at 8311' CTD, correct to 8312' BKB. Set down 3000 #. Pick up clean with liner, no overpull, 37.5K up wt. Flag coil at 8200' EOP. 01:45 - 04:10 2.42 PULL P DECOMP POH with 2-7/8" liner. Circ. at 0.5 bpm, 520 psi, 35.5K up wt at 8100'. 33.5K at 7500'. No overpull with liner for first 1000 ft off bottom. POH clean to surface. 3500 # at surface. 04:10 - 04:20 0.17 PULL P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out fishing BHA and 2-7/8" liner. 04:20 - 06:00 1.67 PULL P DECOMP Layout Baker fishing BHA, 3.70" deployment sleeve and 2-7/8" liner. LD BOT deployment sleeve with 2-7/8" PJ L = 8.34 ft 23 jts 2-7/8" Tubing len = 680.06.72 ft 1- 15.71 ft cut off2-7/8" jt Found two chem cuts (one partial) where expected only one. Total Length = 704.11ft Top 06:00 - 06:20 0.33 CLEAN P WEXIT PJSM on UR BHA Handling 06:20 - 07:00 0.67 CLEAN P WEXIT PU UR BHA w/2 jts 2-3/8" tubing 07:00 - 08:45 1.75 CLEAN P WEXIT RIH. Set down in SSSV at 2008 ft. PU and RIH to flag. No correction at flag 08:45 - 13:40 4.92 CLEAN P WEXIT U/R using UR @ 2.00 bpm 1420 psi off btm. Didn't tag anything from 8500 ft to 8990 ft. "Clean hole" PUH to 8900 ft Printed: 11/1/2004 1:51:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Spud Date: 12/27/1979 End: 10/23/2004 10/12/2004 10/23/2004 N1 1 0/13/2004 13:40 - 14:10 0.50 CLEAN P WEXIT 14:10- 14:20 0.17 CLEAN P WEXIT 14:20 - 15:15 0.92 CLEAN P WEXIT 15:15 - 15:40 0.42 CLEAN P WEXIT 15:40 - 16:00 0.33 CLEAN P WEXIT 16:00 - 17:15 1.25 CLEAN P WEXIT 17:15-18:40 1.42 CLEAN P WEXIT 18:40 - 19:30 0.83 CLEAN P WEXIT 19:30 - 20:15 0.75 CLEAN P WEXIT 20:15 - 21:00 0.75 WHIP P WEXIT 21 :00 - 22:40 1.67 WHIP P WEXIT 22:40 - 23:30 0.83 WHIP P WEXIT 23:30 - 00:00 0.50 WHIP P WEXIT 10/14/2004 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 02:00 1.50 STWHIP P WEXIT 02:00 - 04:30 2.50 STWHIP P WEXIT 04:30 - 06:00 1.50 STWHIP P WEXIT 06:00 - 09:30 3.50 STWHIP P WEXIT 09:30 - 10:50 1.33 STWHIP P WEXIT 10:50 - 11 :00 0.17 STWHIP N DPRB WEXIT 11 :00 - 12:05 1.08 STWHIP N DPRB WEXIT Reaming WS area again from 8900 ft to 8990 ft PUH to drop 3/4" ball to open CS. Displace to CS POOH. Qp = 3.2 bpm OOH, LD UR BHA SAFETY METTING. RU PDS and SLB Eline RU Eline to run PDS Memory Caliper. Wait on Power Supply for PDS Computer. Make up tools, check PDS tools. Time = 1 :29 hh:mm RIH, Log Memory PDS Caliper log in 7", 29# liner POH with PDS caliper. Layout caliper and download data. PDS Caliper showed no cement in 7" liner with a 6.18" ID. Good to go for whipstock. Prepare SWS E-Line running / setting tools with one EC weight bar. M/U Baker Gen II, 4-1/2" x 7",29# Whipstock set for high side tool face. No RA tag as per program. RIH with Baker Whipstock on SWS E-Line. Tied-in with CBL GR/CCL of 01/12/80. Logged up and positioned top of whipstock at 8965' as per program. Whipstock is set with 9 deg LOHS tool face with top of whipstock at 8965'. Good indication of tool setting. Stacked wt on whipstock and logged off. Whipstock is set OK. POH with SWS running tools. Layout SWS tools. Rig down SWS E-Line unit. M/U Baker 3.80" window milling BHA with 3.80" HC diamond window mill and string reamer, circ sub, hyd disc, 2 jts PH6, check valves and CTC. OAL = 81.77'. RIH with window milling BHA #3. CÎrc at 0.6 bpm. Tag whipstock pinch point at correct depth of 8970'. Flag coil at 8970'. Milling 3.80" window thru 7", 29# L-80 liner. 2.6 bpm, 2050-2200 psi, 3-4K WOB, slow milling, stacking wt with only 100 psi motor work, 2 stalls, Milled to 8972'. Milling window, 2.6 bpm, 2050-2200 psi, 4-5K WOB, stacking wt, slow ROP. Had very large stall at 8972.5 ft. Window not milling normal. Start stacking at 8971'. Milling window. Qp = 2.6/2.6 CTP 2050/2142 psi. WOB 0 to 4001bm. The top of the window may be in question due to the orginal tag. Window milling acts normal starting at 8974 ft. CT stacking up in 7" Milling window. Qp = 2.6/2.7 CTP 2050/2380 psi. WOB 0 to 18001bm. CT is stacking up in the 7" liner. Motor work, wt coming off slow, center section of mill could be damaged. PU to 8960 ft, RIH, tagged at 8970 ft 5 time with motor work. Not able to get past top of whipstock. Top of whipstock must be damaged. POOH to set another WS and cement in place Printed: 11/1/2004 1:51:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Spud Date: 12/27/1979 End: 10/23/2004 10/12/2004 1 0/23/2004 N1 10/14/2004 12:05 - 13:35 1.50 STWHIP N DPRB WEXIT 13:35 - 16:50 3.25 STWHIP N DPRB WEXIT 16:50 - 18:30 1.67 STWHIP N DPRB WEXIT 18:30 - 19:30 1.00 STWHIP N DPRB WEXIT 19:30 - 20:00 0.50 STWHIP N DPRB WEXIT 20:00 - 20:15 0.25 STWHIP N DPRB WEXIT 20:15-21:25 1.17 STWHIP N DPRB WEXIT 21 :25 - 22:00 0.58 STWHIP N DPRB WEXIT 22:00 - 22:15 0.25 STWHIP N DPRB WEXIT 22:15 - 22:40 0.42 STWHIP N DPRB WEXIT 22:40 - 23:30 0.83 STWHIP N DPRB WEXIT 23:30 - 00:00 0.50 STWHIP N DPRB WEXIT 1 0/15/2004 00:00 - 02:00 2.00 STWHIP N DPRB WEXIT 02:00 - 02:15 0.25 STWHIP N DPRB WEXIT 02:15 - 02:30 0.25 STWHIP N DPRB WEXIT 02:30 - 02:50 0.33 STWHIP N DPRB WEXIT 02:50 - 05:00 2.17 STWHIP N DPRB WEXIT 05:00 - 06:00 1.00 STWHIP N DPRB WEXIT 06:00 - 11 :30 5.50 STWHIP P WEXIT OOH LD Milling BHA, Mill cored with one jet welfded shut PT Casing to 400 psi, 20 minutes P = 300 psi RU Eline to reset WS PU WS orient to Pos Tool and confirmed. CCL to TOW 15.37 ft RIH and tie-in with GR. Position top of whipstock at 8943', tool face at 3 deg left of high side. Set whipstock, good indication of set at 42 seconds, saw 400# wt loss, log off. POH with SWS E-Line tools, recover 100% of BHA, all looked OK. R/D SWS E-Line equipment. M/U cementing nozzle and 6' stinger. OAL = 8'. RIH with cementing BHA. Held PJSM while RIH. Reviewed procedure, hazards and mitigation for pumping cement. Tagged Whipstock at 8958' with 3K WOB. Whipstock is inplace. Correct depth to 8948' CTD. Pick up 10 ft and flag coil at 8938'. Press test cement line. Circ. 50 bbl fresh water to jet whipstock area. Stage 15.8 PPB, G Cement, Pump 7.5 bbls cement. Stage 10 bbl fresh water behind cement with cementers. Displace with 2# Biozan using rig pumps. Tag whipstock and pick up 1 ft. Jet whipstock with fresh water prior to cement reaching nozzle. Jet with 3.4 bpm, 2900 psi, Reciprocate coil from 8947-8920'. RIH and lay in cement from 8945 ft up to WCTOC of 8740'. Lay in at 1 bpm, pull at 27 fpm. Pull to safety at 8500'. Cement in place at 2230 hrs. WOC to gravity swap across whipstock. 3.8 bbls capacity below whipstock to swap with 7.5 bbls cement above whipstock. Dress off cement to 8928'. Circ out cement contaminate to surface with 2# Biozan at 3.1 bpm. POH with cementing nozzle while chasing contaminated cement to surface. Discard all contaminated returns. 3.1 bpm. Jet stack and all surface lines. SAFETY MEETING. Review procedure, hazards and mitigation for M/U window milling BHA. M/U 3.80" He diamond window mill and 3.80" HC diamond string reamer, motor, circ sub, hyd disc, 2 jts PH6, check valves and CTC. OAL = 81.8 ft. RIH with 3.80" window milling BHA. SWS UCA cement sample was at 600 psi at 5 hours. Cement in place for 6 hrs at 0430 hrs. Mill down to 8942' and set down at pinch point. correct depth to 8948'. Mill 3.8" window, 2.6 bpm, 1500 psi free spin, 1500-2000 PSI, 2K WOB. Milled to 8949'. Mill 3.80" window. Qp = 2.57/2.65 bpm, CTP = 1500/1715 psi, WOB 2-3klb Stall 8952.4 ft, PU and restart Milling window. Exited casing at approximately 8956 ft, Drilled 10ft formation to 8966 ft Printed: 11/1/2004 1:51:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/12/2004 10/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 10/15/2004 11 :30 - 13: 1 0 1.67 STWHIP P WEXIT Back reaming window to 8944 ft. Reamed back to 8966.5 ft, Backed reamed and started mud swap with 50 bbl behind CT, I dry tagged at 8966 ft. Clean window 13:10 - 15:00 1.83 STWHIP P WEXIT POOH chasing new Flo-Pro to surface 15:00 - 15:30 0.50 STWHIP P WEXIT LD Milling BHA. Window Mill 3.8"; String Mill 3.78" No-Go. Core point, good looking mill 15:30 - 17:15 1.75 DRILL P PROD1 Cut CT, install SLB CTC, pull tested to 40k Ibf and PT to 4k psi. PU DS 100 BC bit, 1.04 deg motor and Sperry MWD tools. OAL = 65.22 ft 17:15 - 18:55 1.67 DRILL P PROD1 RIH and shallow hole tested at 3400 ft, OK. RIH to 8850'. 18:55 -19:10 0.25 DRILL P PROD1 Orient TF to 20L. 19:10 - 21:00 1.83 DRILL P PROD1 Ran thru window clean. Tagged TD at 8972'. Corrected depth to 8966'. Drilled Sag River and Shublik, 2.6/2.6 bpm, 2800 - 3800 psi, 36L, 21 deg incl, Drilled to 8990'. 21 :00 - 23:00 2.00 DRILL P PROD1 Drilling Shublik, 2.6/2.6 bpm, 2800-3800 psi, 20L, 22 deg incl, 10-20 fph, Drilled to 9012'. 23:00 - 23:15 0.25 DRILL P PROD1 Orient TF to 100L. 23:15 - 00:00 0.75 DRILL P PROD1 Drilling Shublik, 2.6/2.6 bpm, 2800-3800 psi, 120L, 23 deg incl, 10-20 fph, Drilled to 9024'. 10/16/2004 00:00 - 02:30 2.50 DRILL P PROD1 Drilled Shublik, 2.6/2.6 bpm, 2700 - 3800 psi, 100L, 21 deg incl, 15 fph, Drilled to 9062'. 02:30 - 03:45 1.25 DRILL P PROD1 Drilled Shublik, 2.6/2.6 bpm, 2700 - 3800 psi, 90L, 21 deg incl, 20 fph, Drilled to 9090'. 03:45 - 04:30 0.75 DRILL P PROD1 Drilled 24, 2.6/2.6 bpm, 2700· 3800 psi, 90L, 21 deg incl, 30 fph, Drilled to 9110'. 04:30 - 04:45 0.25 DRILL P PROD1 Wiper trip to window. Clean hole. 04:45 - 05:15 0.50 DRILL P PROD1 Log GR tie-in. Added 3 ft to CTD. 05:15 - 05:25 0.17 DRILL P PROD1 RIH clean to TD. 05:25 - 06:00 0.58 DRILL P PROD1 Drilled 24, 2.6/2.6 bpm, 2700 - 3800 psi, 90L, 21 deg incl, 30 fph, Drilled to 9135'. 06:00 - 08:47 2.78 DRILL P PROD1 Drilling TF @ 111 L in 2-4 Qp = 2.74/2.87 bpm, CTP = 2600/ 2875 psi. Vol p = 298 bbl. 08:47 - 10:11 1.40 DRILL P PROD1 Drilling TF @ 111 L to 86L in 2-3 Qp = 2.74/2.87 bpm, CTP = 2600/2875 psi. Vol p = 298 bbl. Top 23 at approximately 9197 ft. Drilled to 9207 ft, unable to get DLS/BR to make turn. 10: 11 - 11 :35 1.40 DRILL P PROD1 POOH, 11 :35 - 12:00 0.42 DRILL P PROD1 BHA handling. DS 100 at 1-1, PU HTC RWD RR bit adjusted motor to 1 .37 deg 12:00 - 13:00 1.00 DRILL P PROD1 Weld up 6 CT reel spokes 13:00 - 15:25 2.42 DRILL P PROD1 RIH, shallow hole test at 3400 ft. Tagged window at 8957 ft. Orient TF to HS Went through 15:25 - 15:30 0.08 DRILL P PROD1 Tagged at 9207 ft Orient TF to 90L 15:30 - 18:00 2.50 DRILL P PROD1 Drilling TF @ 83L in 2-3 Qp = 2.74/2.87 bpm, CTP = 2600 I 2875 psi. Vol p = 294 bbl ROP = 5 to 30 ftIhr Drilled to 9226'. 18:00 - 20:00 2.00 DRILL P PROD1 Drilling 23. slow, hard drilling, 2.6/2.6 bpm, 2750 - 3600 psi, 100L, 20 deg incl, 10 fph. Drilled to 9244'. Printed: 11/1/2004 1:51:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/12/2004 1 0/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 10/16/2004 20:00 - 21 :30 1.50 DRILL P PROD1 Drilling Z3. slow, hard drilling, 2.6/2.6 bpm, 2750 - 3600 psi, 90L, 20 deg incl, 2 fph. Drilled to 9247'. 21 :30 - 23:00 1.50 DRILL P PROD1 POH for new bit. 23:00 - 23:30 0.50 DRILL P PROD1 C/O Bit, bit #4 was trashed [8,8,3]. Run used HC bi-center bit #5. Press test CTC, OK. Check motor, OK. 23:30 - 00:00 0.50 DRILL P PROD1 RIH with MWD BHA #7, with 1.37 deg motor and 4.125" HC bicenter bit #5. 10/17/2004 00:00 - 01 :20 1.33 DRILL P PROD1 RIH with MWD BHA #7 with 1.37 motor and USED HC bi-center bit #5 01 :20 - 01 :35 0.25 DRILL P PROD1 Orient TF to 90L. Tag TD at 9248' and correct to 9246'. 