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Suprv Comm ________ JBR 06/21/2022 InspectNo:susMFH220606132007 Well Pressures (psi): Date Inspected:6/5/2022 Inspector:Matt Herrera If Verified, How?LAT / LONG Suspension Date:12/13/2012 #312-311 Tubing:480 IA:0 OA:172 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:6/4/2022 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT 07-10A Permit Number:1980160 Wellhead Condition Good, fairly clean, all valves and gauges operational and SSV in place in the closed position. Wing Valve closed and LO/TO Surrounding Surface Condition Good, No stains or debris and no subsidence. Flowlines connected. Well house on well. Condition of Cellar Good, clean with no stains or debris. Ice in cellar but not covering annulus valves. Operator to vac out water upon thaw. Comments Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, June 21, 2022 9 9 9 9 9 3KRWRV$WWDFKHG 2022-0605_Suspend_PBU_07-10A_photos_mh Page 1 of 2 Suspended Well Inspection – PBU 07-10A PTD 1980160 AOGCC Inspection Rpt # susMFH220606132007 Photo by AOGCC Inspector M. Herrera 6/5/2022 2022-0605_Suspend_PBU_07-10A_photos_mhPage 2of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operati ns utdoym..-, --, ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Changed Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number 198-016 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20335-01-00 7. Property Designation (Lease Number): ADL 028309 8. Well Name and Number. PBU 07.10A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 13405 feet Plugs measured 7607, 9501, 11580 feet true vertical 9035 feet Junk measured None feet Effective Depth: measured 7607 feet Packer measured 9116, 9191 feet true vertical 7119 feet Packer true vertical 8332. 8387 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 34-113 34-113 1530 520 Surface 2676 13-3/8" 34-2710 34-2710 5380 2670 Intermediate 9396 9-5/8" 32-9428 32-8562 8150 / 6870 5080 / 4760 Liner 4434 7" 4994-9428 4982-8562 8160 7020 Liner 4156 4-1/2" 9243-13399 8426-9034 8430 7500 Perforation Depth: Measured depth: None feet True vertical depth. feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 / L-80 30-9247 30-8429 Packers and SSSV (type, measured and 4.1/2- Baker S-3 Penn Packer 9116 8332 true vertical depth) 4-1/2' Baker S-3 Penn Packer 9191' 8387 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13_ Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14. Attachments: peymra4 wr 20 MC 25.070,25.07, & 25 2831 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ 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 Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: SIM Speciali Contact Email: Trevis.MontgomeryAbp.wm Authorized Signature: D'wiiii"ll/I Contact Phone: +1 907 564 4127 Form 10.404 Revised 04/2017 Moll, 04'Row"2 RBDMS AUG 0 12019 Submit Original Only Daily Report of Well Operations 07-10A ACTIVITYDATF CI IMWIGRV T/I/O = 600/0/170. Temp = SI. Pre AOGCC SU well inspection. No AL. Wellhouse, wellhead and cellar are clean and dry. Surface area around well is clean, dry and clear of debris. Well ID sign on wellhouse. 6/30/2019 SV, SSV, MV = C. WV = LOTO. IA, OA = OTG. 00:20 TWO = SSV/0/150. Temp = SI. AOGCC SU well inspecrtion (Witnessed by Bob Noble). No AL. 7/6/2019 SV = C. WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 08:50 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 07-10A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1980160 API Number: 50-029-20335-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 12/13/2012 Surface Location: Section: 33 Twsp: 11N Range: 14E Nearest active pad or road: Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation 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: C tpr' n G,tcytI Location cleanup needed: NQ Zy7 Pits condition: 6- � ,q Surrounding area condition: C1c�GA Water/fluids on pad: n/nAo Discoloration, Sheens on pad, pits or water: NO Samples taken: None Access road condition: Photographs taken (# and 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: lit2' Cellar description, condition, fluids: pry Rat Hole: —eLJt1 Wellhouse or protectivetbarriers /r I I t-Intic Well identification sign: V*E< Tubing Pressure (or casing if nd tubing): Annulus pressures: A-) Wellhead Photos taken (# and description): -Sit .l, sn +: uired: Operator Rep (name and signature): Josh Prow nt AOGCC Inspector: (� Other O ervers. p Inspection Date ?is AOGCC Notice Date: Time of arrival: fjR'4S- Time of Departure: Site access method: Access Road OPERAtOR API NUMBER SUR LOCATION DRZJJNG PERM fr Apt .r6: r 7 aaaa'a ' Y aii: !a% r "NNNII� , L M I1II t � 1 15-04P13i`^ 15.03 } 15- 5-25BJ C C-39 _qf 15.04P81 18-23A 15-x3 iv -�1"t;r32 _ iS4y(�I' �1 10 C 4;-41A'" 15.02B81 C-4 t APB 1 `^32A D S 1' 1 15.3222 L- 15-12A ,.. 105AP 1 20 ` G32 C -31F C e_32B 21 V �_– -,.. 15-24P BT– 15.31 CG32C 15.0;A 15-23 :; 15-12APB G31 1548C _15-48A 15-24 1 C-02. .. 1FD2BPB-f 1°-010. C 07-29C 15-32C_ '_152rAjI+-31B ` C-32DPB1 I15-02APB 1. _15-01 1522BPB2 = 1K,h8B '�: 15-1 15-32A �; 1^'-i_ 07-299 _ –I 1--119 15-11A .. C 'C'31B 15-02. 15-13 1F -39A – } r C- 12E -3}c [ 07-28AL1 Or -29A 15-12 8?131 BPBI C07 -28A :'1-07-2 98P61 81 C-�2CPB1 _ 15-4' 1°..142PB ., _ -12 C: 1 C-31 _07-28 0 "90 F �' "5 a--'10APB1- 1'-4�P83 �v 10R ^,`'– L_--87 " -_r _—� q�_ 15, 0 "t 07-1 07-19A 15.40PB1-_15.40PB2 15-128, C 12AP61. i. G29B C -29A C 0 -15CF� iF 49 0"7-14A A Y-1� 38 _ C -12A C 15.130. 15�zCP8t '- 1q -15C C-10 07-14 G10B 07-?; L 0_29^ l -'-40A 15- APB L G29 – 0r 4– �- ` � C 07-3 A G27C 8-28 ' 0?.0. i D °.2(� 07 ._ 29E 15-15 – 212PIB 0?- 9 f U 336 5-3814 - - • 9 - PR2-1114 T - 0' 1dBP�1`c' 0r - 07-3 r – 13-0-' [ 07-15A. Ar 32 -14B 61 8-04A 07-13C 07 13CF'E1 v 07-3P I B-04APB1 _ _,E_3C �. : 07-10 Q7.1513 ._ °.pJ ^� vF- OSA 7 8-07A C�38 07-0� _ 07-308 'l A B ` 0? -09 7 – _. 07 -OS ,07-07 -20A – &27 I = 07-08A 07-0: A B-27CPB5" '. " 8-27CPd2-- - - 07-35 7-34 L- B -27A B -1'7>r –� ff. 07-33 PBi _ - __•� _ _ 07-0813_ --�:. — _ _Y - 37-02.13 O 07-17 67- C _ --B-16 C a278 C 07-03A it 07-09A 07-07B 02 15A _ .5 -03APB1 (� 07-04A 07-03 � 07 -04 07 J B-37 �. ._ - _ 07-05 0 B -23A:-'" •� 11 07 7-0A2A C 07-25A 14C t 02-2eC C�L.ze, �25 07_8107-03B F — 07-25BPB1 rs.^'0 07-35A 34�C 0 -02B 33 1 32 . B -14A t 07-1IA ' 07-18 B-14APB2 0i-01l�. LI 8-02 - L 13.14 07-OiP81 07- 2A _ 07-298 – B-14AP61 _ 07-11 -•� IF -0 tAPBI C 07-02 11 07-01 U:' 07-22A 07-23A B -25B !"`�: 07-12 v 07-2313 1 C 07-19A 6_ 07-23 C 907 .258 L C 07-01 B9;, 8 —, TREE = 7_1116• FMC 07-10 SUSPENDED NELLHFAD= GRA ACTUATOR= BAKER'C' OKS. ELEV = 64' REFELEV= 619 BF. ELEV- 27.55' KOP - 4698' Max Angb = 95' it 1193 0' DaYMD= m 10036' DaYanTVD= flaw SS YI4Yi i : iX"X:j WB' CSG, 47#, S0095 BTC XO TO L-80 BTC I—t 13-3/8' CSG, 72#, N-80, D = 12.34T Minimum 10 = 3.813 @ 9225' HES X NIPPLE 5-12' TBG, 17#, 13CR-80 VAM TOP, ,0233 bpf, D=4.892' 9-51W X T LTP & 9-5/8' CSG, 47#, L-80 BTC XO TO S0095 BTC 4-12' TBG, 12.8#, 13CR-80 VAM TOP, .0152 bpf, D = 3.958' 4-mr STUB (RIG TAG 20031 4-12' TBG, 12.6#, L-80 NSCr, .0152 bpf, D = 3.958' PEF FXMTDN SIAMMARY REF LOG MIMGR ON 08/98 ANUXATTOPPERF: 0 @' Note: Refer to Production DB for historical perf data SIZE SPF NTBNAL Opn/Sgz SHOT SQZ 2-3/8" 4 108M-11120 S 08/12/98 1228/12 2-3/8' 4 11160-11550 S 08/12/98 12IM12 2-3/8" 4 11640-12550 C 08/12198 JNJJMD ADDED OKB, REF, BF & SUSPENDED 2-3/8" 4 12670- 13070 C 00/12198 2-318" 4 13130-13240 C 08/12198 ITOP OF VVHPSTOCK J -j 7 TBRDGE PLl1Ca 7- SCAB LNR, 298, L-80 BTC, .0371 bpf, D = 8.184' 10180' 35/8' CSG, 47#, 50095, BTC, .0732 bPf. D = 8.681 10240' 1 4-12- LNR, 12.6#, L-80 DT, .0152 bpf, D = 3.953' I 15-1/2- HES X NIP. D = 4.562- FS5/8" FOC 5-12' TBG GAS LFT MANDRELS ST ID 1 TVD DEV 1 TYPE VLV LATCH PORI DATE 2 3932139321 1 1 MMG DIMY RK 1 0 07/19/1 115-12" X 4-12" XO, D= 3-958- 4-1/2' TBG GAS LFT MANDRELS TOP OF CEMENT (1226/1 2) X 4-12' BKR S-3 PCR, D X 4-12'UNIQUE MACHINE OV ERSI X 4-12' BKR S-3 WR, D = 3.875W- 1/2- HES X NP_ D = 3 813• 9243' 7'X 5" BKR ZXP PM w/TIE & HMC LNR HGP, D- 4.437' 924T 4-12' VVLEG, D = 3.958' ELMD TT NOT LOGGED 92SW J-15' X 4-12' XO, D = 3.958' 35/8' & 7- MLLOUr WINDOW (07-10A) 9428' - 9440' 8801' TOP OF CMT (12/08/12) 11880' 4-12' HES CBP (07/10/101 DATE I REV BY I COMMENTS DATE REV BY I COMMENTS 0311016779 ROW34 OPoGINALCOBPLETION DBW10 RCT/PJC SETPXPLUG M M0 04Q4FJ0 MU014 RVVO 09/10/12 DASIPJC I PLLL PX PLUG 08/14198 014 SDETRACK -1 01M6/13 MVNGJM CMT PLUGS&TBG PUNCH C12JO8,164M 0926103 NOES RWO 07!31/19 JNJJMD ADDED OKB, REF, BF & SUSPENDED 07/11/10 CJSISV SETCBP 07/10/10 0724110 SV1C/A GLVC/0 7/19/10 1 13312' 1 PRUDHOE BAY UNIT WELL: 07-10A PERMTr N7: r1980160 API No: 5"29-20335-01 SEC 33, T11N, R14E, 216 FEL & 98(Y FN. BP Exploration (Alaska) Suspended Well Inspection Review Report InspectNo: susRCN190708121138 Date Inspected: 7/6/2019 Inspector: Bob Noble Well Name: PRUDHOE BAY UNIT 07-10A - Permit Number: 1980160 Suspension Approval: Sundry 9 312-311 Suspension Date: 12/13/2012 Location Verified? O If Verified, How? Other (specify in comments) - Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 7/5/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? D Photos Taken? Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: 220 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead looked to be in good condition. Flowline is installed with SSV closed. AL line has been removed and blinded. Wellhead protected with a wellhouse. Condition of Cellar Good clean dry gravel. Surrounding Surface Condition Clean gravel. Comments Location is verified with a pad map. Supervisor Comments Photos(2)attached Monday, August 19, 2019 Suspended Well Inspection — PBU 07-10A PTD 1980160 AOGCC Inspection Rpt # susRCN190708121138 Photo by AOGCC Inspector B. Noble 7/6/2019 2019-0706_Suspend_PBU_07-10A_photos_bn.docx Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMI ON . REPORT OF SUNDRY WELL OPER/0 r..NS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other:Suspend Well Inspection II 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-016 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service CI6. API Number: 50-029-20335-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-10A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13405 feet Plugs measured 7607/9501/11580 feet E C E V E D true vertical 9035 feet Junk feet measured 7 Effective Depth: measured 7607 feet Packer measured See Attachment feet AUG 2 2015 true vertical 7119 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 79 20"94#H-40 34-113 34-113 1530 520 Surface 2676 13-3/8"72#L-80 34-2710 34-2710 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10835-11120 feet 11160-11550 feet 11640-12550 feet 12670-13070 feet _ 13130-_13240 feet True vertical depth: 9018-9020 feet 9020-9027 feet 9024-9004 feet 9000-9006 feet 9010-9022 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: sumac 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,a 25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP I3 SPLUG ❑ 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 /tlCom— Phone +1 907 564 4424 Date 8/27/15 Form 10-404 Revised 5/2015 VTL 9gizj/� RBDMS �0 2 8 2015 Submit Onginal Only • I Packers and SSV's Attachment 1 PBU 07-10A SW Name Type MD TVD Depscription 07-10A PACKER 9118.05 8333.2 4-1/2" Baker S-3 Perm Packer 07-10A PACKER 9193.38 8389.1 4-1/2" Baker S-3 Perm Packer 07-10A PACKER 9244.89 8427.34 5" Baker ZXP Top Packer a o 0 0 o 0 0 0 o O o o O co N N 00 O 00 CO CO N O CO O O - CO O N- O N O O LU N (C) L() O N (() to to N- N- (O N- 1�- U L o 0 0 o O o to co o CO o O o CO CO • to co r- CO 1— ct N- V d' CO v CO CO CO CO o0 00 CO N w CO (,) oNrntnv 'Cr v "Cr to - - 00 CO to OO O0 CO N- N- CO NMd' t0Otn (c) Ot0C7 t N N N CO CO CO C) 'Cr CO CO al I- N- 0) Cn 'cr O) N- 11') N N CO CO Lo O N O N- O CO Cr) Cr) CO .cr Cn O O d' CO to CO N N N CO 'Cr CO CO 4.0C ch OC` O to CO O O t() O C}) N- CO "cr to N- rn co (0 CO N = • N N N N CO 01 O CM O v o 4-1 I i Q Qr N- C) CO N to Cn C)▪ V N CO CO O N- O CO Cr) Cr) CO 'cr O N C) t() N- O ti N N N CO to 0) 0) to to Cn O OOWOO • J O 0 0 U J -- J I J J C° C'7 C 0NCO U) CO -I o N (A COO t? N _ - (NI U C) C? 0\0 t o 0\O t 1 0\0 I� N N N In 6) to d) CC') ` O O th V , 4 t w C3) N- C() N O N to V O CO C N- O Cr) CO d' (NI •- to to CO N N O O 'Cr V J cr Z Z Z Z Z a)p 00000 C F- u j I- I- F- 7) 0000000 UOw00000aHZZZ Z 0 0 0 0 0 w w m m m - N O p - ; N (/) I I _c O (0 � N C N O N - -0 Co Q a) C > _ -C U C 0 T E 4-1 YE a) �L 2 j N3 _c to F O < u >,Q _O a D a) 7 N N LL ti OL CO o o a j a a) -o °' CL ca a a) -0 alCL Q = � o a CA � U o -0 U 0 5 • 73 LL O o• rn z w I- Q 0 o cn ~ N m 5 co 1 U Suspended Wel! Site Inspection Form 5 year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 07-10A Field/Pool: PRUDHOE BAY/PRUDHOE OIL Permit#(PTD): 198-016 API Number: 50029203350100 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 12/13/2012 Surface Location: Section 33 Twsp: 11N Range: 14E Nearest active pad or road: Drill Site 07 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: good, 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) (2)well house and area around well 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 Gray wellhead, FMC tree, clean, all valves functional, casing valves open to gauge Cellar description, condition, fluids backfilled with gravel 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=0 psi OA= 200 psi Wellhead Photos taken (#and description): (2)wellhead and tree Work Required: None Operator Rep (name and signature) Whitney Pettus ' "f AOGCC Inspector: Waived by Chuck Scheve Other Observers: Ryan Hayes Inspection Date: 8/3/2015 AOGCC Notice Date 8/2/2015 Time of arrival 1:50 PM Time of Departure: 2:05 PM Site access method. 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',;,''':,,'' l'i. •it" ' .,,r„:,,,..:0.,,,,,, • ,,,,.,,..„., 14, . ,,.i:„:„.!:„; 1,,,I, , ,, 1 • , , ),,.:,„0. ,,.,,.,..i.,,,,„!.., o.,; •, ,:,,,..., , .,, . ,., 1 . , . . , • • . .. , I ., . . . „ , - i ,4 • . . i •, . . .1 , . TREE= 7-1/16"FMC 7 1OA E"S�rS�12 CFfl2 M E TBG'+:70'010185'"* WEL I EAD= GRAY ACTUATOR= BAKER"C' 10B.8_E1/= 62' 1 BF.ELEVV= I KOP= / I 2104' I--I5-1/2"HES x NF,D=4.562" --- 20"CONDUCTOR — 109' 1 Max Angle= 95°@ 11930' _ 2359' H9-5/8"FOC Detum MD= 10036' Datum TVD= 8800'SS — 2486' I—9-5/8"FOC 9-5/8'CSG,47#,S0095 BTC XO TO L-80 BIC H 2511' 1.--' 1[ 5-1/2"TBG GAS LFT MANDRELS 13-3/8"CSG,72#,N-80,D=12.347" H 2706' ST MD TVD DEV TY FE VLV LATCH FORT DATE LI . 3932 3932 1 MAG DM/ RK 0 07/19/10 Minimum ID =3.813 @ 9225' HES X NIPPLE / 4570/• H51/2"x4-1/2"XO,D=3.958" 5-12"TBG,17#,13CR-80 VAM TOP, H 4574' 4-1/2'TBG GAS LFT MANDRELS ,0233 bpf,0=4.892" ® ST MD TVD DEV TYPE VLV LATCH PORT DATE 85/8"X7"LTP&HGR D=? H4992' IJ 1 6553 6270 39 KBG2LS DMY NT 0 07/19/10 4+�� 9-5/8'CSG,47#, L-80 BTC XO TO S0095 BTC 1-- 8739' —X7607' TOP OF CHANT(12/26/12) 4X ��4sa►F 4 ♦ A4e1.. �liv 9096' —14-112-11C-,X NP,0=3.813" .4EF�44+�4+ TBG PUNCH(12/16/12) — 9101'-9106' y+1,W 9106' H BOTTOM OF CI34tBYT(12/26/12) 4-1/2"-TBG,12.6#,13CR40 VAM TOP, — 9161' $ $ 9116' _--17"X 4-1/2"BKR S-3 PKFt,D=3.875" .0152 bpf,D=3.958" �' ' 9140' —14-1/2"HES X NP,0=3.813" 4-1/2'STUB(RIG TAG 2003) —1 9163' I____, 9168' H7"X 4-12"UNIQUE MA CHNE OVERSHOT z X 9191' H 7'X 4-1/7 BKR S-3 A(R,D=3.875" ' , 9225' —14-12"I IS X NP,ID=3.813" TOP OF 4-12"LNR H 9243' \ 4-12"TBG,12.6#,L-80 NSCT,.0152 bpf,D=3.958" —1 9247' 9243' 17'X 5"BKR ZXP FKR w/TEBK SLV &HMC LNR HGR,D-4.437' F -FORATION SUMAARY 9247' H4-1/2"WLEG,D=3.958" REF LOG:MWD/GR ON 08/98 \ HSM)TT NOT LOGO) ANGLE AT TOP PEW: °0' Note:Refer to R-oduction DB for historical pert data 9264' --15"X 4 12"XO,D=3.958" SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-3/8" 4 10635-11120 S 08/12/98 12/26/12 2-3/8" 4 11160-11550 S 08/12198 12/26/12 ( 9-5/8"&7"MLLOUT WINDOW(07-10A) 9428'-9440' I 2-3/8' 4 11640-12550 C 08112/98 1 i 2-3/8" 4 12670-13070 C 08/12/98 2-3/8" 4 13130-13240 C 08/12/98 9501' TOP OF CMT(12/08/12) QI. •fr4 �4~,t 11680' 4-1/2"FES C16P(07tlato) ♦♦ ♦4+ 4• TOP OF WHIPSTOCK —1 ? �+ ♦�� 4� 7"BRDGE PLUG —1 9449' // r SCAB LNR,29#,L-80 BTC,.0371 bpf,D=6.184" —1 10180' 14VN � 13312' PBTD 9-5/8"CSG,47#,S0095,BTC,.0732 bpf,D=8.681' H 10240' 1— Iihm.m • 4-12"LHR,12.6#,L-80 ET,-0152 bpf,0=3.953" --1 13399' w TD —1 13405' DATE REV BY COMMENTS DATE REV BY COMMENTS PRI CHOE BAY INT 03/06179 ROW 34 ORIGINAL COMPLETION 08/30/10 RCT/PJC SET PX RUG(08106/10) WELL: 07-10A 04/24/90 AID 4 liWO 09/10/12 DAS/PJC PULL PX RUG PE MT No:'1980160 08/14198 D14 SIDETRACK(07-10A) 01/16/13 MWK/JMD CMT RUGS&TBG PUNCH(12/08,16-2611; AR No: 50-029-20335-01 09126/03 N4E5 RWO SEC 33,T11 N,R14E 216 FEL&980'FNL 07/11/10 CJS/SV SET CEP(07/10/10) 07/24/10 SWC/AGR GLV C/O(07/19/10) .- BP Exploration(Alaska) XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~""- ~/~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] Logs of vadous kinds n Other COMMENTS: Scanned by: Beverly Mildred Damtha~owell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ • STATE OF ALASKA \R g ` Zip i3 ALASKA OIL AND GAS CONSERVATION COMMISSION A. WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned _� Suspended • lb. Well Class 20AAC 25 105 20AAC 25110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 12/13/2012 198 - 016 ' 312 - 311 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 7/29/1998 50 029 - 20335 - 01 - 00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 8/8/1998 PBU 07 - 10A • 980' FNL, 216' FEL, Sec. 33, T11 N, R14E, UM 8. KB (ft above MSL): 61.5' 15. Field / Pool(s) Top of Productive Horizon: 1265' FSL, 1558' FEL, Sec. 28, T11 N, R14E, UM GL (ft above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD) Oil Pool 4978' FSL, 2630' FEL, Sec. 28, T11N, R14E, UM 7606' 7118' 4b. Location of Well (State Base Plane Coordinates, NAD ; 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x - 675980 • y 5949939 • Zone ASP4 . 13405' 9035' • ADL 028309 • TPI: x- 674580 y- 5952152 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: 1 Total Depth: x- 673414 y- 5955839 Zone- ASP4 None 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): 18. Directional Survey: ❑ Yes El No (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, DIR, GR, 4 - Phase RES, RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES 9428' 8562' 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" 94# H -40 Surface 109' Surface 109' 30" 271 sx Arctic Set 13 -3/8" 72# L -80 Surface 2706' Surface 2706' 17 -1/2" 5000 sx Arctic Set II 9 -5/8" 47# L - 80/S00 - 95 Surface 9428' Surface 8562' 12 -1/4" 1200 sx Class 'G' 7" 29# L -80 4992' 9428' 4980' 8562' 8 -1/2" 420 sx TLW, 82 sx Class 'G' 4-1/2" 12.6# L - 80 9243' 13399' 8426' 9034' 6" 477 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 5 -1/2 ", 17 #, 13Cr80 x 9247' 9116' / 8332' 4 -1/2 ", 12.6#, 13Cr 80 / L -80 9191' / 8387' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. SCANNED APR 2 3 ZU2 WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ❑ No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9501' - 10580' 23 Bbls Class 'G' 9101' - 9106' Tubing Punch 7606' - 9106' 49 Bbls Class 'G' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No . Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None R9DMv MAR 14 20HS(r) Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE Submit Original Only 6 i REVERSE '''',/,-- 014,/,,,, 5y - „Z- 29. GEOLOGIC MARKERS (List all formations a arkers encounter 30. FORMATION TESTS NAME D TVD Well Testellt Yes ® No , Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit 9410' 8549' None Zone 4A 9609' 8671' Zone 3 9725' 8723' Zone 2C 9874' 8792' Zone 2B 10003' 8847' Zone 2A 10280' 8963' Zone 1B 10758' 9014' Formation at Total Depth: 31. List of Attachment Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Allely; 732 Email: Josh.Allely @bp.com Printed N Jo Title: Drilling Technologist L^ Phone 564 -4091 Date: 3 / 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 10/2012 Submit Original Only • • , 07 -10A Well History Date Summary 10/29/12 T /I /0- 20/276/355 Temp S/I Injectivity test (Plug & abandonment reservoir) Injectivity of 5 bpm at -800 psi. Pumped 5 bbls MEOH followed by 65 bbls diesel & 296 bbls SW for injectivity test. Pumped 70 bbls DSL for FP. FWHP's= 0/440/400 DSO notified upon departure of SV,WV,SSV= closed, MV =open, IA and OA =OTG. 12/07/12 T/I/O= 0/220/340 Temp= S/I (Plug and Abandonment Reservoir) Heat diesel transport N# 30019 to 70* safety drill. Spot unit, rig up to choke skid. Job in progress. Did not pump any fluids. 12/08/12 Assist SLB (Plug and Abandonment Reservoir) SLB spear in TBG w/ 5 bbls meth followed by 200 bbls 1% KCL to load. SLB pumped 5 bbls fresh water, 23 bbls of 15.8 ppg class G cement, 2 bbls of fresh water to clear lines. Open 4.5" gate valve to pump water to launch balls, upper flow path froze. Open lower leg and pump 3 bbls fresh water. Isolate SLB, line up for LRS to pump. LRS pumped 178 bbls of 75* diesel down TBG, ran out of diesel swap to meth and pumped 7 bbls for a total of 185 bbls fluid pumped down TBG. Estimated TOC is 9501'md. Valve positions upon departure: upper and lower swabs,WV, SSV= closed. MV IA OA= open. FWHPS= 1000/20/380. 12/13/12 DRIFTED W/3.5O" CENT /SB, SD @ 9483' SLM (rec. 1/4 cup cement). LRS MIT -T TO 3000 psi (pass). 12/13/12 T/I/O= 0/44/326, Temp= Hot, AOGCC MIT -T PASSED to 3000 psi (Plug and Abandonment Reservoir) (AOGCC Witnessed by Bob NobTe) Pressured up Tbg with 3.7 bbls of diesel to reach 3000 psi. MIT -IA lost 84 psi in 1st 15 minutes and 29 psi in 2nd 15 minutes for a total of 113 psi in a 30 minute test. Bled IAP (- 2 bbls). SV, WV= Closed; SSV, MV, IAV, OAV =Open. FWHP's= 600/80/326. 12/16/12 INTIAL T /I /O = 650/50/350, SSV CLOSED. RAN IN W/ 5' OF "20DL" TBG PUNCHER AND PUNCHED TBG @ 9101' - 9106, GOOD INDICATION OF HOLES, TBG AND IAP PRESSURES DROPPED AFTER SHOOTING. DEPTH CORRECTED TO TUBING TALLY. WELL LEFT SHUT IN - NOTIFIED DSO OF WELL STATUS. FINAL T /I /O = 250/0/350. 12/22/12 T /I /O =0/0/0 Temp =SI Prove Injectivity from Tbg to IA (PLUG AND ABANDONMENT - RESERVOIR) Rig Up and PT. 12/23/12 Pumped 5 bbls of neat followed by 50 bbls of 0* DSL down Tbg to prove injectivity from Tbg to IA. Got an Injectity rate of 5 bpm at 1550 psi. Pumped 1 bbl DSL into IA to FP valve. Pumped 9 bbls of DSL down hardline and into well 07 -09 to FP hardline. DSO notified of well status per LRS departure. FWHP's= 1400/1050/300 SV,WV,SSV= C MV= 0 CV's =OTG Hardline =C. 12/26/12 Initial T /1 /O: 741 / 358 / 390. Assist SLB (Plug and Abandonment Reservoir) CMT Phase 2 (ballance plug) SLB spear in TBG w/ 5 bbls 60/40 followed by 350 bbls 1% KCL to load, followed by 130 bbls diesel, followed by 140 bbls 1% KCL, followed by 10 bbls fresh water, followed by 49 bbls 15.8 ppg class G,_,_ cement, followed by 2 bbls fresh water to clear lines, closed bottom to valves on ball launcher, opened upper valves on ball launcher tea 8" Foam Balls, followed by 5 bbls fresh water to launch balls, opened ALL valves on ball launcher, then followed with 75 bbls 1% KCL, followed by 70 bbls diesel. Total of 836 bbls fluid pumped down TBG putting TOC at - 7606md on Tbg and - 7606md in IA. Valve positions upon departure: swab,WV, SSV, IA= closed. MV, OA= open. Swab on 07 -09 (receiving well) closed. FWHPS= 0/0/500. 12/30/12 TAGGED CEMENT WITH 3.50 CENT /SB @ 7586' SLM( AOGCC WITNESSED ). TAGGED WITH 2.70" CENT /SB @ 7589' SLM. Page 1 of 2 • • 07 -10A, Well History Date Summary 12/30/12 T /I /0 =0 +/0 +/360 Temp= SI Assist Slickline, AOGCC Witnessed (by Chuck Scheve) CMIT -TxIA * *FAILED ** to 3000 psi (P &A) Pumped 9.2 bbls ambient neat methanol to reach test pressure. 1st 15 minutes T /IA lost 40/150 psi. 2nd 15 minutues T /IA lost 36/125 psi. 3rd 15 minutes T /IA lost 32/124 psi. Total T /IA Toss in 45 minutes= 108/399 psi. Bled TxIAP (— 3 bbls ). WHP's= 260/460/380. IA & OA= OTG. 01/01/13 T /I /O = 276/352/372 Temp = S/I Pumped 5.17 bbls amb Diesel down IA and U- Tubing to TBG. 01/02/13 CMIT TxIA FAIL to 3000 psi MIT -IA FAIL to 3000 psi . Pumped .5 bbls amb Diesel to achieve 3000 CMIT TxIA test pressure. TBG lost 24 and IA lost 114 psi in the 1st 15 minutes. TBG lost 21 psi and IA lost 95 psi in the second 15 minutes. TBG lost a total of 45 psi and IA lost a total of 209 psi over the 30 min test. Pumped 1.32 bbls amb Diesel to achieve 3000 psi MIT -IA test pressure. IA lost 85 psi in the 1st 15 minutes and 76 psii in the 2nd 15 minutes for a total Toss of 161 psi over the 30 minute test. Bleed TBG and IA down —3.5 bbls back. FWHP's= 6/551/550 SW,WV,SSV= CLOSED MV =OPEN IA,OA =OTG. Page 2 of 2 , .. ,TRIffi= 7-1/16' FRC ... Slily NOTES: WELL ANGLE > 70u @ 10185 Y‘•IELLFEAD= GRAY • 0 7 -1 OA 4-1 & 5-1/2" CHROME TBG*** ACTUATOR= BAKER "C" KB. ELEV = 62 I 11 I ...._ _ BF. ELEV = 7 ... 2104' 1-15-1/2' HES X NE, V= 4.562' KOP= 4698' - — - - -- 20" CONDUCTOR --I 109' IVIzoi Angle = 95° @ 11930' 2359' H9-5/8" FOG Datum MD= 10036' Datum TVD = 8800' SS — 2486' 1-19-5/8" FOC , __:•-.. 9-5/8" CSG, 47#, S0095 BTC XO TO L-80 BTC -- 2511' 1--- 13-3/8' CSG, 72#, N-80, ID = 12.347" H 2706' 5-1/ TBG GAS LFT MANDRELS ST MD TVD DEV TYFE VLV 'LATCH FORT DATE NI 3 932 93 11111111111= DM' RK 0 07/19/10 Minimum ID = 3.813 @ 9225' HES X NIPPLE I 4574' I-15-112" X 4-1/2" X0, ID = 3.958" I 5-1/2" TBG, 17#, 13CR-80 VAM TOP, --I 4574' / 4-1/2" TBG GAS LET MANDRELS re ,0233 bpf, 11 3=4.892' ST MD ND DEV TYPE VLV LATCH PORT DATE 1 6553 6270 39 KBG2LS DMY INT 0 07/19/10 9-5/8" X 7' LIP & HGR, ID = ? -- 4992' f .......... ,., 9-5/8" CSG, 47#, 1-80 BTC X0 TO S0095 BIG I-1 8739' —,,--■ A i. 1 7607' HTOP OF CEMBs/T (12/26/12) 41 1 ..11-11 9095' — 14 - 11T HES X NIP, 0=3.813" TBG PUNCH (12/16/12) I— 9101'-9106' rie . .111441111 9106' ---1 Bo OF CEMENT (12126/12) 9116' H r X 4-1/2" BKR S-3 FKR E) = 3.875" 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, — 9161' 2 Rill .0152 bpf, D = 3.958 I 9140' --14-1/2" HES X NE, ID = 3.813" I " 4-1/2" STUB (RIG TAG 2003) H 9163' 1 r ,11 :.1 9168' H7" X 4-1/2"UNIQUE MACHINE OVERSHOT I 9191' —17" X 4-1/2" BKR S-3 FKR, ID = 3.875' I 9225' --41/2" HES X NP, El = 3.813" I TOP OF 4-1/2' LNR —1 9243' 1 4-1/2" TBG, 12.6#, 1-80 NSCT, .0152 tipf, ID = 3.958' H 9247' 9243' — 7" X 5" BKR ZXP PKR w / TEBK SLV I & HMC LNR HGR, ID - 4.437" PERFORATION SUMMARY Vi SU ! 9247' —[4-1/2" IiM_EG, ID = 3_858 REF LOG. MWD/GR ON 08/98 1 I I --i ELIVID TT NOT LOGGED I A NGLE AT TOP PERE: ° g . 9264' — 5" X 4-1/2" XO, 13 = 3.958* Note: Refer to Production DB for historical pert data SIZE I SPE - INTERVAL Opn/Sqz SHOT SOZ 2-3/8" 4 10835- 11120 S 08112/98 12/26/12 2-3/8" 4 11160 - 11550 S 08/12/98 12/26/12 9-5/8' & 7" MLLOUT WIINDOVV (07-10A) 9428' - 9440' 2-3/8" 4 11640 - 12550 C 08/12198 2-3/8" 4 12670- 13070 C 08/12/98 2-3/8" 4 13130 - 13240 C 08/12/98 9501' 1— TOP OF CM!' (12J08/12) % lk ,..,4.40 11680' 4-1/2" HES CIBP (07/10/10) [TOP OF WHIPSTOCK --I ? 4 At .... „j( 7"BRIDGEFLUG H 9449' 1 13312' PBTD 7” SCAB LNR, 29#, L-80 BTC, .0371 bpf, 0= 6.184" --I 10180' 1, . , .'........ 1 CSG, 474, S0095, BTC, . 0732 bpf, ID = 8.681" I-1 10240' 1 . ......- 1 4-1/2" L142, 12.6#, L-80 BT, .0152 bpf, ID = 3.953* H 13399' TD I—[ 13405' 1 I DATE REV BY COIVIVENTS DATE 1 REV BY COM , ENTS FRUDHOE BAY MIT 03/08/79 ROW 34 'ORIGINAL COMPLETION 08/30/10 RCT/PJC SET PX PLUG (08106/10) WELL: 07-10A 04/24/90 AUDI 4 RWO 09/10/12 DAS/PJC PILL PX PLUG FMIAIT No y 1980160 08/14/98 D14 SIDETRACK (07-10A) 01/16/13 tVIM/LIM) CIVIT PLUGS & TBG PUNCH (12/08, 16-26/1; AR Na: 50-029-20335-01 09/26/03 N4E5 RWO SEC 33, T11N, R14E 216' FR_ & 990 RC 07/11/10 CJS/SV - SET CIBP (07/10/10) 07/24/10 SWC/AGR GLV 00 (07/19/10) I BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, January 10, 2013 P.I. Supervisor e l c i Kit 3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 07-10A FROM: Chuck Scheve PRUDHOE BAY UNIT 07 -10A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 07 - 10A API Well Number 50 029 - 20335 - 01 - 00 Inspector Name: Chuck Scheve Permit Number: 198 - 016 - Inspection Date: 12/30/2012 Insp Num: mitCS121231081033 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 07 -10A - Type I nj N ' TVD IA 0 2890 . 