01 :35 - 03:30 1.92 DRILL P PROD1 Drilled Zone 2, 2.7/2.7 bpm, 2900 - 3600 psi, 90L, 21 deg incl, 60 fph, Drilled to 9330'. 03:30 - 04:40 1.17 DRILL P PROD1 Drilled Zone 2, 2.7/2.7 bpm, 2900 - 3600 psi, 80L, 21 deg incl, 60 fph, Drilled to 9390'. 04:40 - 05:00 0.33 DRILL P PROD1 Drilled Zone 2, 2.7/2.7 bpm, 2900 - 3600 psi, 80L, 22 deg incl, 80 fph, Drilled to 9420'. 05:00 - 06:45 1.75 DRILL P PROD1 POH for build BHA and Resistivity tool. Clean hole. Flag CT at 8800' EOP. 06:45 - 07:45 1.00 DRILL P PROD1 CO bit, set motor to 3.07 deg, PU Sperry Res Tool 07:45 - 08:30 0.75 DRILL P PROD1 Upload sofware to res tool 08:30 - 08:45 0.25 DRILL P PROD1 RIG EVACUATION DRILL. 2 min and all accounted for. Review Drill at TL Shack 08:45 - 10:15 1.50 DRILL P PROD1 RIH with 3.07 deg motor Corrected -5 ft at 8800 ft EOP pipe flag. Check Orientation above WS. TF at 10R Didn't see window 10:15 - 10:30 0.25 DRILL P PROD1 Tie-in coming up from 9006 ft. TF at 2L Correct -4 ft 10:30 - 11 :00 0.50 DRILL P PROD1 RIH and tagged at 9420 ft 11:00 -11:05 0.08 DRILL P PROD1 Orient TF to 70L. 11:05-12:00 0.92 DRILL P PROD1 Drilling 78L TF Qp = 2.60/2.71 bpm CTP = 2850/ 3000 psi Volp= 276 bbl 12:00-12:10 0.17 DRILL P PROD1 Orient TF to 10L 12:10 -13:15 1.08 DRILL P PROD1 Drilling 7L TF Qp = 2.60 /2.71 bpm CTP = 2850/ 3000 psi Volp= 276 bbl ROP= 20 to 65 fph 13:15 - 13:45 0.50 DRILL P PROD1 Orient TF around, 3.07 deg bend motor is giving 40 deg DL 13:45 - 15:00 1.25 DRILL P PROD1 Drilling 100R to 13L TF Qp = 2.60 / 2.71 bpm CTP = 2850/ 2980 psi Volp= 271 bbl ROP=63 fph Sperry tool SD due to high DL 40 dge/100 ft. PUH and restarted tools. Tool flipped to R-side. Will drill on L-side Last survey at 37 dge DL 15:00 - 15:35 0.58 DRILL P PROD1 PUH mad pass 9540 ft to 8875 ft 15:35 - 16:45 1.17 DRILL P PROD1 POOH. 16:45 - 18:20 1.58 DRILL P PROD1 Changed out bit, set motor bend to 1.37 deg and downloaded Res Tool. Printed: 11/1/2004 1 :51 :43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/12/2004 1 0/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 10/17/2004 18:20 - 20:15 1.92 DRILL P PROD1 RIH with Lateral RES MWD BHA #9, with HC Bi-center bit #7 and 1.37 deg motor. SHT, OK. RIH. 20:15 - 20:25 0.17 DRILL P PROD1 Orient TF to 20L to run thru window. 20:25 - 20:45 0.33 DRILL P PROD1 RIH clean to TD. 20:45 - 20:55 0.17 DRILL P PROD1 Orient to 20L. 20:55 - 21 :45 0.83 DRILL P PROD1 Tag TD at 9577'. Correct depth to 9570' [-7' CTD]. Drilling, 2.6 I 2.6 bpm, 3100-4000 psi, 37L, 81 deg incl, Drilled to 9620'. 21:45 - 22:00 0.25 DRILL P PROD1 Orient TF. Circulating pressure went from 3100 psi to 4100 psi after 12 clicks. Circ. press = 3530 psi at 1.9 bpm. Pressure to high to drill with. 22:00 - 23:30 1.50 DRILL N DFAL PROD1 POH to check BHA. Hole was clean. 23:30 - 00:00 0.50 DRILL N DFAL PROD1 Check bit, new condition, ports were clear, C/O motor and adjust to 1.04 deg bend. Check top of Sperry tools for plugging, OK. Check orienter, OK. C/O MHA. We did find rubber from motor on shaker, most likely motor is chunked. BHI will check motor for failure. 1 0/18/2004 00:00 - 00:15 0.25 DRILL N DFAL PROD1 Change out MHA. M/U CTC. 00:15 - 01:45 1.50 DRILL N DFAL PROD1 RIH with RES MWD BHA #10 with 1.04 deg motor and He Bi-center bit #8. SHT OK, RIH. 01 :45 - 02:00 0.25 DRILL N DFAL PROD1 RIH thru window with 40L TF. RIH clean to TD. 02:00 - 02:30 0.50 DRILL P PROD1 Orient TF to 70L. 02:30 - 04:15 1.75 DRILL P PROD1 RIH and tag TD at 9627 ft, correct depth to 9620 ft. [-7 ft CTD]. Drilled 21, 2.6/2.6 bpm, 3000 - 3800 psi, 70L, 85 deg incl, 100 fph, Drilled to 9680'. 04:15 - 05:30 1.25 DRILL P PROD1 Drilled 21, 2.6/2.6 bpm, 3000 - 3800 psi, 160L, 88 deg incl, 100 fph, Drilled to 9765 ft. 05:30 - 06:00 0.50 DRILL P PROD1 Wiper trip to window at 9765 ft. Hole was clean. RIH. 06:00 - 06:55 0.92 DRILL P PROD1 Drilling 21 at 80L TF, Qp =2.77/2.83 bpm CTP=3000 I 3300 psi. Vp = 250 bbl ROP @ 70-90 fph 06:55 - 07:30 0.58 DRILL P PROD1 Orient TF around, hole angle projected at 87.5 deg 07:30 - 09:15 1.75 DRILL P PROD1 Drilling 21 at 32L TF, Qp =2.77/2.83 bpm CTP=3000 I 3300 psi. Vp = 250 bbl ROP @ 70-90 fph Try land at 8984 ft TVD Possible HOT at 8987 ft TVD. Possible shale at 9831 ft Took several motor stall to get from 9831 ft 9840 ft Back to drilling at 70 fph from 9845 ft Resultant TVD now 8993 TVD Last survey at 9852 ft shows 8993 TVD. 09:15 - 09:20 0.08 DRILL P PROD1 Orient TF to HS and maintain 8993 TVD 09:20 - 09:45 0.42 DRILL P PROD1 Drilling 21 at HS to 5R TF, Qp =2.77/2.83 bpm CTP=3000 / 3300 psi. Vp = 250 bbl ROP @ 70-90 fph Printed: 11/1/2004 1 :51 :43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/12/2004 1 0/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 10/18/2004 09:20 - 09:45 0.42 DRILL P PROD1 Geo changed TVD to 8985 ft 09:45 - 09:55 0.17 DRILL P PROD1 Orient TF to 90L 09:55 - 10:10 0.25 DRILL P PROD1 Drill at 103 L TF 9911 ft to 9925 It Qp =2.60/2.77 bpm CTP=3000 I 3375 psi. Vp = 250 bbl ROP @ 70-90 Iph Resultant TVD needs to 8985 ft 10:10 -10:45 0.58 DRILL P PROD1 Wiper Trip to window 10:45 - 11 :05 0.33 DRILL P PROD1 Tie-in at WS, pulling up hole Irom 8995 ft (Added 10ft) 11 :05 - 11 :30 0.42 DRILL P PROD1 RIH to 9934 ft corrected 11 :30 - 12:00 0.50 DRILL P PROD1 Drill at 103 L TF 9934 It to 9990 ft Qp =2.60/2.77 bpm CTP=3000 / 3375 psi. Vp = 250 bbl ROP @ 90-150 fph Survey at 9948 ft projected to bit is at 8985 ft TVD 12:00-12:15 0.25 DRILL P PROD1 Orient TF to 180 L to level out at 8985 ft TVD CTC increased 1000 psi while orienting, fell off 400 psi 12:15 - 12:55 0.67 DRILL P PROD1 Drill at 155 L TF from 9990 ft to 10020 ft Qp =2.54/2.63 bpm CTP=3250 / 3690 psi. Vp = 250 bbl. Taking 50 ft Geo samples ROP 50 to 80 fph Drilling interbedded sand and shale. Hole angle doesn't seem to want to drop with this TF. Getting stickeyat 10,016 ft (shales) Lots of stacking 12:55 - 13:20 0.42 DRILL P PROD1 Make 100 ft wiper. Back to drilling Drill at 158 L TF from 10023 ft to 10035 ft Qp =2.54/2.61 bpm CTP=3200 / 3980 psi. Vp = 250 bbl Working through shales 13:20 - 13:25 0.08 DRILL P PROD1 Orient TF to 1 OOL to level out at 8985 ft 13:25 - 13:50 0.42 DRILL P PROD1 Make 100 ft wiper. Back to drilling Drill at 105 to 85 L TF1 0,035 ft to 10,060 ft Qp =2.62/2.71 bpm CTP=3200 I 3980 psi. Vp = 250 bbl Taking 50 ft Geo samples 13:50 - 14:00 0.17 DRILL P PROD1 Orient TF around to 170L 14:00 - 14:30 0.50 DRILL P PROD1 Drilled 10,060 It to 10,064 It Conducting mud swap (1108 It on old mud). Started new mud down CT with 4% L T, 12ppg KlaGard at 80k LSRV. 14:30 - 15:40 1.17 DRILL P PROD1 Wiper trip to window with new mud at bit 15:40 - 16:30 0.83 DRILL P PROD1 Drilling at 180 to 117L TF to drop of TVD Qp =2.62/2.69 bpm CTP=3150 / 3530 psi. ROP = 75 ftIhr 16:30 - 16:40 0.17 DRILL P PROD1 Orient TF to level out at 8985 It TVD 16:40 - 17:00 0.33 DRILL P PROD1 Drilling at 90L TF to hold 8985 ft TVD Qp =2.62/2.69 bpm CTP=3150 /3530 psi. Printed: 11/1/2004 1:51:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/12/2004 Rig Release: 10/23/2004 Rig Number: N1 Spud Date: 12/27/1979 End: 10/23/2004 10/18/2004 17:00 - 17:10 0.17 DRILL P PROD1 Unable to get orienter to function at 10,111 ft PUH to 10,031 ft and try again to orient. 17:10 - 17:37 0.45 DRILL P PROD1 Drilling at 25L TF Qp =2.62/2.69 bpm CTP=3150 / 3430 psi. ROP = 1 00 fph 17:37 - 17:50 0.22 DRILL P PROD1 Orient TF 111 L 17:50 - 18:40 0.83 DRILL P PROD1 Drilling at 111 L TF Qp =2.62/2.69 bpm CTP=3125/3278 psi. ROP = 130 fph Vp = 190 bbl, Drilled to 10,215'. 18:40-19:15 0.58 DRILL P PROD1 Wiper trip to window. Clean hole. 19:15 - 19:40 0.42 DRILL P PROD1 Log GR tie-in. Added 7' to CTD. 19:40 - 20:15 0.58 DRILL P PROD1 RIH clean to TD. Dwn Wt = 20.5K, Tag at 10,219.5'. 20:15 - 20:30 0.25 DRILL P PROD1 DrilledZ1, 2.7/2.7bpm, 3000-3800 psi, 100L, 92degincl, Drilled to 10232' 20:30 - 20:45 0.25 DRILL P PROD1 Orient TF to 155L to drop inclination. 20:45 - 21:15 0.50 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000-3800 psi, 155L, 90 deg incl, Drilled to 10,300'. 21 :15 - 21 :45 0.50 DRILL P PROD1 Orient TF to right side. 21 :45 - 23:00 1.25 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000-3800 psi, 130R, 88 deg incl, Drilled to 10,390'. 23:00 - 00:00 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. 36K up wt. 10/19/2004 00:00 - 00:20 0.33 DRILL P PROD1 RIH clean to TD. 00:20 - 00:30 0.17 DRILL P PROD1 Orient TF to 130L. 00:30 - 01 :15 0.75 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000 - 3900 psi, 120L, 86 deg incl, Drilled to 10,450'. Very good sand. 01:15 - 02:20 1.08 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000 - 3900 psi, 15L, 89 deg incl, Drilled to 10,504' 02:20 - 02:30 0.17 DRILL P PROD1 Orient to 115L. 02:30 - 02:50 0.33 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000 - 3900 psi, 115L, 92 deg incl, Drilled to 10,522'. 02:50 - 03:00 0.17 DRILL P PROD1 Orient to 135L. 03:00 - 03:40 0.67 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000 - 3900 psi, 115L, 94 deg incl, Drilled to 10,570'. 03:40 - 05:00 1.33 DRILL P PROD1 Wiper trip to window. Clean hole. RIH to TD. 05:00 - 05: 15 0.25 DRILL P PROD1 Orient TF to 160L. 05:15 - 05:40 0.42 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000 - 3900 psi, 135L, 91 deg incl, Drilled to 10,630'. Very good sand. 05:40 - 06:00 0.33 DRILL P PROD1 Drilled Z1, 2.7/2.7 bpm, 3000 - 3900 psi, 105L, 89 deg incl, Drilled to 10,660'. 06:00 - 06:30 0.50 DRILL P PROD1 Drilling 90L TF Qp = 2.5/27 bpm; CTP 3000 /3212psi Vp = 273 bbls 06:30 - 06:45 0.25 DRILL P PROD1 PUH, shut pump down to get survey. Gtotals high 06:45 - 07:00 0.25 DRILL P PROD1 Drilling 90L TF Qp = 2.5/27 bpm; CTP 2850 /3212psi Vp = 273 bbls 07:00 - 07:45 0.75 DRILL P PROD1 Wiper trip to tie-in 07:45 - 08:10 0.42 DRILL P PROD1 Tie-in Correction + 18 ft 08:10 - 09:00 0.83 DRILL P PROD1 RIH after Tie-in Tagged TD at 10,735 ft 09:00 - 09:35 0.58 DRILL P PROD1 Drilling at 120L TF Qp = 2.6/2.73 bpm ; CTP = 2850/3210 Printed: 11/1/2004 1:51:43PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/12/2004 10/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 10/19/2004 09:00 - 09:35 0.58 DRILL P PROD1 psi Vp = 264 bbl ROP = 100 to 190 fph Controlled ROP <200 fph in kitty litter 09:35 - 09:45 0.17 DRILL P PROD1 Make 100 ft wiper trip at 10,817 ft due to stacking Drilled to 10840 ft 09:45 - 11 :30 1.75 DRILL P PROD1 Wiper trip before turning TF to 180 to find HOT 11 :30 - 11 :45 0.25 DRILL P PROD1 Orient TF to 180deg LS 11 :45 - 12:35 0.83 DRILL P PROD1 Drilling at 179L TF Qp = 2.6/2.73 bpm ; CTP = 2950 /3248 psi Vp = 256 bbl ROP = 190 fph Lossing 10 bbl every wiper trip, some over shaker While drilling at 10894 ft found shal, ROP went from 190 fph to 77 fph back to 170 fph at 10897 ft. Drilled to TD of 10,965'. 12:35 - 13:30 0.92 DRILL P PROD1 Wiper trip to window. Clean hole, no motor work, no overpulls. 13:30 - 13:50 0.33 DRILL P PROD1 Log final GR Tie-in. Added 8 ft CTD. 13:50 - 14:45 0.92 DRILL P PROD1 RIH. Circ. in new FloPro for liner pill. Tag Final TD at 10,969'. Hole in good condition. 14:45 - 16:45 2.00 DRILL P PROD1 POH while laying in 100 bbl new FloPro liner pill. Flag CT at 8200' EOP and 6200' EOP. POH while circ at 2.8 bpm, 3100 psi. 16:45 - 19:00 2.25 DRILL P PROD1 Download RES tool. Layout drilling BHA. Bit grades - 2/3/1. 