2740 - 2615. 2491 - PTD 1980160 - Type Test SPT Test psi OA 375 400 - 400 400 400 Interval OTHER P/F F ` Tubing l 0 3012 2972 - 2926 - 2904 ' Notes: CMIT performed to test cement plug to suspend this well. Thursday, January 10, 2013 Page 1 of 1 • • Page 1 of 1 Schwartz, Guy L (DOA) P77 /?8-0/4 From: Scheve, Charles M (DOA) Sent: Monday, December 31, 2012 10:14 AM To: Schwartz, Guy L (DOA) Subject: RE: P&A report Guy This was the second plug 9106 to 7606. Test pressures were separated but performed at same time. Their procedure called for MITT on lower plug and a liquid leak rate if it failed (they said it passed). Second plug calls for testing tubing and casing. 1 will bring copy of what they gave me in on Wednesday. Chuck From: Schwartz, Guy L (DOA) Sent: Monday, December 31, 2012 9:48 AM To: Scheve, Charles M (DOA) Subject: RE: P&A report SCANNED APR 11 ZU1 Chuck, I had to look this one up... This must be the lower fullbore plug they are testing (10000' and TOC) . Agree with you to retest. Upper packer is way up at 9116' though. They are adding another cement plug above this point. Did they do a CMIT or test separately? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Scheve, Charles M (DOA) Sent: Monday, December 31, 2012 9:32 AM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA) Subject: P&A report Jim Attempted to pressure test and tag plug on PBU 7 -10A. Pressure test failed with IA losing 150,125,124 during 45min test. Tubing losing 40,46,22 during same time frame. Slick line tagged up close to expected depth but no sample recovered. Don't know which way you want to go with this one, I recommended to BP rep to try to retest tubing and IA without all the ancillary equipment rigged up to verify pressure test numbers. Chuck 12/31/2012 ELLH&D= GRAY i'roptsed 0 ■ -10A ", .�,�.�...��,�� ;TUATOR = BAKER "C" Old ceme. ' & 5-1/2" CHROME TBG*** 3. ELLV = 62' W, =. EL EV = ? New Cement JP= 4698' - ' 2104' H 5 -1/2 "HESX NIP, ID = 4.562" ax Angle = '95° @ 11930' 20" CONDUCIDR H 109' 3tun� MD= 10036' 1 2359° H9 -5/8" FOC 3tum TVD = 8800' SS """' 2486' H 9 -5/8" FOC 9 -5/8" CSG, 47 #, S0095 BTC XOTO L -80 BTC I---I 2511' I.--- ^ • 5-1/2" TBG GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2706' ST MD TVD DEV TYPE VLV LATCH PORT DAT Minimum ID= 3.813 @ 9086° 2 3932 3932 1 MMG DMY RK 0 07/19/ HES X NIPPLE i.- .R/1(C// 4574' 1-15-1/2" X 4-1/2" X0, ID= 3.958" 5 -1/2" TBG, 17 #, 13CR -80 VAM TOP, H 4574' r 0233 bpf, ID = 4.892" 4-1/2" TBG GAS LIFT MANDRaS ST MD TVD DEV TYPE VLV LATCH PORT DAT 9 -5/8" X 7" LTP & HGR ID = ? H 4992' : ; : WUI 1 6553 6270 39 KBG2LS DMY INT 0 07/19/ 9 -5/8" CSG, 47 #, L -80 BTC XOTO S0095 BTC 1-I 8739' X Top of Cement at 7606' 9095' H4 -1/2" HESX NIP, ID = 3.813" f 9116° —17" X 4-1/2" BKR S -3 PKR, ID = 3.875" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, H 9161' � .0152 bpf, ID = 3.958" II 9140' I- 14-1/2" HESX NIP, ID= 3.813" 4-1/2" 9140' I- I 4 -1/2" PX PLUG(08/06/10) -1/2" STUB (RIGTAG 2003) H 9163' I I 9168' 1-17" X 4-1/2"UNIQUEMACHNEOVERSHOT I �,1 f 4 9191' I-17" X 4-1/2" BKR S -3 PKR, ID = 3.875" I U 9225' I-14-1/2" HESX NIP, ID = 3.813" I TOPOF4 -1/2" LNRI -- I 9243' -1/2" TBG, 12.6 #, L- 80 NSCT, .0152 bpf , ID = 3.958" H 9247' 9243' I X 5" BKR ZXP PKR w / TIEBK SLV L & HMC LNRHGR, ID - 4.437" ex PERFORATION SUMMARY No 9247' i- 14 -1/2" WLEG, ID = 3.958" I t REF LOG: MWD/GR ON 08/98 H ELMD TTNOTLOGG® ANGLE AT TOPPERF 87° @ 10835' Note: Refer to Production DB for historical perf data 9264' I-{ 5" X 4 -1/2" XO, ID = 3.958" SIZE SPF INTERVAL Opn /Sqz DATE 2 -3/8" 4 10835 - 11120 0 08/12/98 2 -3/8" 4 11160 11550 0 08/12/98 Top of Cement at 10080' 2 -3/8" 4 11640 - 12550 C 08/12/98 2 -3/8" 4 12670 - 13070 C 08/12/98 9 -5/8" & 7" MILLOUTWINDOW (07 -10A) 9428' - 9440' 2 -3/8" 4 13130 - 13240 C 08/12/98 11580' 4 -1/2" HESCIBP (07/10/10) TOP OFWHIPSTOCKIH ? 7 "BRIDGEPLUG I--{ 9449' ( 13312' PBTD 7" SCAB LNR, 29 #, L- 80 BTC, .0371 bpf , ID = 6.184" H 10180' ` mow. "4 ,11101011■1■1•111010. .5/8" CSG, 47 #, S0095, BTC, .0732 bpf, ID = 8.681" — 10240' ql■MaIIIMILW "1131010111 4-1/2" LNR, 12.6 #, L-80 IBT, .0152 bpf , ID = 3.953" I-1 13399' I TD H 13405' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHCE BAY UNIT 03/06/79 ROW34 ORIGINAL COMPLETION 08/30/10 RCT/PJCSET PX PLUG (08/06/10) WELL: 07 -10A 04/24/90 AUDI4 RWO PERMI1No:'1980160 08/14/98 D14 SIDETRACK (07 -10A) API No: 50 -029- 20335 -01 09/26/03 N4ES RWO SEC33, T11 N, R14E, 216' FEL& 980' FNL 07/11/10 CJS /SV SET CIBF(07 /10/10) 07/24/10 SWC /AGF GLV C/O (07/19/101 BP Exnlnration (A Iaskal • • MEMORANDUM State of Alaska AOGCC TO: Jim Regg j�c� �, � DATE: December 31, 2012 P. I. Supervisor FROM: Chuck Scheve SUBJECT: Suspension Plug Petroleum Inspector Prudhoe Bay Unit 07 -10A PTD 198 -016 - SCANNED APR 11 2013 Sundry # 312 -311 BPXA December 30, 2012: I witnessed the attempted pressure test and tag the suspension plug on PBU 07 -10A. Pressure test failed with inner annulus losing 150,125, and 124 psi during a 45 minute test (15 minute increments); tubing lost 40, 46, and 22 psi during same time frame. Slick line tagged up close to expected depth but no sample recovered. I recommended to BPXA representative to retest the tubing and inner annulus without all the ancillary equipment rigged up to verify pressure test numbers. This was not done ✓ while I was at the location. Summary: I witnessed an unsuccessful tag and pressure test of a suspension plug in PBU 07 -10A. Attachments: Suspension Plug Tag Report PBU 07 -10A MIT PBU 07 -10A 2012 -1231 _Suspend_Plug_PBU_07- 10A_cs. docx • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I DATE: December 30, 2012 P.I. Supervisor _ ('( I ) t ( 3 FROM: Chuck Scheve SUBJECT: Suspension plug Petroleum Inspector PBU 7 -10A BPXA PTD# 1980160 - CONFIDENTIAL Section: 33 Township: 11N Range: 14E - Meridian: Umiat Lease No.: ADL028309 - Drilling Rig: Rig Elevation: Total Depth: 13405 ft MD - Operator Rep.: Casinq/Tubinq Data: Casing Removal: Conductor: 20" - O.D. Shoe@ 109 ft MD Casing Cut@ Feet Surface: 13 3/8" ' O.D. Shoe@ 2706 ft MD ' Casing Cut@ Feet Intermediate: 9 5/8" ' O.D. Shoe@ 9428 ft MD Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: 4.5" O.D. Shoe@ 13399 ft MD - Casing Cut@ Feet Tubing: O.D. Tail@ Casing Cut@ Feet type Pluq Type Plug Founded on Bottom Top of Cement Mud Weight Pressure (bottom up) of Cement Depth Verified? above plug Test Applied Annulus Balanced 9101 ft MD 7586 ft MD wireline tag 8.5 yes 1 Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface I traveled to the BPX PBU Well 7 -10A to witness the pressure test and of a tag cement plug in this well. A cement plug had been placed per approved procedure(sundry number 312 -311) leaving the estimated top of cement @ 7606'. Attempt to pressure test Tubing and Inner Annulus was unsucessful (see MIT report form) Wire line with a sample bailer was run in the hole and tagged up solid at 7586'. No sample of cement was recovered . Rev.:5 /28/00 by L.R.G. 2012 - 1230_ Suspend_Plug_PBU_07- 10A_cs.xlsx 1/11/2013 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ' TO: Jim Regg 1� Iz/z,(,� DATE: 12/13/2012 P. I. Supervisor FROM: Bob Noble SUBJECT: Plug Tag and Test Petroleum Inspector BP Exploration (Alaska), Inc. PBU 07 -10A (PTD 1980160) 12/13/2012 arrived on location and met with BPXA representative Travis Hallifax. We discussed how they were going to tag and pressure test of the bottom plug. Schlumberger slick line was rigged on the tree and they ran into the well with a 2 -inch bailer. The bailer tagged bottom at 9483 feet. They picked up and set down 5 or 6 times — all at the same depth. The bailer was tripped out of the well and found to have good hard cement in it. So we called top of cement at 9483 feet. Hot Oil rigged up their pump truck to Schlumberger's lubricator. They pressured the tubing from 0 psi to 3000 psi. A passing 30 minute test was witnessed. The well pressures during the tubing test were as follows [Tubing (T); Inner Annulus (I); Outer Annulus (0)]: Pre -test T /I /O = 0/44/326 psi SCANNED APR 1 1 2013 Initial T /I /O = 3000/226/327 psi 15 min T /I /O = 2916/230/326 psi 30 min T /I /O = 2887/230/326 psi There was a pressure loss in the tubing of 84 psi in the first 15 minutes and 29 psi in the second 15 minutes for a total loss of 113 psi in 30 min. Attachments: none Plug Verification PBU 07 -10A 12 -13 -12 bn • • scifo[E o[p ansg SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Josiah Igwe / Wells Engineer 0 it; BP Exploration (Alaska), Inc. L ��"` P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07 -10A Sundry Number: 312 -311 Dear Mr. Igwe: AUG 3 :p. �U1 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. 5'7 4-- Commissioner DATED this 3/ day of August, 2012. Encl. STATE OF ALASKA g.. *'t R ECEIVED AL KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL AUG 0 9 2012 • 20 AAC 25.280 t1 n OCCC . 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program • ® Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other _ 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 198 - 016 ' 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20335 - 01 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 07 -1 OA Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028309 / Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13405' • 9035' ' 13313' 9026' 11580' None Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20" 109' 109' 1530 520 Surface 2706' 13 -3/8" 2706' 2706' 4930 2670 Intermediate 9428' 9 -5/8" 9428' 8562' • 6870 4760 Production Liner 4436' 7" 4992' - 9428' 4980' - 8562' 8160 7020 Liner 4156' 4-1/2" 9243' - 13399' 8426' - 9034' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10835' - 13240' 9018' - 9022' 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 / L -80 9247' Packers and SSSV Type: 7" x 4-1/2" Baker S -3 packer Packers and SSSV 9116' / 8332' 7" x 4 -1/2" Baker S -3 packer MD (ft) and TVD (ft): 9191' / 8387' 12. Attachments: 13. Well Class after proposed work: _i Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 20, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe, 564 -4753 Printed Name Josiah Igwe Title Wells Engineer t �,. Prepared By Name /Number: Signature Nv a Phone 564 - 4753 Date 6/b//2_, Terrie Hubble, 564 -4628 Commission Use Only Co Sundry Number: . .3/c2. ., 3 / 1 itions of approval: Notify Commission so that a representative may witness t. Plug Integrity ❑BOP Test ❑Mechanical Integrity Test ❑Location Clearance / / Other: / r /_ 17 9 `y / t.., 9 l f L 7 t � pt kl I i ;i'7 .. (I /0 ti T _ 4'c' a (-C. 2 it 1 i t-' e;C l 4'7 l ['' Subsequent Form Required: Approved By: f COMMISSIONER APPROVED BY THE COMMISSION Date e37/1z_, Form 10 -403 Revi 01 010 /,*� ' � AUG 3 ZO Submit In Duplicate \v OP IPI 1 i • To: J.Bixby & R.Liddelow, Wireline Ops Team Leads Date: June 9, 2012 C.Olsen & T.Norene, Well Services Ops Leads From: Tim Lee Pad Engineer Code: APBRISK Josiah Igwe Intervention Engineer Subject: 07 -10A Reservoir Abandonment IOR: N/A Est. Cost: $200,000 Please perform the following: 1. S Pull 4 -1/2" PX plug, Drift to max deviation . 2. F Plug #1 ( TD - 10080' md), WOC for 3 days. 3. S SLB Slick Line: Drift and Tag top of cement / MIT -T to 3000 psi (AOGCC must witness). 4 E Punch Tubing from 9106' — 9101' 5. F Plug #2 (9106' — 7606') 6. S Drift and tag cement / MIT to 3000 psi ( AOGCC must witness) Well Status: Current Status: SI for high GOR: naturally flowing producer (swing well) • (Well is twinned with 07 -32B) Last Test: 7/13/10 548 BOPD, 69 BWPD, 30.3 MMCFD at 55,250 GOR Max Deviation: 70° @ — 10185' MD; 90° @ — 10500' MD Minimum ID: 3.813" @ 9086' MD, 4 -1/2" HES X- Nipple Last Downhole Op: 7/18/10 Set DGLVs for MITIA Last Drift: 7/9/10 CT tag 10856' CTMD with 3.7" drift SBHP/T 3250 psi / 198 deg F Latest H Value: 30 ppm on 4/30/2007 JOB OBJECTIVE As part of BP's risk mitigation program to minimize the number of unsecured non - operable • wells across its area of operation, well 07 -10 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 r sidetrack in the future. Page 1 of 8 • The abandonment will require cement to be pumped in two stages. For the first stage we will bullhead cement from the top of CIBP to the 10080'. After waiting on cement and tagging the top of cement we will pump a balanced cement plug with the top of cement in the T and IA at 7606'. This will provide a -1500' column of cement above the Sag River in the tubing and all annuli. Well History Well 07 -10A was sidetracked with Doyon 14 in August 1998 to replace the vertical completion with a horizontal in Zone 1A/B just above the HOT. 2900' of horizontal was drilled with 1300' of perfs shot in predominantly Zn 1B. This includes 100' of very poor quality Zn 1A (very toe in HOT). The well encountered about 200' of HOT in the central portion. Two faults were also crossed. The rig replaced the 3 -1/2" tubing with new 4 -1/2" tubing with GLM's. Well 07 -10A is twinned with 07 -32A in the HP system. The well was never entered until it failed a TIFL and the GLV's were dummied in April 2002. A caliper and multiple LDL's showed very bad tubing and multiple leaks. It was shut -in and secured with a TTP in September 2002. The well remained shut -in until a RWO by Nabors 4ES in September 2003. The 4 -1/2" L -80 tubing was pulled and a new chrome 4 -1/2" x 5 -1/2" was run. The 5 -1/2" extends down to the 7" scab liner. The well came BOL and stabilized at 1100 BOPD at 20,000 GOR. The SSV failed it's state test on 4/1/08, causing the well to be shut -in until 6/29/08 when the tree was changed out. In May 2009 an MCNL with an IPROF was logged by CTU #5, indicating most of the flow was coming from the second half of the lateral. A CIBP was set on 7/9/10 @ 11,580' MD, resulting in oil and gas rate reductions of -150 bopd and - 13MMSCFD, respectively. The GOR stayed about the same at 55,000. A TIFL failed on 7/15/10. DGLVs were set and an MITIA failed on 7/21/10 with 0.46gpm liquid leak rate. VOLUMES Tubing OD ID bbl /ft S Co c ". 604 ha Cf!/b f 4 -1/2 ", 12.6# 4 -1/2" 3.953" 0.0152 /� 7 ", 29# 7 6.184" 0.0371 ing ✓ ` Casing OD ID bbl /ft wag Ayr Ito jor /"' " 9 -5/8 ", 47# 9 -5/8" 8.681 0.0732 Wpr(4 issue. A o� '4j Annular Capacity 9 -5/8" x 7" 0.0256 r1 c 11 CU1 ?r kffrior 9 -5 /8 "x 5 -1/2" 0.0438 Are>ectro ,r,. �� , 9 -5/8" x 4 -1/2" 0.0535 � 7" x 4 - 1/2" 0.01748 f6 41 hh r'MP"Over _s � 1 toil 144 prt, r�{ , Anncomm: �� > 06/29/08: Tree changed out diL > 07/11/08: Pulled TTP > 06/10/09: Set generic GL design Page 2 of 8 • • > 06/23/09: TIFL Failed for overnight IAP BU > 06/28/09: CIO OGLV > 06/29/09: TIFL Passed > 07/01/09: PPPOT -IC Passed to 3500 psi > 08/13/09: TIFL Passed > 07/11/10: Set CIBP at 11580' for zonal isolation > 07/14/10: Op called in high IAP > 07/15/10: TIFL Failed > 07/18/10: Pull OGLV #1 and LGLV #2 > 07/19/10: Set DGLV Sta #2 & 1, MIT -IA Failed > 07/21/10: MIT -IA Failed, LLR — 0.46 gpm © 3000 psi > 07/28/10: PPPOT -IC Passed > 08/01/10: OART Failed > 08/06/10: Set TTP @ 9140', MIT -T Passed to 3000 psi > 08/07/10: MIT -IA Failed > 08/08/10: MIT -IA Failed, LLR of 0.58 gpm > 06/16/12: MIT -T, to 3000 psi Passed, CMIT -TxIA to 2500 psi Failed, LLR is .80 gpm > 06/25/12: LDL, Leak found at Full Open Cementer FOC on 2359' Contacts: Josiah Igwe Wells Engineer Office / CeII: 564 - 4753/590 -0610 TimLee Petroleum Engineer Office / CeII: 564 - 4904/360 - 3585 07 -10A Well Status: o Cement Filled to 7" TOL o Pumped 101 bbls of cement on the 4 -1/2" Liner o Top of cement behind 9 -5/8" casing is @ 4559' o THRZ is at 8255' and (7613' TVDSS) o The top of Sag is at 9289' and ( -8396' TVDSS) o Top out cement job with Arctic pak to surface on 9 -5/8" casing annulus. o 13 -3/8" casing cemented to surface with 15.2 ppg Artic set cement o PX plug set at 9140' 1. Slickline: 1. MIRU Slick Line 2. MU tool string and retrieve PX plug at 9140' 3. Drift to maximum deviation. 4. RDMO Page 3 of 8 • • Cement Design: BHST: 198 degF BHCT: 170 degF SBHP: 3250 psi Slurry density: 15.8 ppg Thickening time: 6 -8 hours Fluid Toss: 60 - 80 cc/30 min Estimated zone tops: Top of Sag - 9289' md, 8389' tvd (8352' tvd, 9077' md) THRZ is at 8255' md, 7613' tvd Top of Sadlerochit - 9200' md, 8452' tvd Offline opportunities: • Grease all tree valve cavities, including SSV • Lock wing closed • PT all iron per SOP: Well Entry Procedures • Close lateral valve • Ensure SLB has transducers to monitor IAP • Service all tree valves and annular valves 2. Full bore Plug #1: 1. MIRU SLB cement Unit o Ensure to rig up iron for fullbore cement job with ball launcher loaded with 8" foam balls. Include horse trailer or 4 way manifold so that SLB only needs to rig up to the trailer. 2. Rig Up Fullbore Cementers and test lines to 3,500 psi with fresh water. 3. Spear in 5 bbls of 60/40 meth followed with 200 bbls of 1% KCL down tubing to condition well bore fluid and cool down PBTD o Returns will be bullheaded into the formation but monitor the surface pressure gauges and bleed if necessary. 4. Pump cement as follows to put TOC at 10080' md: o 5 bbls of fresh water followed by Page 4 of 8 • ,? _3 , may l ( o 23 bbls of 15.8 ppg Class G Cement s o 2 bbls of fresh water to clear lines 11..- O 8" wiper ball lunched through the launcher o 2 bbls of fresh water o 185 bbls of warm diesel 5. Shut -in and wash up cement unit. RDMO 6. Have Tree Valves and Annulus Valves greased after rig down. 7. WOC 3 Days. ,1vc t7 X 4c c i rC 2 4 I-7 <'g / ri Target TOC: 10,080' MD cl ei ' i �� c cr /;I� JJ %"' f o / /1F' 1 3. Slick Line: Drift and tag cement / MIT -T (Sundry requires AOGCC must witness this step): 1. MIRU Slick Line 2. Drift to top of cement with centralizer and sample bailer at — 10080' md, note sample and depth in the AWGRS. 3. MIT -T, LLR if it leaks 4. Send test chart to Josiah.lgwe( bp.com and retain hardcopy. 4. E -Line Tubing Punch: 1. MIRU E -Line 2. MU and RIH tool string with CCL and 5' tubing puncher with MPDs. Load at 4 SPF with "20DL" charges. 3. RIH and punch tubing from 9106' to 9101'. • Tie to Tubing - e- - • ? 3/2003. 4. Establish communication by pumping down Tubing and up IA to the formation with 50 bbls of warm diesel. 5. RDMO 5. Full bore Plug #2 1. MIRU SLB cement Unit Page 5 of 8 • • • Ensure to rig up iron for fullbore cement job with ball launcher loaded with 8" foam ball. Include horse trailer or 4 way manifold so that SLB only needs to rig up to the trailer. 2. Rig up Cementers and test lines to 3,500 psi with fresh water. 3. Pump cement as follows to put TOC from 9106' to - 7606': o 5 bbls of 60/40 meth o 100 bbls of 1% KCI water / o 77 bbls of warm diesel (.4 qi,i/,,j - ) /J `0 O 200 bbls 1% KCI l 47 j z Z O 10 bbls of fresh spacer o 49 bbls of 15.8 ppg Class G Cement. o 2 bbls of fresh water to clear lines o 8" wiper ball lunched through the launcher o 5 bbls of fresh water o 77 bbls of 1% KCI o 68 bbls of warm diesel 4. Shut -in and wash up cementing Unit. RDMO 5. Well support to grease tree and IA valves 6. WOC 3 Days. ^ I h J G trrl l v' G� C l y( ✓ c' f / / G j ; �i f r ln-z 5 6. Slick Line Drift and taq cement / MIT -T (Sundry requires AOGCC must witness this step): 1. MIRU Slick Line 2. Drift to top of cement with centralizer and sample bailer at - 7606' md, note sample and depth in the AWGRS. 3. MIT -T, LLR if it leaks 4. Send test chart to Josiah.lowe(a bp.com and retain hardcopy. 5. The Sundry requires us to notify the state to witness pressure testing of cement in the tubing and casing. Page 6 of 8 • • TUBING SUMMARY ` RIG Nabors 4es Date 9/23/2003 WELL # 07 -10a TUBING 4.5" x 5.5" 13Cr 80 Vam Top TBG WT. 12.6/17 lb/ft 221 JTS RAN 18.60 4es RKB to BF 10666.88 FT ON RACK 8965 FT RAN ITEM Description includes: SIZE, TYPE, CONNECTION (JTS #- #) ID OD LENGTH TOP BOTTOM Unique Overshot 6.55' swallow of 4.65" ID 3.940 5.990 7.10 71;0946047- 9157.67 4 1/2" 12.6 #, 13Cr -80, VAM TOP, pup jt 3.958 4.980 9.75 9140.82 9150.57 4 1/2" 12.6 #, 13Cr -80, VAM TOP, pup jt 3.958 4.930 9.59 9131.23 9140.82 41/2' 'X" NIPPLE w/ RHC -M PLUG 3.813 5.030 1.24 9/39 9131.23 4 1/2" 12.6#, 13Cr -80, VAM TOP, pup jt 3.958 4.930 9.82 9120.17 9129.99 4 1/2" 12.6#, 13Cr -80, VAM TOP, pup jt 3.958 4.930 9.74 9110.43 9120.17 BAKER 7" X 4.5" S-3 PACKER 3.875 5.968 3.739J/b- 49406.79. 9110.43 4 1/2" 12.6 #, 13Cr -80, VAM TOP, pup jt 3.958 4.930 9.72 9096.98 9106.70 4 1/2" 12.6 #, 13Cr -80, VAM TOP, pup jt 3.958 4.930 9.59 9087.39 9096.98 4 1/2" "X" NIPPLE 3.813 5.030 1.28 9695- 9066-41- 9087.39 4 1/2" 12.6 #, 13Cr -80, VAM TOP, pup jt 3.958 4.930 9.89 9076.22 9086.11 60 jts 4 1/2" 12.6#, 13Cr -80, VAM TOP tbg 3.958 4.930 2519.41 6556.81 9076.22 4 1/2" x/o pup Fox Box x Vam Top pin 3.958 4.930 7.66 6549.15 6556.81 4 1/2" x 1" KBG -2LS GLM w/ DGLV / RK 3.958 5.985 7.25 5526544:98 6549.15 4 1/2" x/o pup Fox box x NSCT box 3.958 4.930 2.25 6539.65 6541.90 4 1/2" x/o pup Vam TOP box x Fox pin 3.958 4.930 7.48 6532.17 6539.65 47 jts 4 1/2" 12.6#, 13Cr -80, VAM TOP tbg 3.958 4.930 1966.30 4565.87 6532.17 5.5" x 4.5" WO Vam Top Box x Pin 9cr 4.892 6.085 2.2545 4565.87 15 jts 5 1/2" 17 #, 13Cr -80, VAM TOP tbg 4.892 6.085 623.17 3940.45 4563.62 5 1/2" 17 #, 13Cr -80, VAM TOP, pup jt 4.892 6.085 9.81 3930.64 3940.45 5 1/2" x 1.5" MMG GLM w/ DCR -1 / RKP 4.750 7.937 9.103931 331:1.4 3930.64 5 1/2" 17 11, 13Cr -80, VAM TOP, pupjt 4.892 6.085 9.89 3911.65 3921.54 44 jts 51/2" 17 #, 13Cr -80, VAM TOP tbg 4.892 6.085 1805.19 2106.46 3911.65 5 1/2" 17 #, 13Cr x/o pup TCII x Vam Top 4.892 6.085 9.83 2096.63 2106.46 5 1/2" HES "X" NIPPLE 4.562 6.070 1.50 6,43 2096.63 5 1/2" 17 #, 13Cr x/o pup TCII x Vam Top 4.892 6.085 9.91 2085.22 2095.13 34 jts 51/2" 17 #, 13Cr -80, VAM TOP tbg 4.892 6.085 1386.99 698.23 2085.22 5 1/2" 17 #, 13Cr x/o pup TCII x Vam Top 4.892 6.085 9.79 688.44 698.23 5 1/2" 17 #, 13Cr x/o pup New Vam x TCII 4.892 6.085 1.82 686.62 688.44 21 jts 5 1/2" 17 #, 13Cr -80, New VAM tbg 4.892 6.085 664.07 22.55 686.62 5 1/2" 17 #, NSCC, pupjt 4.892 6.085 2.30 20.25 22.55 TBG HANGER 4.892 13.00 1.65 4576& 20.25 RKB 48766- 26 DO 4566- .2100 • • 2.110C • I/2 k* Q i,q1 a,f- "AA • • f regsl tvi- • • Gary K. Ct 1rrn • Page 7 of 8 • 4111 . , -,.. 7-1116' FMC . WELLHEAD = GRAY 0 - 10A SAFETY NOTES: WELL ANGLE ) 70' it 10185' ** ACTUATOR= BAKER 'C' 4-112" & 5.112° CHROME TBG*** KB. ELEW = 62 it 1 BF. ELEV = ? 2104 H5-1:2^ HES X NP, C 4.562" INCYR = 4696 Atix'Arg■9 = 95 -4 1 19 xi 2' CONDUCTOR 1--1-11 11 _. 1 FOC Dat."7 MO = 10036' baLtr- TsiD = saoct ss . 2486' 9-5'3" FOC ......- I 9.-5/6" CSG. 4 50095 BTC X0 TO L-80 BTC H 2511' ....., 1116 5-1;2' 'BG GAS LET MANDRELS I 13-3S' CSG 720. 14-80, u= 12, 347' H 2706 Si MO I TV D I DEVI TYPE I VLV 'LATCH] FOR DATE 2 3932139321 1 WA I MY 1 Pt< I 0 07,091 0 Minimum ID = 3.813 @ 9086' HES X NIPPLE I 4574' 1-15-1/2" X 4-12' X0, ID 3.958' I 5-1,2" TBG. 17*, ix R.60 VA1.4 TOP. 4574' I ". NI 4-1;2' TBG GAS L Fr1 ,02.D bpi, C=4.692' H 4992' 11 51 wic I iv o I °Ey 1 71' FE I VLV 'LATCH I PORT! okrE 1 16553162701 39 11tB(32L51 MY I INT 1 0 15711910 9-53' CSG, 47*, ,--80 8°C X0 TO 50035 BTC ft 8739' I I 9095 F14112 HES X NIP, C = 3.813' I X p: 9116' I r x 4-1.2' BKR 5-3 R03, 13= 3.875' I 4-1,2" TOG. 12,64, 13C R-80 VAM TOP --I 9161' _I 1 9140. H# lir HEB X RP, C = 3.813' I .0152 opf, 10= 1958' NI I4- 5TLB (MG 'AG 20331 H 9163' I i I 9168 Hr X 4-1..21_11410IJE MA CAVE OV ERS HO I $ z 9191' Fir X 4-1.2' BK R 5-3 FKR ID = 3.875' I I I 9225' H4-1,1 HES X NIP. C = 3.813' I ITOF OF 4-1,7 Lf•ft H 9243' I., I 4- 1 2' Tli, 12.60. L-80 %CT, .3 152 o C =1958" H 9247' 'I 9243' 13 125' BKR ZXPPKR w I TEBK SLV & WC LP MGR, - 4.43 7 " PERFORA - ION SUMMARY 9247' I—I4- 1:7 WLEG, 0= 3.958' REF LOG: 1,1WCYGR ON 08/518 " . .. ,,..,.... 4 HEJADT'1477LOGGED I ANGLE AT TOP FEW. 87. @ 10835 9264' F1' X 4-1.2" X0, ID = 3.958' I tile: Refer b Productbn CE fa hIstacal pail data SEE SPF WOW AL 0011/Sqz DATE 2-3(8' 4 1033 5 - 1 1120 0 08112/98 2-3/8 4 11160- 1 1550 0 06/12/96 2-3(3' 4 1 1540 - 12550 C 0012/98 2-301 4 12670 - 1 3070 C 03112f93 9-53' 5, 7 " /ALLO' WINDOW (07- 9428'- 9440' 2-3(3' 4 13130- 13240 C 09/12/98 *4 4 • kt , 1 1580' 4-12'11E5 C1BP i07:10 I I OF WHFS ? 712RIDGER.00 Fi 9449' 1 SCAB LNR, 29*, L-80 BTC„C071 b pf , ID= 6.18 4' /-1_ . 10' I ---. AIM, .110•111011 IIIIIIIIIi", .■11 Val, 13317 PSTD i L9-5 CSG, 470. 50095, BTC..0 bpi, IC= 8.681' H 10240' I-- ... LLLLLLLLLL ...or I 4- 1/2" LIIR 12.51, L-80 B bpf,U= 3.953" H 13399' ..- ' D 13405' I GATE REV BY cowers DA TE REV BY COMM3 PRLICHCE BAY UN 03106/79 ROW 34 ORIGINAL COMPLETION 1118108 P.IC DRAWNG CORRECTS:NS WELL: 07-10A 04124/90 AU014 RWO 06:10..09 JC%8 OLV CO PERMT ND: v lS00160 08114/98 014 SIDETRACK (07-10A) 0528109 ACEI: GLV 0,0 AF1 No: 50-029-20335-01 0926.03 N4ES RWO 07:11,10 CJ&SV SE CEP /07110..10) SEC 33, T1 1N, R14E 216 FEL & 9EKS FNL 3r3(o634 JUPTLP GLV GO 0724-10 5WCIA GR C. C/0 (07/19 0 7 22,08 DSONSV TREE C.0 .. 06:30108i BP BtploratIon (Alaska) • Page 8 of 8 ELLHRD= GRAY P 40" & 5 -1/2" CHRCME TBG*** ;TUATOR = BAKER "C" ® Old ceme� 3. ELEV = 62' E E, = ? New Cement JP = 4698' I 2104' IH 5 -1/2" HESX NIP, ID = 4.562" ax Angle = 95° @ 11930' 20" CONDUCTOR H 109' iturwMD= 10036' - 2359' I -I9- 5 /8 "FOC atum TVD = 8800' SS 2486' 1-19-5/8" FOC 9 -5/8" CSG, 47 #, S0095 BTC XOTO L -80 BTC H 2511' I/ X 5 -1 /2 "TBG G AS LIFT MANDRB S 13-3/8" CSG, 72 #, N -80, ID = 12.347" I-I 2706' ST MD TVD DEV TYPE VLV LATCH PORT DAT L 2 3932 3932 1 MMG DMY RK 0 07/19/ Minimum ID= 3.813 @ 9086' HES X NIPPLE / 4574' H5- 1/2 " X4- 1/2 "X0, ID= 3.958" I 5 -1/2" TBG, 17 #, 13CR -80 VAM TOP, H 4574' ,0233 bpf, ID = 4.892" 4-1/2" TBG GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DAT 9 -5/8" X 7" LTP & HGR ID = ? I 4992' U 1 6553 6270 39 KBG2LS DMY INT 0 07/19/ 9 -5/8" CSG, 47 #, L -80 BTC XOTO SO095 BTC IH 8739' p . X Top of Cement at 7606 ,,/ .{ 9095' h4 -1/2" HESX NIP, ID= 3.813" I 9116' 1-i 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, H 9161' 0152 bpf, ID = 3.958" ' 9140' H4-1/2" HESX NIP, ID = 3.813" I 9140' I - I4 -1/2" PX PLUG(08 /06/10) J 4 -1/2" STUB (RIGTAG 2003) H 9163' 9168' H7 " X4- 1 /2 "UNIQUEMACHNEOVERSHOT I `, C I X 9191' H7" X 4-1/2" BKR S -3 PKR, ID = 3.875 I 9225' h4 -1/2" HESX NIP, ID= 3.813" I TOPOF4 -1/2" LNRI-f 9243' -1/2" TBG, 12.6 #, L- 80 NSCT, .0152 bpf , ID = 3.958" H 9247' -I 9243' I- 7" X 5" BKR ZXP PKR w / TIEBK SLV L & HMCLNRHGR, ID - 4.437" PERFcRATICN SUMMARY 9247' H4-1/2" WLEG, ID = 3.958" REF LOG: MWD/GR ON 08/98 ANGLEATTOPPERF 87° @ 10835' H ELMD TTNOTLOGG® Note: Refer to Production DB for historical perf data 9264' H 5" X 4-1/2" XO, ID = 3.958" I SIZE SPF INTERVAL Opn /Sqz DATE 2 -3/8" 4 10835 - 11120 0 08/12/98 2 -3/8" 4 11160 - 11550 0 08/12/98 Top of Cement at 10080' 2 -3/8" 4 11640 - 12550 C 08/12/98 2 -3/8" 4 12670 13070 C 08/12/98 9 -5/8" & 7" MILLOUTWINDOW (07 -10A) 9428' - 9440' 2 -3/8" 4 13130 - 13240 C 08/12/98 - 11580' 4 -1/2" HES CIBP ((07/10/10) TOP OFWHIPSTOCK I—I ? 7 "BRIDGEPLUG I-I 9449' 13312' PBTD 7" SCAB LNR, 29 #, L- 80 BTC, .0371 bpf , ID = 6.184" H 10180' -_` 21111 AMILIMIIIIIMIM -5/8" CSG, 47 #, SOO95, BTC, .0732 bpf, ID = 8.681" H 10240' . }..p.w.