19:00 - 19:30 0.50 CASE P RUNPRD Prep rig floor & R/U to run completion liner. Meanwhile weld-up cracks in CT reel spoke. 19:30 - 19:45 0.25 CASE P RUNPRD Held PJSM on M/U & RIH with liner. 19:45 - 23:30 3.75 CASE P RUNPRD M/U 2-7/8" liner float equipment & STL shoe jt. M/U 40 jts of 2-7/8" STL 6.16# L-80, LSL sub, M/U 41 jts 3-3/16" 6.2# L-80 TCII, XO, 1 jt of 3-1/2" 9.3# L80 STL, X nipple, 2 pups 3-1/2". MIU Baker CTLRT (OAL - 2648.29') 23:30 - 00:00 0.50 CASE P RUNPRD Install Baker CTC. Pull test to 36k & pressure test to 3500psi - OK. Meanwhile jack up rig slightly to allow putting of front wheel tires. 10/20/2004 00:00 - 01:15 1.25 CASE P RUNPRD Install dart catcher. Load wiper dart. Launch & chase with mud to pig CT. Dart bumped on catcher @ 55.5bbls. M/U injector. 01 :15 - 03:10 1.92 CASE P RUNPRD RIH with liner on CT to 1st flag @ 8859' circ @ 0.60/0.72bpm & 820psi. Correct CTD by -10.7'. Check up wt - 40k, down wt- 24k. RIH smoothly @ 50fpm thru window. Continue RIH smoothly. Saw 2nd flag 3' deep. Tag TD @ 10953' CTD. P/U @ 47k. RBIH @ retag TD @ same depth. Set down 10k down on CTLRT. 03:10 - 03:45 0.58 CASE P RUNPRD Load & launch 5/8" steel ball & circ with mud @ 2.2I2.2bpm, 2160psi. Slow down to 0.5bpm/1080psi @ 40bbls away. Ball on seat @ 42.9bbls. Pressure up to 4400psi & release CTLRT. P/U @ 32k & confirm release. Set back 10k down on CTLRT. 03:45 - 07:00 3.25 CASE P RUNPRD Displace well to 2% KCL at 2.7/2.7bpm & 1440psi. Send used FloPro to MI for reconditioning. Meanwhile R/U Dowell cementers. 07:00 - 07:15 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. 07:15 - 08:55 1.67 CEMT P RUNPRD Press test cement line. Batch cement. Cement at weight at 0740 hrs. Stage 41 bbls, 15.8 ppg, G cement with latex. 2.1 bpm, 2200 psi. Insert Dart. Clean cement line. Printed: 11/1/2004 1:51 :43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/12/2004 1 0/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 1 0/20/2004 07:15 - 08:55 1.67 CEMT P RUNPRD Displace dart with 2# Biozan water. 3.2 bpm, 2600 psi. 10 bbl displ, 2.9 bpm, 1600 psi, full returns 20 bbl displ, 2.9 bpm, 900 psi, full returns 32 bbl displ, 2.9 bpm, 950 psi, full returns, Cement at shoe, zero out totalizer 40 bbl displ, 2.9 bpm, 1300 psi, full returns 45 bbl displ, 2.9 bpm, 1350 psi, full returns, slow pump to 2 bpm. 50 bbl displ, 1.7 bpm, 400 psi, full returns, Dart on LWP at 56.4 bbls, sheared at 3100 psi 60 bbl displ, 3.1 bpm, 2100 psi, full returns, 70 bbl displ, 2.8 bpm, 2700 psi, full returns 71 bbl displ, slow rate to 1.0 bpm 73.2 bbl displ, Bumped LWP [ calc = 73.8 bbl ] held 1800 psi, bled off press, check valves holding. Sting out. Cement out totalizer showed full returns with 42 bbls cement past shoe. Cement job went very well. 08:55 - 10:15 1.33 CEMT P RUNPRD POH. pump to replace coil volume. 10:15 - 12:00 1.75 CEMT P RUNPRD Layout Baker CTLRT. Recover all of BHA. Clean out cuttings tank. 12:00 - 12:15 0.25 EVAL P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U Memory CNL BHA. 12:15 - 14:50 2.58 EVAL P LOWER1 M/U milling, MCNLlGR BHA. RIH on 45 stds of CSF workstring. BHA = 2826'. 14:50 - 16:30 1.67 EVAL P LOWER1 RIH with 2.30" diamond mill, motor and MCNUGR inside carrier. SWS UCA cement sample at 1000 psi. Stacked weight while at 7980'. Pick up and RIH with some motor work at 7995 and 8200'. Ream possible cement stringers at 7995' and 8200'. Ream down, up and down. No motor work on second pass. 16:30 - 19:00 2.50 EV AL P LOWER1 Log down from 8200 ft with SWS Memory CNUGRlCCL at 30 fpm, Circ at 1.5 bpm. 2jts of 1-1/4" CSH between motor and logging tools for vibration. No motor work entering top of liner. Circ. in 15 bbl high viscosity FloPro perf pill while log in hole. Sat down early at 10,804'. Sat down 3 times at same depth with no motor work. Log up to 8900'. Observe that SLB logging depth encorder is not tracking rig depth very well. Swap out encoder & decide to RBIH to relog. 19:00 - 19:30 0.50 EVAL N SFAL LOWER1 RBIH to HUD tagged @ 10798'. 19:30 - 19:45 0.25 EVAL N SFAL LOWER1 Changeout encoder cable to ensure failure source is eliminated. 19:45 - 20:15 0.50 EV AL N SFAL LOWER1 Log up @ 60fpm from 10798' to 8900' while laying-in 150kcps perf pill in liner. 20:15 - 20:30 0.25 EVAL P LOWER1 Log up @ 60fpm from 8900' to 8200'. 20:30 - 21 :25 0.92 EVAL P LOWER1 Drop 5/8" phenolic ball & cìrc to cìrc sub @ 1.5bpm. Open up circ sub with 31 OOpsì. 21 :25 - 23:30 2.08 EVAL P LOWER1 Continue POOH logging/cleanout BHA circ @ 2.68bpm/2500psì. Still getting cement contaminated KCI fluid. Printed: 11/1/2004 1:51:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/12/2004 1 0/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 10/20/2004 21 :25 - 23:30 2.08 EVAL P LOWER1 Continue circ till returns clean up. 23:30 - 23:45 0.25 EVAL P LOWER1 Held PJSM for R/B 1-1/4" CSH. 23:45 - 00:00 0.25 EVAL P LOWER1 SIB injector & R/B 10 stands of 1-1/4" CSH. 10/21/2004 00:00 - 01 :30 1.50 EVAL P LOWER1 R/B 34 stands of 1-1/4" CSH. UD MHA. 01 :30 - 01 :45 0.25 EVAL P LOWER1 Held PJSM for UD CNL carrier & RA source. 01 :45 - 02:00 0.25 EVAL P LOWER1 LID MCNL/CCUGR carrier. R/B 1 stand of 1-1/4" CSH, XIOver & motor/mill. Inspect motor & mill - nothing amiss. C/O mill with another used mill in a better condition. 02:00 - 02:40 0.67 CEMT P RUNPRD Cement> 2700psi compressive strength. Line up & P/test wellbore for 30mins as follows: Time WHP CTP lAP OAP Onset 11 0 18 1 0 2150 0 151 127 10 2084 0 146 121 20 2062 0 144 121 30 2054 0 144 121 => Leaked 4.5% of test pressure in 30 mins. 02:40 - 03:15 0.58 CEMT P RUNPRD M/U swizzle stick & jet BOP stack. Flush lines. UO swizzle stick & SIB injector. Meanwhile download MCNL data. From log data, TOL was located @ 8323' & hold-up depth was @ 10809.1 '. Suspect 3" OD section of BHA was hanging up @ +/-7985' - across the area initially reamed with 2.3" mill. Will make aditional cleanout run(s) before perforating liner. 1st run will include enough CSH to place 3" OD section of BHA above 7900'. 03:15 - 03:30 0.25 CEMT N DPRB RUNPRD Held PJSM for RIH cleanout BHA #13 with 1-1/4" CSH. 03:30 - 05:30 2.00 CEMT N DPRB RUNPRD P/U cleanout BHA #13 with a used 2.30" D331 parabolic mill, 2-1/8" straight motor, lower MHA, XO, 100jts of 1-1/4" CSH tbg, XIO & upper MHA. 05:30 - 07:30 2.00 CEMT N DPRB RUNPRD RIH cleanout BHA #13. RIH clean to PBTD. Circ. at 1.7 bpm, 2200 psi. Tagged PBTD at 10,926 ft. 07:30 - 10:20 2.83 CEMT N DPRB RUNPRD Circ. high viscosity FloPro perf pill to bit. Lay in high vis pill over full length of liner. POH. 10:20 - 12:00 1.67 CEMT N DPRB RUNPRD Stand back CSH workstring. 50 stds. 12:00 - 12:10 0.17 CEMT N DPRB RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U underreaming BHA. 12:10 - 13:45 1.58 CEMT N DPRB RUNPRD M/U Baker 3-5/8" X 6.0" Inteq 3 blade underreamer with motor, circ sub, discon, 2 jts PH6, checks and eTC. M/U Baker CTC and pull/press test. OAL = 84.96'. 13:45 - 15:30 1.75 CEMT N DPRB RUN PRO RIH with Baker UR BHA #14. RIH with no pump to ensure blades were closed. Ran past SSSV insert with no wt loss. RIH. Tagged fill at 7930'. 15:30 - 16:30 1.00 CEMT N DPRB RUNPRD Start Underreaming with 6.0' blades [ 3 blades] at 7900' at 5 fpm, Pumping 2# Biozan at 2.4 bpm, 1600 psi. Stalled at 7997'. UR at 2-5 fpm, U/R to 8,160'. 16:30 - 17:20 0.83 CEMT N DPRB RUNPRD U/R at 6 fpm, Stalled at 8170'. UR at 1-3 fpm, 2.5 bpm, 1950 psi, Stalled at 8230'. Pick up and UR down easy at 2.1 bpm, 1700 psi, 1 fpm, Printed: 11/1/2004 1:51:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/12/2004 1 0/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 1 0/21/2004 16:30 - 17:20 0.83 CEMT N DPRB RUNPRD Lite Stall again at 8230'. Deep enough. 7" X 4.5" XO at 8256'. Pick up to 7900' 17:20 - 18:00 0.67 CEMT N DPRB RUNPRD U/R down from 7900' at 10 fpm. 2.5 bpm, 1900 psi, UR to 8225'. Did not see any motor work on cement or any stalls. Pick up to 7900' for third pass. 18:00 - 18:30 0.50 CEMT N DPRB RUNPRD U/R third pass down from 7900' to 8225' at 15 fpm, 2.5 bpm, 1850 psi. 18:30 - 18:50 0.33 CEMT N DPRB RUNPRD Drop 3/4" steel ball & chase @ 2.5bpm. Drop rate to 1.5bpm @ 40bbls away. Ball on seat @ 48.7bbls. Open up circ sub with 2500psi. 18:50 - 20:50 2.00 CEMT N DPRB RUNPRD POOH under-reaming BHA chasing out contaminated KCL fluid @ 3.25bpm/2714psi. 20:50 - 21 :30 0.67 CEMT N DPRB RUNPRD OOH. PJSM. SIB injector. UD under-reaming BHA #14. 21 :30 - 23:00 1.50 CEMT N DPRB RUNPRD P/U cleanout BHA #15 with a 2-1/4" nozzle, 100jts of 1-1/4" CSH tbg, XIO & MHA. M/U injector. 23:00 - 00:00 1.00 CEMT N DPRB RUNPRD RIH cleanout BHA #15. 10/22/2004 00:00 - 01 :30 1.50 CEMT N DPRB RUNPRD Set down @ 8575'. P/U & wash down @ 2.3bpm/2760psi & 33-50fpm. Tag PBTD @ 10926'. Pump down 15bbls of perf pill followed by 30bbls of biozan pill. 01 :30 - 02:00 0.50 CEMT N DPRB RUNPRD POOH laying-in 150kcps perf pill in liner. 02:00 - 02:15 0.25 CEMT N DPRB RUNPRD Circulate out 30bbls of bio-KCL pill. 02:15 - 04:00 1.75 CEMT N DPRB RUNPRD Continue POOH cleanout BHA chasing out contaminated KCI fluid @ 2.7bpm/2500psi. Tag up @ surface & continue circ out dirty KCL fluid till returns clean up. Flush surface lines. 04:00 - 05:30 1.50 CEMT N DPRB RUNPRD PJSM. SIB injector. LID MHA. R/B 50 stands of 1-114" CSH. UD nozzle. 05:30 - 06:30 1.00 PERFO LOWER1 R/U to run perf guns. Load SWS, 2" PowerJet guns & blanks in pipe shed. Layout guns in running order. 06:30 - 06:45 0.25 PERFO LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for running perf guns. 06:45 - 09:00 2.25 PERFO LOWER1 RIH with 54, SWS, 2", 6 SPF, PowerJet perf guns and blanks, with SWS ball seat firing head. 09:00 - 10:15 1.25 PERFO LOWER1 M/U BKR Hyd Disc, XO and 30 STDs of CSH workstring. M/U circ sub, hyd disc, checks, NRJ and CTC. OAL = 3,018.88 ft. 10:15 - 12:00 1.75 PERFO LOWER1 RIH with Perforating BHA #16. RIH thru top of liner with no wt loss. Tag PBTD at 10,933'. correct depth to 10,932 ft [-1 ft CTD]. 12:00 - 13:00 1.00 PERFO P LOWER1 Pump 12 bbl high vis new FloPro ahead of ball. Insert 5/8" AL ball and pump 5 bbl FloPro behind ball. Displace with KCL water. 1.75 bpm, 1900 psi, Slow pump to 1 bpm at 48 bbls, Ball on seat at 55.5 bbls, Pull coil and fire guns on the fly. Firing head!sheared at 3000 psi. PERFORATED INTERVAL: 9,790 - 9,910' 10,100 - 10,420' 10,580 - 10,920' 780' OF PERFS 13:00 - 15:00 2.00 PERFO LOWER1 POH while circ at 1.1 bpm. Flow check above liner top - OK. POH to surface. Flow check again. OK. 15:00 - 16:00 1.00 PERFO LOWER1 SIB 30 stds of CSH workstring. 16:00 - 16:15 0.25 PERFO LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired perf guns. 16:15 -18:15 2.00 PERFO LOWER1 Layout fired perf guns and blanks. All shots fired. Printed: 11/1/2004 1 :51 :43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/12/2004 1 0/23/2004 N1 Spud Date: 12/27/1979 End: 10/23/2004 Crew change & PJSM for UD perf guns. Continue LID perf guns & blanks. ASF!. Load out spent guns & R/D SLB TCP crew. 20:15 - 21 :30 1.25 RIGD P POST M/U & RIH with nozzle BHA to 2500'. Start pumping MeOH. 21 :30 - 22:00 0.50 RIGD P POST Lay in MeOH @ 60/40 from 2500' to 300'. Circulate 100% MeOH to surface. SI Master valve (34-1/2 turns). 