■ 4 -1/2" LNR, 12.6 #, L- 80 IBT, .0152 bpf , ID = 3.953" h 13399' TD H 13405' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHO BAY UNIT 03/06/79 ROW34 ORIGINAL COMPLETION 08/30/10 RC17PJCSET PX PLUG (08/06/10) WELL: 07 -10A 04/24/90 AUDI 4 RWO PERMI1No: 1980160 08/14/98 D14 SIDETRACK (07 -10A) API No: 50- 029 - 20335 -01 09/26/03 N4ES RWO SEC33, T11 N, R14E, 216' FEL& 980' FNL 07/11/10 CJS /SV SET CIBI(07/10/10) 07/24/10 SWC /AGF GLV C/O (07/19/101 BP Exnloratinn (A laskal NOT OPERABLE: Producer 07-10A •D #1980160) Secured with Downhole~g Page l s~~ Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Monday, August 09, 2010 11:10 AM I~ClG~ ~ ~IJIt~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, GGy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 OSM; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production Optimization Engineer Cc: AK, D&C Well Integrity Coordinator; King, Whitney; Lee, Timothy Subject: NOT OPERABLE: Producer 07-10A (PTD #1980160) Secured with Downhole Plug All, Producer 07-10A (PTD #1980160) has failed aMIT-IA and has been secured with a down hole plug on 8/8/2010. The well is reclassfied as Not Operable and will remain shut iri until tubing integrity can be restored. Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger} Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Thursday, July 15, 2010 10:16 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Engel, Harry R; AK, D&C Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility ; AK, OPS GCl OSM; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production timization Engineer Cc: AK, D&C Well Integrity Coordinator; King, Whitney; Lee, Timothy Subject: UNDER EVALUATION: Producer 07-10A (PTD #1980160) for Sustained casing press due to TxIAxOA Comm All, Producer 07-10A (PTD #1980160) has been found to hav ustained casing pressure on the IA and OA. The wellhead pressures were tubing/IA/OA equal to 23 /2380/1030 psi on 07/15/10. A subsequent TIFL failed the following day on IA repressurization. The ell has been reclassified as Under Evaluation and may be produced under a 28-day clock. The plan forward is as follows: 1. DHD: TIFL FAILED 2. Slickline: Set DGLVs 3. Pumping: MIT-IA to 3000 i, LLR if fails 4. Wellhead: PPPOT-IC 5. DHD: OA repress zation test A TIO plot a~ad wellbore schematic have been included for your reference. 8/10/2010 UNDER EVALUATION: Producer O~OA (PTD #1980160) for Sustained ca pressure due t... Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] I j Sent: Thursday, July 15, 2010 10:16 PM ~~1 71~3~io To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS FS3 DS Ops Lead; AK, OPS FS3. Facility OTL; AK, OPS GC1 OSM; AK, RES GPB East Production Optimization. Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production Optimization Engineer Cc: AK, D&C Well Integrity Coordinator; King, Whitney; Lee, Timothy Subject: UNDER EVALUATION: Producer 07-10A (PTD #1980160) for Sustained casing pressure due to TxIAxOA Comm Attachments: 07-10A TIO Plot 07-15-10.doc; 07-10A.pdf All, Producer 07-10A (PTD #1980 60) has been found to have sustained casing pressure on the IA and OA. The wellhead pressures were tubing/IA/OA equal to 2380/2380%1030 psi on 07/15/10. A subsequent TIFL failed the following day on IA repressurization. The well has been reclassified as Under Evaluation an3-- may be produced under a 28-day clock. The plan forward is as follows: 1. DHD: TIFL FAILED 2. Slickline: Set DGLVs 3. Pumping: MIT-IA to 3000 psi, LLR if fails 4. Wellhead: PPPOT-IC C 5. DHD: OA repressurization test .,.. 1~ ~ ~ 1;, ~ tai ! ~)~s~ A TIO plot and wellbore schematic have been included for your reference. «07-10A TIO Plot 07-15-10.doc» «07-10A.pdf» Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 --~ Gj s~~ " ~oq~ ~ ~i ?pp F ~KP - v I ~C~P„ Sip = ~3~~t ~ ~ ~r~ z ~_~ 13~~~' N ~~ .7L~ ~P = to3~,~ ~~- c~~ ~ v ~i2oi2o 10 PBU 07-10A PTD 1980160 7/15/2010 TIO Pressures Plot Well: 07-10 • TREE= 7-1/16" FMC WELLHEAD= ~ ACTUATOR = GRAY m. _.~. BAKER "C" KB. ELEV = 62' - BF. ELEV = KOP = 4698' Max Angle = 95° @ 11930' Datum MD = .............10036' !, Datum TV D = 8800' SS 120" CONDUCTOR 1 v>~ 2104' -15-1/2" HES X NIP, ID = 4.562" 2359' s-5/8^ FOG 24$6' 9-5/8" FOC ® 5-1l2" TBG GAS LIFT MANDRELS ~' ST MD 7VD DEV TYPE VLV LATCH 2 3932 3932 1 MMG DOME RK _ 4574' S-112" X 4-1i2" XO, ID = 3.958" 9-5i8" GSG, 47#, S0095 BTC XO TO L-80 BTC (-~ 13-3l8" CSG, 72#, N-80, ID = 12.347" Minimum ID = 3.813 @ 9086` HES X NIPPLE 5-1l2" TBG, 17#, 13CR-80 VAM TOP, ,0233 bpf, ID = 4.892" 9-518" X 7" LTP &HGR, ID = ? '' 9-5(8" GSG, 47#, L-80 BTC XO TO S0095 BTC ', 4-1/2" TBG GAS LIFT MANDRELS DEV TYPE VLV LATCH 39 KBG2LS SO INT 9095' ~--~4-1,12" HES X NIP, fD = 3.813" -{ 9116' ~--~7" X 4-1i2" BKR S-3 PKR, ID = 3.875" 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 9161` - .0152 bpf, ID = 3.958" 9140' 4-1 /2" HES X NIP, ID = 3.813' ~4-112" STUB (RIG TAG 2003) 9163' 916$' 7" X 4-112"UNIQUE MACHINE OVERSHOT 9191` 7" X 4-112" BKR S-3 PKR, ID = 3.875" 9225' 4-1(2" HES X NIP, ID = 3.813" TOP OF 4-1 /2" LNR 4-112" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: MWD/GR ON 08/98 A NGLE AT TOP PERF: 87° @ 10835' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/8" 4 10835 - 11120 O 08!12/98 2-3/8" 4 11160 - 11550 O 08!12/98 2-3/8" 4 11640 - 12550 C 08112/98 2-318" 4 12670 - 13070 C 08/12/98 2-318" 4 13130 - 13240 C 08/12/98 TOP OF WHIPSTOCK - ~~ 7"BRIDGE PLUG 9449' 7"' SCAB LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 101$0' 9-518" CSG, 47#, S0095, BTC, .0732 bpf, ID = 8.681" 10240' 4-1 t2" LNR, 12.6#, L-80 IBT, .0152 bpf, iD = 3.953" TD 13312' H PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 03!06!79 ROW 34 ORIGINAL COMPLETION 11!18/08 PJC DRAWING CORRECTIONS 04!24/90 AUD14 RWO 06/10!09 JCMVTLH GLV C/O 08(14/98 D14 SIDETRACK {07-10A) 06!28/09 ACB/TLH GLV C/O 09/26103 N4ES RWO 07!11/10 CJS/SV SET CIBP (07110110) 09/06104 JLJ/TLP GLV C/O 07/22(08 DSNUSV TREE C/O (06130/08} PRUDHOE BAY UNIT WELL: 07-10A FERMTf No: 1980160 API No: 50-029-20335-01 SEC 33, T11 N, R14E, 216' FEL & 980' FNL BP Exploration {Alaska} • ~ ~ 4-1/2~T2S C ROME TBG **~ 70° @ 101$5' *** 9243' 7" X 5" BKR ZXP PKR w t TIEBK SLV & HMC LNR HGR, ID - 4.437" 8247' 4-112" WLEG, ID = 3.958" ELMD TT NOT LOGGED 9r 264' 5" X 4-1/2" XO, ID = 3.958" 9-5/8" & 7" MILLOUT WINDOW {07-10A) 9428' - 9440' _ 115$0' 4-112" HES CIBP (07110/10} ~~~F~~~~~~~~ .t Iu~; ,`?' 4~~t~°^' F~.. t ~~' ~~, h f~ " ~f {'' ~ ~~_ti~~ ~~~~ ,. N0.5310 ~,laska Data F~ Consuiting Services Company: State of Alaska 2525 Gambeu Sereet, Suite aoo Alaska Oil & Gas Cons Comm ~Anchorege, AFf 99503-2838 Attn: Christine Mahnke3n t4'~Tfv: Beth 333 West 7th Ave, Suite~ 100 Anchorage, AK 99501 IAlell Job # Log Description Date BL Color CD PLEASE ACKRIOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exptoration (Alaska) Inc. Petrotechnicai Data Center LR2-1 900 E. Benson Blvd. "` i ;~ ~ ,~ 1 ~ 07/14/09 Z-20 AP3Q-00043 SBHP SURVEY O6H7/09 1 1 P2-31 AZCM-00029 LDL G~ 06/17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 06/15/09 1 1 ~-148 AYQQ-00036 TEMP SURVEY & BHP O6/23/09 1 ~ 6~-16 AP3Q-00042 SBHP SURVEY ` ~ ~ 06/16/09 1 1 V~Q5.,: 11999053 USIT 10/12/OS 1 1 ,~' RI-71G AP3Q-00042 SBHP SURVEY 06/16/09 1 ~ '""'" -1`3-12 AY3J-00030 LDL ._ 06/12/09 1 1 L1-30 AVYS-00049 PRODUCTION PROFILE -~j ~ O6/22/09 1 ~ 17-078 AYQQ-00031 SBHP SURVEY "`~ t5 06/11/09 1 1 05-25~ AP3Q-00040 SBHP SURVEY ~ 06/11109 1 1 B-27A AXBD-00028 MEAA INJ PROFILE 06/12/09 1 1 1136 6146-00066 CROSSFLOW & IBP ~ O6/23/09 1 1 ~-21A B74B-00065 SBHP SURVEY ' 06/21/09 1 1 ~-17 AYTU-00043 PROD PROFILE -/ 06/08/09 1 1 Z-25 AWL8-00018 LDL ()'Z~ ~'~- 05/28/09 1 1 02-33B AYTU-00033 USIT `~ ~ 05/19l09 1 1 P2-07 AVYS-00051 PRODUCTION PROFILE ~~ 06/25/09 1 1 13-03 AWLS-00020 LDl 06/01/09 1 1 3-i7F/K30 B2NJ-00008 MEM INJ PROFILE (J 06/15/09 1 1 IIflPS-08 AYS4-00080 LDL O6/15/09 1 ~ 13-1~ AV1H-00019 LDL 07/05/09 1 1 01-25 AYTU-00046 USIT -° ~~ 06/28/09 1 1 1N-39A AWL8-00023 STATIC TEMP SURVEY ~~ ~ 06/26/09 1 1 T Z-35 AYTO-00022 SBHP SURVEY ~ ~ 06/29/09 1 1 Z-16 AV1H-00017 SBHP SURVEY ~ ()~j 06/29/09 1 1 18-20 B581-00004 LDL ~ ,~ O6/27/09 1 1 Z-29 AVYS-00053 SBHP SURVEY ~ a=~)~j~a" ~•° '~~ 07/03/09 1 1 L5-09 07-10A AYQQ-00032 B1JJ-00022 . RST - j(- ~ MCNL - ~ 06l13/09 05/26/09 1 1 1 Alaska Data & Consuiting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ u OPERABLE: 0'7-10A (PTD #19~0160) Tubing integrity restored • Page 1 of 2 ~ Schwar~, Guy L (DOA) _ _ ~~ o~ From: NSU, ADW Weil Integrity Engineer [NSUADWWeilintegrityEngineer@BP.com] ?~y~t ~ Sent: Tuesday, June 30, 2009 7:49 AM To: Regg, James B(DOA); Schwartz, Guy L(DOA); Maunder, Thomas E(DOA); GPB, F53 DS Ops Lead; GPB, FS3 07L; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossbecg, R Steven; Engel, Harry R; GPB, WeAs Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; Kaminski, Alice Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 07-10A (PTD #1980160) Tubing integrity restored All, Wel! 07-10A (PTD #1980160) passed a TIFL after the screened orifice was changed out. The passing test confirms that tubing integrity has been restored. The well has been reclassified as Operable. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) WeN integrity Coordinator Office (907) 659-5102 Celt (406) 570-9630 Pager (907) 659-5100 E~. 1154 ~ ~~. ~?~Z.~.~4: i' _.. _ ~L~~~> .,. • From: NSU, ADW Wefl Ir~tegrity Engineer Seot: Ttwrsday, June 25, 2009 12:39 PM To: 'Regg, ]ames B(DC1Ay; Schwariz, Guy L(DOA); 'Maunder, Thomas E(DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 07L; GPB, Area Mgr Central (GCi/3/FS3); NSU, ADW WeN Operations Supervi~r; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Kaminski, Alice; GPB, Gas Lfft Engr Subject: UNDER EVALUATION: Oi-10A {PTD #1980160) for Sustained casing pressure due to TxIA Camm All, Well 07-10A {PTD #1980160) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 2390/228fl/920 psi on 06/25/09. A subsequent TIFL f~ailed later that same day. The well has been reclassified as Under Evaluation and may be produced under a 28-day clock. The plan forward for this well is as follows: 1. D: TIFL - FAlLED 2 S: C/O GLVs 3. D: Re-TI FL A TI~ plot and wellbore schematic have been included for reference. « File: 07-10A TIO Plot.doc» « File: 07-10A.pdf» 7/27/2009 OPERABLE: 07-10A (PTD #19~0160) Tubing integrity restored Page 2 of 2 ~ • Ple~se call with any questions or concerns. Thank you, Torin Roschinger (ait. Anna Dube) Weii integrity Coordinator O~Ce (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 E~. 1154 7/27/2009 I TRE~= 7-1/16" FMC Va/ElLHEAD= GRAY ACTUATOR = BAKER "C' , K.B. E1EV = _ 62' _. BF. E1EV = ? KOP = 4698' Max Angle = 95° @ 11930' Datum MD = 10036' Datum ND = 8800' SS 120" CONDUCTOR ~ 07-10 9-5/8" CSG, 47#, S0095 BTC XO TO L-80 BTC ~~ 13-3/8" CSG, 72#, N-80, ID = 12.347" Minimum ID = 3.813 @ 9086' HES X NIPPLE 5-1/2" TBG, 17#, 13CR-80 VAM TOP, ,0233 bpf, ID = 4.892" 9-5/8" X 7" LTP & HGR, ID =? 9-5/8" CSG, 47#, L-80 BTC XO TO S0095 BTC 4-1/2" TBG, 12.6#, 13CR•80 VAMTOP, .0152 bpf, ID = 3.958" 4-1/2" STUB (RfG TAG 2003; 2104, ~--~ 5-1 /2" HES X NIP, ID = 4.562" ~ 2359~ 9-5/8" Foc 2486' 9-5/8" FOC 5-1/2" TBG GAS LlFT MANDRELS " MD ND DEV TYPE VLV LATCH PORT DATE 3932 3932 1 MMG DOME RK 16 O6l10/09 4574~ 5-1/2" X 4-1/2" XO, ID = 3.958" 4-1/2" TBG GAS LIFT MANDRELS ~~ MD TVD DEV TYPE VLV LATCH PORT DATE 6553 6270 39 KBG2LS SO INT 20 06/10/09 9095~ -j 4-1 /2" HES X NIP, ID = 3.813" ~ 9116~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9140~ 4-1/2" HES X NIP, ID = 3.813" 9168~ I-~~~~X4-1/2"UNIQUEMACHINEOVERSNOT 9191~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9225~ 4-1/2" HES X NIP, ID = 3.813" ~TOP OF 4-1/2" LNR 4-1/2" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: MWD/GR ON O8/98 ANGLE AT TOP PERF: 87° @ 10835' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3l8" 4 10835 - 11120 O 08/12/98 2-3/8" 4 11160 - 11550 O 08/12/98 2-3/8" 4 11640 - 12550 O 08/12/98 2-3/8" 4 12670 - 13070 O 08/12/98 2-3/8" 4 13130 - 13240 O 08/12/98 ITOP OF WHIPSTOCK I ? \ 7"BRIDGE PLUG 9449~ 7" SCAB LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 10180~ 9-5/8" CSG, 47#, S0095, BTC, .0732 bpf, ID = 8.681" 10240~ 4-1/2" LNR, 12.6#, L-80 IBT, .0152 bpf, ID= 3.953" - TD 9243~ ~ 7" X 5" BKR ZXP PKR w/ TIEBK SLV & HMC LNR HGR, ID - 4.437" 9247' 4-1/2" WLEG, ID = 3.958" ~ ELMD TT NOT LOGGED J264' 5" X 4-1 /2" XO, ID = 3.958" 9-5/8" & 7" MILLOUT WINDOW (07-10A) 9428' - 9440' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/79 ROW 34 ORIGINAL COMPLETION 11/18/08 PJC DRAWING CORRECTIONS 04/24/9Q AUDI 4 RWO O6/10/09 JCNUTLH GLV GO 08/14/98 D74 SIDETRACK (07-10A} 09/26/03 N4ES RWO 09/06/04 JLJ/TLP GLV C/O 07/22lO8 DSfWSV TREE C/O (06/30/08) 13312' H ~To PRUDHOE BAY UNfI" WELL: 07-10A PERMff No: 1980160 API No: 50-029-20335-01 SEC 33, T11 N, R14E, 216' FE1 & 980' FNL BP Exploration (Alaska) ~ ~ . Well 07-10A (PTD #1980160) ,~ ~ ._ T~fl ^ IA 2000 -a__ Op OOA • OOOA ~ ' ~ On N~~ ^ ~N ~ 1 000 l ~~~ 03RBN9 OC/01/W U8/11l09 ~7/18/05 D1/25/UV 05rD2/Q9 U5/~/CFJ 05.~16/09 O~i/13IQ9 05/30/09 U6/06109 fffin3/L'q O6/20/09 Sc6b~~g~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.5279 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD os/1 s/os 14-23A AYKP-00016 USIT 04/10/09 1 1 A-44 AP3O-00036 SCMT - 04/28/09 1 1 14-23A AYKP-00016 USIT _ 04/10/09 1 1 07-10A B1JJ-00022 MEM CN STP 05/26/09 1 1 07-14B AYOO-00029 LDL _ - ~- ~ 05/26/09 1 1 12-09 AYTU-00038 PRODUCTION PROFILE .® 05/31/09 1 1 V-218 AVY5-00048 INJECTION PROFILEIWFL J^ p 05/29/09 1 1 15-34A AWJI-00020 MCNL 04/20/09 1 1 A-44 AWL8-00017 CH EDIT PDCL-GR (SCMT) - 05/25/09 1 F'LtA,C At:RIVVYVLtUUt titl:tlY1 tlT ,IlaIVllVta AIVU tttl VFirVllVla UIVt I:UYT tA(:t7 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 fl 900 E. Benson Blvd. ~ '~"`%i~a~~, ~~t.~~Y a, < ~U~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 07-10A (PTD #1980160) Classified as Problem Well ') Subject: 07-10A (PTD #1980160) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 03 Sep 200409:54:02 -0800 '. .. TO;':."Cahalane, Ted W" <CahalaTW@BP.com>, "GPB, FS3 TL" .<GPBFS3TL@BP.com>, "Rossb~rg~.R.Steven" <RossbeRS@BP.com>,."NSU, .ADW Well Operations SuperVisor"'.. <NSUADWWellOperationsSupervisor@BP.com>; "GPB,WellsOpt Erig". ... : . . <CJ:PIiWellsOptEng@BP.com>,. "AOGCCJim Regg(F>mail)" <jiin~regg@~dmin"state.ák~us>~.' ttAOGCCWintón .Aubert.(E~mail)tI.<winton~flubert@admin.state.ak.us>. "NSU, ADWWL& ... Completion Supervisor" <NSUADWWL&CompletionSuperv-isor@BP :com>,. "GPB,.FS3 DS Op~ratQrs" <GPBFS3DSOperators@BP.com>' ... . . .':. '.. ~: ..... .... . ..... ". . . '.. CC: "NSU, ADW Well Integrity Engin~er't'~NSUADWWellIntegrityEngïn~er@BP.com>; ,ftReeves~:. Donald'F" <ReevesDf@BP.com>.. .... .'., . ..'.'. . . . ) All, Well 07-10A (PTD #1980160) has been found to have sustained casing pressure on the IA. The TIO's on 08/30/04 were 2350/2220/1270. A TIFL Failed on 08/30/04. The OA pressure was bled down and is being monitored for build-up rate. The well should remain shut-in until the gas lift valve work is completed. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: GLV c/o, MITIA 3. DHD: Monitor WHPs A wellbore schematic has been included for reference. «07-10A.pdf» The well has been classified as a Problem well. Please questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 call if you have any Content-Description: 07-10A.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED NOV () 2 2004 1 of 1 9110/20049:50 AM ') TREE = GRA Y GEN 2 WB..LHEAD = GRA Y ACTUÃTOR = AXELSON KR ELEV ';;'----"'-- ----'--62" BF:^ELEV = . ? -"-'---.----'------' KOP = 4698' n. . """'''''''' ................ . .................................... Max Angle = 95 @ 11930' Datum MD = 10036' -Datum TVo';"-aa6õö's's 13-3/8" CSG, 72#, N-80, 10= 12.347" H 2706' ~ 15-1/2" 18G, 17#, 13-CR-80, .0233 bpf, 10 = 4.892" H 4564' 1 ITOPOF7" LNR- SCAB 1-1 4992' h Minimum ID = 3.813 @ 90861 HES X NIPPLE 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, D = 3.958" H 9151' 1 TOP OF 4-1/2" LNR 1-1 9243' I 4-112" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 9247 PERFORATION S lJvIIMA. RY REF LOG: MJVD'GR ON 08198 ANGLEA TTOP PERF: 87 @ 10835' t>t>te: Refer to A"oductbn DB for historical perf data SIZE SPF INfER\! AL OpnlSqz DA. TE 2-3/8" 4 10835 - 11120 0 08/12/98 2-318" 4 11160 - 11550 0 08/12/98 2-3/8" 4 11640 - 12550 0 08/12/98 2-318" 4 12670 - 13070 0 08/12/98 2-318" 4 13130 - 13240 0 08/12/98 1 7" LNR - SCAB, 29#, L-80, .0371 bpf, 10 = 6.184" 1-1 9-5/8" CSG, 47#, N-80, .0732 bpf, 10=8.681" 1-1 r TOP OF WHIPSTOCK H 1 BRDGE PLUG 1-1 9449' ) 07 -1 OA I SAÆTY NOTES: 5-1/2" & 4-1/2" CHROME TBG I 2104' 1-1 5-1/2" HESX NIP, 10 =4.562" 1 ~ 5-112" TBG GAS LFT MA.NDRELS I STI MD I TVD I DEV TYPE I VLV ILA Ta-II PORT DA. TE I 2 3931 3921 1 Mrvr3 GEN RK 16 09130/03 L \ 4573' 1-1 5-1/2" X 4-1/2" XO, 10 = 4.892" 1 I 4-1/2" 18G GAS LFT MA.NDRELS I STf MD I TVD I OBI I TYPE VL V ILA Ta-I PORT DA. TE I 1 6552 6261 39 KBG2LS GEN INT 20 09130/03 L i t~ 9095' - 4-1/2"HESXNIP,ID=3.813" 1 9116' - 7" X 4-1/2" BAKER S-3 A<R, 10 = 3.875" 1 9139' 1-1 4-1/2" HES X NIP,ID = 3.813"1 9160' H UNIQUE MA. a-IINE OV ERSHOT, 10 = 3.94" I Z :g I 9191' 1-1 7" X 4-1/2" BAKER S-3 A<R, 10 = 3.875" I I I 9225' 1-1 4-1/2" HESX NIP,ID =3.813"1 . II 9247 1-1 4-1/2" TUBING TAIL WLEG, D = 3.958" 1 ~ ~ 1-1 ELMD 1T NOT LOGGED 1 9256' 1-1 7" X4-1/2" BAKER 5-3 A<RW/llE BACK 1 I 9-5/8" AND 7" MLLOUTWNDOW: 9428' - 9440' I 13312' H PBTD I 4-112" LNR, 12.6#, L-80, .0152 bpf, D =3.953" H 13399' 1 DA.1E RBI BY COMNENTS 07/79 ORIGINAL COMPLETION 08113/98 SIDETRACK (07-10A) 09126/03 JLMITL~ RWO (07-10A) 09/02/01 RNITP CORREC1l0NS 09/30/03 JLJIlLP GLV ao 10/12/03 JCI'vVllP PULLs) F?< A..UG @ 9225' I TO H 13405' DATE REV BY COMNENfS 01/30/04 GRCJTLP ŒPTH CORRECTIONS PRUDHOE BAY UNIT VlÆLL: 07-10A PERMT lib: 1980160 API lib: 50-029-20335-01 sæ 33, T11 N, R14E, 2630.12' FEL & 301.19' FNL BP Exploration (Alaska) STATE OF ALASKA ALASK,~ 'L AND GAS CONSERVATION C(( ~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: [] Abandon [] Suspend ["1 Operation Shutdown [] Perforate [] Vadance [] Oth6 [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate I-I Time Extension [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well [] Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. [] Development [] Exploratory 198-016 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20335-01-00 7. KB Elevation (ft): KBE = 61.5' 9. Well Name and Number: PBU 07-10A ,8. Property Designation: 10. Field / Pool(s): ADL 028309 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 13405 feet true vertical 9035 feet Plugs (measured) Effective depth: measured 13313 feet Junk (measured) true vertical 9026 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20" 109' 109' 1530 520 Surface 2706' 13-3/8" 2706' 2706' 4930 2670 Intermediate 9428' 9-5/8" 9428' 8562' 6870 4760 Production Liner 4436' 7" 4992'- 9428' 4980'- 8562' 8160 7020 Liner 4156' 4-1/2" 9243' - 13399' 8426' - 9034' Perforation Depth MD (ft): 10835' - 13240' Perforation Depth TVD (ft): 9018'- 9022' Tubing Size (size, grade, and measured depth): 5-1/2", 17# x 4-1/2", 13Cr80 & L-80 9247' Packers and SSSV (type and measured depth): 2 - 7" x 4-1/2" Baker 'S-3' packers; 9191' & 9107'; 5-1/2" HES 'X' Nipple 2095' ¢~ ..... :,,'.7~ ~;'":"~., ;~:'".ii~~ !'~, .~ ..... ~ .,~,,, 'i'2. s{imul&'ti0n' 0r'cement 'squeeze summary: ,~;-'"::,,, ....... ,,,., ' .... ., ,.... Intervals treated (measured): ',. :"" .: Treatment description including volumes used and final pressure: 13. Representative Daily Avera~le Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure' Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: [] Copies of Logs and Surveys run [] Exploratory [] Development [] Service [] Daily Report of Well Operations 16. Well Status after proposed work: [] Oil [] Gas [] WAG [] GINJ [] WINJ [] WDSPL 1~. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254I N/A Printed Name TerrieHubble, c.,.r,/,.,~,,~.. ..... ,,,^~. ,., ~ ,,, Title Technical Assistant Signature . hone 564-4628 Date Terrie Hubble, 564-4628 ,, Form 10-404 Revised 2/20( t 'i,,,',"' ~,'~ '~- '; ,~ .: ';) F'; !-,, BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: 07-10A Common Well Name: 07-10A Spud Date: 2/9/1979 Event Name: WORKOVER Start: 9/20/2003 End: 9/26/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2003 Rig Name: NABORS 4ES Rig Number: Date From- To Hours TaSk COde NPT Phase DescriPtion of Operations 9/20/2003 12:00 - 13:30 1.50 MOB P PRE Scope down & lower derrick. Finish rigging down equip. 13:30 - 18:00 4.50 MOB P PRE Move rig from DS 1-20 to Ds 7-10. Move distance 9.1 miles. 18:00 - 21:00 3.00 RIGU P PRE Spot rig sub, pits & pipe shed. Spot in shop & rig camp. Begin rigging up. 21:00 - 23:00 2.00 RIGU P PRE Raise & scope up derrick. Rig up lines etc. 23:00 - 00:00 1.00 RIGU , P DECOMP Accept rig 26 2000 hrs, 9/20/2003. (Adjusted rig accept time by 3 hrs due to road conditions requiring extra time to move rig). Spot in tiger tank. R/U lines. 9/21/2003 00:00 - 01:00 1.00 RIGU P DECOMP Finish rigging up lines to tree & tiger tank. Install annulus valve. Take on heated seawawter. R/U & lubricator & pull BPV. RID lubricator. 01:00 - 03:00 2.00 KILL P DECOMP Pressure up to test lines, Bleeder valve leaking on wing valve. Wait on replacement. Replace bleeder on wing valve bypass. Test lines. Hold Pre-spud & PJSM. 03:00 - 06:00 3.00 KILL P DECOMP Open well. SITP 0 psi. IA Pressure 0 psi. OA Pressure 300 ~si. Circulate well, 5 BPM @ 800 psi, 500 bbls total pumped. OA pressure 600 psi. Monitor well, well dead. 06:00 - 07:00 1.00 WHSUR = DECOMP PJSM. Set BPV & test @ 1000 psi, OK. 07:00 - 09:00 2.00 WHSUR = DECOMP PJSM. Nipple Down existing wellhead. 09:00 - 13:00 4.00 BOPSUI; ~ :DECOMP PJSM. Nipple up 13 3/8" x 5M BOPE. 13:00 - 17:00 4.00 BOPSUF; ~ DECOMP PJSM. Conduct full test on all BOP components @ 250 / 3500 3si. Pressure test annular preventor @ 250 / 2500 psi. Conduct accumulator drawdown test, OK. Will test upper & lower kelly valves when we pick it up. Witnessing of test waived by AOGCC inspector Chuck Scheve. 24 hour notice given. 17:00 - 18:00 1.00 WHSUR 3 DECOMP M/U lubricator, Pull test plug & TWC. L/D lubricator. 18:00 - 19:30 1.50 PULL 3 DECOMP P/U spear RIH & attempt to engage hanger. Could not fully engage spear. POOH & L/D spear. 19:30 - 20:30 1.00 PULL ~ DECOMP P/U X-over & M/U into hanger. BOLDS. P/U to 145K. 45K over pull, Tubing came free. Weight dropped off to 105K. 20:30 - 21:00 0.50 PULL ~ DECOMP . Pull hanger to floor & LID X-over & hanger. 21:00 - 22:30 1.50 PULL ~ DECOMP ' Circulate bottoms up. 6 BPM @ 400 psi. No gas, monitor well, well stable. R/U to L/D tubing. 22:30 - 00:00 1.50 PULL ~ DECOMP POOH & LID 4 1/2" completion. 55 its out @ midnight. 9/22/2003 00:00 - 06:00 6.00 PULL P DECOMP POOH & L/D 4 1/2" completion. Recovered 220 jts, 3 GLMs assy, "X" nipple assy, + 20.35' cut off jt. Cut looked good. OD 4.55" 06:00 - 07:00 1.00 PULL P DECOMP PJSM. Set wear bushing. 07:00 - 08:00 1.00 CLEAN P DECOMP Clean & lubricate rig. Level pipeshed. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM. P/U BHA #1 to swallow & clean out around tubing stub. 09:00 - 16:30 7.50 CLEAN P DECOMP PJSM. Pick up & RIH w/3 1/2" DP. Tag top of tubing stub @ 9154', 26' in on joint #283. L/D jt #283. 16:30 - 17:30 1.00 CLEAN P DECOMP PJSM. Pick up kelly. Establish parameters. Up wt- 145,000#, Down wt - 122,000#, Rotating wt- 131,000#. 4000 E/lbs of torque off bottom @ 55 RPM, pumping 3 bpm @ 500 psi. Rotate / wash down over tubing stub. Take weight & see pressure increase @ 9164', 26' in on kelly. Pick up & rotate down over, pick up again & slack off over tubing stub with out rotating, OK. 17:30 - 19:30 2.00 CLEAN i P DECOMP PJSM. Pump 40 bbls Hi Vis sweep & chase around @ 5 1/2 bpm / 1400 psi. Sweep came back to surface clean w/ no trash. Monitor well. No losses. Printed: 9~29~2003 9:24:16 AM BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: 07-10A Common Well Name: 07-10A Spud Date: 2/9/1979 Event Name: WORKOVER Start: 9/20/2003 End: 9/26/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2003 Rig Name: NABORS 4ES Rig Number: Date From To Hours Task Code NPT Phase DescriPtion of Operations 9/22/2003 19:30 - 23:00 3.50 CLEAN P DECOMP POOH & stand back 3 1/2" DP. 23:00 - 23:30 0.50 CLEAN P DECOMP LID BHA #1 as follows: Shoe, 2 extensions, triple connection, X-over, casing scraper & bit sub. 23:30- 00:00 0.50 CLEAN P DECOMP Begin making up BHA #2. 9/23/2003 00:00 - 00:30 0.50 CLEAN P DECOMP Held PJSM. M / U BHA #2:2 7/8" Muleshoe - 2 jts 2 7/8" PAC DP - XO - Bumper Sub - Oil Jars - 3 x 4-3/4" DC. 00:30 - 03:00 2.50 CLEAN P DECOMP RIH w/BHA #2 on 3 1/2" DP to Top of Tubing Stub at 9,154'. 03:00 - 04:00 1.00 CLEAN P DECOMP Slowly Entered Top of Tubing Stub, Continued to RIH to 9,203'. Did Not Observe any Indication on Weight Indicator. Observed Small Indication of Fill in Tubing, No Indication on Weight Indicator. Stopped at 9,203'. R / U and Reverse Circulated 4 Drill Pipe Volumes. Pump Rate 5 bpm, 1,400 psi. Circulated Out Oily Water and Trash; Rubber, Dope, Scale and Sluggits. Circulated Until Fluid Cleaned Up. No Losses While Circulating. Blew Down Lines, R / D Circulating Head and Lines. 04:00 - 11:30 7.50 CLEAN P DECOMP POOH, L / D 3-1/2" DP. 11:30 - 12:30 1.00 CLEAN P DECOMP Broke Out and L / D BHA. 12:30 - 14:30 2.00 BOPSUF P COMP Held PJSM. M / U Retrieving Tool, Latched and Pulled Wear Bushing. Ran and Set Test Plug. C / O 2-7/8" x 5" Variable Rams f/3 1/2" x 6" Variable Rams. Pressure Tested to 250 psi Low / 3500 psi High. Held Tests f/5 Minutes w/No Leaks or Pressure Loss. Latched and Pulled Test Plug. 14:30 - 23:00 8.50 RUNCOI~I= COMP Held PJSM. Loaded and Tallied 5-1/2" and 4-1/2" Tubing and Jewelry. R / D 3-1/2" DP Handling Equipment, R / U 4-1/2" 13Cr Tubing Handling Equipment. 23:00 - 00:00 1.00 RUNCOr~!:) COMP Held PJSM w/Rig Crew, Baker Rep, Casing Hand, Tour Pusher and Drilling Supervisor. M / U 4-1/2" Tail Pipe: Unique Overshot Assembly - X Nipple Assembly w/RHC-M Sleeve - 7" x 4-1/2" Baker S-3 Packer Assembly - Upper X Nipple Assembly. Torque Turned Connections, M / U Torque 3,620 ft / lbs. BAKERLOC'D All Connections Below Packer. 9/24/2003 00:00 - 08:00 8.00 RUNCOI~I~ COMP M / U and RIH w/107 Joints 4-1/2" 12.6# 13Cr80 Vam TOP Tubing. P / U Tubing w/Compensator and Torque Turned All Connections, M / U Torque 4,440 ft / lbs. 08:00 - 08:30 0.50 RUNCOI~I:' COMP R / D 4-1/2" Handling Equipment, R / U 5-1/2" Handling Equipment. 08:30 - 11:00 2.50 RUNCOI~ COMP Held PJSM. M / U and RIH w/5-1/2" 17# 13Cr80 Vam TOP Tubing. P / U Tubing w/Compensator and Torque Turned All Connections, M / U Torque 5,420 ft / lbs. Tagged Top of 7" Liner 8.5' in on Jt #13 of the 5-1/2" Tubing. 4-1/2" x 1~1/2" GLM OD = 7.031", 7" Liner ID = 6.276". 11:00 - 12:00 1.00 RUNCOI~Iq HMAN COMP Held PJSM. R / U to POOH. POOH and L / D 5-1/2" Tubing Using Compensator. 12:00 - 12:30 0.50 RUNCOI~lq HMAN COMP R / D 5-1/2" Handling Equipment, R / U 4-1/2" Handling Equipment. 12:30 - 19:00 6.50 RUNCOI~I',I HMAN COMP POOH and L / D 4-1/2" Tubing and GLM Assemblies Using Compensator. 19:00 - 19:30 0.50 RUNCOI~N HMAN COMP Pulled Packer Through Rotary Table and Inspected Same, OK. R / U to RIH w/4-1/2" Tubing. 19:30-00:00 4.50 RUNCOI~I HMAN COMP M/UandRIHw/4-1/2"12.6#13Cr80VamTOPTubing. P/U Printed: 9/29/2003 9:24:16AM BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: 07-10A Common Well Name: 07-10A Spud Date: 2/9/1979 Event Name: WORKOVER Start: 9/20/2003 End: 9/26/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2003 Rig Name: NABORS 4ES Rig Number: Date From -To Hours TaSk =Co'de NPT Phase DeSCription of OPerations 9~24~2003 19:30 - 00:00 4.50 RUNCO~ 1,4 HMAN COMP Tubing w/Compensator and Torque Turned All Connections, M / U Torque 4,440 ft / lbs. 9/25/2003 00:00 - 01:00 1.00 RUNCOr I~1 HMAN COMP M / U and RIH w/a Total of 107 Joints 4-1/2" 12.6# 13Cr80 Vam TOP Tubing. P / U Tubing w/Compensator and Torque Turned All Connections, M / U Torque 4,440 ft / lbs. M / U 4-1/2" x 5-1/2" XO. 01:00 - 01:30 0.50 RUNCOI~I',I HMAN COMP R / D 4-1/2" Handling Equipment, R / U 5-1/2" Handling Equipment. 