22:00 - 22:10 0.17 RIGD P POST PJSM for B/D CT with N2. 22:10 - 23:00 0.83 RIGD P POST prrest N2lines - OK. B/D CT & lines with N2 & bleed off. UD nozzle BHA. Meanwhile clean out pits & tanks. 23:00 - 23: 15 0.25 RIGD P POST PJSM for stripping off & pulling back CT to the reel. 23:15 - 00:00 0.75 RIGD P POST Slip connector into CT & pull test. Strip-off CT from injector & spool back to reel. 10/23/2004 00:00 - 01 :00 1.00 RIGD P POST Secure CT & prep reel for shipment. 01:00 - 01:15 0.25 RIGD P POST PJSM for N/D BOP. 01:15 - 03:00 1.75 RIGD P POST N/D BOP. N/U tree cap. Will P/test tree cap after moving off well. Release rig @ 03:00Hrs on 10/23/04. Printed: 11/1/2004 1 :51 :43 PM . . 01-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well F-11 B Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,900.00' MD 8,943.00' MD 10,969.00 I MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date (!/JIð t.f ~ '1 Signed ~ oiL) t Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ;hctJ/-rQG/ e Halliburton Sperry-Sun North Slope Alaska BPXA PBU_ WOA F Pad F-11 B 19 October, 2004 Job No. AKMW3338369, Surveyed: Survey Report 26 October, 2004 - Your Ref: API 500292042402 Surface Coordinates: 5974592.00 N, 651958.00 E (70020' 15.3888" N, 148046' 01.1309 Grid Coordinate System: NAD27 A/aska State Planes, Zone 4 Survey Ref: svy4426 W) Surface Coordinates relative to Project H Reference: 974592.00 N, 151958.00 E (Grid) Surface Coordinates relative to Structure Reference: 2042.96 N, 1039.74 E (True) Kelly Bushing Elevation: 66.76ft above Mean Sea Leve/ Kelly Bushing Elevation: 66. 76ft above Project V Reference Kelly Bushing Elevation: 66.76ft above Structure Reference Sipai''-'Y-SiUI! CRIL-LING seRVIc:es A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU_ WOA F Pad - F-11 B Your Ref: API 500292042402 Job No. AKMW3338369, Surveyed: 19 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8900.00 18.370 75.190 8389.19 8455.95 1018.44 N 1935.03 E 5975649.44 N 653872.00 E -2136.96 Tie On Point MWD Magnetic 8943.00 18.030 75.740 8430.04 8496.80 1021.81 N 1948.03 E 5975653.07 N 653884.93 E 0.886 -2149.09 Window Point 8973.55 21.010 73.600 8458.83 8525.59 1024.52 N 1957.87 E 5975655.98 N 653894.71 E 10.030 -2158.36 9003.85 23.910 71 .500 8486.83 8553.59 1028.00 N 1968.91 E 5975659.69 N 653905.67 E 9.929 -2169.06 9033.49 21.090 69.500 8514.21 8580.97 1031.78 N 1979.60 E 5975663.68 N 653916.29 E 9.857 -2179.68 e 9063.84 20.550 67.620 8542.58 8609.34 1035.72 N 1989.64 E 5975667.82 N 653926.24 E 2.831 -2189.90 9095.41 21.530 57.360 8572.05 8638.81 1040.95 N 1999.65 E 5975673.26 N 653936.14 E 12.058 -2200.93 9125.72 22.410 50.150 8600.17 8666.93 1047.66 N 2008.77 E 5975680.15 N 653945.12 E 9.355 -2212.23 9156.10 21 .450 42.420 8628.35 8695.11 1055.47 N 2016.96 E 5975688.12 N 653953.16 E 10.006 -2223.53 9186.08 19.860 35.910 8656.41 8723.17 1063.64 N 2023.65 E 5975696.43 N 653959.68 E 9.309 -2233.90 9216.58 20.040 26.770 8685.09 8751.85 1072.51 N 2029.04 E 5975705.40 N 653964.89 E 10.232 -2243.73 9246.27 19.600 14.120 8713.03 8779.79 1081.88 N 2032.55 E 5975714.85 N 653968.21 E 14.496 -2252.44 9277.31 20.390 3.920 8742.21 8808.97 1092.33 N 2034.19 E 5975725.33 N 653969.64 E 11.506 -2260.42 9309.92 20.660 349.040 8772.77 8839.53 1103.65 N 2033.48 E 5975736.63 N 653968.70 E 15.980 -2267.15 9345.40 21.700 336.690 8805.87 8872.63 1115.83 N 2029.70 E 5975748.73 N 653964.67 E 12.889 -2272.08 9378.07 21.180 322.260 8836.30 8903.06 1126.05 N 2023.69 E 5975758.83 N 653958.46 E 16.185 -2274.05 9406.38 21.670 309.070 8862.67 8929.43 1133.39 N 2016.50 E 5975766.02 N 653951.12 E 17.073 -2273.26 9440.53 26.780 287.220 8893.86 8960.62 1139.66N 2004.22 E 5975772.04 N 653938.71 E 29.984 -2267.88 9470.54 38.150 280.700 8919.15 8985.91 1143.40 N 1988.60 E 5975775.46 N 653923.02 E 39.593 -2258.32 9506.68 51.720 278.410 8944.68 9011.44 1147.56 N 1963.48 E 5975779.12 N 653897.82 E 37.809 -2241.75 9538.68 62.640 274.180 8962.00 9028.76 1150.44 N 1936.79 E 5975781.46 N 653871.08 E 35.876 -2223.16 e 9568.75 73.570 271.540 8973.20 9039.96 1151.81 N 1908.97 E 5975782.26 N 653843.24 E 37.246 -2202.73 9601.29 82.290 268.190 8980.00 9046.76 1151.72 N 1877.19 E 5975781.52 N 653811.46 E 28.623 -2178.32 9635.21 89.340 266.780 8982.47 9049.23 1150.23 N 1843.41 E 5975779.35 N 653777.72 E 21.193 -2151.49 9666.19 91.720 264.490 8982.18 9048.94 1147.88 N 1812.53E 5975776.37 N 653746.89 E 10.660 -2126.32 9710.06 87.580 265.900 8982.45 9049.21 1144.20 N 1768.82 E 5975771.81 N 653703.27 E 9.969 -2090.48 9759.45 82.910 264.660 8986.55 9053.31 1140.16 N 1719.78 E 5975766.77 N 653654.33 E 9.781 -2050.31 9792.18 85.730 262.020 8989.79 9056.55 1136.38 N 1687.44 E 5975762.34 N 653622.07 E 11.775 -2023.10 9822.37 87.580 259.380 8991.55 9058.31 1131.51N 1657.70 E 5975756.87 N 653592.43 E 10.665 -1997.19 9852.06 88.110 253.910 8992.66 9059.42 1124.66 N 1628.85 E 5975749.43 N 653563.72 E 18.497 -1970.68 9880.33 89.690 252.500 8993.21 9059.97 1116.49 N 1601.79 E 5975740.72 N 653536.84 E 7.490 -1944.71 9914.78 93.300 250.920 8992.31 9059.07 1105.68 N 1569.10 E 5975729.25 N 653504.37 E 11 .438 -1912.72 9948.44 94.890 248.800 8989.90 9056.66 1094.13N 1537.58 E 5975717.06 N 653473.09 E 7.860 -1881.14 9992.08 95.590 244.580 8985.92 9052.68 1076.93 N 1497.68 E 5975699.06 N 653433.55 E 9.762 -1839.53 10021.24 91.450 238.940 8984.13 9050.89 1063.17 N 1472.05 E 5975684.78 N 653408.21 E 23.960 -1811.05 26 October, 2004 - 9:37 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_ WOA F Pad - F-11 B Your Ref: API 500292042402 Job No. AKMW3338369, Surveyed: 19 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (01100ft) 10069.62 88.810 237.000 8984.02 9050.78 1037.51 N 1431.04 E 5975658.30 N 653367.73 E 6.771 -1763.14 10096.42 86.700 234.360 8985.07 9051.83 1022.42 N 1408.93 E 5975642.76 N 653345.92 E 12.604 -1736.50 10137.80 91.630 231.360 8985.67 9052.43 997.45 N 1375.96 E 5975617.12 N 653313.47 E 13.945 -1695.19 10163.21 92.250 228.720 8984.81 9051.57 981.14 N 1356.50 E 5975600.42 N 653294.34 E 10.666 -1669.80 10202.61 91.890 222.730 8983.38 9050.14 953.66 N 1328.32 E 5975572.38 N 653266.72 E 15.221 -1630.55 10236.25 93.040 218.500 8981.94 9048.70 928.16 N 1306.45 E 5975546.44 N 653245.37 E 13.019 -1597.40 e 10271.38 90.480 216.730 8980.86 9047.62 900.35 N 1285.02 E 5975518.20 N 653224.51 E 8.858 -1563.11 10299.50 89.430 214.090 8980.88 9047.64 877.43 N 1268.73 E 5975494.96 N 653208.68 E 10.104 -1535.90 10330.16 90.040 217.440 8981.02 9047.78 852.55 N 1250.81 E 5975469.73 N 653191.28 E 11 .1 06 -1506.19 10362.23 88.460 222.020 8981.44 9048.20 827.90 N 1230.32 E 5975444.66 N 653171.29 E 15.106 -1474.64 10411.04 85.730 223.610 8983.92 9050.68 792.15 N 1197.19 E 5975408.24 N 653138.89 E 6.470 -1426.28 10445.65 85.550 219.730 8986.55 9053.31 766.37 N 1174.25 E 5975382.01 N 653116.48 E 11.190 -1392.15 10479.44 89.430 216.030 8988.03 9054.79 739.74 N 1153.53 E 5975354.96 N 653096.31 E 15.858 -1359.15 10522.54 95.240 210.390 8986.27 9053.03 703.74 N 1129.96 E 5975318.49 N 653073.47 E 18.776 -1317.96 10572.57 92.600 205.100 8982.85 9049.61 659.58 N 1106.74 E 5975273.87 N 653051 .15 E 11.794 -1271.78 10616.27 89.600 202.110 8982.01 9048.77 619.55 N 1089.25 E 5975233.50 N 653034.47 E 9.691 -1232.66 10678.22 87.400 196.290 8983.63 9050.39 561.10 N 1068.89 E 5975174.65 N 653015.30 E 10.040 -1179.49 10711.56 87.670 198.230 8985.07 9051.83 529.29 N 1059.01 E 5975142.64 N 653006.07 E 5.870 -1151.47 10746.77 88.720 191.890 8986.18 9052.94 495.33 N 1049.87 E 5975108.50 N 652997.62 E 18.242 -1122.64 10781.08 89.690 181.140 8986.65 9053.41 461.29 N 1045.98 E 5975074.39 N 652994.42 E 31.456 -1097.78 10814.35 90.570 179.550 8986.58 9053.34 428.02 N 1045.78 E 5975041.13 N 652994.90 E 5.462 -1076.25 10842.88 91 .450 176.730 8986.08 9052.84 399.52 N 1046.71 E 5975012.64 N 652996.40 E 10.353 -1058.63 e 10875.36 88.550 174.440 8986.08 9052.84 367.14 N 1049.21 E 5974980.32 N 652999.55 E 11.376 -1039.73 10921.51 83.880 175.320 8989.12 9055.88 321.29 N 1053.32 E 5974934.56 N 653004.59 E 10.296 -1013.41 10938.18 82.380 174.800 8991.12 9057.88 304.80 N 1054.74 E 5974918.11 N 653006.35 E 9.516 -1003.90 10969.00 82.380 174.800 8995.20 9061.96 274.38 N 1057.51 E 5974887.75 N 653009.74 E 0.000 -986.47 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 230.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1 0969.00ft. , The Bottom Hole Displacement is 1 092.53ft., in the Direction of 75.455° (True). 26 October, 2004 - 9:37 Page 3 of 4 Dril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for P8U_ WOA F Pad - F-118 Your Ref: API 500292042402 Job No. AKMW3338369, Surveyed: 19 October, 2004 North Slope Alaska 8PXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8900.00 8943.00 10969.00 8455.95 8496.80 9061.96 1018.44 N 1021.81 N 274.38 N 1935.03 E 1948.03 E 1057.51 E Tie On Point Window Point Projected Survey e Survey tool program for F-11 B Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8900.00 0.00 8900.00 8455.95 10969.00 8455.95 BP Conventional Gyro - BOSS-GYRO (F-11) 9061.96 MWD Magnetic (F-11 B) e 26 October, 2004 - 9:37 Page 4 of 4 Dríl/Quest 3.03.06.006 Minimum 2~7/8" PIN 2" 2" 2" 6 6 6 REF LOG: SW8 ANGLE AT TOP Note:Re . . (ill fE' ~ FRANK H. MURKOWSKI, GOVERNOR AIfASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay F-IIB BP Exploration (Alaska) Inc. Permit No: 204-194 Surface Location: 2208' SNL, 2869' WEL, SEC. 02, TIIN, R13E, UM Bottomhole Location: 1939' SNL, 1823' WEL, SEe. 02, TIIN, R13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 pager). S· e BY ORDER OJ'THE COMMISSION DATED this ~ day of October, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1a. Type of work o Drill II Redrill rb. Current Well Class [J Exploratory M«"~~ .~;¡ ~~:~gle Zone ~ ORe-Entry o Stratigraphic Test [J Service as 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Nan ~'ãi1 Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU F-11B,- 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10950 TVD 8984 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028280 2208' SNL, 2869' WEL, SEC. 02, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate ~e: Top of Productive Horizon: 603' SNL, 692' WEL, SEC. 02, T11N, R13E, UM Octob r 10,2004 Total Depth: 9. Acres in Property: 14. Distance to Náê!ßSt Property: 1939' SNL, 1823' WEL, SEC. 02, T11N, R13E, UM 2560 9900' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-651958 y- 5974592 Zone- ASP4 (Height above GL): 66.76' feet F-13A is 626' away at 10946' MD 16. Deviated Wells: Kickoff Depth: 8945 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3200 Surface: 2200 .-' la.Casing Program: Setting D~pth (c.1......'-!! .à. h Size Top .......? '. . .....? ...... . ·.Bo!tbm Hole Casina WeiQht Grade Couplina LenQth MD TVD MD TVD (includinQ staae data) 4-1/8" x 3-3/4" 3-3/16" x 2-7/8" 6.2# / 6.5# L-80 TCIII STL 2630' 8320' 7839' 10950' 8984' 185 cu ft Class 'G' 19. PRE$ENTWI;LLCONDITIONSt.JMMA~Y (TO bØ .completed for ~edrinANº~c:!-Øntry OþèrEltibn$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft)l Junk (measured): 10875 9038 ~ None I 10813 9041 None ?" ......?. .. ·??S! .....:. ...i..i:::..·..· ·i' i:i:. ... 