01:30-02:30 1.00 RUNCOI~I',I 'HMAN COMP MIUandRIHw15-112"17#13Cr80VamTOPTubing. P/U Tubing w/Compensator and Torque Turned All Connections, M / U Torque 5,420 ft / lbs. Tail Pipe and Packer Assembly Transitioned into 7" Liner Top w/No Problems. 02:30 - 10:00 7.50 RUNCOI~ COMP M / U and RIH w/a Total of 93 Joints 5-1/2" 17# 13Cr80 Vam TOP Tubing. P / U Tubing w/Compensator and Torque Turned All Connections, M / U Torque 5,420 ft / lbs. M / U 5-1/2" Vain TOP pin x 5-1/2" New Vam box XO, M / U and RIH w/22 Joints 5-1/2" 17# 13Cr80 New Vam Tubing. P / U Tubing w! Compensator and Torque Turned All Connections, M / U Torque 5,500 ft / lbs. 10:00 - 11:00 1.00 RUNCOI~ COMP Held PJSM. Established Parameters: String Weight Up 129,000#, String Weight Down 117,000#. M / U Circulating Head on Joint #222. R / D Compensator. M / U Circulating Line. Engaged Pump, Rate 2 bpm, 125 psi. Washed Down and Swallowed Tubing Stub w/Overshot. Observed Pressure Increase 20' in on Joint. No-Goed Out on Top of Tubing Stub, 26.5' in on Joint. Shut Down Pump Pressure Held at 275 psi, w/Good Indication of Being Located Out on Top of Tubing Stub at 9,160'. Bled Down Pressure. 11:00 - 12:00 1.00 RUNCO~/P COMP Held PJSM. Spaced Out Tubing 4' Off of No-Go Depth at 9,156' w/2.5' of Tubing Stub Swallowed by Overshot. L / D Joint # 222. M / U Tubing Hanger, Landing Joint, Circulating Head and Line. 12:00 - 13:30 1.50' RUNCOr P COMP Held PJSM. R / D Tubing Handling Equipment. 13:30 - 18:00 4.50 RUNCO~ P COMP Held PJSM. Reverse Circulated 300 bbls 140 deg Seawater, Pump Rate 3 bpm, 200 psi. Pressure Increased on O/A to 700 psi. Bled off O/A. Reverse Circulated 300 bbls 140 deg Seawater w/Corrosion Inhibitor, Pump Rate 3 bpm, 200 psi. Kept O/A Pressure Bled Down. 18:00 - 18:30 0.50 RUNCOkP COMP Drained BOP Stack, RIH and Landed Tubing Hanger. RILDS Completion Equipment Set At The Following Depths: Item Length Depth Overshot Assembly 16.86' 9,157.30' X Nipple Assembly w/RHC Sleeve 20.65' 9,119.79' 7"x 4-1/2" S-3 Packer Assembly 23.23' 9,096.56' X Nipple Assembly 20.64' 9,075.92' 60 Jts 4-1/2" 12.6# 13Cr Vam TOP Tbg 2,519.41' 6,556.51' #1 GLM Assembly 24.66' 6,531.85' 47 Jts 4-1/2" 12.6# 13Cr Vam TOP Tbg 1,966.30' 4,565.55' 4-1/2"x 5-1/2"XO 1.99' 4,563.56' 15 Jts 5-1/2" 17# 13Cr Vam TOP Tbg 623.17' 3,940.39' #2 GLM Assembly w/DCK Shr Valve 28.78' 3,911.61' 44 Jts 5-1/2" 17# 13CrVam TOP Tbg 1,805.19' 2,106.42' X Nipple Assembly 21.22' 2,085.20' Printed: 9/29/2003 9:24:16AM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: 07-10A Common Well Name: 07-10A Spud Date: 2/9/1979 Event Name: WORKOVER Start: 9/20/2003 End: 9/26/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2003 Rig Name: NABORS 4ES Rig Number: Date From,To :Hours Task Code NPT Phase ' Description of OPerations 9/25/2003 18:00 - 18:30 0.50 RUNCO~ P COMP 34 Jts 5-1/2" 17# 13Cr Vam TOP Tbg 1,386.99' 698.21' 5-1/2" Vam TOP x 5-1/2" TC-II XO 9.79' 688.42' 5-1/2" TC-II x 5-1/2" New Vam XO 1.82' 686.60' 21 Jts 5-1/2" 17# 13Cr NewVam Tbg 664.04' 22.56' 5-1/2" New Vam x 5-1/2" NSCC XO 2.33' 20.26' Tubing Hanger 1.65' 18.60' Dropped Ball/Rod Assembly and Allowed to Fall On Seat in RHC Sleeve at 9,119'. 18:30 - 20:00 1.50 RUNCOI~' COMP Held PJSM. Broke Out and L / D Landing Joint. R / U and Tested Lines to 3,500 psi, OK. Closed Blind Rams. Pressured ~Up on Tubing To 2,500 psi To Set Packer, Continued To Pressure Up on Tubing To 3,500 psi. Tested Tubing f/30 Minutes, OK. Bled Tubing Pressure Down to 1,500 psi and Shut In. Tested 9-5/8" x 7" x 4-1/2" x 5-1/2" Annulus to 3,500 psi f/30 Minutes, OK. Bled Down Tubing Pressure and Observed DCK Valve Shear. Bled Down All Pressures. Pumped Down Both Annulus and Tubing to Ensure DCK Valve Fully Sheared, Good Communication Through Both IA and Tubing. Pump Rate 2 bpm, 200 psi. 20:00 - 21:00 1.00 WHSUR P COMP Blew Down and R / D Lines. Ran and Set BPV in Tubing Hanger. 21:00 - 23:00 2.00 BOPSUR P COMP Held PJSM. N / D BOPE. 23:00 - 00:00 1.00 WHSUR P COMP Held PJSM. N / U Production Tree and Adapter. 9/26/2003 00:00 - 01:30 1.50 WHSUR P COMP N / U Adapter Flange and Production Tree. Tested Hanger, Neck Seal and Void to 5,000 psi, OK. Tested Tree to 5,000 psi, OK. 01:30 - 02:30 1.00 WHSUR P COMP Held PJSM. R / U DSM Lubricator, Pulled Dart and BPV, R / D DSM. 02:30 - 04:30 2.00 WHSUR P COMP Held PJSM. R / U Little Red Hot Oil, Pressure Tested Lines to 3,000 psi, OK. Pumped 160 bbls of Diesel Freeze Protect Down Annulus. Pump Rate 2.5 bpm, 650 psi. R / D Little Red. Opened Tree Valves and U-Tubed Diesel Freeze Protect. 04:30 - 06:00 1.50 WHSUR P COMP Blew Down and R / D Lines. Removed Secondary Annulus Valve. Set BPV. Installed Blind Flange on Tree. Secured Well. Release Rig at 0600 hrs, 09 / 26 / 2003. Printed: 9~29~2003 9:24:16AM Well C°mplianceReport File on Left side of folder . 198-016-0 MD 13405 ' TVD 09035 Microfilm Roll / - PRUDHOE BAY UNIT 07-10A 50- 029-20335-01 BP EXPLORATION (ALASK A ~ T~Tfa Completion Date: 8 Completed Status: 1-OIL Current: Roll 2 / Name _ Interval Sent Received T/C/D D 8771 SPERRY GR/EWR4 OH 11/4/98 11/4/98 L BHCS ~ 9100-11800 ¢1~ ~ OH 11,16,98 11,20,98 L CMTVOL ~-9100-11830 N,~ OH 2 11/16/98 11/20/98 L DGR/EWR4-MD ~. 9460-13405 r-}/~O/~.~ ~/d/,/~ OH 11/4/98 11/4/98 L DGR/EWR4-TVD ~ 8586-9050 4e' OH 11/4/98 11/4/98 L PEX-CN/3DD ~ 9100-11815 ~/.~/q'~ OH 11/16/98 11/20/98 L PEX-CNL .4"~' 9100-11815 ! OH 11/16/9811/20/98 L SSTVD ~J~ OH 11/16/98 11/20/98 R SRVY RPT ~9397.50-13405. OH 9/17/98 9/23/98 T 8646 , lc,~'' SCHLUM PEX-BHC OH 11/16/98 11/20/98 Daily Well Ops "ff/?/f-37 } .~//~/~3t Are Dry Ditch Samples Required? yes (~__~And Received? Was the well cored? yes (<~_. Analysis Description Rece_Lwe~ ~mpl~. g~f_~ Comments: Tuesday, August 01, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG i'? 1. Status of Well Classification of Service Wel.J: '-D 'I [~ Oil 1--] Gas ~1 Suspended [~ Abandoned l--] Service ,,..-' 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 98-0016 ~Jaska, 0ii & Gas Cof!s. 3. Address 8. APl Number Anchorage P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20335-01 4. Location of well at surface ................. 9. Unit or Lease Name 980' SNL, 216' WEL, SEC. 33, T11N, R14E, UM.J (;0~,,'i~:'L.~::-/h)~'J i, .,.. .... __. ,~_...~..... Prudhoe Bay Unit At to.p, of productive interval i ~]A't%, ' ~'-~J~;;~'-~-¢~:'~-::J 10. Well Number .......... ~ ~~"'_ ] 07-10A 1265 NSL, 1563'WEL, SEC. 28, TllN, R14E, UM j ,,-i '~,: At total depth ~.:/:t~.~. ..... ~. !~~., 11. Field and Pool 4978' NSL, 2643' WEL, SEC. 28, T11 N, R14E, UM ~....~ ........ _ ....... .~ ..... -":- ~- ',-,~-~?--~,,"'- Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and se~tl~l'~?~ Pool KBE = 61.50'I ADL 028309 17. Total Depth (MD+'I-VD) 18. Plu~ Back Depth (MD+'I-VD)I19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 13405 9035 FT 13313 9026 FT] [~]Yes [~No] (Nipple) 2178' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, 4-Phase RES, RES/ALT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 109' 30" 271 sxArcticset 13-3/8" 72# L-80 Surface 2706' 17-1/2" 5000 sx Arcticset II 9-5/8" 47# L-80 / S00-95 Surface 9428' 12-1/4" 1200 sx Class 'G' 7" 29# L-80 4992' 9428' 8-1/2" 420 sx TLW, 82 sx Class 'G' 4-1/2" 12.6# L-80 9243' 13399' 6" 477 sx Class 'G' '24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9247' 9191' MD TVD MD TVD 10835' - 11120' 9017' - 9020' 11160' - 11550' 9020' - 9027' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11640' - 12550' 9024' - 9004' DEPTH iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12670' - 13070' 9001' - 9009' 13130' - 13240' 9012' - 9021' Freeze Protect with 150 Bbls of Diesel Date First Production Method of Operation (Flowing, gas lift, etc.) ~ ~ ~ ~, .~ August 16, 1998 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAs-OIL RATIO TEST PERIOD ! Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. rnmi Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sadlerochit 9410' 8549' Zone 4A 9609' 8670' Zone 3 9725' 8723' Zone 2C 9874' 8792' Zone 2B 10003' 8847' Zone 2A 10280' 8959' Zone 1 B 10758' 9014' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone Title Senior Drilling Engineer Date 07-10A 98-0016 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28'- If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 07 Well 07-10A Page 1 Rig Doyon 14 Date 27 August 98 Date/Time 17 Jul 98 16:30-17:00 17:00-17:45 17:45-18:30 18:30-20:00 20:00-21:45 21:45-22:00 22:00-00:00 18 Jul 98 00:00-01:30 01:30-02:00 02:00-03:00 03:00-03:15 03:15-03:30 03:30-03:45 03:45-04:15 04:15-06:00 06:00-06:45 06:45-07:15 07:15-08:00 08:00-09:00 09:00-09:30 09:30-14:00 14:00-14:15 14:15-15:00 15:00-15:45 15:45-16:15 16:15-17:15 17:15-18:00 18:00-18:15 18:15-20:30 20:30-21:00 21:00-04:45 19 Jul 98 04:45-05:00 05:00-06:00 06:00-07:15 07:15-07:30 07:30-09:00 09:00-16:15 16:15-21:30 21:30-22:00 22:00-22:15 22:15-00:15 20 Jul 98 00:15-01:00 01:00-06:00 06:00-11:30 11:30-12:00 12:00-12:45 12:45-14:30 14:30-15:00 15:00-20:30 20:30-21:15 21:15-22:00 22:00-22:45 22:45-01:30 21 Jul 98 01:30-02:30 Duration 1/2 hr 3/4 hr 3/4 hr 1-1/2 hr 1-3/4 hr 1/4 hr 2 hr 1-1/2 hr I/2 hr 1 hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1-3/4 hr 3/4 hr 1/2 hr 3/4 hr lhr 1/2 hr 4-1/2 hr 1/4 hr 3/4 hr 3/4 hr 1/2 hr lhr 3/4 hr 1/4 hr 2-1/4 hr 1/2 hr 7-3/4 hr 1/4 hr 1 hr 1-1/4 hr 1/4 hr 1-1/2 hr 7-1/4 hr 5-1/4 hr 1/2 hr 1/4 hr 2 hr 3/4 hr 5 hr 5-1/2 hr 1/2 hr 3/4 hr 1-3/4 hr 1/2 hr 5-1/2 hr 3/4 hr 3/4 hr 3/4 hr 2-3/4 hr 1 hr Activity Held safety meeting Rigged up Annulus wing - surface tree Tested Hanger plug Removed Xmas tree Rigged up All functions Tested Blind / Shear ram Removed Hanger plug Removed Tubing hanger Rigged up Tubing handling equipment Laid down 150.0 ft of Tubing Rigged up sub-surface equipment - Retrievable packer Singled in drill pipe to 45.0 ft Set packer at 45.0 ft with 0.0 psi Removed Seal assembly Retrieved Seal assembly Retrieved Seal assembly (cont...) Rigged down BOP stack Installed BOP stack Installed Seal assembly Tested Seal assembly Tested All functions Retrieved Retrievable packer Tested Casing Tested Casing Pulled out of hole to 0.0 ft Serviced Block line Rigged up Tubing handling equipment Held safety meeting Laid down 2300.0 ft of Tubing Held drill (Kick (well kill)) Laid down 7300.0 ft of Tubing Rigged down Tubing handling equipment Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Installed Wear bushing Made up BHA no. 1 Singled in drill pipe to 8607.0 ft Worked stuck pipe at 8607.0 ft Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Rigged down Logging/braided cable equipment Pulled out of hole to 4700.0 ft Pulled out of hole to 928.0 ft (cont...) Pulled BHA Made up BHA no. 2 R.I.H. to 8529.0 ft Fished at 8529.0 ft Pulled out of hole to 842.0 ft Pulled BHA Laid down fish Made up BHA no. 3 R.I.H. to 8587.0 ft Fished at 8587.0 ft Progress Report Facility PB DS 07 Well 07-10A Rig Doyon 14 Page 2 Date 27 August 98 Date/Time 02:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-06:45 06:45-08:00 08:00-08:15 08:15-09:15 09:15-17:00 17:00-20:15 20:15-21:30 21:30-22:45 22:45-23:45 23:45-02:00 22 Jul 98 02:00-03:00 03:00-05:45 05:45-06:00 06:00-08:00 08:00-08:45 08:45-11:15 11:15-12:00 12:00-14:00 14:00-15:00 15:00-16:15 16:15-18:45 18:45-03:00 23 Jul 98 03:00-06:00 06:00-06:15 06:15-07:00 07:00-07:15 07:15-08:00 08:00-10:15 10:15-12:15 12:15-13:15 13:15-18:00 18:00-18:15 18:15-21:00 21:00-23:00 23:00-05:00 24 Jul 98 05:00-06:00 06:00-07:30 07:30-08:30 08:30-12:45 12:45-13:15 13:15-14:15 14:15-15:00 15:00-18:00 18:00-18:30 18:30-19:30 19:30-03:00 25 Jul 98 03:00-03:15 03:15-06:00 06:00-07:15 07:15-08:30 Duration 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/4 hr 1 hr 7-3/4 hr 3-1/4 hr 1-1/4 hr 1-1/4 hr 1 hr 2-1/4 hr 1 hr 2-3/4 hr 1/4 hr 2 hr 3/4 hr 2-1/2 hr 3/4 hr 2 hr 1 hr 1-1/4 hr 2-1/2 hr 8-1/4 hr 3 hr 1/4 hr 3/4 hr 1/4 hr 3/4 hr 2-1/4 hr 2 hr 1 hr 4-3/4 hr 1/4 hr 2-3/4 hr 2 hr 6 hr 1 hr 1-1/2 hr 1 hr 4-1/4 hr 1/2 hr 1 hr 3/4 hr 3 hr 1/2 hr 1 hr 7-1/2 hr 1/4 hr 2-3/4 hr 1-1/4 hr 1-1/4 hr Activity Pulled out of hole to 876.0 ft Pulled BHA Made up BHA no. 4 Made up BHA no. 4 (cont...) Held safety meeting R.I.H. to 6500.0 ft Held drill (Kick while tripping) R.I.H. to 8587.0 ft Washed over string at 8599.0 ft Pulled out of hole to 892.0 ft .Pulled BHA Made up BHA no. 5 Serviced Block line R.I.H. to 8587.0 ft Fished at 8599.0 ft Pulled out of hole to 888.0 ft Pulled BHA Pulled BHA (cont...) Made up BHA no. 6 R.I.H. to 8603.0 ft Washed to 8603.0 ft Pulled out of hole to 860.0 ft Pulled BHA Made up BHA no. 7 R.I.H. to 8605.0 ft Washed over string at 8607.0 ft Pulled out of hole to 1500.0 ft Pulled out of hole to 860.0 ft (cont...) Pulled BHA Tested Downhole equipment - Via annulus Made up BHA no. 8 R.I.H. to 8600.0 ft Washed over string at 8608.0 ft Singled in drill pipe to 8997.0 ft Jarred stuck pipe at 8997.0 ft Held safety meeting Fished at 8997.0 ft Rigged up Logging/braided cable equipment Fished at 8997.0 ft Fished at 8997.0 ft Fished at 8997.0 ft (cont...) Circulated at 8971.0 ft Pulled out of hole to 860.0 ft Pulled BHA Serviced Block line Made up BHA no. 9 R.I.H. to 8960.0 ft Held safety meeting Circulated at 8971.0 ft Washed over string at 8992.0 ft Flow check Pulled out of hole to 2500.0 ft Pulled out of hole to 854.0 ft (cont...) Pulled BHA Progress Report Facility PB DS 07 Well 07-10A Rig Doyon 14 Page 3 Date 27 August 98 Date/Time 08:30-09:00 09:00-09:45 09:45-13:15 13:15-13:45 13:45-14:15 14:15-17:00 17:00-21:00 21:00-02:00 26 Jul 98 02:00-03:30 03:30-03:45 03:45-06:00 06:00-07:00 07:00-07:45 07:45-08:30 08:30-11:00 11:00-14:15 14:15-16:00 16:00-19:30 19:30-20:30 20:30-21:00 21:00-22:00 22:00-23:30 23:30-00:00 27 Jul 98 00:00-02:00 02:00-06:00 06:00-08:00 08:00-09:00 09:00-19:00 19:00-19:15 19:15-22:30 22:30-23:30 23:30-01:00 28 Jul 98 01:00-02:00 02:00-04:30 04:30-06:00 06:00-12:00 12:00-12:15 12:15-15:00 15:00-15:15 15:15-15:30 15:30-18:30 18:30-20:30 20:30-21:00 21:00-21:15 21:15-00:30 29 Jul 98 00:30-01:30 01:30-02:00 02:00-03:30 03:30-06:00 06:00-07:30 07:30-06:00 30 Jul 98 06:00-14:30 14:30-15:30 15:30-15:45 Duration 1/2 hr 3/4 hr 3-1/2 hr 1/2 hr 1/2 hr 2-3/4 hr 4 hr 5 hr 1-1/2 hr 1/4 hr 2-1/4 hr 1 hr 3/4 hr 3/4 hr 2-1/2 hr 3-1/4 hr 1-3/4 hr 3-1/2 hr lhr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 4 hr 2 hr 1 hr 10hr 1/4 hr 3-1/4 hr 1 hr 1-1/2 hr 1 hr 2-1/2 hr 1-1/2 hr 6 hr 1/4 hr 2-3/4 hr 1/4 hr 1/4 hr 3 hr 2 hr 1/2 hr 1/4 hr 3-1/4 hr 1 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 22-1/2 hr 8-1/2 hr 1 hr 1/4 hr Activity Laid down fish Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 10 R.I.H. to 8957.0 ft Milled Production packer at 8981.0 ft Singled in drill pipe to 9606.0 ft Circulated at 9606.0 ft Flow check Pulled out of hole to 2500.0 ft Pulled out of hole to 850.0 ft (cont...) Pulled BHA Rigged up Logging/braided cable equipment Made up BHA no. 11 R.I.H. to 9585.0 ft Circulated at 9582.0 ft Pulled out of hole to 860.0 ft Pulled BHA Rigged down Drillstring handling equipment Set downhole equipment (wireline) Pulled out of hole to 9449.0 ft Tested Bridge plug - Via string Made up BHA no. 12 R.I.H. to 7500.0 ft R.I.H. to 9400.0 ft (cont...) .. Circulated at 9449.0 ft ~ Milled Other sub-surface equipment at 9436.0 ft Flow check Pulled out of hole to 908.0 ft Pulled BHA Made up BHA no. 13 Serviced Block line R.I.H. to 9436.0 ft Milled Other sub-surface equipment at 9437.0 ft Milled Other sub-surface equipment at 9457.0 ft (cont...) Flow check Pulled out of hole to 900.0 ft Pulled BHA Made up BHA no. 14 R.I.H. to 9429.0 ft Milled Other sub-surface equipment at 9428.0 ft Circulated at 9457.0 ft Flow check Pulled out of hole to 900.0 ft Pulled BHA Held safety meeting Made up BHA no. 15 R.I.H. to 8000.0 ft R.I.H. to 9410.0 ft (cont...) Drilled to 10150.0 ft Drilled to 10336.0 ft (cont...) Circulated at 10336.0 ft Flow check Progress Report Facility PB DS 07 Well 07-10A Page 4 Rig Doyon 14 Date 27 August 98 Date/Time 15:45-20:00 20:00-21:00 21:00-21:15 21:15-21:30 21:30-21:45 21:45-01:15 31 Jul 98 01:15-01:30 01:30-02:00 02:00-04:30 04:30-05:30 05:30-06:00 06:00-09:00 09:00-10:00 10:00-11:30 11:30-06:00 01 Aug 98 06:00-06:00 02 Aug 98 06:00-08:00 08:00-11:30 11:30-12:30 12:30-13:30 13:30-16:00 16:00-16:15 16:15-18:00 18:00-18:30 18:30-21:00 21:00-23:00 23:00-23:15 23:15-00:30 03 Aug 98 00:30-06:00 06:00-07:00 07:00-10:00 10:00-13:00 13:00-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-21:30 21:30-22:30 22:30-23:30 23:30-00:00 04 Aug 98 00:00-03:30 03:30-04:30 04:30-06:00 06:00-07:00 07:00-10:30 10:30-11:30 11:30-12:00 12:00-14:00 14:00-14:30 14:30-15:00 15:00-06:00 05 Aug 98 06:00-06:00 06 Aug 98 06:00-16:00 16:00-19:00 Duration 4-1/4 hr 1 hr 1/4 hr 1/4 hr 1/4 hr 3-1/2 hr 1/4 hr 1/2 hr 2-1/2 hr 1 hr 1/2 hr 3 hr 1 hr 1-1/2 hr 18-1/2 hr 24 hr 2 hr 3-1/2 hr lhr 1 hr 2-1/2 hr 1/4 hr 1-3/4 hr 1/2 hr 2-1/2 hr 2 hr 1/4 hr 1-1/4 hr 5-1/2 hr 1 hr 3 hr 3hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1 hr 1 hr 1/2 hr 3-1/2 hr 1 hr 1-1/2 hr 1 hr 3-1/2 hr 1 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 15hr 24 hr 10hr 3 hr Activity Pulled out of hole to 880.0 ft Pulled BHA Held safety meeting Retrieved Wear bushing Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Installed Wear bushing Made up BHA no. 16 Serviced Block line R.I.H. to 4500.0 ft R.I.H. to 10208.0 ft (cont...) Took MWD survey at 10161.0 ft Circulated at 10336.0 ft Drilled to 10997.0 ft Drilled to 11788.0 ft (cont...) Drilled to 11780.0 ft (cont...) Circulated at 11870.0 ft Pulled out of hole to 9366.0 ft R.I.H. to 11870.0 ft Circulated at 11870.0 ft Flow check Pulled out of hole to 8542.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 250.0 ft Pulled BHA Held safety meeting Test Logging/braided cable equipment unit R.I.H. to 8700.0 ft R.I.H. to 9068.0 ft (cont...) Conducted electric cable operations Test Computer software unit Conducted electric cable operations Rigged up Wireline units Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Pulled out of hole to 6500.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 140.0 ft Retrieved Formation logs Made up BHA no. 18 Made up BHA no. 18 (cont...) R.I.H. to 9334.0 ft Serviced Block line R.I.H. to 10175.0 ft Took MWD survey at 10208.0 ft R.I.H. to 11840.0 ft Logged hole with LWD: DIR/DD from 11840.0 ft to 11870.0 ft Drilled to 12231.0 ft Drilled to 12771.0 ft (cont...) Drilled to 13025.0 ft (cont...) Circulated at 13025.0 ft Progress Report Facility PB DS 07 Well 07-10A Page 5 Rig Doyon 14 Date 27 August 98 Date/Time 07 Aug 98 08 Aug 98 09 Aug 98 10 Aug 98 19:00-19:15 19:15-19:30 19:30-05:30 05:30-05:45 05:45-06:00 06:00-09:15 09:15-10:00 10:00-11:00 11:00-11:30 11:30-11:45 11:45-16:00 16:00-16:15 16:15-17:15 17:15-21:15 21:15-22:00 22:00-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-06:00 06:00-20:15 20:15-22:30 22:30-22:45 22:45-01:00 01:00-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-07:00 07:00-07:15 07:15-13:15 13:15-14:15 14:15-14:45 14:45-15:15 15:15-15:30 15:30-20:00 20:00-20:15 20:15-20:30 20:30-01:00 01:00-01:15 01:15-01:30 01:30-02:15 02:15-05:00 05:00-05:30 05:30-06:00 06:00-07:00 07:00-10:30 10:30-10:45 10:45-14:45 14:45-15:00 15:00-15:15 15:15-15:30 Duration 1/4 hr 1/4 hr 10hr 1/4 hr 1/4 hr 3-1/4 hr 3/4 hr 1 hr 1/2 hr 1/4 hr 4-1/4 hr 1/4 hr 1 hr 4hr 3/4 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 5-1/2 hr 14-1/4 hr 2-1/4 hr 1/4 hr 2-1/4 hr 1 hr 1 hr 1 hr 2hr 1 hr 1/4 hr 6 hr 1 hr 1/2 hr 1/2 hr 1/4 hr 4-1/2 hr 1/4 hr 1/4 hr 4-1/2 hr 1/4 hr 1/4 hr 3/4 hr 2-3/4 hr 1/2 hr 1/2 hr 1 hr 3-1/2 hr 1/4 hr 4 hr 1/4 hr 1/4 hr 1/4 hr Activity Flow check Held safety meeting Logged hole with LWD: Formation evaluation (FE) from 13025.0 ft to 9 ft Pulled out of hole to 8950.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 196.0 ft Pulled BHA Downloaded MWD tool Retrieved Wear bushing Held safety meeting Tested All functions Installed Wear bushing Made up BHA no. 10 R.I.H. to 8970.0 ft Rigged up Drillstring handling equipment R.I.H. to 10048.0 ft Took MWD survey at 10048.0 ft R.I.H. to 12930.0 ft Reamed to 13025.0 ft Drilled to 13117.0 ft Drilled to 13405.0 ft (cont...) Circulated at 13405.0 ft Flow check Logged hole with LWD: Formation evaluation (FE) from 13405.0 ft to 12975.0 ft Pulled out of hole to 9360.0 ft Serviced Block line R.I.H. to 13405.0 ft Circulated at 13405.0 ft Circulated at 13405.0 ft (cont...) Flow check Pulled out of hole to 186.0 ft Pulled BHA Downloaded MWD tool Installed Casing handling equipment Held safety meeting Ran Liner to 4126.0 ft (4-1/2in OD) Installed Tubing handling equipment Held safety meeting Ran Tubing to 4033.0 ft (2-7/8in OD) Rigged up Drillstring handling equipment Installed Liner hanger Circulated at 4263.0 ft Ran Drillpipe in stands to 9033.0 ft Rigged up Drillstring handling equipment Circulated at 9033.0 ft Circulated at 9033.0 ft (cont...) Ran Drillpipe in stands to 13405.0 ft Rigged up Circulating head Circulated at 13405.0 ft Held safety meeting Tested Circulating head Pumped Brine spacers - volume 20.000 bbl lO0.O Progress Report Facility PB DS 07 Well 07-10A Page 6 Rig Doyon 14 Date 27 August 98 Date/Time 11 Aug 98 12 Aug 98 15:30-15:45 15:45-16:00 16:00-16:30 16:30-17:00 17:00-18:30 18:30-19:00 19:00-20:00 20:00-20:45 20:45-22:00 22:00-22:15 22:15-22:30 22:30-00:00 00:00-00:15 00:15-00:30 00:30-02:00 02:00-03:00 03:00-03:30 03:30-03:45 03:45-06:00 06:00-06:15 06:15-06:30 06:30-08:00 08:00-08:15 08:15-08:45 08:45-11:30 11:30-11:45 11:45-12:30 12:30-12:45 12:45-13:00 13:00-13:15 13:15-13:30 13:30-14:30 14:30-15:15 15:15-16:15 16:15-16:30 16:30-18:30 18:30-22:00 22:00-23:15 23:15-23:30 23:30-00:30 00:30-00:45 00:45-06:00 06:00-06:30 06:30-07:30 07:30-07:45 07:45-08:00 08:00-16:15 16:15-17:15 17:15-17:30 17:30-19:00 19:00-19:30 19:30-19:45 19:45-20:00 20:00-20:30 Duration 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 3/4 hr 1-1/4 hr 1/4 hr 1/4 hr 1-1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 1 hr 1/2 hr 1/4 hr 2-1/4 hr 1/4 hr 1/4 hr 1-1/2 hr 1/4 hr 1/2 hr 2-3/4 hr 1/4 hr 3/4 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1 hr 3/4 hr 1 hr 1/4 hr 2 hr 3-1/2 hr 1-1/4 hr 1/4 hr 1 hr 1/4 hr 5-1/4 hr 1/2 hr 1 hr 1/4 hr 1/4 hr 8-1/4 hr 1 hr 1/4 hr 1-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr Activity Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 101.000 bbl Displaced slurry - 130.000 bbl Functioned Liner hanger Circulated at 13296.0 ft Rigged down Cement head Laid down 1395.0 ft of 5in OD drill pipe Tested Tie back packer - Via string Laid down 2029.0 ft of 5in OD drill pipe Pulled Drillpipe in stands to 8933.0 ft Rigged up Drillstring handling equipment Pulled Drillpipe in stands to 4068.0 ft Retrieved Setting tools Rigged up Tubing handling equipment Laid down 2271.0 ft of Tubing Pulled Tubing in stands to 0.0 ft Retrieved Wear bushing Held safety meeting Installed Gun assembly Installed Gun assembly (cont...) Rigged up Tubing handling equipment Ran Tubing in stands to 4176.0 ft Rigged up Drillstring handling equipment Installed Retrievable packer Ran Drillpipe in stands to 12412.0 ft Rigged up Drillstring handling equipment Ran Drillpipe in stands to 13304.0 ft Installed Circulating head Tested Circulating head Held safety meeting Perforated Reverse circulated at 9051.0 ft Functioned Retrievable packer Flow check Rigged down Circulating head Laid down 830.0 ft of 5in OD drill pipe Laid down 8204.0 ft of 3-1/2in OD drill pipe Rigged down sub-surface equipment - Retrievable packer Rigged up Tubing handling equipment Laid down 1763.0 ft of Tubing Held safety meeting Retrieved Gun assembly Rigged down Tubing handling equipment Serviced Block line Rigged up Completion string handling equipment Held safety meeting Ran Tubing to 9247.0 ft (4-1/2in OD) Space out tubulars Rigged up Circulating head Reverse circulated at 9247.0 ft Installed Tubing hanger Tested Tubing hanger Set packer at 9191.0 ft with 2400.0 psi Tested Hydraulic packer - Via string Progress Report Facility PB DS 07 Well 07-10A Rig Doyon 14 Page 7 Date 27 August 98 Date/Time 13 Aug 98 20:30-21:15 21:15-22:15 22:15-00:30 00:30-02:00 02:00-02:30 02:30-03:30 03:30-06:00 06:00-07:00 07:00-08:15 08:15-08:30 08:30-09:00 Duration 3/4 hr 1 hr 2-1/4 hr 1-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1 hr 1-1/4 hr 1/4 hr 1/2 hr Activity Tested Casing Installed Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Freeze protect well - Diesel of 150.000 bbl Freeze protect well - 150.000 bbl of Diesel (cont...) Installed Hanger plug Tested Hanger plug Functioned Xmas tree RECEIVED BPXA ;PDC ARCO ALASKA INC. DRILLSITE 7, WELL NO..7-10 PRUDHOE BAY, E.O.A., ALASKA APl NUMBER: 50-029-20335-00 Gyro Continuous Multishot Survey Inside 3.5" TUBING Survey date: 04-JULY, 1998. Job number' AK0798GCE481 CONTENTS JOB NUMBER ' AK0798GCE481 = DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION, SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' AK0798GCE481 Tool 772 was run in WELL# 7-10 on SCHLUMBERGER 7/32" wireline inside 3,5" TUBING. The tool was pumped off the line while trying to get started on the first run. The survey was completed with back up equipment (tool 768) without any )roblems. ' SURVEY CERTIFICATION SHEET JOB NUMBER' AK0798GCE481 . The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of ,:. my knowledge. . _ .? ToM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data' obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS CLIENT ' RIG · LOCATION ' WELL · LATITUDE ' LONGITUDE: SURVEY DATE' SURVEY TYPE' DEPTH REFERENCE' MAX. SURVEY DEPTH ' SURVEY TIED ONTO ' SURVEY INTERVAL' APl NUMBER' TARGET DIRECTION · GRID CORRECTION ' CALCULATION METHOD' SURVEYOR' SURVEY DETAILS JOB NUMBER' AK0798GCE481 ARCO ALASKA INC. SCHLUMBERGER DRILLSlTE 7 07-10 70.28 N 148.4 W 04 -JULY, 1998 GYRO CONTINUOUS MULTISHOT ROTARY TABLE ELEVATION 64.0 10000' NA o_ oooo, 050-029-20335-00 N/A ' N/A MINIMUM CURVATURE TOM STODDARD 3. INRUN SuRvEY LISTING A G yr oda t a D i r e c t i ona i Survey for ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Lo~!~tion- DRILLSITE 7, PRUDHOE BAY FIELD, ALASKA Job Number: AK0798GCE481 Run, Date: 4-Jul-98 09:02:13 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE surv. ey Latitude: 70.280000 deg.. N Sub-sea correction.from Vertical Reference: 64 ft. Azimuth correction: Gyro: Bearings are, Relative to True North Vertical SectiOn Calculated, from Well Head Location Closure Calculated from Well Head Location Hori'zontal Coordinates Calculated from Local Horizontal Reference A G y r o da t a D i r e c t ARCO ALASKA INC. WELL.: 7-10, 3.5"TBG Location: DRILLSITE 7, Job Number: AK0798GCE481 PRUDHOE BAY FIELD, ALASKA MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA SEVERITY DEPTH DEPTH deg./ feet feet 100 ft. .0.0 0.00 0.00 100;0 .16 12.45 .200~0 .14 267.52 300.0 .15 257.12 400.0' .16 258.68 0..00 0.0 -64.0 .16 100.0 36.0 . .24 200.0 136.0 .03 300.0 236.0 .01 400.0 336.0 500.0 600 .'o '700.0, 800.0 900.0 1000 1100 1200 13.oo 1400 .0 ~0 .0 .'0 .0 . 