'i;: ëmIn i. ~" I r.onrh (-,tnr 110' 20" x 30" 7.5 cu yds Concrete 110' 110' 2655' 13-3/8" 3153 cu ft Arcticset II 2655' 2655' 8815' 9-5/8" 1193 cu ft Class 'G', 130 cu ft AS I 8815' 8375' prorh Jr.tinn Liner 982' 7" 01 cu ft Class 'G' 8307' - 9289' 7894' - 8829' Liner 2563' 2-7/8" 107 cu ft Class 'G' 8312' - 10875' 7899' - 9038' Perforation Depth MD (ft): 10125' - 10800' perfOration Depth TVD (ft): 9025' - 9041' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 MC 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 Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer IIJf}tf!/),J i ~7d¡JUJtt 7/29/04_ Prepared By Name/Number: Sianature Phone 564-4388 Date Terrie Hubble, 564-4628 :.t. .); /t 'i::ii: ?? ···:·i);"·i) ....C·,:, :;:. ·····:·····?·':::I:..:.··::?:;),,·:·· :.:.:::i'.: :. Permit To Drill 19S1 API Number: I Permit APProV:!¿, Ie See cover letter for Number: 7.-// 50- 029-20424-02-00 Date: 1& {¿t 01./ other requirements Conditions of Approval:F Samples Required DYes J!No Mud Log Required DYes J8No H"'V.n SuW"'. Measures )'šYes D No Directional Survey Required .:8'Yes DNo Othe' TeSt- ßO ~ ' '>SOO fV< fi7" {,O Slto.{){)[.? , ~Dmvoo új '1~ no I ~ 1 t\1 ~~¡ROVED BY /Ðhiðt/ . "'" E COMMISSION Date Form 10-401 ~d 0 ßPd4 '-- _1\'_11""'- ~bm¡{ In l1uplicate yJCA- ql ~O 12-~)ot ALASKA OILeD ~::;~g~S~~~:iìON COMMI.OREC IVED PER~~¿~ O~5RILL ~,SEP 2 9 2004 . BP F-11 B CTD Sidetrack . Phase 1 Operations: Prep Work: · Integrity pressure test OA, IA &tbg, wellhead seals & Xmas tree valves. · Set CIBP · Cut 2 7/8" liner at TOC Phase 2 Operations: Pull liner, set whipstock, Mill window, Drill and Complete sidetrack. Mud Program: · Phase 1: Seawater/1 % KCI _,' · Phase 2: Mill with seawater 1 Y2lb biozan, drill with Solids Free Flo-Pro (8.G9) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: . 33hsTCII x 2%" STL from 10950' - 83'ss) to 8,320'MD (-7,839'ss). . The liner will be cemented with -33 Is with a planned TOC at top of liner. // Parent Well Casin s 133/8" 72# L-80 9%" 47#, L-80 7" 29#, L-80 liner Sidetrack Casin s 3-3/16" 6.2#, L-80, TCII- Prod LNR 2Vs" 6.5#, L-80, STL - Prod LNR Hole Size 4.125 3.75 8520 10570 7660 11170 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · F-11 B will be approximately 626' ctr-ctr away from well F-13A at 10946' md · F-11 B will be approximately 9900' from the unit boundary, (Prudhoe Bay Unit) Logging · MWD Gamma Ray and Resistivity will be run in the open hole section. · Memory CNL will be run inside the liner. Hazards /-"ì · H2S last measured on F-11 was 10Ppm in 2000. ~pm is the maximum measured on the pad. · The risk of a lost circulation event is considered medium, one small fault and one fracture will be crossed. · Stuck pipe in 13N shale. Reservoir Pressure · Res. press. is estimated to be 3200 psi at 8800'ss (7.1 ppg emw). · Max. surface pressure with gas (0.12 psi/ft) to surface is 2200 psi. / TREE = WELL HEA 0 = ACTUA TOR = KB. ELBI = BF. ELEV = KOP= rv1ax Angle = [Btum M) - [Btum 1V 0- 6" OW McBlOY 011S 66.76' 38.16' 3400' 95 @ 9779' 9329' 8800' SS F-11A/ SAFETY NOTES: CTD HORIZONTAL SIDE TRACK- 70° @ 9526' AND 90° @ 9712' 2008' 7' OTIS SSSV NIP, 10 = 3.813" . 13-318" CSG, 72#, L-80, 10 = 12.347" 7" 1BG, 26#, L-80, AB-IJ4S, 0.0383 bpf, 10 = 6.276" Minimum 10 = 2.372" @ 8312' 2-7/8" LINER TOP OF 7' LNR TOP OF 2- 7/8" LNR 4-1/2" TBG, 12.75#, L-80, 0.0152 bpf, 10 = 3.958" 8307' 8302' 4-1/2" OTIS X NIP, 10 = 3.813" DEA...OYMENT SLEEVE 8312' 8312' 8334' 4-1/2" OTIS XN NIP, 10 = 3.725" 8367' 8367' 8361' 4-1/2" SA KER SOS TBG TA IL HELM) TT LOG NOT AVALABLE I 9-5/8" CSG, 47#, L-80, 10 = 8.681" 9265' MARKER JOINT PERFORATION SUI'vIv1ARY REF LOG: SWS 01/09180 ANGLEATTOPÆRF: 86 @ 10125' /lbte: Refer to Production DB for historical perf data SIZE SAO INTERVAL Opn/Sqz D6.TE 2" 6 10125 - 10150 0 OS/29/04 2" 4 10200 - 10300 0 06101/00 2" 4 10340 - 10600 0 06101/00 2" 4 10720 - 10800 0 06101/00 ~ 9620' 7" LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" 9673' MLLOur WINDOW: 3.80" FROM 9289' TO 9295' 2-7/8" LNR, 6.16#, SlL, L-80, 0.00579 bpf, 10= 2.441" CO I'vIv1 ENTS PRUDHOE SA Y UNIT WELL: F-11A PERMIT No: 200-0620 API No: 50-029-20424-02 SEC2,T11N, R13E BP Exploration (Alaska) DATE REV BY COMIvENTS D6. TE RBI BY 01/14/80 ORIGINAL COrvPLEIlON OS/21/00 CRM em HORlZ SDTRK COMPLET 03/06/01 SIS-MH CONl/ERfEDTO CANVAS 03/10/01 SIS-MD RNAL 03/04/02 RNlTP CORRECfIONS TREE =' WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD- 6" erN McEVOY OTIS 66.76' 38.16' 3400' 95 @ 9779' 9329' 8800' SS . F-11 B SAFETY NOTES: CTD HORIZONTAL SIDETRACK· 70° @ 9526' AND 90° @ 9712' PROPOSED CTD SIDETRACK . 2008' -i 7" OTIS SSSV NIP, 10 = 3.813" I 113-3/8" CSG, 72#, L-80, 10 = 12.347" I 2655' ÆRFORA TION SUMMARY REF LOG: SWS 01/09/80 ANGLEATTOPÆRF: 86 @ 10125' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA TE 2" 6 10125 - 10150 0 OS/29/04 2" 4 10200 - 10300 0 06/01/00 2" 4 10340 - 10600 0 06/01/00 2" 4 10720 - 10800 0 06/01/00 I Minimum 10 = 14-1/2" TBG, 12.75#, L-80, 0.0152 bpf, 10 = 3.958" 8367' 7" TBG, 26#, L-80, AB-LJ4S, 8256' 0.0383 bpf, 10 = 6.276" I TOP OF 7" LNR 8307' TOCaSSUming Sag River KOP l-i 8320' 4-1/2" OTIS X NIP,ID= 3.813" Top of 3-3/16" Liner 3-1/2" X NIP ID::: 2.813" 4-1/2" OTIS XN NIP, MILLED? ID::: 3.725" 4-1/2" BAKER SOS TBG TAIL ELMD TT LOG NOT A V AILABLE I 9-5/8" CSG, 47#, L-80, ID = 8.681" I IWHIPSTOCK H 8965' 10910' I '" 9060' l-i Cut and Pull 2-7/8" liner I I TOC (SCMT) H 9028' I 10950' I I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 9673' tAiLLOLT WINDOW. f)28~V TO DATE REV BY COMMENTS DATE REV BY COMMENTS 01/14/80 ORIGINAL COMPLETION 09/16/04 MSE PROPOSED CTD ST OS/21/00 CRM CTD HORIZ SDTRK COMPLET 03/06/01 SIS-MH CONVERTED TO CANVAS 03/10/01 SIS-MD FINAL 03/04/02 RNITP CORRECTIONS PRUDHOE BAY UNrr WELL: F-11B ÆRMrr No: API No: 50-029-20424-02 SEC2, T11N, R13E BP Exploration (Alaska) Plan: Plan #2 (F-11/Plan#2 F-11B) Created By: Brij Potnis Date: 9/29/2004 Cnniacllnfom¡¡:'IUorr D¡re(;t; (907) 267-6613 (-mail: b¡ij,potnrs@intcq,ccm Baker Hughes INTEQ~ (907) 267~6t-¡OO Azimuths to True North Magnetic North: 25.03' Magnetic Field Strenth: 57615nT D~at;gò1~~~:; Model: bggm2004 M ft T ~:~~ ~Þ:~~l) Plan#2 F-11B Plan #2 BP Amoco WELLPATH DETAILS PIaIl#ZF.11. aoOU2042402 P.....t W"lp"hl P-11 TI.o.MDt "00.00 ... 11111 1212711811 00180 11.71ft Itef.O't..... V.s.-ctiH ~':t~ ~~ ::::Ttm ....,. 230.00' .... . ...1400::' c: i! 130' o ~1201 .... +1101 - .c: 1:: 1001 o Z 901 - - . - .c: .. ::I o en T..... - =:: ~ 66.76 SRTION DIETAILS s.~ MD IlK AzI TVD ....... .II-W DUI Th~. YSIoo: 1 .1100.00 18.37 78.1. .:au.1. 1018..... 1"8.03 0.00 0.00 -2130.M 2 .lN5.oo 18.01 75.77 1431.M 1021." 1.....3 0.80 1U.S' -21..... 3 8MS.00 1...1 75.77 84110... 1023.55 11t!14.81 8.00 0.00 -2158... i æ~=:::1 ~:ii =: 15E i:t¡; Å:: =:gg :: ¡ :g::: ~::= 338-:t: mt.u ~~ft I~::~Z U:&X =:gg :=:: 8 835Loo 1.... 31a.a7 "17.M 1128.57 2002.34 12.00 280.00 4257.38 10 N2Loo 1.... 2....3 8883.82 1137." 1M2.52 12.00 280.00 -22Mt... 11 11833.12 80.00 20!1.241 8..8.30 1140... 11SH.20 35.00 335.00 -2132.34 :i1æ~1i ::if ~~ :5t:: ~~arn 1æ:!1 1i:: =:: :!æ: 15 10343.12 80.18 23eA7 '''7.10 801." 1ÞG.38 12.00 110.00 -1as... , r' l' 1X1"- J' . 1"'" -- 1ONo.OI)ulNðfAtfð1II1 '''3.84 18 1040.02 12."ARIIEIf.HTAlUØ74." MD A._"ttow :; 1:: 2:: ~¡ :~Iä jm~ 890i5.oo 1132.85 18911.49 "'7.1' .....74 1113.&4 ë'84 i! 85' o !2.8550 .c: .. 1CL81 CÞ CI iã u :e CÞ > CÞ 2 ... REFERENCE INFORMATION WeU Centre: F·11. True North System: Mean Sea Level ~\~; {i ~2~1~~90gg!OO Minimum Curvature Nlm. ~:m~1 F·11BF...tI3 F.11BFd2 F.11BT2.3 f-lIBTH F_1tBTU F-l1BT2.t Co-~~Jr~r ~~ ~::~:~~ Section (VS) Reference: Measured Depth Reference: Calculation Method: 1:S...1. 1431.14 14SO." "'7.0S UIS.II ..)S.IO .....1& aU1." "17.14 UI3..2 "".30 "U.07 "'1.2' . -400 -450 -500 -550 -600 -650 -700 -750 -800 -850 1400 1600 1700 181 West(-)/East(+) [100ft/in] -900 ,·-¡i··'··· . I ' TTTTTT',rT1T T ,.T. """', -2300-2250 -2200 -2150 -2100 -2050-2000-1950 -1900-1850 -1 àoo -1750 -1700 -1650 -1600 -1550 -1500 -1450 -1400 -1350 -1300 -1250 -1200 -1150 -1100 -1Ò50 -1ÒOO Vertical Section at 230.00· [50ft/in] . . BP-GDB Baker Hughes INTEQ Planning Report Field: Prudhoe Bay 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: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5972527.29 ft 650960.70 ft Latitude: 70 19 Longitude: 148 46 North Reference: Grid Convergence: 55.283 N 31.468 W True 1.15 deg Well: F-11 Slot Name: 11 F-11 Well Position: +N/-S 2044.37 ft Northing: 5974592.00 ft Latitude: 70 20 15.389 N +E/-W 1038.73 ft Easting : 651958.00 ft Longitude: 148 46 1.131 W Position Uncertainty: 0.00 ft Wellpath: Plan#2 F-11 B 500292042402 Current Datum: 11 : 11 12/27/197900:00 Magnetic Data: 9/29/2004 Field Strength: 57615 nT Vertical Section: Depth From (TVD) ft 31.26 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 F-11 8900.00 ft Mean Sea Level 25.03 deg 80.86 deg Direction deg 230.00 Height 66.76 ft Targets F-11 B Polygon2.1 0.00 1060.62 2106.08 5975695.00 654042.00 70 20 25.817 N 148 44 59.611 W -Polygon 1 0.00 1060.62 2106.08 5975695.00 654042.00 70 20 25.817 N 148 44 59.611 W -Polygon 2 0.00 1298.76 1904.85 5975929.00 653836.00 70 20 28.160 N 148 45 5.487 W -Polygon 3 0.00 1184.47 1473.41 5975806.00 653407.00 70 20 27.037 N 148 45 18.091 W -Polygon 4 0.00 1008.23 1186.76 5975624.00 653124.00 70 20 25.304 N 148 45 26.465 W -Polygon 5 0.00 704.90 952.55 5975316.00 652896.00 70 20 22.321 N 148 45 33.308 W -Polygon 6 0.00 266.56 913.66 5974877.00 652866.00 70 20 18.010 N 148 45 34.445 W -Polygon 7 0.00 281.03 1187.03 5974897.00 653139.00 70 20 18.152 N 148 45 26.461 W -Polygon 8 0.00 607.39 1222.65 5975224.00 653168.00 70 20 21.362 N 148 45 25.419 W -Polygon 9 0.00 1009.31 1577.89 5975633.00 653515.00 70 20 25.314 N 148 45 15.040 W F-11B Fault 1 0.00 1335.16 405.17 5975935.00 652336.00 70 20 28.520 N 148 45 49.295 W -Polygon 1 0.00 1335.16 405.17 5975935.00 652336.00 70 20 28.520 N 148 45 49.295 W -Polygon 2 0.00 1493.32 794.48 5976101.00 652722.00 70 20 30.075 N 148 45 37.922 W -Polygon 3 0.00 1534.80 1067.40 5976148.00 652994.00 70 20 30.483 N 148 45 29.950 W -Polygon 4 0.00 1911.57 1429.13 5976532.00 653348.00 70 20 34.188 N 148 45 19.380 W -Polygon 5 0.00 2034.59 2071.81 5976668.00 653988.00 70 20 35.396 N 148 45 0.604 W -Polygon 6 0.00 1911.57 1429.13 5976532.00 653348.00 70 20 34.188 N 148 45 19.380 W -Polygon 7 0.00 1534.80 1067.40 5976148.00 652994.00 70 20 30.483 N 148 45 29.950 W -Polygon 8 0.00 1493.32 794.48 5976101.00 652722.00 70 20 30.075 N 148 45 37.922 W F-11B Fault 3 0.00 782.70 1703.34 5975409.00 653645.00 70 20 23.085 N 148 45 11.377 W -Polygon 1 0.00 782.70 1703.34 5975409.00 653645.00 70 20 23.085 N 148 4511.377 W -Polygon 2 0.00 1310.44 1377.94 5975930.00 653309.00 70 20 28.276 N 148 45 20.879 W F-11 B Fault 2 0.00 987.97 1002.30 5975600.00 652940.00 70 20 25.105 N 148 45 31.853 W -Polygon 1 0.00 987.97 1002.30 5975600.00 652940.00 70 20 25.105 N 148 45 31.853 W -Polygon 2 0.00 655.24 1181.61 5975271.00 653126.00 70 20 21.832 N 148 45 26.617 W -Polygon 3 0.00 384.95 1488.22 5975007.00 653438.00 70 20 19.173 N 148 45 17.663 W -Polygon 4 0.00 655.24 1181.61 5975271.00 653126.00 70 20 21.832 N 148 45 26.617 W F-11B T2.3 8986.00 719.79 1105.90 