1'8 .12 .21 .22 .17 .07 .18 .21 .39 .76 271.92 10.05 1.58 .345.88 319.45 288 .29 152 .35 127 .37 196.02 185.04 .O5 .23 ..10 .06 .10 .11 .23 .09 .37 .38 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 436.0 536.0 636.0 736.0 836.0 936.0 1036.0 1136.0 1236.0 1336.0 1500;0 1600.0 1700'0 1800.0 1900.0 2000.0 2100~0 2200.0 2300.0 2400.0 .52 .44 ..38 .21 .11 .20 .21 .10 .28 .39 196.97 224.25 209.35 57.47 32.31 179.32 79.48 245.42 104.39 139.94 .2'7 .24 .12 .'58 .12 .30 .31 .31 .36 .23 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0, 1436.0 1536:0 1636.0 1736.0 1836.0 1936.0 2036.0 2136.0 2236.0 2336.0 i o n a 1 Survey Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES} feet 0.0 .1 .3 .4 .6 .9 1.1 1.1 1.4 1.7 1.9 1.8 1.5 1.2 1.3 2..1 2.9 3.6 3.7 3.5 3 .5' ,~.5 3.6 0.0 12.5 346.9 307.0 287.2 280.1 284.4 298.8 311.6 315.9 315.3 313.0 311~7 297.3 249.9 22~. '4 218.8 218.5 216'.8 215.8 214.2 210.5 209.1 206.1 197.5 0.0 N 0.0 E .1 N .0 E .3 N .1 W' .2 N .3 W .2 N .6 W .2 N .9 W .3 N 1.0 W .5 N 1.0 W .9 N 1.0 W 1.2 N 1.2 W 1.4 N 1.3 W 1.2 N 1.3 W 1.0 N 1.1 W .5 N 1.1 W .4 S 1.2 W 1.5 S 1.4 W 2.2 S 1.8 W 2.8 S 2.2 W 3.0 S 2.2 W 2.8 S 2.0 W 2.9 S 2.0 W 3.0 S 1.8 W 3.1 S 1.7 W 3.2 S 1.5 W. 3.5 S 1.1 W ARCO ALASKA INC. WELL: 7-I0, 3.5"TBG Location: DRILLSITE 7, Job Number: AK0798GCE481 A G y r o d a t a D i PRUDHO~': BAY FIELD, ALASKA MEASURED I N CL AZIMUTH DOGLEG VERTICAL SUBSEA DEPTH SEVERITY DEPTH DEPTH feet .deg. deg. deg./ feet feet 100 ft. 2500.0 2600.0 2700.0 2800.0 290.0.0 3000' 31oo. 3200. 3300. 3400. .95 96.96 1.24 112.04 .96 123.63 1.06 118.74 .82 105.97 1.05 1.01 1.03 .94 117.98 121.77 116.02 119.22 133.10' .71 .41 .36 .13 .31 .17 .24 .11 .06 .25 2500.0 2599.9 2699.9 2799.9 2899.9 2999.9 3099..9 3199.9 3299.8 3399.8 3500.0' 3600.0 3700.0 3800.0 3900.0' , 40,00.0 4100,.0 4200.0 4300~0 4400.0 .67 .54 .45 .30 .52 .56 .59 .60 .64 .65 141.47 1'28.16. 123.48 151.67 158.58 179.46 181.67 182.31 187.87 186.71 .3O .19 .10 .23 .23 .20 .04 .01 .07 .02 3499.8 3599.8 3699.8 3799.8 3899.8 3999.8 4099.8 4199.8 4299.8 4399.8 4500. 4600. 4700. 4750: 4800'. .33 5.37 10.44 12.87 14.64 245.81 325.01' 321,46 318.81 317'.79 56 32 O8 98 57 4499.8 4599.6 4698.6 4747.6 4796.2 r e c t i 2436.0 2535.9 2635.9 2735.9 2835.9 2935.9 .3035.9 3135.9 3235.8 3335.8 3435.8 3535.8 3635.8 3735.8. 3835.8 3935.8 4035.8 4135.8 4235.8 4335.8 4435.8 4535.6 4634.6 4683.6 . 4732.2 o n a 1 Survey Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES} feet 3.8 180.7 4.7 157.7 6.3 146.3 7.9 140.8 9.4 136.2 10.7 133.1 12.3 131.4 14.0 129.8 15.8 128.4 17.5 128.2 18.9 19.9 20.8 21.4 22.0 , 22.8 23.4 24.1 24.8 25.6 25.9 21.1 .,7.4 14'.6 128.8 129.1 129.0 129.2 130.0 13~. 5 133.4 135.2 137,2 139.1 140.6' 140 .'4 136.3 330.2 320.5 3.8 S .0 W 4.3 S 1.8 E 5.2 S 3.5 E' 6.1 S 5.0 E 6.8 S 6.5 E 7.3 S 7.8 E 8.1 S 9.2 E 9.0 S 10.8 E 9.8 S 12.4 E 10.8 S 13.7 E 11.8 S 14.7 E 12.6 S 15.4 E 13.1 S 16.1 E 13.5 S 16.6 E 14.2 S '16.9 E 15.1 S 17.0 E 16.1 S 17.0 E 17.1 S 17.0 E 18.2 S 16.9 E 19.3 S 16.8 E 20.0 S 16.4 E 16.3 S 13.5 E 5.4 S 5.1 E 2.4 N 1.4 W, 11.2 N 9.3 W A G y r o d a t a D i ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Location: DRILLSITE 7, PRUDHOE BAY FIELD, Job'Number: AK0798GCE481 ALASKA :- MEASURED I N C L DEPTH feet deg. r e c t i o n a 1 4850'0 490.0.0 4950.0 5000.0 5050.0 51o,o .,o 51'50.0 5200.0 5250.0 5300'. 0 15.36 16.71 17.63 18.85 20.30 20.90 21.87 22.71 23.86 25.15 AZIMUTH DOGLEG VERTICAL SUBSEA CLOSURE SEVERITY DEPTH DEPTH DIST. AZIMUTH deg. deg./ feet feet feet deg. 100 ft. 317.69 'l .44 317.65 2.70 318 . 06 11.. 85 318.39 2.44 318.71 2.92 1.. 21 'l . 97 ].. 80 2.38 2.64 4844.5 4892.5 4940.3 4987.8 5034.9 5081.7 5128.3 5174.5 5220.4 5265.9 5350 5400 5450 5'500 5550 ~0 .0 26.72 28.26 29.82 31.11 32.22 319.02 319.49 320.37 321.1'6 321.82 3 . 16 3.11 3.15 2.60 2 .24 5310.9 5355.3 5399.0 5442.1 5484.6 5600.0 5650.0 5700.0 5750.0 5800.0 , 33.30 ,34.80 35.98 37.45 38.26 322'.23 322 ;69 323.01 323.40 323,.61 .68 .73 .69 .91 .69 2 .16 2 .99 2 .37 2.94 ]. 66 5526.7 5568.1 5608.9 5648.9 5688.4 585o.o 59oo.o 595O,.o '600,0.0 6050.0 39.27 39.75 39.94 39.97 39.80 '323 323 323 323 323 .44 .38' .45 .43 .39 2.04 .97 .39 .06 .33 .5727.4 5766.0 5804..4 5842.7 5881.1 '323 323 323 323 323 4780.5 27.5 319.2 4828.5 41.3 318.7 4876.3 56.1 318.5 4923.8 71.7 318.4 4970.9 88.5 318.4 5017.7 106.1. 318.5 5064.3 124.3 318.6 5110.5 143.3' 318.8 5156.4 163.0 319.0 5201.9 183.7 319.3 5246.9 5291.3 5335.0 5378.1 5420.6 5462.7 5504.1 5544.9 5584.9 5624,.4 5663.4 5702.0 5740.4 5778.7 5817.1 205.6 319.6 228.6 319..9 252.9 320.2 278.2 320.5 304.4 320.7 331.4 ' 32%.0 359.4 321..2 388.3 321.4 418.2 321.5 448.8 321.7 480.1 321.8 511.9 321.9 54A.0 322.0 57 ~i"1 322'. 1 608.1 322.1 Survey Page HORIZONTAL COORDINATES~ feet 20.8 N 18.0 W 31.0 N 27.3 W 42.0 N 37.2 W' 53.6 N 47.6 W 166.2 N 58.7 W 79.4 N 70.3 W 93.3 N 82.2 W 107.8 N 94.4 W 123.1 N 106.9 W 139.3 N 119.8 W 156.5 N 133.2 W 174.8 N 147.3 W 194.2 N 161.9 W 214.5 Iq 177.1 W 235.6 N 192.7 W 257.4 N 208.8 W 279.9 N 225.3 W 303.3 N 242.5 W 327.4 N 260.1 W 352.2 N 278.3 W 377.4 N 296.9 W 402.9 N 315.8 W ,428.6 N 334.9 W 454.4 N 354.0 W · 480.2 N 373.2 W .! A G y r o d a t a Direct i o n a 1 Survey ARCO ALASKA INC. WELL:- 7-10, 3.5"TBG Location: DRILLSITE 7, Job Number: AK0798GCE481 PRUDHOI!: BAY FIELD, ALASKA MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA CLOSURE SEVERITY DEPTH DEPTH DIST. AZIMUTH deg./ feet feet feet deg. 100 ft. Page HORIZONTAL COORDINATES feet 6100.0 6150:'0 6200.0 62'50.0 6300,.0 39.93 39.48 39.75 39.60 39.12 323.53 323.68 323.84 324.12 324.47 .31 .92 .57 .46 .05 5919.4 5957.9 5996.4 6034.9 6073.6 5855.4 5893.9 5932.4 5970.9 6009.6 640.1 322.2 672.1 322.3 703.9 322.3 735.9 322.4 767.6 322.5 505.9 N 392.2 W 531.6 N 411.2 W 557.3 N 430.0 W' 583.1 N 448.8 W 608.9 N 467.3 W 6350,0 ' 6400.0 6450.0 65'00.0 6550.0 8.94 9.02 9.18 8.85 8.95 324.75 324.93 325.05 325.19 325.25 .51 .28 .34 .67 .21 6112.4 6151.3 6190.1 6228.9 6267.8 6048.4 6087.3 6126.1 6164.9 6203 .'8 799.0 322.6 830.4 322.7 862.0 322.7 893.4 322.8 924.8 322.9 634.6 N 485.5 W 660.3 N 503.7 W 686.1 N 521.8 W 711.9 N 539.8 W 737.7 N 557.7 W 6600.0 6650'.0 6700.0 6750.0 6800.0 6850.0 6900.0 6950.0 7000.0 705'0.0 7100.0 7150.0 7200;0 725.0.0' 7300.0 38.59 .38.66 38.39 37.97 37.89 . 37.66 37.45 37.41 37.01 36.63' 6.65 6.06 5.98 5'.51 5.01 325.19 325.25 325.16 325.11 325.26 325.26 325.40 325.42 325.40 325.94 325.98 32,6.10 326.25 326.04 326.06 .73 .16 .54 .84 .24 .46 .45 .09 · 79 .02 .06 1.19 .23 .97 .01 6306.8 6345.9 6385.0 6424.3 6463.7 6503.3 6542.9 6582.6 6622.4 6662.'4 6702.6 6742.8 6783.3 6823.8 6864.7 6242.8 6281.9 6321.0 6360.3 6399.7 6439.3 6478.9 6518.6 6558.4 .6598.4 6638.6 6678.8 6719.3 6759.8 6800.7 956.1 987.3 1018.4 1049.3 1080.0 1110.6 '1141.1 1171.4 1201.6 1231.6 1261.4 1291.0 1'320.4 1349~i"6 1378.4 323.0 323.1 323.1 323.2 323.2 32%. 3 323.4 323.4 323.5 323.5 323 .'6 323.6 323.7 323.7 323.8 763.4 N 57.5.5 W 789.1 N 593.3 W 814.6 N 611.1 W 8'40.0 N 628.8 W 865.2 N 646.3 W 890.4 N 663.8 W 915.5 N 681.1 W 940.5 N 698.4 W 965.4 N 715.5 W 990.1 N 732.4 W 1014.9 N 749.1 W 1039.4 N 765.7 W 1063.9 N 782.1 W 1088.1 N 798.3 W · 1112.1 N 814.4 W A Gyrodata Di ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Location: DRILLSITE 7, PRUDHOE BAY FIELD, Job Number: AK0798GCE481 ALASKA MEASURED DEPTH feet I N C L AZIMUTH DO(~LEG SEVERITY deg. deg. deg./ 100 ft. r e c t i o n a 7350 7400 7450 7500 7550 .0 .0 .0 .0 . 0 34.78 326.16 .47 34.34 326.25 .89 34.07 326.29 .55 33.67 326.41 .82 33.42 327.06 .87 1 Survey 7600 7650 770,0 7750 7800 .0 .0 .0 .0 ~ '.0 33.10 32.53 32 .15 31.31 30.54 327.05 .64 326.98 [I .14 32'7.56 98 327.63 1'1.69 327.95 ~1.58 VERTICAL SUBSEA CLOSURE DEPTH DEPTH DIST. AZIMUTH feet feet feet deg. 7850 7900 7950 8000 .8050 .0 .0 .0 .0' .0' 8100.'0 8150.,0 8200.0' 825'0,0 8300.0 83'50. 8400~ 8450 · 8500. 8550· 0.34 9.32 8.62 8.11 8'.61 9.37 0.76 2.06 3.18 4.64 6.07 7.55 8 ..92 0.16 1.29 328.47 328.98 330.19 330.94 331.43 ,' 331.85 332.54 333.27 333.87 334.69 335.3.0 336.00 336.47 337.00 337,53 .66 2.10 ~1.,. 83 ].. 25 ~'1.11 1.56 2.88 2.71 2.33 3.06 2.95 3.07 2 .80 2 .58 2 .36 6905.7 6946.9 6988.2 7029.7 7071.4 7113.2 7155.2 7197.5 7240.0 7282.9 7326.0 7369.4 7413.1 7457.1 7501.1 7544.9 7588.1 7630.8 7672.9 7714.4 7755.2 7795.2 7834.5 7873.0 7910.9 Page HORIZONTAL COORDINATES feet 6841.7 6882.9 6924.2 6965.7 7007.4 7049.2 7091.2 7133.5 7176.0 7218.9 1407.0 323.8 1435.3 323.9 1463.4 323.9 1491.3 .324.0 1518.9 324.0 1546.2 324.1 1573.3 324.1 1600.0 324.2 1626.3 '324.2 1651.9 324.3 7262.0 1677.2 324.3 7305.4 1702.0 324.4 7349.1 1726.1 324.5 7393.1 1749.7 324.6 7437.1 1773.3 324.7 7480.9 179'7.4 32%.7 7524.1 1822.2 324.8 7566.8 1848.0 325.0 7608.9 1874.7 325.1 7650.4 1902.2 325.2 7691.2 1930.7 325.4 7731.2 1960.2 325.5 7770.5 1990.6 325.7 7809.0 2021'79 325.9 7846.9 2053.8 326.0' 1135.8 N 830.4 W 1159.4 N 846.2 W 1182.8 N 861.8 W~ 1206.0 N 877.2 W 1229.1 N 892.4 W 1252.1 N 907.3 1274.8 N 922.0 1297.3 N 936.5 1319.5 N 950.'6 1341.2 N 964.3 1362.8 N 977.6 W 1384.0 N 990.5 W 1404.9 N 1002.8 W 1425.6 N 1014.5 W 1446.4 N 1025.9 W 1467.7 N 1037.4 W 1489.9 N 1049.1 W 1513.1 N 1061.0 W 1537.2 N 1073.0 W 1562.4 N 1085.1 W 1588.6 N 1097.3 W 1615.9 N 1109.6 W 1644.2 N 1122.1 W 1673.4 N 1134.7 W 1703.5 N 1147.3 W A G yr o da t a D i r e c t i ona I Survey ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Location: DRILLSITE 7, Job Number: AK0798GCE481 PRUDHOE BAY FIELD, ALASKA Page MEASURED .DEPTH feet I N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA CLOSURE SEVERITY DEPTH DEPTH DIST. AZIMUTH deg./ feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 8600.0 8650.0 8700.0 8750.0. 8.800,0 41.56 337.89 41.79 337.91 41.79 338.06 41.73 338.21 41.66 338.36 .73 .46 .19 .23 .25 7948.4 7884.4 2086.3 326.2 7985.8 7921.8 2118.8 326.4 8023.0 7959.0 2151.5 326.6 8060.3 7996.3 2184.1 326.8 8097.7 8033.7 2216.7 326.9 1734.1 N 1159.8 W 1764.9 N 1172.3 W 1795.8 N 1184.8 W' 1826.7 N 1197.2 W 1857.6 N 1209.5 W 8850. 890O. 8950. 900'0~ 9050. 41.98 338.78 41.98 339.13 42.21 339.23 41.95 339.81 42.29 340.20 .86 .47 .47 .94 .85 8134.9 8070.9 2249.4 327.1 8172.1 8108.1 2282.1 327.3 8209.2 8145.2 2314.9 327.4 8246.3 8182.3 2347.7 327.6 8283.4 8219.4 2380.5 327.8 1888.7 N 1221.7 W 1919.9 N 1233.7 W 1951.2 N 1245.7 W 1982.6 N 1257.4 W 2014.1 N 1268.8 W 9100 '9150 9200 9250 9300 .0 .0 ,0 .0 ,9350.0 9400.0 9450.0 9500~0 , 9550.0 96'00.0 9650.0 9700.0 9750.0 9800.0 42.15 340.34 42.06 341.06 42.16 340.92 41.91 34]..36 42..32 341.77 42.50' 341.96 42.43 342.56 42.47 342.25 42.38 '342.15 42.32' 342.42 41.84 342.03 41.91 342.18 41.18 341.84~ 40.86 342.31 40.35 341.97 .34 .98 .27 .77 .99 .44 .82 .42 .23 .38 .08 .24 :]i. 52 .88 1.11 8320.4 8256.4 2413.3 328.0 8357.5 8293.5 2446.0 328.1 8394.6 8330.6 2478.7 3'28.3 8431.8 8367,8 2511'.3 328.5 8468.8 8404.8 2544.0 328.6 8505.8 8441.8 2576.9 32%.8 8542.7 8478.7 2609.7 329.0 8579.5 8515.5 2642.5 329.2 8616.5 8552.5 2675.4 329.3 8653.4 8589.4 2708.2 329.5 8690.5 8626.5 2740.9 329.6 8727.7 8663.'7 2773.5 329.8 8765.2 8701.2 2806.0' 329.9 8802.9 8738.9 283~i'0 330.1 8840.9 8776.9 2869.9 330.2 204s.7 N 1280.2 w 2077.4 N 1291.3 W 2109.1 N 1302.2 W 2140.8 N 1313.0 W 2172.6 N 1323.6 W 2204.6 N 1334.1 W 2236.8 N 1344.4 W 2268.9 N 1354.6 W 2301.1 N 1364.9 W 2333.1 N 1375.2 W 2365.1 N 1385.4 W 2396.8 N 1395.6 W 2428.4 N 1405.9 W 2459.6 N 1416.0 W 2490.6 N 1426.0 W A G y r o d a t a D i r e c t ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Locati'on. DRILLSITE 7, Job Number: AK0798GCE481 PRUDHOI,: BAY FIELD, ALASKA MEASURED I N C L AZIMUTH DO(~LEG VERTICAL SUBSEA DEPTH SEV~!:RITY DEPTH DEPTH feet deg. deg. deg./ feet feet 100 ft. 9850.0 39.82 342.15 9900.0 39.23 342.74 9950.0 38.86 342.34 1000,0 0 38.53 342.47 Final Station. Closure: . 10 .39 .90. .68 8879.1 8917.7 8956.5 8995.5 i o n a 1 CLOSURE DIST. AZIMUTH feet deg. 8815.1 2901.4 330.3 8853.7 2932.5 330.5 8892.5 2963.3 330.6 8931.5 2993.9 330.7 Survey Page Disl~.ance:' 2993.92 ft Az: HORIZONTAL COORDINATES~ feet 330.72 deg. 2521.2 N 2551.5 N 2581.6 N 2611.4 N 1435.9 W 1445.5 W 1454.9 W' 1464.4 W A G y r o da t a D i r e c t i on a i Survey for ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Location: DRILLSITE 7, PRUDHOE BAY FIELD, ALASKA Job Number: AK0798GCE481SS Run Date: 4-Jul-98 09:02:13 Surveyor: TOM STODDARD Calculation Method.: MINIMUM CURVATURE Survey Latitude: 70.280000 deg.' N Sub-sea Correction from Vertical Reference: 64 ft. Azimuth'Correction: Gyro: Bearings are Relative to ']?rue North vertical SectiOn Calculated. fr(i~ln Well Head Location Ciosnre Calculated from Well Head Location Hori'zOntal CoOrdinates Calculated from'Local Horizontal ReferenCe A G y r e d a t a D i r e c t i o n a I Survey ARCO ALASKA INC. WELL.: 7-10, 3.5"TBG Location: DRILLSITE 7, PRUDHOI,: BAY FIELD, Job Number: AK0798GCE481SS ALAS KA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL CLOSURE DEPTH DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet -64.0 0.0 100.0 200.0 300.0 0.00 0.00 .10 7.97 .15 175'.69 .15 260.86 .16 258.12 0.00 .10 .21 .10 .02 0.0 64.0 164.0 264.0 364.0 0.0 0.0 .1 8.0 .3 356.1 .4 321.3 .6 294.3 0.0 N .iN .2 N '.2 N .2 N 0.0 E .0 E .1 W .2 W .5 W 4OO 500' 600 700 8OO .0 1.8 18 '22 19 267.15 104.32 4.63 351.53 328.97 .O3 .16 .15 .07 .09 464.0 5'64.0 664.0 764~0 864.0 .9 282.6 1.1 282.8 1.1 293.6 1.4 306.9 1.7 314.3 .2 .2 .4 .8 1.1 .8 W 1.0 W 1.0 W 1.0 W 1.1 W 90'0 10'00 1100 1,200' 1300 .0 1400.0 1500,.0 16o0.o 1700.0 1800~0' , 19oO.o 2000.0 ,2100.0 2200.0 2300.0 .11 .14 .20 .33 .63 .60 .47 ,.40 .27 .15 .17 .21 .14' .21 .35 299.51 201.28 136.36 171.31 188.99 192 . 68 214.43 214 . 71 112 . 11 41.36 126.43 '115.40 185.72 155.13 127.15 .11 .19 .14 .27 .38 .31 .25 .16 .41 · 29 .24 .31 .31 .34 .28 964'.0 1064.0 1164.0 1264.0 1364.0 1464.0 1564.0 1664.0 17'64,0 1864.0 1964.0 2064.0 2164.0 2264.0 2364.0 1.9 315.5 1.8 313.8 1.5 312.1 1.2 302 ..5 1.3 267.0 2.1 232.3 2.9 220.1 3.6 218.6 3.7 217.4 3.5 216..1 3.5 3.5 .3.5 3.5 3.6 214.8 211.8 209.6 207.2 ~ .... 200.6 1.3 1.3 1.1 .7 .5 '1.1 2.0 2.6 2.9 2.9 2.9 3.0 3.1 3.1 3.4 N N N N S 1.3 W 1.3 W 1.2 W 1.1 W 1.2 W 1.3 W 1.7 W 2.1 W 2.2 W 2.1 W 2.0 W 1.9 W 1.7 W 1.6 W 1.3 W A G y r o d a t a D i r e c t i o n a i S u rve y ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Location: DRILLSITE 7, PRUDHOI,: BAY FIELD, Job Number: AK0798GCE481SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet .deg. deg. de~./ 100 ft. VERTICAL CLOSURE DEPTH DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 2400.0 2500.0 2600.0 2700.0 28,00.0 2900.0 3000.0 3100.0 3200.0 3300.0 3400.,0 35'00..0 3600.0 3700.0 3800.0 3900.0 4000.0 410'0.0 4200.0 4300.0 .75 112.42 .54 1.14 106.62 .52 1.06 119.47 .38 1.02 120.49 .'21 .91 110.56 .25 .82 .97 1.03 1.02 .97 .77 .58 .48 .35 .44 .55 .58 .60 .63 .65 113.67 120.41 118.08 118.07 128.12 138.47 1.32.93 125.16 141.58 156.10 171.98 180.88 182.0.8 185.88 187.13 .22 .22 .16 .08 .]_8 .2 .2 .1 .1 .2 .2 .1 .0 .0 .0 2 , 5 4 2464.0 2564.0 2664.0 2764.0 2864.0 2964.0 3064.0 3164.0 3264.0 3364.0 3464.0 3564.0 3664.0 3764.0 3864.0 3964.0 4064.0 416'4.0 4264.0 4364.0 3.8 186.8 4.7 166.0 6.3 150.4 7.9 142.8 9.4 137.9 10.7 134.2 12.3 132.0 14.0 130.3 15.8 128.9 17.5 128.3' 18.9 128.6 19.9 129.0 20.8 129.1 21.4 129.1 22.0 129.7 22.8 131.0 23.4 132.7 24.1 134.6 24.8 136.5 25.6 138.4 3.7 S .4 W 4.2 S 1.2 E 4.9 S 2.9 E 5.8 S 4.4 E 6.5 S 5.9 E 7.1 S 7.8 S 8.7 S 9.5 S 10.4 S 11.5 S 12.3 S 12.9 S 13.4 S 13.9 S ~14.8 S 15.7 S 16.8 S 17.8 S' 18.9 S 7.3 E 8.7 E 10.2 E 11.8 E 13.2 E 14.4 E 15.2 E 15.9 E 16.4 E 16.8 E 17.0 E 17.0 E 17.0 E 16.9 E 16.8 E 4400.0 4500.0 4600.0 4700.0 ,4800.0 .45 3 .57 8.66 13.47 15.91 224.67 296.751 322.71 318.46 317167 .3 3.6 5..1. 4.5 1.9 4464.0 '4564.0 4664.0 4764.0 4864.0 25.9 140.1 21.1 140.5 7.4 137.7' 14.6 .326.9 ~ 41.3 319.0 . 19,.8 S 1'7.6 S 9.2 S 5.4 N 25.0 N 16.5 E 14.5 E 8.1 E 4.0 W 21.8 W .., A G y r o d a t a D i r e c t i ona i S u rve y ARCO ALASKA INC. WELL: 7-10, 3.5"TBG Location: DRILLSITE 7, PRUDHOt.i: BAY. FIELD, ALASKA Job'Number: AK0798GCE481SS SuBsEA I N C L AZIMUTH DEPTH feet deg. deg. 4900.0' 18.24 50.00.0 20.68 5100,0 22.52 5200,0 25.09 5300.0 28..57 31.68 34.65 37.76 39.73 39.88 318.22 318.91 320.17 321.79 322.75 323.51 323.72 323.83 323.3'8 323.40 DOGLEG VERTICAL CLOSURE SEV]~RITY DEPTH DIST. AZIMUTH deg./ feet feet deg. 100 ft. 2. ].5 1.86 ]..84 2.63 3.12 4964.0 71.7 318'.4 5064.0 106.1 318.5 5164.0 143.3 318.8 5264.0 183.7 319.3 5364.0 252.9 319.9 2.41 2.91 2.45 ].. 02 .21 5464.0 304.4 320.6 5564.0 359.4 321.1 566.4.0 448.8 321.6 5764.0 511.9 321.9 5864.0 608.1 322.1 54'oo. o 5500.0 5600. O, 5700.0 5800.0 HORIZONTAL COORDINATES feet 47.8 N 74.4 N 104.5 N 138.6 N 178.7 N 225.4 N 277.7 N 336.9 N 401.6 N 468.7 N 42.4 W 65.9 W 91.6 W 119.2 W 150.2 W 185.2 W 223.7 W 267.1 W 314.8 W 364.7 W Page 5900 6000 6100 '6200 6300 6400 6500 6600 6700 68OO .0 39 39 39 38 3'8 37 .37 36 36 35 .52 .24 .08 .94 .54 .89 .43 .63 .0'2 .02 323.71 324.38 324.97 325.24 325,.21 325.26 325.41 325.95 326.18 326.06 .86 .91 .30 .25 .34 .24 .26 .98 .69 ]. 01 5964.0 703.9 322.3 .6064.0 767.6 322.5 6164.0 862.0 322.7 6264.0 924.8 322.9 6364.0 1018;4 '323.1 6464.0 1110.6 323.2 6564.0 1171.4 323.4 '6664.0 1261.4 323.5 6764.0 1320.4 323..7 6864.0 1378..4 323.8 535.7 N 602'. 5 N 668.8 N 735.2 N 800.9 N ~65.. 4 N 928.8 N 991.1 N 1052.2 N 1111.7 N 414.2 W 462.7 W 509.6 W 555.9 W 601.6 W 646.4 W 690.3 W 733 . 1 W 774.3 W 814.2 W 6900.0 70'00.0 7100.0 7.200 ..0 7300.. 0 34.23 33 .46 32.45 30.88 29.45 326.26 326.94 327.10 ,327.81 328.91 .75 .86 ]. 10 11.62 ]. 92 .6964.0 1463.4 323.9 7064.0 1518.9 324.'0 7164..0 1600.0 324.1~ 7264.0 1651.9 324.3~ .... '7364.0 1702.0 324.4 1169.1 N 1225.0 N 1279.5 N 1331.7 N 1381.4 N 852.6 W 889.7 W 925.0 W 958.2 W 988.9 W A G y r o d a t a D i r e c t AR~O ALASKA INC. WELL:. 7-10, 3.5"TBG Location- DRILLSITE 7, PRUDHOI,: BAY FIELD, ALASKA Job Number: AK0798GCE48155 SUBSEA I N C L AZIMUTH DO{]LEG VERTICAL CLOSURE DEPTH SEVI.:RITY DEPTH DIST. AZIMUTH feet deg. deg. deg./ feet feet deg. 100 ft. 7400.0 28.18 331.02 11.23 7500'.0 29.98 332.15 2.14 7600.0 32.94 333.75 2.41 7,700.0 36.40 335.46 2.9'7 7800.0 39.87 336.88 2.63 7464.0 1773.3 324.6 7564.0 1822.2 324.8 7664.0 1874.7 325.1 7764.0 1960.2 325.4 7864.0 2021.9 325.8 7900.0 '. 41.66 .337.90 .61. 8000.0 41.73 338.22 .23 8100.0 41.98 339.06 .56 8200.0 42.11 340.00 .89 8300.0 42.08 341.04 .86 8400.0 42.26 341.72 .96 8500.0 42.45 342.38 .59 8600.0 4218 342.31 .58 870'0'0 41.20 341.85 i.48 8800.0 40.03 342.08 ] .10 8900.0 38.79 342.37 86 8931.5, 38.53 34'2.47 .68 Final ' Station 'Closure: Disi.~n. ce - , , 7964.0 2118.8 326.3 8064.0 2216.7 326.8 8164.0 2282.1 327.2 8264,.0 2380.5 327.7 8364.0' 2478.7 328.2 8464.0 2544.0 328 6 8564.0 2642.5 329.1 8664.0 2740.9 3295 8764.0 2806.0 329.9 8864.0 2901.4 330.3 8964.0 2993.9 330.6 8995.5 2993.9 330.7 2993.92 ft Az: i o na 1 Survey HORIZONTAL COORDINATES feet 1428.8 N 1016.3 1477.5 N 1042.6 1532.1 N 1070.4 1594.6 N 1100.0 1666.6 N 1131.7 1747.0 N 1829.8 N 1913.1 N 1997.6 N 2082.9 N 2168.4 N 2255.4 N 2342.3 N 2427.4 N 2509.1 N 2%87.3 N 2611.4 N 1165.1 W 1198.5 W 1231.1 W 1262.8 W ,1293.2 W 1322.2 W 1350.3 W 1378.1 W 1405.6 W 1432.0 W 1456.7 W 1464.4 W 330.72 deg. Page 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK0798GCE481 TOOL NUMBER: 768 MAXIMUM GYRO TEMPERATURE: MAXIMUM AMBIENT TEMPERATURE: 88.31 C 92.15 C MAXIMUM INCLINATION: AVERAGE AZIMUTH: 42.21 330.72 WIRELINE REZERO VALUE: -5 REZERO ERROR/K: N/A CALIBRATION USED FOR FIELD SURVEY: 2535 CALIBRATION USED FOR FINAL SURVEY: 2535 PRE JOB MASS BALANCE OFFSET CHECK: .20 POST JOB MASS BALANCE OFFSET CHECKs: .28 USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS BOTTOM LINE CoMpARISIONS M.D. INC OK AZIMUTH TVD NORTHING EASTING FINAL SURVEY 10000 38.53 342.47 1979 GYRO 10000 38.25 339.00 8995.5 2611 8995.0 N/A -1464 N/A FUNCTION TEST JOB NUMBER' AK0798GCE481 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclinatior and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 4700 10.44 10.44 10.44 10.44 10.44 AZIMUTH M.D. ft 1 2 3 4 5 4700 321.39 321.59 321.67 321.46 321.41 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER' AK0798GCE481 - DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 768 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 772 GYRO SECTION DATA SECTION POWER SECTION A0212 C0111 C0083 A0162 C0089 C0086 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0467 A0085 A0079 A0143 A0433 A0107 A0029 A0055 WIRELINE COMPANY' CABLE SIZE · 7/32" SCHLUMBERGER RUNNING GEAR 2.5" HOUSING W/TOP CENTRALIZER TOTAL LENGTH OF TOOL' 25' MAXIMUM O.D.' 2.5 INCHES TOTAL WEIGHT OF TOOL ' 280 POUNDS · . CHRONOLOGICAL REPORT JOB NUMBER' AK0798GCE481 FRIDAY, 7/03/98 11:00 TO SLOPE 12:40 ARRIVE DEADHORSE 18:00 CHECK TOOLS, STANDBY SATURDAY, 7/04/98 07:00 08:00 08:30 09:45 10:45 11:30 13:00 14:00 15:00 21:00 TO LOCATION MU TOOL, RU SCHL~ERGER PICK UP GYRO, RIH REPAIR SWAB VALVE TOOL SHORTED, DROP TOP CENTRALIZER AND SWIVEL TRY RIH, TOOL NOT DROPPING. CUT LINE REHEAD, ADD WEIGHT . WORK TOOL TO 130'. PUMP METHANOL. PUMP TOOL OFF LINE?. RD SCHLUMBERGER. RUN JOB 482 SUNDAY, 7/05/98 09'00 FINISH 482. 13'00 16'00 17'00 i9'00 21:45 22'15 TO DRILLSITE 7. RU SCHLUMBERGER, PUMP METHANOL. RIH TO 1300'. WORK TOOL TO 2000'. TOOL DROPPEN*G FEN*E. RIH SU~RVEY 4600-10000' CONTENTOUS. SURVEY OUT. LD TOOL, RD SCHLUMBERGER. MONDAY, 7/06/98 01:00 PROCESS SURVEY, RESULTS TO PBOC. 12:00 CHECK TOOLS. 16:00 TO ANCHORAGE. ri F! I I_1_ I Itl G SEFI~JI r' E ~ 17-Sep-98 AC)GCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 07-10A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,397.50' MD 9,428.00' MD 13,405.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 07 07- IOA Corrected SURVEY REPORT September, 1998 ORiGI:NAL Your Reft API-500292033501 Last Survey Date 08-August-98 Job# AKMWS0297 KBE - 61.50' ~l:,=,r,r-,~-~um DRILLING c; I:: RV I (: E 5 Survey Reft svy3718 Prudhoe Bay Unit Measured Sub. Sea Vertical Depth Incl. Azim. Depth Depth Northings (fi) (~) (~) (fi) 9397.50 42.430 342.560 8478.67 8540.17 2236.76 N 9428.00 43.660 341.100 8500.96 8562.46 2256.54N 9461.92 46.700 339.580 8524.87 8586.37 2279.19 N 9494.66 50.410 338.160 8546.54 8608.04 2302,07 N 9526.46 54.380 336.910 8565.94 8627.44 2325.35 N 9558.27 57.370 335.760 8583.78 8645.28 2349.46 N 9589.89 61.230 334.670 8599.92 8661.42 2374.14 N 9622.01 62.170 333,660 8615.15 8676.65 2399.59 N 9653.72 63.610 332.020 8629.60 8691.10 2424.70 N 9685.17 63.310 334.090 8643.65 8705.15 2449.78 N 9716.95 62,680 336.570 8658,09 8719.59 2475.50 N 9749.13 62.350 336.210 8672.94 8734.44 2501.66 N 9780.82 62,410 337.090 8687,63 8749.13 2527.44 N 9812,57 63.020 338.130 8702.18 8763.68 2553.53 N 9842.53 62.350 337.790 8715.93 8777.43 2578.21N 9874,35 62.710 337.730 8730.61 8792.11 2604.34N 9905,86 64.230 339,600 8744.68 8806.18 2630.60 N 9938.14 65.330 341.330 8758,44 8819.94 2658.12 N 9970.49 65.080 340.480 8772.01 8833.51 2685.87 N 10002.05 64.780 340.230 8785.38 8846.88 2712.79 N 10033.54 64.560 341.150 8798,85 8860.35 2739.65 N 10065.28 64.100 339,900 8812.60 8874.10 2766,62 N 10096.92 64.060 340.740 8826.43 8887.93 2793.42 N 10129.36 63.720 340.330 8840.71 8902.21 2820.88 N 10160.61 63.339 340.742 8854.64 8916.14 2847.26 N 10344.21 74.082 342.696 8921.21 8982.71 3009.48 N 10376,62 78.236 342.709 8928.96 8990.46 3039.52 N 10408.46 81.745 341.785 8934.49 8995.99 3069.38 N 10440.06 84.416 341.770 8938.30 8999.80 3099.17 N 10470,83 86,764 340.668 8940.67 9002.17 3128.21 N Sperry-Sun Drilling Services Survey Report for 07-10A Corrected Your Ref: API-500292033501 Local Coordinates Global Coordinates Eastings Northings Eastings (fi) (fi) 1344.34W 5952144.03 N 674583,28 E 1350.83W 5952163.65 N 674576.33 E 1358.94W 5952186.10 N 674567.70 E 1367.79W 5952208.77 N 674558.31E 1377.42W 5952231.82 N 674548.14 E 1387.99W 5952255.68 N 674537.01E 1399.39W 5952280.08 N 674525.03 E 1411.72W 5952305.24 N 674512.12 E 1424.60W 5952330.04 N 674498.65 E 1437.35W 5952354.81N 674485.32 E 1449.17W 5952380.26 N 674472.90 E 1460.60W 5952406.14 N 674460.86 E 1471.73W 5952431.65 N 674449.13 E 1482.48W 5952457.48 N 674437.77 E 1492.47W 5952481.92 N 674427.21E 1503.15W 5952507.79 N 674415.92 E 1513.41W 5952533.80 N 674405.05 E 1523.17W 5952561.09 N 674394.65 E 1532.78W 5952588.61N 674384.40 E 1542.39W 5952615.30 N 674374.16 E 1551.80W 5952641,93 N 674364.12 E 1561.34W 5952668.67 N 674353.96 E 1570.92W 5952695.24 N 674343.75 E 1580.63W 5952722.47 N 674333.41 E 1589.95W 5952748.62 N 674323.47 E 1643.43W 5952909.54 N 674266,21 E 1652.78W 5952939.36 N 674256.16 E 1662.34W 5952968.98 N 674245.90 E 1672.15W 5952998.54N 674235.40 E 1682.03W 5953027.34 N 674224.85 E Dogleg Vertical Rate Section (°ll00ft) (ft) 5,190 9.509 11,788 12.866 9.864 12.562 4,029 6,466 5.965 7.230 1.427 2,468 3.488 2.453 1.144 7,174 5,926 2.507 1,191 2,732 3.834 2.391 1.545 1.697 5.934 12.817 11.385 8.453 8.425 2461.85 2482.53 2506.35 2530.54 2555.28 2581.03 2607.50 2634.91 2662.11 2689.24 2716,82 2744.75 2772.24 2799.96 2826.14 2853.89 2881.68 2910.60 2939.72 2968.03 2996.24 3024.57 3052.75 3081.61 3109.32 3278.99 3310.30 3341.47 3372.63 3403.07 Comment Tie-on Survey Window Point Alaska State Plane Zone 4 PBU EOA DS 07 Continued... 11 September, 1998 - 10:36 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 07-10A Corrected Your Ref: API-500292033501 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth Northings (ft) (ft) (ft) (ft) 10502.21 88.951 340.637 8941.84 9003.34 3157.80 N 10533.95 89.198 340,262 8942.35 9003.85 3187.70 N 10566.48 87.876 339,533 8943.18 9004.68 3218.24 N 10597.85 86.553 337.944 8944.71 9006.21 3247,44 N 10629.70 86.550 337.605 8946.62 9008.12 3276.87 N 10662,14 86.892 337.704 8948.48 9009.98 3306.82 N 10693.96 87.538 337.778 8950.02 9011.52 3336.24 N 10725.64 87.721 338.039 8951.33 9012.83 3365.57 N 10757.40 87.814 337.885 8952.57 9014.07 3394.98 N 10789.18 87.382 337.525 8953.90 9015.40 3424,36 N 10819.62 87.382 337.918 8955.29 9016.79 3452.50 N 10852.95 87.470 337.545 8956.79 9018.29 3483.31 N 10883.91 88.707 337.866 8957.82 9019.32 3511.94 N 10915.95 91.505 341.150 8957.76 9019.26 3541.95 N 10947.72 91.659 346.785 8956.89 9018.39 3572.46 N 10979.46 89.937 349.232 8956,44 9017.94 3603.50 N 11011.86 89,382 349.376 8956.64 9018.14 3635.34 N 11043.44 89.079 349.211 8957.06 9018.56 3666.36 N 11074.88 89.135 349.265 8957.55 9019.05 3697.25 N 11106.61 89.445 348.856 8957.94 9019.44 3728.40 N 11138.46 89.782 347.966 8958.16 9019.66 3759.60 N 11168.65 90.372 348.047 8958.12 9019.62 3789.13 N 11200.31 88.643 348.396 8958.39 9019.89 3820.12 N 11231.79 86.919 348.091 8959.61 9021.11 3850.91 N 11263.61 86,855 347.706 8961,34 9022,84 3881.98 N 11295.11 87.168 347.692 8962,98 9024.48 3912.72 N 11326.86 87.200 347.250 8964.54 9026.04 3943.67 N 11358.42 87.625 347.258 8965.96 9027.46 3974.42 N 11390.13 88.365 346.552 8967.07 9028.57 4005.29 N 11421.52 90.521 347.960 8967.38 9028.88 4035.90 N Local Coordinates Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (fi) (fi) (fi) (°/100~) (fi) 1692.41W 5953056.68 N 674213.77 E 6.970 3434,14 1703.03W 5953086.33 N 674202.45 E 1.415 3465.58 1714.21W 5953116.59 N 674190.57 E 4.640 3497.74 1725,57W 5953145.52 N 674178.53 E 6.587 3528.63 1737.60W 5953174.66 N 674165.82 E 1.062 3559.88 1749.91W 5953204.32 N 674152.81E 1.097 3591.70 1761.95W 5953233.44 N 674140.08 E 2.043 3622.94 1773.85W 5953262.49 N 674127.50 E 1.006 3654.06 1785.76W 5953291.62 N 674114.90 E 0.~66 3685.28 1797.81W 5953320.71N 674102.17 E 1.769 3716.48 1809.34W 5953348,57 N 674089.99 E 1.290 3746.37 1821.95W 5953379.08 N 674076.66 E 1.149 3779.09 1833.69W 5953407.42 N 674064.25 E 4.128 3809.50 1844.91W 5953437.16 N 674052.34 E 13.465 3841.15 1853.67W 5953467.45 N 674042.86 E 17.737 3872.80 1860.27W 5953498.33 N 674035.54 E 9.426 3904.53 1866.28W 5953530.02 N 674028.79 E 1.770 3936.93 1872.15W 5953560.90 N 674022.20 E 1.092 3968.50 1878.02W 5953591.64 N 674015.61E 0.247 3999.93 1884.04W 5953622.64N 674008,86 E 1.617 4031.66 1890.44W 5953653.68 N 674001.73 E 2.988 4063.51 1896.71W 5953683.06 N 673994.77 E 1.973 4093.70 1903.17W 5953713.89 N 673987.59 E 5.571 4125.35 1909.58W 5953744.53 N 673980.46 E 5.561 4156.81 1916.24W 5953775.43 N 673973.07 E 1.225 4188.58 1922.94W 5953806.00 N 673965.66 E 0.995 4220,04 1929.82W 5953836.79 N 673958.06 E 1.394 4251.74 1936,78W 5953867.37 N 673950.38 E 1.347 4283.26 1943.96W 5953898.06 N 673942.48 E 3.224 4314.94 1950.88W 5953928.50 N 673934.85 E 8.203 4346.32 Comment Alaska State Plane Zone 4 PBU EOA DS O7 Continued,.. 