5975334.00 653049.00 70 20 22.467 N 148 45 28.828 W . . BP-GDB Baker Hughes INTEQ Planning Report F-11BT2.4 8990.00 268.88 1045.74 5974882.00 652998.00 70 20 18.033 N 148 45 30.587 W F-11B T2.2 8991.00 1092.93 1548.58 5975716.00 653484.00 70 20 26.136 N 148 45 15.896 W F-11B T2.1 8995.00 1132.85 1898.49 5975763.00 653833.00 70 20 26.528 N 148 45 5.674 W Annotation 8900.00 8389.19 TIP 8945.00 8431.94 KOP 8965.00 8450.86 end 9 DLS / begin 12 DLS 9015.00 8497.05 4 9090.00 8565.89 5 9165.00 8635.90 6 9228.00 8695.18 7 9288.00 8751.86 8 9358.00 8817.94 9 9428.00 8883.92 end 12 DLS / begin 35 DLS 9633.12 8995.30 end 35 DLS / begin 12 DLS 9683.12 8995.07 12 9908.12 8991.28 13 10158.12 8987.79 14 10343.12 8987.19 15 10493.12 8986.74 16 10950.00 8983.84 TO Plan: Plan #2 Date Composed: 9/29/2004 Identical to Mary's Plan #2 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 8900.00 18.37 75.19 8389.19 1018.44 1935.03 0.00 0.00 0.00 0.00 8945.00 18.01 75.77 8431.94 1021.96 1948.63 0.90 -0.80 1.29 153.58 8965.00 19.81 75.77 8450.86 1023.55 1954.91 9.00 9.00 0.00 0.00 9015.00 25.18 68.71 8497.05 1029.50 1973.05 12.00 10.74 -14.11 330.00 9090.00 22.01 47.52 8565.89 1044.81 1998.34 12.00 -4.23 -28.26 240.00 9165.00 20.65 22.88 8635.90 1066.53 2013.87 12.00 -1.81 -32.85 250.00 9228.00 19.35 0.98 8695.18 1087.23 2018.38 12.00 -2.06 -34.77 250.00 9288.00 19.39 339.16 8751.86 1106.51 2015.00 12.00 0.07 -36.37 260.00 9358.00 19.68 313.87 8817.94 1125.57 2002.34 12.00 0.42 -36.12 260.00 9428.00 19.95 288.93 8883.92 1137.64 1982.52 12.00 0.38 -35.63 260.00 9633.12 90.00 265.26 8995.30 1140.96 1826.20 35.00 34.15 -11.54 335.00 9683.12 90.52 271.24 8995.07 1139.43 1776.25 12.00 1.04 11.95 85.00 9908.12 91.37 244.25 8991.28 1092.11 1558.44 12.00 0.38 -12.00 272.00 10158.12 90.19 214.27 8987.79 930.81 1371.21 12.00 -0.47 -11.99 268.00 10343.12 90.18 236.47 8987.19 801.64 1240.38 12.00 -0.01 12.00 90.00 10493.12 90.17 218.47 8986.74 700.65 1130.31 12.00 -0.01 -12.00 270.00 10950.00 90.50 163.64 8983.84 269.18 1046.02 12.00 0.07 -12.00 270.50 . . BP-GDB Baker Hughes INTEQ Planning Report 8900.00 18.37 75.19 8389.19 1018.44 1935.03 5975649.36 653871.86 -2136.96 0.00 0.00 TIP 8925.00 18.17 75.51 8412.93 1020.42 1942.62 5975651.50 653879.40 -2144.04 0.90 153.58 MWD 8945.00 18.01 75.77 8431.94 1021.96 1948.63 5975653.16 653885.38 -2149.64 0.90 153.27 KOP 8950.00 18.46 75.77 8436.69 1022.34 1950.15 5975653.57 653886.89 -2151.05 9.00 0.00 MWD 8965.00 19.81 75.77 8450.86 1023.55 1954.91 5975654.88 653891.63 -2155.48 9.00 0.00 end 9 DL 8975.00 20.86 74.08 8460.24 1024.46 1958.27 5975655.85 653894.96 -2158.63 12.00 330.00 MWD 9000.00 23.54 70.51 8483.38 1027.34 1967.26 5975658.92 653903.89 -2167.37 12.00 331.58 MWD 9015.00 25.18 68.71 8497.05 1029.50 1973.05 5975661.19 653909.64 -2173.20 12.00 334.89 4 9025.00 24.60 66.22 8506.12 1031.11 1976.94 5975662.88 653913.49 -2177.21 12.00 240.00 MWD 9050.00 23.34 59.50 8528.97 1035.73 1985.97 5975667.68 653922.43 -2187.09 12.00 242.27 MWD 9075.00 22.40 52.17 8552.01 1041.16 1994.00 5975673.28 653930.35 -2196.74 12.00 248.40 MWD 9090.00 22.01 47.52 8565.89 1044.81 1998.34 5975677.02 653934.61 -2202.41 12.00 255.16 5 9100.00 21.63 44.46 8575.18 1047.40 2001.01 5975679.65 653937.23 -2206.11 12.00 250.00 MWD 9125.00 20.93 36.41 8598.48 1054.28 2006.89 5975686.65 653942.96 -2215.04 12.00 252.84 MWD 9150.00 20.63 27.99 8621.86 1061.76 2011.61 5975694.23 653947.53 -2223.47 12.00 260.34 MWD 9165.00 20.65 22.88 8635.90 1066.53 2013.87 5975699.04 653949.70 -2228.27 12.00 268.22 6 9175.00 20.27 19.63 8645.27 1069.79 2015.14 5975702.32 653950.90 -2231.34 12.00 250.00 MWD 9200.00 19.60 11.04 8668.77 1077.98 2017.40 5975710.56 653952.99 -2238.33 12.00 253.05 MWD 9225.00 19.35 2.07 8692.35 1086.24 2018.35 5975718.84 653953.78 -2244.37 12.00 261.12 MWD 9228.00 19.35 0.98 8695.18 1087.23 2018.38 5975719.83 653953.78 -2245.03 12.00 269.59 7 9250.00 19.07 353.00 8715.96 1094.45 2018.00 5975727.03 653953.26 -2249.38 12.00 260.00 MWD 9275.00 19.16 343.83 8739.58 1102.44 2016.36 5975734.99 653951.46 -2253.26 12.00 267.54 MWD 9288.00 19.39 339.16 8751.86 1106.51 2015.00 5975739.03 653950.02 -2254.83 12.00 276.20 8 9300.00 19.19 334.84 8763.18 1110.16 2013.45 5975742.65 653948.40 -2255.99 12.00 260.00 MWD 9325.00 19.11 325.69 8786.80 1117.26 2009.40 5975749.66 653944.20 -2257.45 12.00 264.08 MWD 9350.00 19.47 316.67 8810.41 1123.67 2004.23 5975755.97 653938.90 -2257.61 12.00 272.72 MWD 9358.00 19.68 313.87 8817.94 1125.57 2002.34 5975757.83 653936.98 -2257.39 12.00 281.24 9 9375.00 19.43 307.82 8833.96 1129.29 1998.05 5975761.46 653932.61 -2256.49 12.00 260.00 MWD 9400.00 19.43 298.79 8857.55 1133.85 1991.12 5975765.88 653925.59 -2254.11 12.00 265.70 MWD 9425.00 19.87 289.96 8881.10 1137.30 1983.48 5975769.17 653917.88 -2250.48 12.00 274.22 MWD 9428.00 19.95 288.93 8883.92 1137.64 1982.52 5975769.49 653916.91 -2249.96 12.00 282.54 end 12 D 9450.00 27.11 281.79 8904.08 1139.88 1974.05 5975771.57 653908.40 -2244.91 35.00 335.00 MWD 9475.00 35.51 277.04 8925.42 1141.94 1961.24 5975773.36 653895.55 -2236.42 35.00 341.56 MWD 9500.00 44.04 273.93 8944.62 1143.43 1945.33 5975774.53 653879.62 -2225.19 35.00 345.63 MWD 9525.00 52.62 271.65 8961.23 1144.31 1926.70 5975775.03 653860.97 -2211.49 35.00 348.03 MWD 9550.00 61.24 269.85 8974.86 1144.57 1905.77 5975774.87 653840.05 -2195.62 35.00 349.55 MWD 9575.00 69.88 268.32 8985.19 1144.19 1883.04 5975774.03 653817.33 -2177.97 35.00 350.53 MWD 9577.40 70.71 268.18 8986.00 1144.13 1880.78 5975773.92 653815.07 -2176.19 35.00 351.17 F-11B T 9591.15 75.47 267.42 8990.00 1143.62 1867.64 5975773.15 653801.94 -2165.80 35.00 351.21 F-11BT 9595.34 76.92 267.20 8991.00 1143.43 1863.58 5975772.87 653797.89 -2162.56 35.00 351 .43 F-11B T 9600.00 78.53 266.95 8991.99 1143.20 1859.03 5975772.55 653793.34 -2158.93 35.00 351 .49 MWD 9625.00 87.19 265.67 8995.10 1141.60 1834.30 5975770.45 653768.65 -2138.96 35.00 351.54 MWD 9633.12 90.00 265.26 8995.30 1140.96 1826.20 5975769.64 653760.57 -2132.34 35.00 351.70 end 35 D 9650.00 90.18 267.28 8995.27 1139.86 1809.36 5975768.21 653743.76 -2118.74 12.00 85.00 MWD 9675.00 90.44 270.27 8995.14 1139.32 1784.37 5975767.16 653718.79 -2099.25 12.00 85.00 MWD 9683.12 90.52 271.24 8995.07 1139.43 1776.25 5975767.10 653710.66 -2093.10 12.00 85.02 12 9700.00 90.59 269.21 8994.90 1139.50 1759.37 5975766.83 653693.79 -2080.21 12.00 272.00 MWD 9725.00 90.70 266.21 8994.62 1138.50 1734.40 5975765.33 653668.84 -2060.44 12.00 271.98 MWD 9750.00 90.80 263.22 8994.30 1136.20 1709.51 5975762.52 653644.01 -2039.89 12.00 271.95 MWD 9775.00 90.89 260.22 8993.93 1132.60 1684.78 5975758.42 653619.35 -2018.63 12.00 271.91 MWD 9800.00 90.99 257.22 8993.52 1127.71 1660.27 5975753.03 653594.95 -1996.71 12.00 271.86 MWD 9825.00 91.08 254.22 8993.06 1121.54 1636.04 5975746.38 653570.86 -1974.19 12.00 271.81 MWD 9850.00 91.18 251.22 8992.57 1114.12 1612.18 5975738.47 653547.15 -1951.14 12.00 271.76 MWD . . BP-GDB Baker Hughes INTEQ Planning Report 9875.00 91.26 248.22 8992.04 1105.45 1588.74 5975729.34 653523.89 -1927.62 12.00 271.70 MWD 9900.00 91.35 245.22 8991.47 1095.58 1565.78 5975719.00 653501.14 -1903.68 12.00 271.64 MWD 9908.12 91.37 244.25 8991.28 1092.11 1558.44 5975715.38 653493.87 -1895.83 12.00 271.57 13 9925.00 91.30 242.22 8990.88 1084.51 1543.37 5975707.48 653478.97 -1879.40 12.00 268.00 MWD 9950.00 91.19 239.22 8990.34 1072.29 1521.58 5975694.82 653457.42 -1854.85 12.00 267.95 MWD 9975.00 91.08 236.22 8989.84 1058.95 1500.45 5975681.05 653436.57 -1830.08 12.00 267.89 MWD 10000.00 90.97 233.23 8989.40 1044.51 1480.04 5975666.21 653416.46 -1805.18 12.00 267.83 MWD 10025.00 90.85 230.23 8989.00 1029.03 1460.42 5975650.34 653397.16 -1780.19 12.00 267.77 MWD 10050.00 90.73 227.23 8988.66 1012.54 1441.63 5975633.47 653378.71 -1755.20 12.00 267.73 MWD 10075.00 90.61 224.23 8988.37 995.10 1423.73 5975615.67 653361.17 -1730.28 12.00 267.69 MWD 10100.00 90.48 221.23 8988.13 976.74 1406.77 5975596.97 653344.59 -1705.48 12.00 267.65 MWD 10125.00 90.36 218.24 8987.95 957.51 1390.79 5975577.43 653329.00 -1680.89 12.00 267.62 MWD 10150.00 90.23 215.24 8987.82 937.48 1375.84 5975557.10 653314.46 -1656.56 12.00 267.60 MWD 10158.12 90.19 214.27 8987.79 930.81 1371.21 5975550.33 653309.96 -1648.72 12.00 267.59 14 10175.00 90.19 216.29 8987.73 917.03 1361.46 5975536.36 653300.50 -1632.40 12.00 90.00 MWD 10200.00 90.19 219.29 8987.65 897.28 1346.15 5975516.30 653285.59 -1607.97 12.00 90.01 MWD 10225.00 90.19 222.29 8987.57 878.35 1329.82 5975497.05 653269.65 -1583.29 12.00 90.02 MWD 10250.00 90.19 225.29 8987.49 860.31 1312.52 5975478.66 653252.72 -1558.44 12.00 90.03 MWD 10275.00 90.18 228.29 8987.41 843.19 1294.30 5975461.18 653234.85 -1533.48 12.00 90.04 MWD 10300.00 90.18 231.29 8987.33 827.06 1275.21 5975444.66 653216.09 -1508.49 12.00 90.05 MWD 10325.00 90.18 234.29 8987.25 811.94 1255.30 5975429.15 653196.50 -1483.52 12.00 90.06 MWD 10343.12 90.18 236.47 8987.19 801.64 1240.38 5975418.55 653181.79 -1465.48 12.00 90.06 15 10350.00 90.18 235.64 8987.17 797.80 1234.68 5975414.60 653176.17 -1458.64 12.00 270.00 MWD 10375.00 90.17 232.64 8987.10 783.16 1214.42 5975399.55 653156.21 -1433.71 12.00 270.00 MWD 10400.00 90.17 229.64 8987.02 767.48 1194.96 5975383.48 653137.07 -1408.71 12.00 269.99 MWD 10425.00 90.17 226.64 8986.94 750.80 1176.34 5975366.42 653118.80 -1383.73 12.00 269.98 MWD 10450.00 90.17 223.64 8986.87 733.16 1158.62 5975348.44 653101.44 -1358.82 12.00 269.97 MWD 10475.00 90.17 220.64 8986.79 714.63 1141.85 5975329.57 653085.05 -1334.06 12.00 269.96 MWD 10493.12 90.17 218.47 8986.74 700.65 1130.31 5975315.36 653073.79 -1316.24 12.00 269.95 16 10500.00 90.17 217.64 8986.72 695.24 1126.07 5975309.86 653069.67 -1309.51 12.00 270.50 MWD 10525.00 90.20 214.64 8986.64 675.05 1111.33 5975289.39 653055.34 -1285.24 12.00 270.50 MWD 10550.00 90.23 211.64 8986.55 654.12 1097.66 5975268.18 653042.10 -1261.32 12.00 270.49 MWD 10575.00 90.25 208.64 8986.44 632.51 1085.11 5975246.32 653029.99 -1237.81 12.00 270.48 MWD 10600.00 90.27 205.64 8986.33 610.26 1073.71 5975223.85 653019.04 -1214.78 12.00 270.46 MWD 10625.00 90.30 202.64 8986.20 587.45 1063.48 5975200.84 653009.28 -1192.28 12.00 270.45 MWD 10650.00 90.32 199.64 8986.07 564.14 1054.47 5975177.35 653000.74 -1170.39 12.00 270.44 MWD 10675.00 90.34 196.64 8985.93 540.38 1046.68 5975153.44 652993.44 -1149.16 12.00 270.42 MWD 10700.00 90.36 193.64 8985.77 516.25 1040.16 5975129.19 652987.40 -1128.65 12.00 270.40 MWD 10725.00 90.38 190.64 8985.61 491.82 1034.90 5975104.65 652982.64 -1108.91 12.00 270.38 MWD 10750.00 90.40 187.64 8985.44 467.14 1030.93 5975079.90 652979.17 -1090.01 12.00 270.36 MWD 10775.00 90.42 184.64 8985.26 442.28 1028.25 5975055.00 652977.00 -1071.98 12.00 270.34 MWD 10800.00 90.43 181.64 8985.08 417.33 1026.88 5975030.02 652976.14 -1054.89 12.00 270.32 MWD 10825.00 90.45 178.64 8984.88 392.33 1026.82 5975005.03 652976.58 -1038.77 12.00 270.30 MWD 10850.00 90.46 175.64 8984.69 367.36 1028.07 5974980.09 652978.34 -1023.68 12.00 270.28 MWD 10875.00 90.47 172.64 8984.48 342.50 1030.62 5974955.29 652981.39 -1009.65 12.00 270.25 MWD 10900.00 90.49 169.64 8984.27 317.80 1034.47 5974930.67 652985.74 -996.73 12.00 270.23 MWD 10925.00 90.50 166.64 8984.06 293.34 1039.61 5974906.32 652991.37 -984.94 12.00 270.20 MWD 10950.00 90.50 163.64 8983.84 269.18 1046.02 5974882.30 652998.27 -974.32 12.00 270.18 TO Nordic 1 big hole All Measurements are from top of Riser :I.... CD (f) .