11Septembe~ 1998-10:36 -3- DdllQuest Sperry-Sun Drilling Services Survey Report for 07-10A Corrected Your Ref: API-500292033501 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 07 Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth Northings (ft) (ft) (ft) (ft) 11453.19 90.618 347.366 8967.06 9028.56 4066.84 N 11485.00 90,647 347.383 8966.71 9028.21 4097.88 N 11516.76 90,803 347,041 8966.31 9027.81 4128.85 N 11548.45 91.262 346.549 8965.74 9027.24 4159.69 N 11579.99 91.756 346.629 8964.91 9026.41 4190.36 N 11612.19 92,220 346.986 8963.79 9025.29 4221.70 N 11644.05 91.904 349.189 8962.65 9024.15 4252.85 N 11675.45 90,833 351.245 8961.90 9023.40 4283.78 N 11706.93 90.583 350,723 8961.51 9023.01 4314.87 N 11738.31 90.126 350.055 8961,31 9022.81 4345.81 N 11769.94 90,372 350,200 8961.18 9022.68 4376.97 N 11801.59 91.506 350,158 8960.66 9022.16 4408.15 N 11835.05 92.306 344,580 8959.54 9021.04 4440.77 N 11866.55 92.493 344,817 8958.22 9019.72 4471.13 N 11898.16 93.454 344.810 8956.58 9018.08 4501.59 N 11929.76 94.756 343.994 8954.32 9015.82 4531.95 N 11961.42 93.915 344.054 8951.93 9013.43 4562.30 N 11968.43 93.167 344,245 8951.50 9013.00 4569.03 N 11992.61 90.865 344,688 8950.65 9012.15 4592.31 N 12024.33 89.753 344.781 8950.47 9011.97 4622.91 N 12042.02 90.492 344.729 8950.44 9011.94 4639.98 N 12055,82 91.139 345.147 8950.24 9011.74 4653.30 N 12088.06 91.946 344.428 8949.37 9010.87 4684.40 N 12119.80 90.649 345,684 8948.65 9010.15 4715.06 N 12151.73 90.246 344,648 8948.40 9009.90 4745.92 N 12183.13 90,741 345,321 8948.13 9009.63 4776.25 N 12214.81 89.171 344.335 8948.16 9009.66 4806.82 N 12246.25 90.000 343.860 8948.39 9009.89 4837.06 N 12278.69 90.183 343.227 8948.33 9009.83 4868.17 N 12310.66 90.618 342.553 8948.11 9009.61 4898.72 N Local Coordinates Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (ft) (fi) (fi) (°1100fi) (fi) 1957.65W 5953959.27 N 673927.36 E 1.900 4377.99 1964.60W 5953990.14 N 673919.68 E 0,106 4409.79 1971.63W 5954020.93 N 673911.93 E 1,183 4441.54 1978.87W 5954051.60 N 673903.97 E 2,123 4473.22 1986.18W 5954082.09 N 673895.94 E 1.587 4504.73 1993.52W 5954113.24 N 673887.87 E 1,818 4536.90 2000.10W 5954144.23 N 673880.57 E 6,981 4568.74 2005.43W 5954175.03 N 673874.52 E 7,381 4600.11 2010.36W 5954206.00 N 673868.86 E 1.838 4631,55 2015.60W 5954236.81N 673862.90 E 2.579 4662.91 2021.02W 5954267.83 N 673856.75 E 0.903 4694.53 2026.42W 5954298.88 N 673850.62 E 3.585 4726.16 2033.73W 5954331.32 N 673842.55 E 16.832 4759.58 2042.04W 5954361.47 N 673833.54 E 0.958 4790.99 2050.31W 5954391.73 N 673824.56 E 3,040 4822.49 2058.78W 5954421,89 N 673815.38 E 4.859 4853.94 2067.47W 5954452.02 N 673805.98 E 2.663 4885.42 2069.38W 5954458.71 N 673803.91 E 11,012 4892.39 2075.85W 5954481.83 N 673796.90 E 9.695 4916.50 2084.20W 5954512.23 N 673787.84 E 3,518 4948.16 2088.85W 5954529.18 N 673782.79 E 4.188 4965.81 2092.44W 5954542,42 N 673778,89 E 5.582 4979.58 2100.90W 5954573.31N 673769,71E 3.352 5011.75 2109.08 W 5954603.77 N 673760.81 E 5.688 5043.43 2117,25 W 5954634.43 N 673751.92 E 3.481 5075.30 2125.39 W 5954664.56 N 673743.08 E 2.661 5106,65 2133.68 W 5954694.93 N 673734.07 E 5.852 5138.27 2142.29W 5954724.96 N 673724.75 E 3.039 5169.62 2151.48W 5954755.85 N 673714.84E 2.031 5201.94 2160.89W 5954786.17 N 673704.72 E 2.509 5233.77 Comment Continued... 11 September, 1998.10:36 -4- DrillQuest Sperry-Sun Drilling Services Survey Report for 07-10A Corrected Your Ref: API-500292033501 Prudhoe Bay Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (fi) (fi) (fi) 12342.27 92.625 343.781 8947.22 9008.72 12405.84 93.736 347.960 8943.69 9005.19 12437.49 91.297 348.416 8942.30 9003.80 12469.29 89.628 346.957 8942.04 9003.54 12500.81 90.126 346.753 8942.11 9003.61 12532.63 89.107 345.855 8942.32 9003.82 12564.03 90.801 345.382 8942.35 9003.85 12595.72 92.988 346.304 8941.30 9002.80 12628.01 93.173 346.805 8939.56 9001.06 12642.93 91.447 346.242 8938.96 9000.46 12691.45 86.151 343.185 8939.98 9001.48 12723.43 86.550 341.614 8942.02 9003.52 12754.86 87.566 341.756 8943.63 9005.13 12786.62 89.044 342.761 8944.57 9006.07 12818.90 91.013 344.648 8944.55 9006.05 12851.18 91.385 345.336 8943.88 9005.38 12869.44 90.586 346.923 8943.56 9005.06 12882.82 89.754 346.496 8943.52 9005.02 12901.22 88.428 346.599 8943.81 9005.31 12914.55 88.305 345.679 8944.19 9005.69 12932.01 88.833 344.093 8944.63 9006.13 12946.25 89.416 345.217 8944.85 9006.35 12976.75 90.832 346.594 8944.78 9006.28 13009.42 91.636 347.157 8944.08 9005.58 13166.71 82.258 348.131 8952.45 9013.95 13197.87 83.697 343.687 8956.26 9017.76 13229.68 85.465 343.917 8959.26 9020.76 13292.42 87.689 345,626 8963.01 9024.51 13355.29 83.711 349.347 8967.72 9029.22 13405.00 83.711 349.347 8973.17 9034.67 Local Coordinates Northings (ft) 4928.96 N 4990.50 N 5021.45 N 5052.51N 5083.21N 5114.12 N 5144.54 N 5175.24 N 5206.60 N 5221.10 N 5267.87 N 5298.29 N 5328.09 N 5358.32 N 5389.31N 5420.48 N 5438.2O N 5451.22 N 5469.12 N 5482.05 N 5498.90 N 5512.63 N 5542.21 N 5574.02 N 5727.28 N 5757.26 N 5787.67 N 5848,09N 5909.27 N 5957.83 N Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/100fi) (fi) 2170.04W 5954816.19 N 673694.87 E 7.443 5265.23 2185.53W 5954877.35 N 673677.94 E 6.792 5328.63 2192.00W 5954908.14 N 673670.75 E 7.839 5360.24 2198.78W 5954939.04 N 673663.24 E 6.971 5392.04 2205.95W 5954969.55 N 673655.36 E 1.707 5423.55 2213.49W 5955000.28 N 673647.11E 4.268 5455.35 2221.28W 5955030.51 N 673638.60 E 5.601 5486.71 2229.03W 5955061.03 N 673630.14 E 7.489 5518.35 2236.53W 5955092,20 N 673621.91E 1.652 5550.57 2240.00W 5955106.61 N 673618.09 E 12.167 5565.47 2252.78W 5955153.07 N 673604.22 E 12.601 5613.86 2262.43W 5955183.26 N 673593.86 E 5.059 5645.60 2272.30W 5955212.82 N 673583,31E 3.264 5676.78 2281.97W 5955242,82 N 673572.93 E 5.627 5708.34 2291.03W 5955273.58 N 673563.15 E 8.448 5740.51 2299,38W 5955304.55 N 673554.07 E 2.423 5772.73 2303.76W 5955322.16 N 673549.28 E 9.729 5790.97 2306.84W 5955335.11N 673545.90 E 6.989 5804.35 2311.12W 5955352.90 N 673541.20 E 7.228 5822.73 2314.31W 5955365.76 N 673537.71E 6.960 5836.05 2318.86W 5955382.50 N 673532.76 E 9.571 5853.47 2322.63W 5955396.13 N 673528.68 E 8,891 5867.68 2330.05W 5955425.53 N 673520.56 E 6.476 5898.15 2337.47W 5955457.16 N 673512.40 E 3.004 5930.80 2371.05W 5955609.59 N 673475.25 E 5.994 6087.68 2378,58W 5955639.39 N 673467.02 E 14.889 6118.56 2387.41W 5955669.58 N 673457.48 E 5.604 6150.13 2403.86W 5955729.61 N 673439.62 E 4.467 6212.63 2417.44W 5955790.45 N 673424.61 E 8.652 6275.29 2426.58W 5955838.78 N 673414.35 E 0.000 6324.69 Comment Projected Survey Alaska State Plane Zone 4 PBU EOA DS 07 Continued... September, 1998 - 10:36 - 5 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for 07.10A Corrected Your Ref: API-500292033501 Alaska State Plane Zone 4 PBU EOA DS 07' All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 348.370° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13405.00ft., The Bottom Hole Displacement is 6433.04ff., in the Direction of 337.839° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9397.50 8540.17 2236.76 N 1344.34 W Tie-on Survey 9428.00 8562.46 2256.54 N 1350.83 W Window Point 13405.00 9034.67 5957.83 N 2426.58 W Projected Survey 11 September, 1998- 10:36 - 6- DrillQuest 11/16/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12067 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape D.S. 07-10A 98419 PEX/BHC 980803 - 1 P.S. 0?-10A 98419 PEX-C~ 980803 1 I D.S. 07-10A 98419 PEX-CNL 3 DET. DENSITY 980803 I ! D.S. 07-10A 98419 BHC 980803 1 1 D.S. 07-10A 98419 SSTVD 980803 1 1 D.S. 07-10A 98419 CEMENT VOLUME 980803 ] ] SIGNED DAT/~i~ 0;; & G~s s An~or~o Please ign an is transmittal to Sherrle at the above address. Thank you. 0 I::11 I-I-- I N G S E I::t U' I r" E S WELL LOG TRANSM1TFAL To: State of Alaska November 4, 1998 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs D.S. 7-10A, AK-MW-80297 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention or2 Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 D.S. 7-10A: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-20335-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20335-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ~ora~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500. Fax (907) 273-3535 CI Ft I I--I--I ~ G SEI:t~JI C E S WEIJ~ LOG TRANSMITY~ To: State of Alaska November 4, 1998 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 7-10A, AK-MW-80297 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ali Turker, Sperry-Stm Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20335-01. 1998 Anchora~te 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 TONY KNOWLES, GOVERNOR ALASi~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Julv 14, 1998 James E. Smith Engineering Supervisor ARCO Alaska Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 07-10A ARCO Alaska Inc. Permit No. 98-0016 Sur. Loc. 980'SNL. 216qvVEL, Sec. 33, T11N, R14E. UM Btmnhole Loc. 5065~NSL. 2335'WEL. Sec. 28, T11N. R14E. UM Dear Mr. Smith: Enclosed is the approved revised application for permit to rcdrill the above referenced well. The provisions of the original approved permit dated February 5. 1998, are in effect for this revision. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section W/o encl STATE OF ALASKA ALASKA ~___. AND GAS CONSERVATION COIV,~.-,-,~SSlON PERMIT TO DRILL 20 AAC 25.005 REVISED.' 07/10/98 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator !5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 63' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028309 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 980' SNL, 216' WEL, SEC. 33, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 2625' NSL, 2064' WEL, SEC. 28, T11N, R14E, UM 07-10A At total depth 9. Approximate spud date Amount $200,000.00 5065' NSL, 2335' WEL, SEC. 28, T11N, R14E, UM 07/16/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028306, 215'I 07-15A, 251' away at 11762' 2560 13419' MD / 8993' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9450' MD Maximum HoleAngle 90.85° Maximum surface 3037 psig, At total depth (TVD) 8800'/3917 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-Mod 4400' 9290' 8400' 13419' 8993' 500 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Alaska 0il & 6as Cons. C0rrlm~ Total depth: measured 10250 feet Plugs (measured) Tagged,tt~g~l tail fish at 10027' (07/15/97) true vertical 9193 feet Effective depth: measured 10048 feet Junk (measured) true vertical 9033 feet Casing Length Size Cemented M D TVD Structural Conductor 81' 20" 271 sx Arctic Set 109' 109' Surface 2642' 13-3/8" 5000 sx AS II, 200 sx AS II Top Job 2706' 2706' Intermediate Production 10176' 9-5/8" 1200 sx Class 'G', 300 sx Arctic Set I 10240' 9185' Liner 5186' 7" 420 sx TLW, 82 sx Class 'G' 4992' - 10178' 4979' - 9136' Perforation depth: measured 9801' - 9806', 9910' - 9920', 9960' - 9974', 10006' - 10014', 10023' - 10052' true vertical 8840' - 8844', 8925' - 8933', 8964' - 8975', 9000' - 9006', 9013' - 9036' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20,&AC 25.050 Requirements Contact Engineer Name/Number: Bob Kaluza, 564-5344 Prepared By Name/Number: Torrid Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge SignedJames Sm~ ~'~ Title Engineering Supervisor Date ~//~¢/~' Commission Use Only Permit Number I APl Number I Approval Date See cover letter 98-0016I 50-029-20335-01I 02/05/98 for other requirements Conditions of Approval: Samples Required []Yes ~,No Mud Log Required []Yes J~No Hydrogen Sulfide Measures [~,Yes []No Directional Survey Required ~[.Yes []No Required Working Pressure for DOPE []2M; []3M; ~L~M; [] 10M; [] 15M Other: Original blLjI ~.-. by order of Approved By David W. J0hnsrn, Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate [Well-Name: ]7- 10A Well Plan Summary I Type of Well (producer or injector): I Producer I Surface Location: 4299' FSL, 216' FEL, Sec. 33, T11N, R14E Start Target Location: Intermediate Location Bottom Hole Location: X = 675,979.55 Y = 5,949,939.31 2625' FSL, 2064' FEL, Sec. 28, T1 iN, R14E X = 674,040.00 Y = 5,953,502.00 Z=8,965'TVDss 3723' FSL, 2196' FEL, Sec. 28, TI IN, R14E X = 673,880.00 Y = 5,954,596.00 Z = 8,950' TVDss 5065' FSL, 2335' FEL, Sec. 28, TI IN, R14E X = 673,707.00 Y = 5,955,934.00 Z= 8,930' TVDss I AFE Number: 14J0357 IEstimated Start Date: ] 07/16/98 [MD I 13,419 I I TVDrkb: IWell Design (conventional, slim hole, etc.): I Rig: I Doyon #14 IOperating days to complete: 24 18,993' I I KBE: 163' Extended Horizontal Sidetrack Objective: Restore wellbore integrity, maximize stand-off from gas & improve areal drainage. Formation Markers Formation Tops MD TVD(RKB) TSAD Begin Sidetrack 9450 8579 Mill thru 7" & 9 5/8" csg into Z4B Z4A 9581 8663 Build incl. at 12°/100, Z3 9671 8703 Build incl. at 6°/100, for Z2C 9924 8775 Holding Inclination at 74° Z2B 10,215 8853 Holding at 74° Z2A 10,627 8963 Holding at 74°, start Z1 10,817 9013 Reach horizontal at +10,950' MD, 9028' TVDrkb TD in Z1 13,419 8,993 Inverted Tail Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD]TVD MD/TVD O.D. 6" 4 V2" csg 12.6# L-80 IBTmo 4,400' 9290'/8,400' 13419¥8993' inside 7" 4 V2" tbg 12.6# L-80 IBT 9,260' 30'/30' 9,290'/8,400' & 9 5/8" mod Logging Program: Open Hole Logs: Drilling section: MWD dir/GR from KOP (9,450' MD) thru build section. Add 4 phase resistivity thru the entire horizontal section. Sample catchers and rig site geologist from KOP to TD. Horizontal section: DPC logs (Platform Express) after reaching horizontal. MAD passes in the horizontal section. Mud Program: Special design considerations Drill from KOP to TD with Quickdriln Polymer system. The formulation of the brine phase will be 6% KCL. Density LSRV LSRV Viscosity Chlorides pH (ppg) (cps) yield point funnel 8.7 35-55,000 12-20 50-65 30,000 8.5-9.0 to to to to to to 8.9 35-55,000 12-20 50-65 30,000 8.5-9.0 If difficulty sliding, treat system with 1%-2 % Lubetex by volume. Ensure good stocks of LCM on location. Directional: . ~ _l KOP: 1) 9450'MD into ZAB, build at 12°/100' from 43° incline to 70° holding 338°azimuth, then build 6°/100, thru Z3 to 75° incline to the base of Z2. Build to horizontal at 12°/100, and turn to 354° azimuth landing in Z1. Hold azimuth to TD at 13,419' invert tail slightly from 9028' TVDrkb to 8993' TVDrkb at TD. KO & Max Hole Angle: Close Approach Well: KOP at 43°, 90.85° in Z1 production section. Closest well 7-15A, 251' planned separation at 11,762' MD. Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments P&A of original well 74/15.8/1.15 "G" at 15.8 ppg 500/15.7/1.19 4 1/2" Liner from 9,290' to 13,419'MD Class "G", 50% of excess in open hole Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Bottom hole pressure is 3,917 psi at 8,800' TVDss (estimated) Maximum shut-in casing pressure is 3,037 psi (assumes 0.1 psi/ft gas gradient to surface). NO ANNULAR INJECTION IN THIS WELL. Disposal: All cuttings will be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. Drilling Discussion ..... Well Objective Well 7-10 was drilled in February, 1979. Initial production was over 8000 bopd until the GOR began to rise in 1982. The well produced mainly from a 29' interval in Zone 1B/2A that was hydraulically fractured in 1990. Well 7-10 was shut in July 1996 due to high GOR. Additionally, current conventional completions are sub-optimal for recoveryu of Zone 1 reserves. Drilling the new sidetrack will initially target a 3,150' horizontal section at the base in Zone 1 and then new perforations will be added to Zone 2 in the build section of the well targeted for 1999. Well 7-10A has a drainage area of 90 acres. An effective net-light-oil column of 78' is prognosed for the proposed horizontal sidetrack in the Romeo interval. An additional 58' of effective net-light-oil column in Zone 2 will be targeted in 1999. Anticipated average initial rate is 1600 bopd. Adding Zone 2 perforations in 1999 forecasts an increase rate by 1700 bopd. Drilling Objective The objective is to cut and pull the existing 3 ½" completion tubing above the top 3 ½" x 7" FB-1 pkr @ 9,641' MD, mill a window by whipstock through the existing 7" scab liner and 9 5/8' csg. @ 9,450' MD, directionally drill 6" hole out of the window into Z4B to the first horizontal section target. Approximately 3,150' of 6" hole will be drilled horizontally in the deepest producible sands of lower Zone 1 above HO/T beginning approximately 1100' NNE of the current well 7-10 bottom hole location. The new well will be cased and cemented with a continuous 4 ½" L-80 liner. Perforating will be done via pipe conveyed guns prior to running the 4 ½" production tubing. Cement isolation is critical in the build section, especially through Zone 2, due to oil lenses that will require future additional perforations for recovery. Three (3) GLM's will be run in the 4 Va" production string. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There are no wells which need to be shut in during the rig move. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on Sperry Sun directional well plan. The closest separation is 251' on well 7-15A at 11,762' MD. HOLE PROBLEMS No faults observed or mapped within 250' of the proposed wellbore. Only minor faults with mapped throws of less than 10' are observed within 700' of the planned wellbore. This well will be kicked off and drilled entirely in the Sadlerochit formation where no unexpected hole problems should be encountered. PORE PRESSURE: The expected pore pressure in the Ivishak reservoir is 3917 psi at 8800'TVDss (8.5 ppg EMW). The planned mud weight of 8.7 to 8.9 ppg will provide sufficient overbalance to the reservoir pressure. Surface Casing Shoe Kick Tolerance The smallest kick tolerance for the casing shoe is calculated as 27.5 bbls of influx assuming a swabbed gas influx in Zone 4 along the planned directional path. Based on 8.7 ppg MW (Z4 at 9,450' MD, 8,579' TVDrkb, 7.8 ppg reservoir pore pressure) and min. frac at the window 12.0 ppg. SUMMARY PROCEDURE Pre-Rig Work: RU slickline and drift 3 ½" tbg.. If cannot get to XN nipple + 9,964', notify Operations Drilling Engineer (ODE). 2. Perform CMIT on tbg. IA/OA to 3,000 psi. Report these results to the ODE. P & A open perforations. Open perforations at 9,801'-9,806' and 10,023-10,052 MD. Perform P&A to 100' below bottom perforation interval, bullhead 15 bbl (74 sx) 15.8 ppg, 1.15 ft3/sx, Class 'G', cement displaced by 84.5 bbl of seawater. Cement top MUST NOT be above 9641' MD (minimum per AOGCC = 9,701' or 100' above uppermost open perforations). Tag and test cement plugback, test cement plug to 3,000 psi. Contact AOGCC representative to witness test. Notify ODE if plug does not test. 4. RU electric line and make a chemical tubing cut in the first full joint above production packer (cut at + 9,616' MD). Circulate well to seawater through the cut if the cement plugback tests to 3,000 psi. Freeze protect to + 2,200' MD (the cement plug needs to t~t, the freeze protect fluid may cause an ineffective overbalance). Note: use a double anchor chemical cutter, the 3 ½" tubing is plastic coated. 5. Pressure test the 9 5/8" packoff. Carefully cycle LDS. 6. Set a BPV in preparation of the rig sidetrack. Rig Sidetrack Procedure 1. MIRU. ND Tree. NU and test BOPE. Circulate well to clean 8.5 ppg seawater. 2. Pull the existing 3 1/2" tubing. Tubing cut at + 9,616' MD. 3. RIH w/GR/JB to PBTD. RIH w/CCL/EZSV, set EZSV + 9,460' 4. Test 7" x 9 5/8" csg against EZSV to 3,000 psi. 5. RIH w/Whipstock/mill/MWD assy. Orient and set Whipstock. Displace wellbore to Baroid Quickdriln mud. 6. Mill window through 7" x 9 5/8" casing as per SSD recommended practices. 7. PU 6" bit, Iow speed motor, MWD/GR, directionally drill as per directional plan to bit exhaustion. Condition hole. POOH. 8. RIH with DPC Platform Express. 9. MU 6" bit, Iow speed motor, MWD/GR/4 phase resistivity, directionally drill to TD + 13,419 MD. 10. Run, cement and test 4 1/2" liner. Cement liner via 4 1/~,, x 2 7/8" inner string job. 11. Test liner to 3,000 psi for 30 min. 12. RIH with DPC perforating assy. Perf. as per geologist requirements. 13. Complete well with 4 1/2" L-80 tbg, (3) GLM's and 7" Baker production packer. Test same. 14. Set BPV. ND BOPE. NU Tree and test. Pull BPV. Freeze protect. Set BPV and test. 15. Release rig. Well 7 ". Zone 2/1B Producer FO @2359' FO @ 2486' @2,213' 13 3/8", 72#, N-80 BT(; 5/8", 47#, N-80, BTC 10,240' I Top of 7" scab liner @ 4,992' MD Depth 2~13' 9641' 9644' 9790' 9884' 9887' 9964' 9975' 9976' 9973' L)nglnal ~,u t"LbV = Pad Elevation = 27.7' Hanger type: Gray Gen II Spud date: 02-02-79 Completion: 04-24-90 Max Hole Angle: 420, 9300' Jewelry Description 3 1/2' AVA TRSV SSSV ID=2.812' 7" x 3 1/2" Baker FB-1 Packer 3 1/2" Seal Bore Extension 3 1/2" Carbide Blast Jt. ID=2.992' 7" x 3 1/2" Baker FB-1 Packer 3 1/2" Seal Bore Extension 3 1/2" Otis XN Nipple ID=2.75' 3 1/2" Baker Shearout Sub 3 1/2" Tubing Tail ELM Tubing Tail Jt. @ 9,790' Z2ped, 4 spf, 9801-9806' Gas Lift Information MD 'I'VD Type 2899' 2899' O-20R 5/16" 4507' 4507' RD 5692' 5596' RD 6985' 6610' RD 8067' 7514' RD 8803' 8093' RD 9499' 8611' RKED 9741' 8794' RD 9831' 8863' RD Port Z2/1 B perf, 4 spf, 10,023-10,052' 8700' SS = 9702' MD 8800' SS = 9831' MD Datum PBTD = 10,137' MD TD = 10,240' MD Date Revised by Jan. 8, '98 Kaluza Comments Ultraslim Sadlerochit Sidetrack APl#: 50-029-20335-00 ARCO Alaska Inc. · o Well '7-10A, Hori.. 3ntal Producer, I FO ~.2.359' FO ~ 2486' SSSV @2,200~ l<13 3/8" ,72#, N-80 BTC ~__.2.706' 9 5/8", 47#, N-80, BTC (i~ 10,240' 4 1/2", 12.6#, L-80, IBT-Mod @ 13,690' 4 1/2" x I 1/2" GLM 4 1/2" x I 1/2" GLM Top of 7" scab liner (i~ 4,992' MD 4 1/2" x 1" GLM set (~ 9,178' MD Original KB ELEV = 64' Pad Elevation = 27.7' Hanger type: Gray Gen !I XN nipple 9248' 7" prod. pkr (i~ 9,218' MD -- 4 1/2" x 7" hgr pkr (i~ 9,290' MD --Top of window ~ 9,440' MD TZ4 Whipstock set (~ 9460' Whipstock Blast Jt. (i~ 9,790' TZ1 B Z2 perf, 4 spf, 9801-9806' TD (~ 13,419' MD Z2/1B perf, 4 spf, 10,023-10,052' Date Revised by I Comments Jan. 8, ' 98 Kaluza Ultraslim Sadlerochit Sidetrack Prudhoe Bay Unit Well: 7-10A APl#: 50-029-20335-01 Sec. 33, T11N, R14E ~narea ~ervlces Llrllllrlg Well' 07-10A Wp6 Scale: linch = 50Oft -3~00 Eastings -2~00 -2(~00 -t~00 4 1/2' Liner tal13419.29 i3419.29ft MD, 8993.00ft TVD 899 O Z- I Off EBS O040.1~ tK 8916.25 ,L'~, I DrillQuesf Proposal Target Summary Target Name: TVDss: TVDd~: Wclll~.ad Offsc~: Glob~! Coordinates: 07-10A BI-IS 89~5.009028,00 3607.06 N, 1855.73 W 5953502.00 N, 674040.00 E 07-10A Im 8950.009013.00 4704.50 N, 1~.11 W 5954596.00 N, 673880.00 E 07-10A EHS 8930.008993.00 604~.18 N, 2131.78 W 5955934.00 N, 673707.00 E SURFACE LOCATION Hortz~nl~ ~: ~4e;~,31 N, 67SeT~J6 E RK, Eteva~on: 63.00.~'30R27'70R W~Fl~.~ PLOT DATE: 09-Jul-98 Dir, Sail @ 90.849°: 12070.01ft MD, 9013.00ft TVD Dir @ 12.000°/100ft: 12062.01ft MD, 9013.11ft TVD ~OZ,08 ~, lSd. Y8 Dir, Sail @ 90.777°: 10964.27ft MD, 9028.O0ft TVD Dir @ 12.000°/100ft: 10782.02ft MD, 9004.57ft 'I'VD Propcmal Data for 7-10A Wp6 Well · V,~~: O~ ~.~ E I I I -3000 -2500 -2000 Scale: linch = 500ft I -1500 Eastings Sail @=74.482°: 9765.16ft MD, 8732.52ft TVD . . Decrease @ 6.000°/10Oft: 9671.24ft MD, 8703.00ft' : Start Dir @ 12.000°/100ft: 9450.00ft MD, 8579.30ft ' -1000 I -500 0 Reference is True North Sharea ',Services Drilling Well' 07-10A Wp6 I DrHIQuest',l Proposal Data for 7-10A Wp6 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ft North Refermnce: Tree North vDOgleg sevedty: Degrees per 100ft e~cal Sectlo~ Azirnu1~: 348.370° Vertical Sectio~ Descrll~3n:Well Vertical SecUon Origin: 0.00 N,0.O0 E Measured Incr, Azim. VeflJcal Northiog$ Eaattnga Vertical Dogleg Depth Depth . Section Rate 9450.00 42.468 342.248 857930 2269.57 N 1354.75 W 2496.08 9671.24 68.869 338.783 8703.00 '2439.95 N 1415.96 W 267530 12.000 9765.16 74.482 338.255 8732.52 2522.88 N 1448.60 W 2763.11 6.000 10782.02 74.482 338.255 9004.5'7 3432.95 N 1811.58 W 3727.67 0.000 10964.27 90.777 353.016 9028.00 3607.06 N 1855.73 W 3907.11 12.000 10964.27 90.777 353.016 9028.00 3607.07 lq 1855.73 W 3907.11 12.000 12062.01 90.777 353.016 9013.11 4696.56 lq 1989.20 W 5001.14 0.000 12070.01 90.849 353.972 9013.00 4704.50 N 1990.11W 5009.11 12.000 13419.29 90.849 353.972 8993.00 6046.18 N 2131.78 W 6351.80 0.000 Proposal Target Summary Target Name: TVDss: TVDrkb: Wellhead Offsets: Global Coordinates: 8965.00 8950.00 8930.00 07° 10A B HS 9028.00 07-10A Int 9013.00 07- l 0A EHS 8993.00 3607.06 N, 1855.73 W 4704.50 N, 1990.11 W 6046.18 N, 2131.78 W 5953502.00 N, 674040.00 E 5954596.00 lq, 673880.00 E 5955934.00 N, 673707.00 E SURFACE LOCATION Horizontal Coordinate~: 5949939.31 N, 675979.55 E RKB Elevation: 35.30 tt Well (~") 27.7o ft R~(E /Coordinate Sy~m: NADP? Alarm. Stat~ Planes, Zone 4. US Foot PLOT DATE- 09-Jul-98 Checked By: ~ Approved By: &~6750 - -- -- ~ it ~ .~. O?-tO/tBItS 07-tO~ttnt e_ 9028.00 I~ , 90t3~0 I~ $995~0 ~ 13419.29 MD J 9250 3807.001g. t88~.73 IF 470,1~qOlg. t990.11 IF 604~.18~.2131.78 IF 8993.00 TVD "'l I I I I I I I 2500 3000 3500 4000 4500 5000 5500 6000 Scale: linch = 500ft ° Vertical Section Section Azimuth: 348.370' (True North) Prudhoe Bay Unit Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9450.00 42.468 342.248 8516.30 8579.30 9500.00 48.425 341.238 8551.37 8614.37 9581.44 58.143 339.935 8600.00 8663.00 9600.00 60.358 339.678 8609.49 8672.49 9671.24 68.869 338.783 8640.00 8703.00 9700.00 70.588 338.618 8649.96 8712.96 9765.16 74.482 338.255 8669.52 8732.52 9800.00 74.482 338.255 8678.84 8741.84 9900.00 74.482 338.255 8705.59 8768.59 9923.95 74.482 338.255 8712.00 8775.00 10000.00 74.482 338.255 8732.35 8795.35 10100.00 74.482 338,255 8759.10 8822.10 10200.00 74.482 338.255 8785.86 8848.86 10215.49 74.482 338.255 8790.00 8853.00 10300.00 74.482 338.255 8812.61 8875.61 10400.00 74.482 338.255 8839.37 8902.37 10500.00 74.482 338.255 8866.12 8929.12 10600.00 74.482 338.255 8892.87 8955.87 10626.64 74.482 338.255 8900.00 8963.00 10700.00 74,482 338.255 8919.63 8982.63 10782.02 74,482 338.255 8941,57 9004.57 10800,00 76,061 339.776 8946.14 9009.14 10816.90 77.554 341.186 8950.00 9013.00 10900.00 84,982 347.923 8962.62 9025.62 10964,27 90.777 353.016 8965.00 9028.00 Sperry-Sun Drilling Services Proposal Report for 07-10A D14 - 7-10A Wp6 Local Co. ordinates Northings (ft) Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (fi) (fi) (fi) (°/100fi) (fi) 2269.57 N 1354.75W 2303.38 N 1365.92W 2364.87 N 1387.64W 2379.83 N 1393.14W 2439.95 N 1415.96W 2465.08 N 1425.76W 2522.88 N 1448.60W 2554.06 N 1461.04W 2648.56 N 1496.73W 2664.99 N 1505.28W 2733.05 N 1532.43W 2822.55 N 1568.13W 2912.05 N 1603.82W 2925.91N 1609.35W 3001.55 N 1639.52W 3091.05 N 1675.22W 3180.55 N 1710.91W 3270.05 N 1746.61W 3293.88 N 1756.12W 3359.54 N 1782.31W 3432.95 N 1811.58W 3449.19 N 1817.81 W 3464.69 N 1823.31W 3543.77 N 1845,11W 3607.06 N 1855.73W 5952176.58 N 674572.11E 2496.08 5952210.13 N 674560.15 E 12.000 2531.45 5952271.09 N 674537.00 E 12.000 2596.05 5952285.92 N 674531.15 E 12.000 2611.82 5952345.49 N 674506.93 E 12.000 2675.30 5952370.39 N 674496.55 E 6,000 2701.89 5952427.63 N 674472.36 E 6.000, 2763.11 5952458.51 N 674459.20 E 0.000 2796.15 5952547.15 N 674421.42 E 0.000 2891.01 5952568.38 N 674412.37 E 0.000 2913.73 5952635.79 N 674383.64 E 0.000 2985.87 5952724.43 N 674345.86 E 0.000 3080.73 5952813.07 N 674308.08 E 0.000 3175.58 5952826.80 N 674302.23 E 0.000 3190.27 5952901.71N 674270.30 E 0.000 3270.44 5952990.35 N 674232.53 E 0.000 3365.30 5953078.99 N 674194.75 E 0.000 3460.15 5953167.63 N 674156.97 E 0.000 3555.01 5953191.24 N 674146.90 E 0.000 3580.28 5953256.27 N 674119.19 E 0.000 3649.87 5953328.97 N 674088,20 E 0.000 3727.67 5953345.05 N 674081.60 E 12.000 3744.83 5953360.43 N 674075.74 E 12.000 3761.12 5953438.98 N 674052.10 E 12.000 3842.98 5953502.00 N 674040.00 E 12.000 3907.11 Alaska State Plane Zone 4 PBU_EOA DS O7 Comment KOP: Start Dir @ 12.000°/100ft: 9450.00ft MD, 8579.30ft TVD Z4A (xray) Dir Rate Decrease @ 6.000°/100fi: 9671.24ft MD, 8703.00ft TVD Z3 End Dir, Sail @ 74.482°: 9765.16ft MD, 8732.52ft 'I'VD Z2C Z2B Z2A Start Dir @ 12,000°/100ft: 10782.02ft MD, 9004.57ft'T'VD Z~ End Dir Sail @ 90.777°: 10964.27ft MD 9028.00ft TVD Target: ~)7-10A BHS, Geological ' Continued... 8 July, 1998- 16:29 - I - DrillQuest Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (") (") (~) 11000.00 90.777 353.016 8964.52 9027.52 11100.00 90.777 353.016 8963.16 9026.16 11200.00 90.777 353.016 8961.80 9024.80 11300.00 90.777 353.016 8960.45 9023.45 11400.00 90.777 353.016 8959.09 9022.09 11500.00 90.777 353.016 8957.73 9020.73 11600.00 90.777 353.016 8956.38 9019.38 11700.00 90,777 353.016 8955.02 9018.02 11800.00 90.777 353.016 8953,67 9016.67 11900.00 90.777 353.016 8952.31 9015,31 12000.00 90.777 353.016 8950.95 9013.95 12062.01 90.777 353.016 8950.11 9013.11 12070.01 90,849 353.972 8950.00 9013.00 12100.00 90.849 353,972 8949.56 9012.56 12200.00 90.849 353.972 8948.07 9011.07 12300.00 90.849 353,972 8946.59 9009.59 12400.00 90.849 353,972 8945.11 9008.11 12500.00 90.849 353,972 8943.63 9006.63 12600.00 90.849 353,972 8942.14 9005.14 12700.00 90.849 353,972 8940.66 9003.66 12800.00 90.849 353.972 8939.18 9002.18 12900.00 90.849 353.972 8937.70 9000.70 13000.00 90.849 353.972 8936.22 8999.22 13100.00 90,849 353.972 8934.73 8997.73 13200.00 90.849 353.972 8933.25 8996.25 13300.00 90.849 353,972 8931.77 8994.77 13400.00 90,849 353.972 8930.29 8993.29 13419.29 90.849 353.972 8930.00 8993.00 Sperry-Sun Drilling Services Proposal Report for 07-10A D14 - 7-10A Wp6 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (~) (~) (") 3642.53 N 1860.07W 5953537.35 N 674034.83 E 3741.78 N 1872.23W 5953636.29 N 674020.35 E 3841.03 N 1834.39W 5953735.23 N 674005.88 E 3940.27 N 1896.55W 5953834.17 N 673991.40 E 4039.52 N 1908.71W 5953933.10 N 673976.92 E 4138.77 N 1920.87W 5954032.04 N 673962.45 E 4238.02 N 1933.02W 5954130.96 N 673947.97 E 4337.27 N 1945.18W 5954229.92 N 673933.50 E 4436.52 N 1957.34W 5954328,85 N 673919.02 E 4535.77 N 1969.50W 5954427.79 N 673904.54 E 4635.02 N 1981.66W 5954526.73 N 673890.07 E 4696.56 N 1989.20W 5954588.08 N 673881.09 E 4704.50 N 1990.11W 5954596.00 N 673880.00 E 4734.33 N 1993.26W 5954625.74 N 673876.15 E 4833.76 N 2003.75W 5954724.91 N 673863.33 E 4933.20 N 2014.25W 5954824.07 N 673850.51 E 5032.64 N 2024.75W 5954923,23 N 673837.69 E 5132.07 N 2035.25W 5955022.40 N 673824.87 E 5231.51 N 2045.75W 5955121.56 N 673812.05 E 5330.95 N 2056.25W 5955220.72 N 673799.22 E 5430.38 N 2066.75W 5955319.89 N 673786,40 E 5529.82 N 2077.25W 5955419.05 N 673773.58 E 5629.25 N 2087.75W 5955518.22 N 673760.76 E 5728.69 N 2098,25W 5955617.38 N 673747.94 E 5828.13 N 2108.75W 5955716.54 N 673735,12 E 5927.56 N 2119.25W 5955815.71N 673722.30 E 6027.00 N 2129,75W 5955914.87 N 673709.47 E 6046.18 N 2131.78W 5955934.00 N 673707.00 E Dogleg Vertical Rate Section (°/~OOft) (ft) 0.001 3942.72 0.000 4042.38 0.000 4142.04 0.000 4241.71 0.000 4341.37 0.000 4441.03 0.000 4540.69 0.000 4640.36 0.000 4740.02 0.000 4839.68 0.000 4939.34 0.000 5001.14 12.000 5009.11 0.000 5038.95 0.000 5138.47 0.000 5237.98 0.000 5337.49 0.000 5437.00 0.000 5536.51 0.000 5636.02 0.000 5735.53 0.000 5835.04 0.000 5934.56 · 0.000 6034.07 0.000 6133.58 0.000 6233.09 0.000 6332.60 0.000 6351.80 Alaska Sta~,:e Plane Zone- 4 PBU_EOA DS, 07 Comment Start Dir @ 12.000°/100ft: 12062.01ft MD, 9013,1 lft TVD End DIr Sail'@ 90,849°: 12070.01ft MD, 9013.00ff TVD Target: ~37-10A Int, Drillers Total Depth: 13419.29ft MD, 8993.00fl TVD 4 1/2" Liher Target: 07-10A EHS, Geological Con#nuee2... 8 July, 1998 - 16:29 - 2 - DrillQ,Juest Sperry- , n Drilling Services Proposal Report for 07-10A D14 - 7-10A Wp6 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 07 Measured Vertical Depth Incl. Azim. Depth Northings Eastings (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (ft) (°/100ft) 9450.00 42.468 342.248 8579.30 2269.57 N 1354.75W 9671.24 68.869 338.783 8703.00 2439.95 N 1415.96W 9765.16 74.462 338.255 8732.52 2522.88 N 1448.60W 10782.02 74.482 338.255 9004.57 3432.95 N 1811.58W 10964.27 90.777 353.016 9028.00 3607.06 N 1855.73W 12062.01 90.777 353.016 9013.11 4696.56 N 1989.20W 12070.01 90.849 353.972 9013.00 4704.50 N 1990.11W 13419.29 90.849 353.972 8993.00 6046.18 N 2131.78W 2496.08 2675.30 12.000 2763.11 6.000 3727.67 0.000 3907.11 12.000 5001.14 0.000 5009.11 12.000 6351.80 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 348.370° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13419.29ft., The Bottom Hole Displacement is 6410.99ff., in the Direction of 340.578° (True). Comments Measured Station Coordinates Depth TVD Northlngs Eastings (~) (~) (~) (~) 9450.00 8579.30 2269.57 N 1354.75W 9671.24 8703.00 2439.95 N 1415.96W 9765.16 8732.52 2522.88 N 1448.60W 10782.02 9004.57 3432.95 N 1811.58W 10816.90 9013.00 3464.69 N 1823.31W 10964.27 9028.00 3607.07 N 1855.73W 12062.01 9013.11 4696.56 N 1989.20W 12070.01 9013.00 4704.51 N 1990.11W Comment KOP: Star1 Dir @ 12.000°/100ft: 9450.00ft MD, 8579.30ft TVD Dir Rate Decrease @ 6.000°/100ft: 9671.24ft MD, 8703.00ft TVD End Dir, Sail @ 74.482°: 9765.16ft MD, 8732.52ft TVD Starl Dir @ 12.000°/100ft: 10782.02ft MD, 9004.57ft TVD Z1A End Dir, Sail @ 90.777°: 10964.27fl MD, 9028.00ft TVD Start Dir @ 12.000°/100ft: 12062.01ft MD. 9013.1 lft TVD End Dir, Sail @ 90.849°: 12070.01ft MD, 9013.00tt TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northlngs (~) (~) (~) (~) 9581.44 8663.00 8600.00 2364.87 N 9671.24 8703.00. 8640.00 2439.95 N 9923.95 8775.00 8712.00 2664.99 N 10215.49 8853.00 8790.00 2925.91 N 10626.64 8963.00 8900.00 3293.88 N Eastings Formation Name (fi) 1387.64W Z4A (xray) 1415.96W Z3 1505.28W Z2C 1609.35W Z2B 1756.12W Z2A Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Sudace> To Measured Vertical Depth Depth (ft) (ft) <Run-TD> <Run-TD> Casing Detail 4 1/2' Liner Targets associated with this wellpath Target Name 07-10A BHS 07-10A DrillPoly 07-10A EHS 07-10^ Int 7-10A Polygon T a r g e t TVD (fi) 9028.00 9028.00 8993.00 9013.00 9075.80 Entry Coordinates Northlngs Eastings Target (fi) (ft) Shape 3607.06 N 1855.73 W Point 6065.65 N 2023.09 W Polygon 6046.18 N 2131.78 W Point 4704.50 N 1990.11 W Point 3620.74 N 1414.29 W Polygon Target Type Geological Geological Geological Ddllers Geological 8 July, 1998- 16:32 .1 - DrillQuest TONY KNOWLE$, GOVEF~NOB ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Fcbmarv 5, 1998 o James Smith Enginccring Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Rc~ Prudhoc Bay Unit 07- I 0A ARCO Alaska. Inc. Permit No. 98-0016 Sur. Loc. 980'SNL, 216'WEL. Sec. 33, T11N, R14E. UM Btmnholc Loc. 4354'NSL, 3383'WEL, Sec. 28. T11N. R14E, UM Dcar Mr. Smith' Encloscd is thc approved application for permit to rcdrill thc above referenced well. Thc pcrmit to rcdrill docs not cxcmpt you from obtaining additional permits rcquircd by law from other govcrnmcntal agcncics, and docs not authorize conducting drilling operations until all other rcquircd pcrmitting dctcrminations arc made. Bloxvout prevention cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25 035· Sufficicnt noticc (approximately 24 hours) must bc givcn to allow a rcprcscntative of thc Commission to witncss a tcst of BOPE installed prior to drilling new hole. Notice max,' be given by coniC o~m field inspcctor on th cNorth S lo pc pagcr at 659-3607. · CC Chairman BY ORDER OF THE COMMISSION dlf/Enclosurcs CC; Department of Fish & Game, Habitat Section w/o cncl. Dcpartmcnt of Environmental Conservation w/o cncl. STATE OF ALASKA AL; .... KA OIL AND GAS CONSERVATIOi~COMMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test .~ Development Oil []Re-Entry I--]DeepenI ElService I--I Development Gas [-I Single Zone //"[--I Multiple Zone 2. Name of\Operator 5. Datum Elevation (D,F or KB) 10. Field anti Pool ARCO Al ka Inc Plan KBE 61 50 · ~k . · Prudh(;~ Bay Field / Prudhoe 3 Address %. 6. Property Designation R~v 'P.O. Box 19b~2, Anchorage, Alaska 99519-6612 ADL 028309 ~' --'/--' 4. Location of well,akk.surface 7. Unit or Property Name 11. Ty)0e Bond (See 20 AAC 25.025) 980' SNL, 216 ..V~.L~ SEC. 33, T11 N, R14E, UM Prudhoe Bay Unit At top, of productive, in"t~rval 8. Well Number umbe.r II_~qn~. n 2697 NSL, 1574' WEL'%.SEC. 28, T11N, R14E, UM 07-10A /~umber U-63(,,. Attot,al depth ~ 9. Approximate spud date / Amount $200,000.00 4354 NSL, 3383' WEL, SEC,,. 28, T11N, R14E, UM 02/21/98 12. Distance to nearest property line1',1,3. Distance to nearest well 14. Number of acres ~n property/'15. Proposed depth (MD and TVD) ADL 028306, 926' I "% 07-28A, 968' away at12966' 2560 ,/ 13690' MD/9351'TVD 16. To be completed for deviated well~,,, o 17. Anticipated pressure {see CAAC 25.035 (e) (2)} , Kick Off Depth 9450' Max11~um Hole Angle 44 Maximum surface 3037 ,p'sig, At total depth (TVD) 8800 / 3917 psig 118. Casing Program ..... .%, Setting Depth / Size ~pecmcauo~ Top BotCm Quantity of Cement Hole Casing Weight Grade Couplih, g.. Length MD TVD MD / TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-Mod~x, 4400' 9290' 8400' 13690/ 9017' 514 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operatio"~. / ~ Present well condition summary % / , Total depth: measured 10250 feet Plugs (meas'N~ed) /T/agged cut tubing tail fish at 10027 (07/15/97) true vertical 9193 feet "%, ~ Effective depth: measured 10048 feet Junk (measured~)( true vertical 9033 feet / _~ Casing Length Size / Cb~ented MD TVD Structural / Conductor 81' 20" ,, 271 sx ~(rctic Set ~ 109' 109' Surface 2642' 13-3/8 5000 ~¢( AS II, 200 sx A~ II Top Job 2706' 2706' Intermediate ,, / ~ , Production 1017.6,' 9-5~8 120~ sx Class 'G', 300 sx A(ctic Set I 1,0240' , 9~85 Liner 5186 7 42/0 sx TLW, 82 sx Class 'G'~ 4992 - 10178 4979 - 9136' / ~ 10023' 10052' i ECE!VE Perforation depth: measured 9801'-9806', 991079920', 9960'-9974', 10006'- 10014';x~o(. -,i ~N 2_, 19q8 true vertical 8840' - 8844', 892¢ ~', 9000' - 9006', 9013~- 9036' / %, Alaska 0ii & ¢~,,s 00nS. Corn 20. Attachments [] Filing Fee [] Pr°Pevrty e~t¢ath Pict [] ~eOfrPacS~oetnCAh nal' 'sis [] ~ieV:~t:c~ RSke~etoCrth 2 AAC 25.050 e uirements ~'1~rilling Pr°gramR Al%h°rag8 [] Drilling Fluid Program []Time S/¢epthPIot [] Refraction Analysis []Seab~d_Rep.o_rt _[-12'1~ . q' Contact Engineer Name/Number: Bob Kaluza, 564-5344 / ...... Prepared By Name/Number: T~e((ie Hubble, 564-4628 21 I hereby ce~ify that the foreo~ing is true and ~orrect to the best of my knowledge ~ . ' Sit, ned {-[ ~' ~/ ' o Jar~s~'~;~f'j ~--~',, ~f~---- / Title Engineering Supervisor Date l) Commission Use Only P rr it I ^PI / I ^ rova I oov; I tt r ~/~ - co / f~ I 50-029-203/35-01 I ~ -__,~"'" ~' ~ I for other r~luirements Conditions of Approval: Samples Requi~'ed []Yes [~-No Mud Log Required []Yes [~.No~ Hydrogen Sul de Measures Yes [~ Directional Survey Required I~Yes I--]No Req u i red We ~iidn.~P_r.e_s...~ r~,fp r B O P E E]No []2M; []3M; J~M; []10M; []15M 0rigYna~ Other: O~[~d \,El. O0h~qS'f.0!'l by order of Approved By Commissioner the commission Datec;~/--~,',~ -/~,,¢~ D Form 10-401 Rev. 12-01-85 Submit In Triplic ~;~,,o.? I oo~,~ VENDOR Ai .AS½AST 14 OO DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 121797 CKi21797D 100.00 100.00 PYMT COMMENTS: accompang permit to d~ill application HANDLINO INSl: s/h kathg campoano~, x5i22 &TT&CHF:I3 CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. · FIELD & POOL_ ADMINISTRATION WELL PERMIT CHECKLIST COMPANY R DA]'E ,~ 12 ' r 1s. INIT CLASS -- ENGINEERING AP .P I~_..~ D~I-E GEOLOGY WELL NAME '~ '~ ~k_ ~ "l GEOL AREA 1. Permit fee attached ..................... 2. Lease number appropriate ................... 3. Unique well name and number .................. ~N 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... r~(_.]N' 6. Well located proper distance from other wells .......... ~ N 7. Sufficient acreage available in drilling unit ....... '(,,~ N 8 If deviated, is wellbore plat included ...... ~ N 9. Operator only affected party ......... f,2¢) N 10. Operator has appropriate bond in force ............ (~ N 11. Permit can be issued without conservation order ...... ~) N Permit can be issued without administrative approval (~. N Carl permit be approved before 15-day wait .......... 'O N Conductor string provided .................. Y N -% Surface casing protects all known USDWs ........... Y N CMT vol adequate to circulate on conductor & surf csg ..... Y N CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... PROGRAM: exp [] dev,~redrll ¢ serv [] wellbore seg [ ann. disposal para req I', UNIT# ) I ~ ~'~.~ ON/OFF SHORE__ ,¢, I/q_ A~',,~ DAT, E 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Adequate tankage or reserve pit ................. (~N If a re-drill, has a 10-403 for abandonmen! been approved... Y Adequate wellbore separation proposed ............. (~ N If diverter required, does it meet regulations ........ Y N Drilling fluid program schematic & equip list adequate .... ~ N BOPEs, do they meet regulation ................ (~ N BOPE press rating appropriate; test to :~r....~ psig.~N Choke manifold complies w/APl RP-53 (May 84) ........ N Work will occur without operation shutdown .......... N Is presence of H.~S gas probable ................. (~ N 30. Permit can be issued w/o hydrogen sulfide ~ Y N 31 Data presented on potential overpr~~ones .... Y N 32. Seismic anal~,zone, s ............. Y N 33. Seabed co~~urvey (if off-shore) ............ Y N 34. name/phone for we.eklyprogress repqrts ....... Y N lexploratory on~yj REMARKS GEOL. RPC ENGINEERING COMMISSION' g E~ 2~.~/~ DWJ ~ JDH ~ RNC ~ co Comments/Instructions: · WELL PERMIT CHECKLIST FIELD & POOL COMPANY //"~_.. ~, INIT CLASS L'.~,~/' WELL NAME//PZ~---,/'. p'-'/"C:~.,,'~ PROGRAM: exp [] dev/~redrll~serv [] wellbore segll ann. disposal para reqll /-,~,, '/ GEOL AREA _g::~/;::,::::::~ UNIT# r//~ ON/OFF SHORE ~ ~ ADMINISTRATION DA/TEl 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate we,bore separation proposed ............. 23. If diveder required, does it meet regulations .......... ~ ~~' 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ...... ,~,._~ ..... ~ .N 26. BOPE press rating appropriate; test to ~c.z,,~.,, psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... YY 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. , 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports ..... .~ Y N [exploratory only] APPR DATE ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: RPC~~ BEW~,.;~-~ WM Dw..F'"~-~ ~ JDPr _~ ~,/.~r'~ RNC ' ~' co ~;~/- '"' Comments/Instructions: M:chet~list rev 05~29~98 dlf: C :\n~soffice\wordian\diana\cl ~(;cklis, t Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this . nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 07-10A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292033501 REFERENCE NO : 98419 LIS Tape Verifi'~c~kion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~ .... PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 6 ORIGIN : FLIC REEL NAME : 98419 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., DS 7-10A, PRUDHOE BAY, #50-029-20335-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 6 ORIGIN : FLIC TAPE NAME : 98419 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : ARCO ALASKA, INC., DS 7-10A, PRUDHOE BAY, #50-029-20335-01 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: RUN1 98419 D.KIRKBY TOM SIMONS TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) F~ELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING D.S. 07-10A 500292033501 ARCO Alaska, Inc. SCHLUNiBERGER WELL SERVICES 6-NOV-98 RUN 2 RUN 3 33 liN 14E 98O 216 64. O0 64. O0 27.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 9428.0 LIS Tape Verifi~c~ion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~-t 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE OPEN HOLE PEX/BHC DATA ACQUIRED ON ARCO ALASKA, INC. WELL D.S. 07-10A ON 3-AUG-98. THIS DATA HAS BEEN DEPTH CORRECTED TO SPERRY SUN'S ~IERGED MWD GAMMA RAY W/LAST RUN DATED 9-AUG-98. *NOTE: HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE BCS CNT SDN $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 11798.0 9428.0 11813.0 9428.0 11828.0 9428.0 BASELINE DEPTH 88888.0 11649.5 11626.0 11609.0 11528.5 11516.0 11439.5 11429.5 11412.0 11406.0 11387.5 11223.5 11202.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BCS CNT SDN 88887.5 11649.0 11625.5 11609.5 11528.5 11517.0 11438.5 11428.0 11411.5 11405.0 11386.5 11223.5 11201.5 LIS Tape Verifi¢.~tion Listing Schlumberger Alaska Computing Center 11121.0 11077.5 11066.5 11055.5 11043.5 11032.5 11022.0 10987.0 10966.0 10916.5 10909.0 10901.5 10879.5 10866.0 10832.5 10819 5 10817 5 10765 5 10760 5 10749 5 10744 0 10669.0 10650.5 10613.5 10599.0 10577.0 10500.5 10357.5 10346.5 10337.5 10324.0 10317.0 10312.5 10307.0 10260.5 10250.5 10234 0 10231 5 10220 5 10203 0 10180 0 10131 0 10113 0 10056 0 10038 5 10031.5 10019.5 9990.5 9928.0 9904.5 9882.5 9837.0 9796.0 9781.5 9772.0 11120.0 11078.0 11066.0 11054 5 11043 5 11032 5 11022 0 10986 0 10965 5 10917 5 10909.5 10902.0 10880.0 10866.0 10832.5 10818.5 10817.5 10764.5 10761.0 10749.5 10744.0 10669.5 10650.5 10612.5 10598.5 10576.5 10500 5 10357 0 10345 5 10337 0 10323 0 10317 0 10313 5 10307 0 10261 0 10252 0 10235.5 10232.0 10221.0 10203.0 10181.0 10131.0 10112.5 10056.0 10038.0 10031.0 10019.0 9990.0 9927.5 9904.0 9882.0 9836.5 9796.0 9781.5 9771.5 6-NOV-1998 09:38"~ PAGE: 6-NOV-1998 09:38 ~=~ PAGE: 4 LIS Tape Verifih~tion Listing Schlumberger Alaska Computing Center 9753.0 9736.5 9719.5 9702.0 9666.0 9657.5 9644.0 9633.0 9631.0 9629.0 9611.0 9599.5 9598.0 9574.0 9566.5 9550.5 9541.5 9527 5 9519 5 9507 0 9498 0 9485 5 9469 5 9463 0 9451 0 9444 5 9439 0 9412 5 9406 5 9397 0 9393 0 9390.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: 9753.0 9736.0 9719.5 9702.0 9666.0 9657.0 9643.5 9633.0 9631.0 9628.0 9611.0 9600.5 9598.0 9574.5 9567.0 9551.0 9541.0 9527.5 9520.0 9507.5 9498.5 9485.0 9470.5 9465.0 9451.5 9443.5 9438.0 9413.5 9406.5 9395.0 9391.0 9386.0 96.0 RUN NO. PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MAIN PASS (UP LOG) ACQUIRED IN OPEN HOLE ONLY. THE DEPTH SHIFTS SHOWN ABOVEREFLECT THE UP LOG GR TO THE BASELINE GAMPIA RAY PROVIDED BY THE CLIENT (GR.MWD). ALL OTHER BCS/CNT/SDN CURVES WERE CARRIED WITH THE GR SHIFT. $ LIS FORMAT DATA LIS Tape VerifiW~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38'~~ PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1291934 GR BCS GAPI 1291934 TENS BCS LB 1291934 TEND BCS LB 1291934 MRES BCS O H~M1291934 MTE~BCS DEGF 1291934 DEV BCS DEG 1291934 CNTC CNT CPS 1291934 CFTC CNT CPS 1291934 FCNT CNT CPS 1291934 NCNT CNT CPS 1291934 CRAT CNT 1291934 NRAT CNT 1291934 NPHI CNT PU-S 1291934 CPHI CNT PU-S 1291934 DT BCS US/F 1291934 CALl SDN IN 1291934 DRHO SDN G/C3 1291934 PEF SDN BN/E 1291934 RHOB SDN G/C3 1291934 MSFL SDN 0HN~41291934 MINVSDN 0H~24 1291934 MNOR SDN 0HN~I1291934 GR MWD GAPI 1291934 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 i 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ~ 6-NOV-1998 09:38<~,l PAGE: 6 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center ** DATA ** DEPT. 14000.000 GR.BCS MRES.BCS -999.250 MTEM. BCS CFTC. CNT -999.250 FCNT. CN~f NRAT. CNT -999.250 NPHI. CNT CAL1.SDN -999.250 DRHO. SDN MSFL.SDN -999.250 MINV. SDN DEPT. 9380.000 GR.BCS ~RES.BCS -999.250 MTEM. BCS CFTC. CNT -999.250 FCNT. CNT NRAT. CNT -999.250 NPHI. CNT CAL1.SDN -999.250 DRHO.SDN MSFL.SDN -999.250 MINV. SDN -999.250 TENS.BCS -999.250 DEV. BCS -999.250 NClTT. CNT -999.250 CPHI.CNT -999.250 PEF. SDN -999.250 I4NOR.SDN -999.250 TENS.BCS -999.250 DEV. BCS -999.250 NCNT. CNT -999.250 CPHI.CNT -999.250 PEF.SDN -999.250 FINOR.SDN -999.250 TEND.BCS -999.250 CNTC. CNT -999.250 CRAT. ClTT -999.250 DT.BCS -999.250 RHOB.SDN -999.250 GR.MWD -999.250 TEND.BCS -999.250 CNTC. CNT -999.250 CRAT. CNT -999.250 DT. BCS -999.250 RHOB.SDN -999.250 GR.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH CNT 9428.0 9062.0 $ ~ 6-NOV-1998 09:38~-~ PAGE: 7 LIS Tape Verific-~f~ion Listing Schlumberger Alaska Computing Center BASELIiFE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH CAUl 88888.0 88887.5 9412.5 9413.5 9406.5 9406.5 9397.0 9395.0 9393.0 9391.0 9390.0 9386.0 100.0 96.0 $ MERGED DATA SOURCE LDWG TOOL CODE REMARKS: RUN NO. PASS NO. IVlERGE TOP MERGE BASE THIS FILE COiTTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MAIN PASS (UP LOG) ACQUIRED IN CASED HOLE ONLY. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE UP LOG GRCH TO THE BASELINE GAMMA RAY PROVIDED BY THE CLIENT (GR.MWD) . ALL OTHER CNT CURVES WERE CARRIED WITH THE GRCH SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verifi~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID oRDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 TENS BCS LB 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 TEND BCS LB 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH BCS GAPI 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S 1291934 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9428.000 TENS.BCS 14.633 TEND.BCS 1009.776 GRCH. BCS CNTC. CNT 1661.438 CFTC. CNT 616.281 FCNT. CNT 602.938 NCNT. CNT CRAT. CNT 2.687 NRAT. CNT 2.718 NPHI.CNT 31.592 CPHI. CNT DEPT. 9062.000 TENS.BCS -5.000 TEND.BCS 1293.223 GRCH. BCS CNTC. CNT 1078.167 CFTC. CNT 256.946 FCNT. CNT 283.812 NCNT. CNT CRAT. CNT 3.667 NRAT. CNT 3.922 NPHI.CNT 49.128 CPHI.CNT 30.336 1645.000 31.885 59. 991 1053. 065 56. 432 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifi~ion Listing Schlumberger A1 aska Compu ting Cent er 6-NOV-1998 09:38L~--i PAGE: 9 FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCRE~IENT: 0.5000 FILE SUFk4ARY VENDOR TOOL CODE START DEPTH BHC 11851.0 PEX 11851.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9428.0 9428.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. MEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFOP~4EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHNk4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (FIT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 3 -AUG-98 8Cl -205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL NUMBER AMS - A DSLC-B HILTB 6.000 9428.0 9428.0 QUICK DRIL-N 8.80 54.0 9.0 200.0 O. 116 82.0 O. 108 70.0 O. 121 74.0 LIS Tape Verifi~dJtion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~ i PAGE: 10 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): .5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW OPEN HOLE MAIN PASS (UP LOG) DATA PRESENTED AT O . 5 ' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 116 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verif~z~C~Jtion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38 .... PAGE: 11 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD N73M~ SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 GR BHC GAPI 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 TENS BHC LB 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 HTEN BHC LB 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 MRES BHC 0~1291934 O0 000 O0 0 3 1 1 4 68 0000000000 MTE~BHC DEGF 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 GDEV BHC DEG 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT PEX CPS 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F1291934 O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BHC US 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BHC US 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BHC US 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 HCAL PEX IN 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 RHOZ PEX G/C3 1291934 O0 000 O0 0 3 i 1 4 68 0000000000 HDRA PEX G/C3 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 PEFZ PEX 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 H~4IN PEX OH~4 1291934 O0 000 O0 0 3 1 1 4 68 0000000000 H~NO PEX OH~ 1291934 O0 000 O0 0 3 i 1 4 68 0000000000 POfOZ PEX OH~4~1291934 O0 000 O0 0 3 1 1 4 68 0000000000 RX08 PEX 0H~941291934 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11851.000 GR.BHC MRES.BHC 0.043 MTE~.BHC CFTC. PEX 1539.792 RCFT. PEX RTNR.PEX 2.043 TNPH. PEX DT.BHC 88.438 TT1.BHC TT4.BHC 367.109 HCAL.PEX PEFZ.PEX -999.250 H~IN. PEX RXO8.PEX 1.482 DEPT. 9428.000 GR.BHC MRES.BHC 0.039 MTEM. BHC CFTC.PEX 610.081 RCFT. PEX RTNR.PEX 2.669 TNPH. PEX DT.BHC 57.559 TT1.BHC TT4.BHC 251.510 HCAL.PEX PEFZ.PEX 10.000 HMIN. PEX 116.378 198 310 1446 129 21 219 549 063 3 874 1 419 31. 451 175. 421 584. 696 31. 904 374. 740 6.109 O. 101 TENS.BHC 22. 000 HTEN. BHC GDEV. BHC -999.250 CNTC. PEX RCNT. PEX 3003 . 573 TNRA. PEX NPHI.PEX 23.158 NPOR.PEX TT2. BHC 373 . 516 TT3. BHC RHOZ.PEX -999.250 BT~RA.PEX H~iNO. PEX 1.122 RXOZ. PEX TENS.BHC 15. 000 HTEN. BHC GDEV. BHC 44. 012 CNTC.PEX RCNT. PEX 1618. 053 TNRA. PEX NPHI.PEX 31.851 NPOR.PEX TT2 . BHC 264.180 TT3 . BHC RHOZ . PEX 4.629 H~RA . PEX H~NO. PEX 0.105 RXOZ. PEX -397.639 3056.070 1.990 20.944 545.313 -999.250 1.482 1009.776 1644.827 2.703 31.514 467.344 0.850 0.104 LIS Tape Verif~u~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 PAGE: 12 RXO8.PEX 0.144 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION . O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUFk4ARY FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH BHC 11851.0 9428.0 PEX 11851.0 9428.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 3-AUG-98 8Cl-205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 LIS Tape Verif~c~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~-I~ PAGE: 13 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. FLEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11815.0 1800.0 TOOL NUM~ER AMS - A DSLC-B HILTB 6.000 9428.0 9428.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): QUICK DRIL-N 8.80 54.0 9.0 200.0 O. 116 82.0 0.108 70.0 0. 121 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): .5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW OPEN HOLE MAIN PASS (UP LOG) DATA ACQUIRED AT O. 1667 ' SAMPLE RATE. $ LIS FORMAT DATA , 6-NOV-1998 09:38~~ PAGE: 14 LIS Tape Verifh~tion Listing Schlumberger Alaska Computing Center ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUPiB SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 RHOZ PEX G/C3 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HDRA PEX G/C3 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 PEFZ PEX 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HMIN PEX OH~4M1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HFINOPEX OH~4~1291934 O0 000 O0 0 4 1 1 4 68 0000000000 RXOZ PEX OH~ 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 RX08 PEX OHMM 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HCNT PEX CPS 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HCFT PEX CPS 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HGR PEX GAPI 1291934 O0 000 O0 0 4 i 1 4 68 0000000000 RHFT PEX CPS 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 RHNT PEX CPS 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HTNP PEX PU 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 HNPO PEX PU 1291934 O0 000 O0 0 4 i 1 4 68 0000000000 TT1 BHC US 1291934 O0 000 O0 0 4 i 1 4 68 0000000000 TT2 BHC US 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 TT3 BHC US 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 TT4 BHC US 1291934 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** , 6-NOV-1998 09:38~/ PAGE: 15 LIS Tape Verifhc~tion Listing Schlumberger Alaska Computing Center DEPT. 11851.000 RHOZ.PEX HMIN. PEX 1.419 H~NO.PEX HCNT. PEX 3056.070 HCFT. PEX RHNT. PEX 3003.573 HTNP. PEX TT2.BHC 373.516 TT3.BHC -999.250 I{DRA.PEX 1.122 RXOZ.PEX 1539.792 HGR.PEX 21.219 I{NPO.PEX 545.313 TT4.BHC -999.250 PEFZ.PEX 1.482 RX08. PEX 116.378 RHFT. PEX 20. 