- cr: op of bag bttm of bag middle of slips Blind/Shears .......................... middle of pipes middle of flow cross middle of blind/shears middle of pipe/slips Flow Tee 9/28/2004 BAG 7 1/16" 5000psi TOTs 7 1/16" 5000psi Mud Cross 7 1/16" 5000psi TOTs 7 1/16" 5000psi TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 153 DATE Cff ~;29 ,0 ~ :;~~i'pOr¡<E ~~~ / w~' $ /Cð. éb £2,tQ ~ CD (1\J DdITARS - First ational Bank Alaska An,,,,,,.,., AK 99501 ~ - ði? ~ MEM08~ 0JL<...p . "Mastercard Check" . 1:.25 2000(;OI:~~ .l.III(; 2 27111.55(;11- O.5:1i e . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME It 11 ¡:: //fi 2oJl-lfi X Development Service PTD# Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLJES (OPTIONS) MULTI Tbe permit is for a new wenboresegment of LATERAL existing weD . Permit No, API No. . (If API number Production. sbould continue to be reported as last two. (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated "in botb name (name on permit plus PH) .. and API Dumber (50 - 70/80) from records, data and Jogs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION .' compliance with 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of ;'! conservation order approving a spacing e:J ception. (Company Name) assumes tbe liability of any prOt est to tbe spacing .e:Jception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater -tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample inter-vals througb target zones. .' Field & Pool PRUDHOEBAY,PRUDHOEOIL-640150 Well Name: PRUDHOE BAY UNIT F-11B Program DEV Well bore seg D PTD#:2041940 Company BPEXPLORATION(ALASKA)INC InitialClasslType DEV/1-0IL GeoArea 890 Unit 11650 On/OffShore On Annular Disposal D Administration 1 Pe(ll)itfee attacheo_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 2 _LeasenIJmber _appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ . . . _ _ _ . . . . . . . Yes _ _ _ _ _ _ . . _ _ _ _ _ . . . _ _ _ _ . . . _ . _ _ _ _ . . . . _ _ _ . . . . . _ _ _ _ . . _ _ 3 .U.nlqIJe weltn.ame.aod oumb.er . _ . . . . . . _ _ . _ . . . . _ _ . . . . . . . _ . . . . . . . . . . . . Yes _ _ . . . . . . _ _ . . . . . _ . _ . . . . _ _ . . . . _ _ _ . . . . . . _ _ _ _ . . . . . . . _ . . _ . . . . _ _ . . . . . . . _ _ . . . . _ . . . 4 WellJQcated lna.clefine.dpoo _ _ _ _ . . . _ _ _ _ _ . . . _ _ _ _ . . . . _ _ _ _ _ . . . . . _Yes _ _ _ . . . . . _ _ _ . . _. _.... _ _ _ . . . . . _ _ _ _ . . . _ _ _ _ _ _ _ _ _ . . . _ _ _ . . . . . _ 5 WeJUQcated proper .dlstaoce from driJling unilb9IJnd>'ll)'. _ _ . . . . . _ _ _ _ _ _ . . . _ _ _ _ _ _ _ Yes _ _ _ _ . . . _ _ _ _ _ _ . . . _ _ _ . . . . . _ _ _ _ . . . .' _ _ _ _ _ _ . . _ _ _ _ . _ . . . . _ _ _ . . . . . _ _ _ . . . 6 WellJQcated pr.oper .dlstaoceJrom other welJs. . . . _ _ _ _ . .. _ _ . _ . . . . _ _ _ . _ . . . . _ Yes _ _ . . . . _ . _ _ _ _ . . _ . . . . _ . _ _ _ . . .. _ _ _ . . . _ _ . _ . . . 7 _S.utficient.acreage_ayailable lndrilliog unjt. _ _ _ _ . . . . . _ _ _ . . . . . . _ . Yes _ _ _ _ _ . . . _ _ _ . . . . _ _ _ . . . . _ _ _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ . . . . _ 8 Jtdeviated, js. weJlbQre platincJu_ded _ _ _ . . .. _ _ _ _ . . . _ _ _ _ _ . . . . _ . Yes _ _ _ _ . . . _ _ _ . . . . _ _ _ _ _ _ . . . . _ _ . . .. _ _ _ . . . . 9 .Operator onl}' affected party. . . _ _ _ . . . _ . _ . . . . _ _ _ . . . . . . _ Yes. . _ _ _ _ . . . _ _ . . . . _ _ _ _ _ . . . . . _ _ _ _ . . _ 10 .Operator bas.approprlate.bond inJQr~ . . . . . _ _ _ . . . . _ _ . . . . . . . _ _ . . . . . . . . _ . Yes. . . _ . . . . . . _ _ . . . . . . _ . . . . . . _ . . . . . _ _ _ . . . . . . . . _ . . . . . . . _ . _ _ . . . . _ _ _ . . . . . . . . . . . . . . 11 PelJTJitc.aoÞeissuedwjthQutconservationQrder_ _ Yes. _ _ _ _ _.... _ _ _ _ _ _.... _ _ _ _ _ _.. _ .. _ _... Appr Date 12 Permitc.ao Þe issued wjthQut administratÌlleapprovaJ . . . _ _ . . . . . _ . _ _ _ _ . . . . . Yes _ . _ _ _ _ _ . . . _ _ . . .. _ _ _ _ _ . . . . _ _ _ _ _ _ _ . . . _ _ _ _ . . . _ . _ _ _ . . . . . _ _ _ _ . . _ RPC 9/30/2004 13 Can permit be approved before 15-daywait Yes 14 WeJUQcated within area and_strataaIJthorized byJojectioo Order # (PutlO# incomm_eots). (FQrNA . _ . _ _ _ . . _ . . _ _ _ _ _ . . . . . . . . . _ 15 AJI welJs.withlnJI4.llJile.area_of reyieW ideotlfied (For servjcewell onl}'). . . . . . . _ . . . . . _ . NA . . . . . . . . . . . . . . _ . . . . . . _ . . . . . _ . . . . . . . . . _ . . . . . . . . _ . . . . . . . . . . . . . . . _ . . . . . . . _ . . . . 16 Pre-produJ;ecliojector; OIJratiQn.ofpre-proolJction less than 3 months_(For.service well QnJy) . _NA . . _ _ _. _ . . _ _ _ _ . . ... _ _ _ .. . . . ... . . . 17 ACMP.F:ïndingofCQnsisteocyhas Þee.nJssIJed.forJbis proiect _ .NA . . . . _ _ . _ . . . _ _ _ _ _ . . . . . . _ . . . _ Engineering Appr Date WGA 9/30/2004 Geology Appr RPC Date 9/30/2004 Geologic Commissioner: f)J~ . 18Coodu.ctor st(ingprQvided . . . . _ . . . . . . . . . . _ _ . . . . _ . NA _ _ _ . . . . _ _ _ _ . . . . . _ _ _ _ . . . . . _ . . . . . . _ _ _ _ _ . . . . _ _ _ . . . . . . _ _ . _ . . 19Surface.casing.protecJs all.known USDWs . _ _ _ . . . . . . _ _ _ . . . . . NA . . _ _ _ _ _ . . . _ _ . . . . . _ _ . . . . . _ _ _ _ . .. _ _ _ _ _ . _ . . . . . _ _ . . . . . _ . . . 20CMT v.ol adeQuateJo circ.utate oncond.uctor &. SUJf. csg . _ . _ _ . . _ . _ . _ _ . _ _ _ _ _ _ . _ _ . NA _ _ _ _ . . . _ _ . . . _ . . . _ . _ . . _ . _ _. _ _ . . . _ _ _ . . . _ _ _ _ _ _ _ . _ _ _ 21 .CMT vol adeQu.ateJo tie-inJQng .string to.SIJrf ~g. . _ . . . . _ NA _ _ _ _ . . . . . . . _ . _ . _ _ _ _ _ . _ . . . _ _ . _ _ . . _ . . _ _ . _ _ . 22CMTwill coyeraJl koown-PfodlJctiye bQri4!:ons _ _ _ . . . . _ _ . _ . . . . . . _ _ _ . . . _ Yes. _ . _ _ _ . . . . _ _ _ _ . . .. _ _ . . . _ . . . . _ . _ _ _ . . . _ ....... _ _ 23C_asiog designs aclequaJe for C,T~ B.&.perllJafr_ost . . _ . . . . . _ . _ _ _ _ .. _ Yes _ _ . . . . _ _ . . _ . _ _ _ _ . . . _ _ _ 24 .Adequate.tan_kage.oJ reServe pit _ . _ . . . . . _ . _ _ _ . . Yes _ CTDU.. . . . . . . _ _ _ . _ . . _ . . . _ . . _ . _ _ _ _ _ _ . _ _ . . . . _ _ . _ _ _ . . . . . . _ _ _ . . _ . 25 JtaJe-orilL hasa. 10,403 fQr abandonment beeo apprQved . . _ . . _ _ _ . . .. .. _ . . . . Yes _ _ . _ _ _ _ . . . . . . _ . . . 26 .Adequatewellboreseparatjon-PfOp9sed.... _ _ . . . . . . _ _ . . . . . . . _ . . . . . . _ _ . . . Yes. . . . . . . _ _ . . . . . . _ _ . . . . . . _ . . . . . _ . . . . . . . _ _ _ . . . . . _ . _ . . . . . . . _ _ _ . . . . . . . . _ . . . . . . . . 27 Jf.djverter required, dQes jt.meet reguJations. _ _ _ . . . _ _ _ _ . . . _ . . _ . . . . . . _ _ . . . . .NA . _ _ Sidetrack. _ . . . . .. _ _ . . . _ _ _ . . . .. . _ _ _ . . . _ . _ 28 Drilliogfluid.prQgramSGhematic&eq.uipJistadequale. . _ _ _ _..... . _ _ _ _.... Yes_ _ _MaxMW8Jppg,.. _ _... _ ...... _ _... _ _. _.. _ _...... 29 .BOPEs, do they meet reguJation .. _. _ . . . . _ . . . . . . _ _ _ _ . . . . Yes. _ _ _ . . . . . . . . . . . . _ . _ _ . . . _ _ . . . _ . _ _ . . . . . . _ 30 BOPEpress ratiog appropriate; test to.(puJ psig in.comments) . _ . _ . . . . _ _ _ . . . . Yes. _ Test lo.350Qpsi. _MSF> 22.00 psi.. _ _ _ . . . . . _ . _ . .. . _ . _ . . . . . . . . . . . . . 31Choke.llJanjfold cQmpJies w/APIR.F>-5HMay 84). . _ _ _ . . . . . . _ . . . . . . _ _ _ . . . _ Yes _ _ _ . .. _ _ . . . . . . _ _ . . . . 32 WQrIç will occur withouLoperatjonsbutdown. _ _ . . . . _ . _ . . . . . . . _ _ . . . _ _ _ . .. . Yes _ . _ _ . . .. _ _ . . . . _ _ . . . . _ _ _ . . _ 33 .Is presence. Qf H2S gas. probaÞle _ . . _ _ _ . .. _ _ _ _ . . . . . _ _ _ . . . _ _ _ _ . . . . Yes. . . . _ _ _ 1 QO.ppmmax._ _ _ . . . _ 34 MechanicalC9odJtlon of wells within ,ð.OR yerified (For.s.ervice welJ onJy). . . _ _ _ _ . NA _ _ _ _ . . _ _ _ _ _ _ . . . _ _ _ . . . . _ _ _ _ . . . _ _ _ _ _ _ . . . _ _ _ _ _ . . . . . _ _ _ . . . . _ _ _ _ _ _ . . . . . _ _ _ _ . _ . - - - - ~ - - e - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit cao Þe issued wlo hydrogen. sulfide meaSjJres. . . _ . . . _ 36 .D.ata_preseoted on pote.ntial oveJpres_slJrezones .' . _ _ _ . . . . 37 _Selsmicanalysjs. Qf sbaJlow gas.zooes _ _ _ . . . . . . _ _ . . . . _ _ _ . _ . . . 38Seabeo .conditioo survey.(if off-shore) . . _ . _ _ . . . . . _ _ _ . . . . . . . _ _ . 39 . CQntact namelphoneJor_weelçly progress.reports [exploratol)'only] _ No.... __.... .NA... NAd .____..._ NA... .' NA - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - -- - - - - " - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date ;p~~ Date ()30 It e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, infonnation of this nature is accumulated at the end of the me under APPENDIX. No special effort has been made to chronologically organize this category of infonnation. . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 18 07:57:51 2005 Reel Header Service name............ .LISTPE Date.................... .05/02/18 Origin...... ............ .STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name. ......UNKNOWN Comments................ .STS LIS Writing Library. . c2& f-/l cf fr n tò2 Scientific Technical Services Tape Header Service name... ... ... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/18 Origin....... ............STS Tape Name............... . UNKNOWN Continuation Number. .... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA F-11B 500292042402 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 18-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 MW0003338369 B. JAHN D. HILDRETH/ MWDRUN 2 MW0003338369 B. JAHN D. HILDRETH/ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 MW0003338369 B. JAHN D. HILDRETH/ MWD RUN 5 MW0003338369 B. JAHN D. HILDRETH/ # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 llN 13E 2208 2869 66.76 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 8943.0 # REMARKS: MWDRUN 3 MW0003338369 B. JAHN D. HILDRETH/ MWDRUN 6 MW0003338369 B. JAHN D. HILDRETH/ 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. . . THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8943'MD IN THE ORIGINAL F-11 WELLBORE. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. TIE-IN SGRD DATA WERE ACQUIRED DURING MWD RUN 1. 5. MWD RUNS 4 - 6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). A MAD PASS WAS RUN AFTER RUN 4 TO ACQUIRE RESISTIVITY DATA OVER THE RUNS 1 - 3 INTERVAL. THESE MAD PASS DATA WERE MERGED WITH THE RUN 4 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN ON 20 OCTOBER 2004. THESE DIGITAL DATA WERE PROVIDED BY W TIFENTAL (SIS/BP) VIA E-MAIL ON 21 JANUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1 - 6 REPRESENT WELL F-11B WITH API#: 50-029-20424-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10969'MD/8995'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ SHIFT-DERIVED RESISTIVITY ( SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8921.5 8946.0 8946.0 8946.0 8946.0 8946.0 8968.5 STOP DEPTH 10929.0 10942.0 10942.0 10942.0 10942.0 10942.0 10973 .5 $ . . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8921.5 8935.0 8961.0 8976.5 8982.5 8985.5 9007.0 9014.0 9018.0 9030.0 9031.0 9041. 5 9054.0 9056.5 9060.0 9062.0 9066.0 9071.5 9075.0 9081.5 9089.0 9107.5 9110.0 9113.0 9124.0 9127.0 9130.0 9133.0 9135.0 9140.0 9146.0 9159.0 9161.5 9164.0 9167.0 9171.5 9190.5 9193.0 9195.0 9203.0 9207.5 9211.0 9220.5 9222.5 9245.5 9248.5 9250.5 9254.5 9257.0 9263.0 9265.5 9294.0 9300.0 9304.5 9316.0 9319.0 9332.0 9336.5 9348.0 9359.5 9376.0 9380.5 9385.5 9399.5 9465.0 9467.5 9477.5 9480.5 9483.5 9491.0 GR 8924.5 8938.0 8962.0 8978.5 8984.0 8986.0 9008.0 9014.5 9019.0 9031.5 9032.5 9042.5 9055.0 9058.5 9060.5 9063.0 9067.0 9072.5 9075.5 9081. 5 9089.0 9107.5 9110.0 9112.0 9125.5 9127.5 9130.0 9133.0 9135.0 9141.5 9147.0 9159.0 9162.0 9164.0 9167.5 9171.5 9190.5 9192.5 9195.0 9203.0 9207.5 9211.5 9221.5 9223.0 9244.5 9247.5 9250.0 9254.5 9256.5 9262.5 9265.0 9294.0 9299.5 9304.5 9316.0 9319.0 9332.0 9336.0 9348.0 9356.5 9375.5 9379.5 9385.0 9397.5 9463.0 9465.0 9477.0 9480.5 9481.5 9489.0 . . 9495.0 9507.0 9518.0 9535.0 9550.0 9560.0 9564.5 9570.5 9578.0 9624.0 9638.5 9657.0 9662.5 9670.5 9680.0 9704.5 9708.0 9713.0 9724.5 9729.5 9750.5 9757.0 9764.5 9770.0 9775.5 9782.5 9786.0 9831.5 9838.5 9849.0 9860.5 9883.5 9889.5 9906.5 9909.5 9938.5 9946.5 9959.0 9968.5 9991.0 10006.0 10023.5 10032.5 10053.5 10062.5 10069.5 10101.5 10103.5 10185.5 10199.0 10204.0 10210.0 10228.5 10267.5 10294.5 10307.0 10367.5 10373.5 10382.0 10389.0 10441.0 10443.5 10448.0 10450.0 10462.5 10480.0 10494.5 10529.5 10531.5 10556.5 10571.0 10576.5 10588.5 10606.5 10611.0 10630.5 9495.0 9506.5 9519.0 9535.5 9549.5 9560.0 9564.0 9571.0 9576.0 9623.5 9639.0 9659.0 9663.0 9669.0 9679.5 9704.0 9707.0 9711.5 9722.0 9727.0 9750.0 9754.5 9764.0 9768.0 9773 . 0 9782.0 9784.5 9832.0 9838.0 9848.5 9860.5 9883.0 9891.0 9907.0 9909.5 9939.0 9946.5 9959.0 9966.5 9991.0 10007.0 10022.0 10032.5 10052.5 10060.0 10067.5 10100.5 10102.0 10184.5 10198.0 10201.5 10206.0 10227.0 10264.5 10292.5 10305.5 10365.0 10371.0 10378.0 10383.5 10436.5 10438.0 10446.0 10447.5 10461.5 10479.5 10491.5 10526.5 10528.5 10554.0 10569.0 10573.5 10586.5 10604.0 10608.0 10626.0 . . 10644.5 10658.0 10670.5 10675.0 10679.5 10690.0 10706.0 10711.5 10718.5 10973.5 $ 10640.5 10653.0 10667.5 10673.5 10677.5 10688.5 10702.0 10706.5 10713.5 10968.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 5 6 MERGE TOP 8924.5 9207.0 9247.0 9420.0 9570.0 9620.0 MERGE BASE 9207.0 9247.0 9420.0 9570.0 9620.0 10968.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type. ... ..............0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units. . . . . . . . . . . Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8921. 5 10973.5 9947.5 4105 8921.5 10973.5 ROP MWD FT/H 0.08 1943.43 96 . 8115 4011 8968.5 10973.5 GR MWD API 16.56 773.79 46.4197 4016 8921. 5 10929 RPX MWD OHMM 0.1 2000 14.9427 3993 8946 10942 RPS MWD OHMM 0.39 2000 19.0584 3993 8946 10942 RPM MWD OHMM 0.1 2000 20.6687 3993 8946 10942 RPD MWD OHMM 0.18 2000 27.0362 3993 8946 10942 FET MWD HOUR 0.12 66.17 7.12987 3993 8946 10942 First Reading For Entire File......... .8921.5 Last Reading For Entire File.. ........ .10973.5 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. . . . . . .05/02/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 . Physical EOF File Header Service name... ..........STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record..65535 File Type..... ...........LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 8924.5 8970.0 STOP DEPTH 9177.0 9207.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ .Down 16 -OCT- 04 Insite 7.75 Memory 9207.0 8925.0 9207.0 18.0 23.9 TOOL NUMBER TLG005 4.250 8367.0 Flo-Pro 8.60 60.0 .0 19000 12.0 .000 .000 .000 .000 .0 129.0 .0 .0 . . Optical log depth units.......... .Feet Data ~eference Point......... .....Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Rap MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8924.5 9207 9065.75 566 8924.5 9207 Rap MWD010 FT/H 0.08 57.55 19.4836 475 8970 9207 GR MWD010 API 19.97 773.79 90.8019 506 8924.5 9177 First Reading For Entire File......... .8924.5 Last Reading For Entire File.......... .9207 File Trailer Service name...... ...... .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . La Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record..65535 File Type.... . . . . . .. . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9177.5 9207.5 STOP DEPTH 9216.5 9247.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 16-0CT-04 Insite 7.75 Memory 9247.0 9207.0 9247.0 20.0 20.0 # . TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............ .....Down Optical log depth units.......... .Feet Data Reference Point......... .....Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code TOOL NUMBER TLG005 4.250 8367.0 Flo-pro 8.60 .0 9.5 19000 7.6 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 133.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9177.5 9247 9212.25 140 9177.5 9247 ROP MWD020 FT/H 0.1 26.29 8.84737 80 9207.5 9247 GR MWD020 API 18.47 57.78 27.0494 79 9177.5 9216.5 First Reading For Entire File... .......9177.5 Last Reading For Entire File.... .......9247 File Trailer Service name. ............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/18 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF . File Header Service name... ...... ....STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 9217.0 9247.5 STOP DEPTH 9390.0 9420.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined 17-0CT-04 Insite 7.75 Memory 9420.0 9247.0 9420.0 19.6 21.7 TOOL NUMBER TLG005 4.125 8367.0 Flo-pro 8.60 .0 9.5 19000 8.0 .000 .000 .000 .000 .0 137.5 .0 .0 . . Frame Spacing..................... 60 .lIN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD030 MWD030 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9217 9420 9318.5 407 9217 9420 ROP MWD030 FT/H 1. 69 149.12 69.5359 346 9247.5 9420 GR MWD030 API 17.19 149.1 27.7418 347 9217 9390 First Reading For Entire File......... .9217 Last Reading For Entire File.... .......9420 File Trailer Service name...... ...... .STSLIB.004 Service Sub Level Name. . . version Number........ ...1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name..... .... ... .STSLIB.005 Service Sub Level Name.. . Version Number.... ...... .1.0.0 Date of Generation.. .....05/02/18 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPM RPS GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 8948.0 8948.0 8948.0 8948.0 8948.0 9390.5 9420.5 STOP DEPTH 9538.5 9538.5 9538.5 9538.5 9538.5 9525.5 9570.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 17-0CT-04 Insite 4.3 Memory 9570.0 9420.0 9570.0 . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... . . .............0 Data Specification Block Type.....O Logging Direction........ ........ . Down Optical log depth units.......... .Feet Data Reference Point....... ...... . Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units... . . . . . .. . . . . . . . . . . . . . Datum Specification Block sub-type...O 26.8 62.6 TOOL NUMBER 78012 171170 4.125 8367.0 Flo Pro 8.60 60.0 9.5 19000 8.0 .130 .070 .145 .200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD040 FT/H MWD040 API MWD040 OHMM MWD040 OHMM MWD040 OHMM MWD040 OHMM MWD040 HOUR Max 9570 120.54 99.31 2000 2000 2000 2000 66.17 Min 8948 1. 87 16.56 0.1 0.39 0.1 0.18 0.44 First Reading For Entire File... .......8948 Last Reading For Entire File.... .......9570 Mean 9259 59.374 29.4662 28.5921 40.9893 45.7644 65.4633 21. 6315 Nsam 1245 300 271 1182 1182 1182 1182 1182 . 65.0 135.3 65.0 65.0 First Reading 8948 9420.5 9390.5 8948 8948 8948 8948 8948 Last Reading 9570 9570 9525.5 9538.5 9538.5 9538.5 9538.5 9538.5 . . File Trailer Service name... .... ......STSLIB.005 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 Physical EOF File Header service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 9526.0 9539.0 9539.0 9539.0 9539.0 9539.0 9570.5 STOP DEPTH 9576.5 9589.5 9589.5 9589.5 9589.5 9589.5 9620.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-0CT-04 Insite 4.3 Memory 9620.0 9570.0 9620.0 73.5 73.5 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 78012 171170 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 8367.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: Flo-pro 8.60 60.0 9.1 19000 7.0 .130 .070 65.0 135.3 . . MUD FILTRATE AT MT: MUD CAKE AT MT: .140 .200 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units...... .....Feet Data Reference Point......... .....Undefined Frame Spacing........... ........ ..60 .1IN Max frames per record............ . Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9526 9620 9573 189 9526 9620 ROP MWD050 FT/H 1. 93 144.56 110.275 100 9570.5 9620 GR MWD050 API 23.21 105.01 36.2949 102 9526 9576.5 RPX MWD050 OHMM 6.54 12.74 9.7752 102 9539 9589.5 RPS MWD050 OHMM 8.59 12.67 11.2381 102 9539 9589.5 RPM MWD050 OHMM 9.68 13 .23 11.8627 102 9539 9589.5 RPD MWD050 OHMM 11.61 14.07 12.5835 102 9539 9589.5 FET MWD050 HOUR 0.23 6.51 4.22559 102 9539 9589.5 First Reading For Entire File......... .9526 Last Reading For Entire File....... ....9620 File Trailer Service name............ .STSLIB.006 Service Sub Level Name. . . version Number.......... .1.0.0 Date of Generation.......05/02/18 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . . LO Next File Name... ....... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/18 Maximum Physical Record. .65535 File Type......... . . . . . . . La Previous File Name...... .STSLIB.006 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 7 . header data for each bit run in separate files. 6 .5000 START DEPTH 9577.0 9590.0 9590.0 9590.0 9590.0 9590.0 9620.5 STOP DEPTH 10924.0 10937.0 10937.0 10937.0 10937.0 10937.0 10968.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. . . . . . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... . Feet Data Reference Point............. .Undefined Frame Spacing. . . . . . . . . . . . . . . . . . . . .60 .1IN Max frames per record..... ....... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 18 -OCT- 04 Insite 4.3 Memory 10969.0 9620.0 10969.0 82.3 95.6 TOOL NUMBER 78012 171170 4.125 8367.0 Flo-pro 8.60 60.0 9.5 19000 8.0 .220 .100 .175 .240 65.0 150.0 65.0 65.0 . . Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9577 10968.5 10272.8 2784 9577 10968.5 ROP MWD060 FT/H 0.61 1943.43 120.254 2697 9620.5 10968.5 GR MWD060 API 22.97 173 .58 42.9459 2695 9577 10924 RPX MWD060 OHMM 5.52 15.11 9.02033 2695 9590 10937 RPS MWD060 OHMM 6.27 14.84 9.60693 2695 9590 10937 RPM MWD060 OHMM 5.51 14.67 9.86856 2695 9590 10937 RPD MWD060 OHMM 6.88 14.75 10.4171 2695 9590 10937 FET MWD060 HOUR 0.12 5.58 0.827362 2695 9590 10937 First Reading For Entire File......... .9577 Last Reading For Entire File...........10968.5 File Trailer Service name.. ..... ......STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/18 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name..... ... .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ..... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name..... ....... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name..... ..... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File