944 TT1. BHC 367.109 -999.250 1.482 1446.129 549.063 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER 5 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH BHC 11851.0 9428.0 PEX 11851.0 9428.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: 3 -AUG-98 8Cl -205 1600 3-AUG-98 LIS Tape Verif~-~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 PAGE: 16 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR): 1600 11870.0 11850.0 9100.0 11815.0 1800.0 3 -AUG-98 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. MEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS $ TOOL ~ER AMS - A DSLC-B HILTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6. 000 9428.0 9428.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) '. MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (Otff~l) AT TEMPERATURE (DEGF): MUD AT MEASURED T~MPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : QUICK DRIL-N 8.80 54.0 9.0 200.0 O. 116 82.0 0.108 70.0 0.121 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): .5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TUI~NERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW OPEN HOLE MAIN PASS (UP LOG) DATA ACQUIRED AT O. 0833 ' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Veri£~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~J' PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD N731Vl~SAMP ELE~4 CODE (HEX) DEPT FT 1291934 O0 000 O0 0 $ 1 1 4 68 0000000000 HCAL PEX IN 1291934 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11851.000 HCAL. PEX 3.874 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38 .... PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH BHC 11766.0 PEX 11766.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9428.0 9428.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. MiEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 3 -AUG-98 8Cl -205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL NUMBER DSLC-B HILTB 6.000 9428.0 9428.0 QUICK DRIL-N 8.80 LIS Tape Verifht-~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:35 PAGE: 19 MUD VISCOSITY (S) : 54.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 200.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.116 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.108 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 121 MUD CAKE AT (BHT) : 82.0 70.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 0.5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CArL AND DENSITY RAN WITH 4.5" TOOL TURIVERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOArD DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW OPEN HOLE REPEAT PASS (DOWN LOG) DATA ACQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~t PAGE: 20 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUAIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 GR BHC GAPI 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 TENS BHC LB 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 HTEN BHC LB 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 FIRES BHC OH~M1291934 O0 000 O0 0 6 1 1 4 68 0000000000 MTEMBHC DEGF 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 GDEV BHC DEG 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PEX CPS 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PEX CPS 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PEX CPS 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PEX CPS 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PEX 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PEX 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PEX PU 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PEX PU 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PEX PU 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 DT BHC US/F 1291934 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11766.000 GR.BHC 82.120 TENS.BHC 1711.000 HTEN. BHC MRES.BHC 0.038 MTEM. BHC 195.687 GDEV. BHC -999.250 CNTC. PEX CFTC. PEX 1703.403 RCFT. PEX 1558.795 RCNT.PEX 3647.698 TNRA.PEX RTNR.PEX 2.308 TNPH. PEX 22.624 NPHI.PEX 25.577 NPOR.P~ DT. BHC 88.645 -195.304 3539.648 2.144 22.473 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE . 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verif~J~Jtion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:36? .... PAGE: 21 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH BHC 11766.0 PEX 11766.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9428.0 9428.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR AUX. I~EAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (?T) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 3 -AUG-98 8Cl -205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL Nt~BER AMS - A DSLC-B HILTB 6.000 9428.0 9428.0 QUICK DRIL-N 8.80 LIS Tape Verifi'~ion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~J PAGE: 22 MUD VISCOSITY (S) : 54.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 200.0 RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): O. 116 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.108 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 121 MUD CAKE AT (BHT): 82.0 70.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THE~ SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW OPEN HOLE REPEAT PASS (DOWN LOG) DATA ACQUIRED AT 0.1667' SAMPLE R~TE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT LIS Tape VerifiL~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38-~.~ PAGE: 23 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 RHOZ PEX G/C3 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 HDRA PEX G/C3 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 PEFZ PEX 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 ~4IN PEX OH~4 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 H~4NO PEX OH~4 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 RXOZ PEX OH~4~1291934 O0 000 O0 0 7 1 1 4 68 0000000000 RX08 PEX 0~1291934 O0 000 O0 0 7 1 1 4 68 0000000000 HCNT PEX CPS 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 HCFT PEX CPS 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 HGR PEX GAPI 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 RHFT PEX CPS 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 RHNT PEX CPS 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 HTNP PEX PU 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 HNPO PEX PU 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 TT1 BHC US 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 TT2 BHC US 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 TT3 BHC US 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 TT4 BHC US 1291934 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11766.000 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX HMIN. PEX 0.110 H~iNO.PEX 0.093 RXOZ.PEX 0.117 RXO8.PEX HCNT. PEX 3593.848 HCFT. PEX 1718.826 HGR.PEX 79.262 PJqFT. PEX RHNT. PEX 3497.019 HTNP. PEX 22.819 PiNPO.PEX 22.988 TT1.BHC TT2.BHC 377.578 TT3.BHC 547.266 TT4.BHC 368.250 -999.250 0.115 1434.973 553.563 ** END OF DATA ** LIS Tape Verifi~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~ PAGE: 24 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~JW~ARY FILE HEADER FILE NUMBER 8 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH BHC 11766.0 9428.0 PEX 11766.0 9428.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. MEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS 3-AUG-98 8Cl-205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL NUMBER AMS-A DSLC-B HILTB LIS Tape Verif~-~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38,~ PAGE: 25 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 6. 000 9428.0 9428.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): QUICK DRIL-N 8.80 54.0 9.0 200.0 O. 116 82.0 O. 108 70.0 0.121 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)'. THERMAL MA TR IX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW OPEN HOLE REPEAT PASS (DOWN LOG) DATA ACQUIRED AT 0.0833' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~.~j~' PAGE: 26 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO?4~ SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 8 1 1 4 68 0000000000 HCAL PEX IN 1291934 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11766.000 HCAL.PEX 3.763 * * END OF DATA * * **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifi'=~Cion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~J PAGE: 27 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH PEX 9428.0 $ LOG HEADER DATA STOP DEPTH 9017.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. MEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): 3 -AUG-98 8Cl -205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL NUMBER AMS - A DSLC-B HILTB 6.000 9428.0 9428.0 QUICK DRIL-N 8.80 54.0 9.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~-~.. PAGE '. 28 MAXIMUM RECORDED TEMPERATURE (DEGF) : 200.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.116 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 0.108 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.121 MUD CAKE AT (BHT) : 82.0 70.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) '. THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW CASED HOLE MAIN PASS (UP LOG) DATA ACQUIRED AT . 5 ' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~ PAGE: 29 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 TENS BHC LB 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 HTENBHC LB 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 GR BHC GAPI 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC PEX CPS 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC PEX CPS 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 RCFT PEX CPS 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 RCNT PEX CPS 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 TNRA PEX 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 RTNR PEX 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 NPOR PEX PU 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 NPHI PEX PU 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 TNPH PEX PU 1291934 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 9428.000 TENS.BHC 15.000 HTEN. BHC 1009.776 GR.BHC CNTC. PEX 1644.827 CFTC. PEX 610.081 RCFT. PEX 584.696 RCNT. PEX TNRA.PEX 2.703 RTNR.PF2f 2.669 NPOR.PEX 31.514 NPHI.PEX TNPH. PEX 31.904 DEPT. 9017.000 TENS.BHC -5.000 HTEN. BHC 1293.223 GR.BHC CNTC. PEX 1050.921 CFTC. PEX 228.941 RCFT.PEX 245.102 RCNT. PEX TNRA.PEX 4.136 RTNR.PEX 4.247 NPOR.PEX 66.682 NPHI. PEX TNPH. PEX 68.473 31.451 1618.053 31.851 64.531 1050. 626 57. 713 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifi=-~Uion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~ ?J' PAGE: 30 **** FILE HEADER **** FILE NAME : EDIT . O10 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O . 1667 FILE SUM~i~gY VENDOR TOOL CODE START DEPTH PEX 9428.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: STOP DEPTH 9017.0 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. MEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): 3 -AUG-98 8Cl -205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL NUMBER AMS - A DSLC-B HILTB 6.000 9428.0 9428.0 QUICK DRIL-N 8.80 54.0 9.0 LIS Tape Verifit~ion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~.~ PAGE 31 MAXIMUM RECORDED TEMPERATURE (DEGF) : 200.0 RESISTIVITY (OH~k4) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 0.116 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 108 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.121 MUD CAKE AT (BHT) : 82.0 70.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 0.5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW CASED HOLE MAIN PASS (UP LOG) DATA ACQUIRED AT . 1667 'SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 $ 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verifih~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~ PAGE: 32 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 HCNT PEX CPS 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 HCFT PEX CPS 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 HGR PEX GAPI 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 RHFT PEX CPS 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 RHNT PEX CPS 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 HTNP PEX PU 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 HNPO PEX PU 1291934 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 9428.000 HCNT. PEX 1643.936 HCFT. PEX 610.339 HGR.PEX RHFT. PEX 535.366 RHNT. PEX 1609.337 HTNP.PEX 31.863 HlVPO.PEX DEPT. 9017.334 HCNT. PEX 1032.404 HCFT.PEX 234.467 HGR.PEX RHFT. PEX 250.169 RHNT. PEX 1032.581 HTNP.PEX 62.063 HNPO.PEX 30.412 31.663 72.231 60.380 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE ' FLIC VERSION ' O01CO1 DATE ' 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 LIS Tape Verif£c~tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 PAGE: 33 RAW CASED HOLE REPE~T PASSES Curves and log header data for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF24ARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 9428.0 8987.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED '. TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 3 -AUG-98 8Cl -205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR AUX. MEAS. SONDE AMS-A BHC BOREHOLE COMP. SONIC DSLC-B PEX PLATFORM EXPRESS HILTB $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 6.000 9428.0 9428.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TblMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : QUICK DRIL-N 8.80 54.0 9.0 200.0 0.116 82.0 0.108 70.0 0.121 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~~ PAGE: 34 TOOL STANDOFF (IN): O. 5 REMARKS: DEPTH CORRELATED TO BHC SONIC LOG ON D.S. 07-10 DATED 25-FEB-1979 1/2" STANDOFFS RAN ON SONIC CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS HIGH RESOLUTION AZMUTHAL LATEROLOG FAILED TO RESPOND DOWNHOLE. NO RESISTIVITY DATA WAS ACQUIRED. ONLY SONIC AND NEUTRON/DENSITY DATA WAS GATHERED. THIS IS THE RAW CASED HOLE REPEAT PASS (DOWN LOG) DATA ACQUIRED AT .5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1291934 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BHC LB 1291934 O0 000 00 0 11 1 1 4 68 0000000000 HTEN BHC LB 1291934 O0 000 O0 0 11 1 1 4 68 0000000000 GR BHC GAPI 1291934 O0 000 O0 0 11 1 1 4 68 0000000000 CNTC PEX CPS 1291934 O0 000 O0 0 11 1 1 4 68 0000000000 CFTC PEX CPS 1291934 O0 000 O0 0 11 1 1 4 68 0000000000 RCFT PEX CPS 1291934 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verifi'ca'tion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~J PAGE: 35 NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) RCNT PEX CPS 1291934 TNRA PEX 1291934 RTNR PEX 1291934 NPOR PEX PU 1291934 NPHI PEX PU 1291934 TNPH PEX PU 1291934 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 9428.000 CNTC. PEX 1630.425 TNRA. PEX 3.007 TNPH. PEX 34.564 DEPT. 8987.000 CNTC. PEX 1448.151 TNRA. PEX 4.392 TNPH. PEX 57.914 TENS.BHC 989. 000 HTEN. BHC 502. 466 GR.BHC CFTC. PEX 570. 410 RCFT. PEX 562.108 RCNT. PEX RTNR.PEX 3.110 NPOR.PEX 35.300 NPHI.PEX TENS.BHC 345.000 HTEN. BHC 624.460 GR.BHC CFTC. PEX 340.596 RCFT. PEX 347.403 RCNT. PEX RTNR.PEX 4.510 NPOR.PEX 56.770 NPHI.PEX 44. 464 1560. 277 39. 634 60.043 1437.511 65.014 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CASED HOLE REPEAT PASSES LIS Tape Verifx~ion Listing Schlumberger Alaska Computing Center 6-NOV-1998 09:38~./ PAGE: 36 Curves and log header data for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SUF~W3L~Y VENDOR TOOL CODE START DEPTH PEX 9428.0 $ LOG HEADER DATA STOP DEPTH 8987.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR AUX. MEAS. SONDE BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 3-AUG-98 8Cl-205 1600 3-AUG-98 1600 3-AUG-98 11870.0 11850.0 9100.0 11815.0 1800.0 TOOL NUMBER AMS-A DSLC-B HILTB 6.000 9428.0 9428.0 QUICK DRIL-N 8.80 54.0 9.0 200.0 O. 116 82.0 O. 108 70.0 0. 121 74.0 THERMAL SANDSTONE 2.65 Sperry-Sun Drilling Services LIS Scan Utility Wed Oct 28 14:05:59 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LIsTPE Date ..................... 98/10/28 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 UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MW-80297 T. MCGUIRE DAVE REID 7-10A , uV 0"% 1998 500292033501 At.~ F~j R. ~ '~'n,~ -~' ..... - SPERRY-S~ DRILLING SERVICES 28-0CT-98 MWD RUN 4 AK-MW- 80297 T. MCGUIRE D. REID MWD RUN 5 AK-MW- 80297 T. MCGUIRE DENNIS ACKER JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 5 AK-MW-80297 T. MCGUIRE DENNIS ACKER MWD RUN 6 AK-MW-80297 T. MCGUIRE DENNIS ACKER 33 liN 14E 98O MWD RUN 6 /LK-MW-80297 T. MCGUIRE DENNIS ACKER FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 216 70.60 69.10 35.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 9.625 10240.0 7.000 9428.0 13405.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. MWD RUNS 4 THROUGH 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 10272'MD, 8965'TVD. 6. TWO SEPERATE MEASUREMENT AFTER DRILLING (MAD) PASSES WERE PERFORMED AFTER MWD RUNS 5 AND 6. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13405'MD, 9050'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH THE EXTENTION "M" ARE MEASURED AFTER DRILLING. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9384 0 13362.0 ROP 9449 5 13396.5 FET 10260 0 13369.0 RPD 10260 0 13369.0 RPM 10260 0 13369.0 RPS 10260 0 13369.0 RPX 10260 0 13369.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 9348 5 9401 5 9404 5 9406 5 9408 5 9413 5 9415 5 9417 5 9419 5 9421 0 9424 5 9426 5 13403.0 $ MERGED DATA SOURCE GR 9358 5 9411 5 9413 5 9415 5 9417 0 9422 0 9423 5 9426 0 9429 0 9430 0 9432 5 9436 5 13411 0 PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 3 9460.0 10336.0 4 10336.0 11871.0 5 11871.0 13026.0 6 13026.0 13405.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OPIMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD ON_MM 4 1 68 MWD HOI/R 4 1 68 Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 9384 13396.5 ROP 5.4707 2812.5 GR 13.7097 174.495 RPX 4.3813 52.635 RPS 5.8749 66.9654 RPM 5.9061 67.1152 RPD 6.533 58.4235 FET 0.2219 55.8302 18 19 20 2 Mean 11390.2 77 6179 57 5169 15 1733 8218 3712 7103 2848 Nsam 8026 7895 7957 6219 6219 6219 6219 6219 First Reading 9384 9449.5 9384 10260 10260 10260 10260 10260 Last Reading 13396.5 13396.5 13362 13369 13369 13369 13369 13369 First Reading For Entire File .......... 9384 Last Reading For Entire File ........... 13396.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 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 ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR RAT FET $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: .5000 STA/~T DEPTH 9348 5 9348 5 9348 5 9348 5 9348 5 9348 5 9460 5 STOP DEPTH 13376.5 13376.5 13376.5 13376.5 13369.5 13403.0 13376.5 MAD RUN NO. MAD PASS NO. MERGE TOP 5 11871.0 6 13026.0 MERGED MAD PASS. $ MERGE BASE 13026.0 13405.0 Data Format Specification Record :.~ Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAdD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 9348.5 13403 11375.8 8110 R3~T 17.2931 5076.56 453.723 8110 GR 7.2996 179.34 58.4363 8042 RPX 0.0891 2000 12.4068 8057 RPS 0.0652 2000 21.2156 8057 RPM 0.0826 2000 36.6865 8057 First Reading 9348 5 9348 5 9348 5 9348 5 9348 5 9348 5 Last Reading 13403 13403 13369 13376.5 13376.5 13376.5 RPD 0.1152 2000 46.8081 8057 FET 3.9303 213.156 112.037 7833 9348.5 13376.5 9460.5 13376.5 First Reading For Entire File .......... 9348.5 Last Reading For Entire File ........... 13403 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Nun~ber ........... 1.0.0 Date of Generation ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9394.0 10271.5 ROP 9459.5 10335.5 $ LOG HEADER DATA DATE LOGGED: 30-JUL-98 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: 42.4 MAXIMUM ANGLE: 66.5 ISC 5.07 3.01E / 7.53 / 5.74 MEMORY 10336.0 9460.0 10336.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUR3LL GAMMA PROBE $ BOREHOLE AND C~%SING 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NIIMBER NGP SPC 219 6.000 6.0 QUIKDRIL-N 8.70 53.0 8.5 27000 6.2 .000 .000 .000 .000 56.3 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9394 10335.5 9864.75 1884 9394 GR 19.6463 174.495 39.3078 1756 9394 Last Reading 10335.5 10271.5 ROP 5.4707 264.174 63.3844 1753 9459.5 10335.5 First Reading For Entire File .......... 9394 Last Reading For Entire File ........... 10335.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 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 ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10263 . 5 11835 . 0 FET 10270 0 11842.0 RPD 10270 0 11842.0 RPM 10270 0 11842.0 RPS 10270 0 11842.0 RPX 10270 0 11~2.0 ROP 10330 0 11870.5 $ LOG HEADER DATA DATE LOGGED: 02-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: 3.01E / 7.53 / 5.74 DATA TYPE (MEMORY OR REkL-TIME) : MEMORY TD DRILLER (FT) : 11871.0 TOP LOG INTERVAL (FT) : 10336.0 BOTTOM LOG INTERVAL (FT) : 11871.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 70.0 91.9 TOOL NUMBER P1065GR4 P1065GR4 6.000 6.0 QUIKDRIL-N 8.70 54.0 8.5 28000 6.0 .130 .060 .130 · 140 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 67.9 RPD MWD 4 OH]MM 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 2O 24 28 Name Min Max Mean Nsam DEPT 10263.5 11870.5 11067 3215 GR 13.7097 166.856 52.7379 3144 RPX 4.3813 52.635 14.533 3145 RPS 7.3052 66.9654 18.0974 3145 RPM 7.9407 67.1152 18.885 3145 RPD 9.3818 58.4235 20.5894 3145 ROP 10.9091 935.156 86.1147 3082 FET 0.2219 23.9986 1.76608 3145 First Reading 10263.5 10263.5 10270 10270 10270 10270 10330 10270 Last Reading 11870.5 11835 11842 11842 11842 11842 11870.5 11842 First Reading For Entire File .......... 10263.5 Last Reading For Entire File ........... 11870.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 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 ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11813.5 FET 11815.0 RPD 11815.0 STOP DEPTH 12991.5 12998.5 12998.5 RPM 11815.0 RPS 11815.0 RPX 11815.0 ROP 11870.0 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12998.5 12998.5 12998.5 13025.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3kTURE MIlD AT MEASURED TEMPEP~ATURE (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 ..... 0 (DEGF) 06-AUG-98 ISC 5.07 3.01E / 7.53 / 5.74 MEMORY 13026.0 11871.0 13026.0 86.6 94.8 TOOL NUMBER P1065GR4 P1065GR4 6.000 6.0 QUICK DRILL-N 8.80 52.0 8.4 28000 .1 .125 .055 .110 .120 70.3 .0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 5 API 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 OHMM 4 1 68 ROP MWD 5 FT/H 4 1 68 FET MWD 5 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 11813.5 13025.5 12419.5 2425 GR 26.4206 126.303 65.9703 2357 RPX 4.4169 31.4515 16.4034 2368 RPS 6.1457 39.2911 20.5522 2368 RPM 6.9799 33.0634 20.8108 2368 RPD 9.1045 30.2771 21.8829 2368 ROP 7.0119 1938.04 64.4578 2312 FET 0.3599 56.3943 3.7247 2368 First Reading 11813.5 11813.5 11815 11815 11815 11815 11870 11815 Last Reading 13025.5 12991.5 12998.5 12998.5 12998.5 12998.5 13025.5 12998.5 First Reading For Entire File .......... 11813.5 Last Reading For Entire File ........... 13025.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 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 ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 12956.0 GR 12958.0 FET 12960.5 RPX 12960.5 RPM 12961.5 RPS 12961.5 ROP 13023.0 $ 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 INTERVA3~ (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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: STOP DEPTH 13377 5 13370 5 13377 5 13377 5 13377 5 13377 5 13404 5 08-AUG-98 ISC 5.07 3.01E / 7.53 / 5.74 MEMORY 13405.0 13026.0 13405.0 81.1 91.6 TOOL NUMBER P1065GR4 P1065GR4 6.000 6.0 QUICK DRILL-N 8.80 52.0 8.5 28800 5.6 .130 .056 · 140 .110 72.7 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service ~rder Units Size Nsam DEPT FT 4 1 GR MWD 6 API 4 1 RPX MWD 6 OHMM 4 1 RPS MWD 6 OHMM 4 1 RPM MWD 6 OHMM 4 1 RPD MWD 6 OHMM 4 1 ROP MWD 6 FT/H 4 1 FET MWD 6 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 12956 13404.5 13180.2 GR 40.9285 169.566 89.806 RPX 4.6037 42.7921 12.7013 RPS 5.8749 38.0017 15.1541 RPM 5.9061 32.2452 15.9808 RPD 6.533 31.245 16.8916 ROP 7.9131 2812.5 118.304 FET 0.3131 34.4501 6.59957 First Last Nsam Reading Reading 898 12956 13404.5 826 12958 13370.5 835 12960.5 13377.5 833 12961.5 13377.5 833 12961.5 13377.5 844 12956 13377.5 764 13023 13404.5 835 12960.5 13377.5 First Reading For Entire File .......... 12956 Last Reading For Entire File ........... 13404.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 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 ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE I~UMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 9358.5 RPM 9358 5 RPS 9358 5 RPX 9358 5 GR 9358 5 RAT 9358 5 FET 9470 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 STOP DEPTH 13011.0 13004.5 13005.0 13006.0 12987.0 13038.5 13006.0 06-AUG-98 ISC 5.07 3.01E / 7.53 / 5.74 MEMORY 13026.0 11871.0 13026.0 86.6 94.8 TOOL NUMBER P1065GR4 P1065GR4 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): REM3LRKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 QUICK DRILL-N 8.80 52.0 8.4 28000 .1 .125 .055 .110 .120 70.3 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 5 API 4 1 68 RPX MAD 5 OMMM 4 1 68 RPS MAD 5 OHMM 4 1 68 RPM MAD 5 OHMM 4 1 68 RPD MAD 5 OHMM 4 1 68 P~AT MAD 5 FT/H 4 1 68 FET MAD 5 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 9358.5 13038.5 11198.5 GR 7.2996 179.34 54.963 RPX 0.0891 2000 12.7242 Nsam 7361 7258 7296 First Reading 9358.5 9358.5 9358.5 Last Reading 13038.5 12987 13006 RPS 0.0652 2000 22.5841 7294 RPM 0.0826 2000 39.1988 7293 RPD 0.1152 2000 50.0576 7306 P~AT 17.2931 5554.69 473.379 7361 FET 3.6064 213.156 117.242 7072 9358.5 9358.5 9358.5 9358.5 9470.5 13005 13004.5 13011 13038.5 13006 First Reading For Entire File .......... 9358.5 Last Reading For Entire File ........... 13038.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12665.5 13377.5 FET 12673 . 5 13384 . 5 RPD 12673 . 5 13384 . 5 RPM 12673 . 5 13384 . 5 RPS 12673 . 5 13384 . 5 RPX 12673 . 5 13384 . 5 P~AT 12700.0 13411.0 $ LOG HEADER DATA DATE LOGGED: 08 -AUG- 98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOW-NHOLE 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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 (OR-MM) AT TEMPEP~ATURE (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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ~.0~E / 7.~ / ~.74 MEMORY 13405.0 13026.0 13405.0 81.1 91.6 TOOL NUMBER P1065GR4 P1065GR4 6.000 6.0 QUICK DRILL-N 8.80 52.0 8.5 28800 5.6 .130 .056 · 140 .110 72.7 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT GR RPX RPS RPM RPD RAT FET MAD 6 MAD 6 MAD 6 M3ID 6 MAD 6 MAD 6 MAD 6 FT 4 1 68 0 1 API 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHM34 4 1 68 20 6 FT/H 4 1 68 24 7 HOLYR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD P_AT FET Min 12665.5 31 7269 4 0278 5 2773 5 9899 6 6406 95 8035 3 9303 Max Mean Nsam 13411 13038.2 1492 173.109 80.8311 1425 35.482 10.3312 1423 37.2589 13.0715 1423 28.3676 14.448 1423 29.5459 16.7498 1423 716.65 457.359 1423 72.0597 38.9624 1423 First Last Reading Reading 12665.5 13411 12665.5 13377.5 12673.5 13384.5 12673.5 13384.5 12673.5 13384.5 12673.5 13384.5 12700 13411 12673.5 13384.5 First Reading For Entire File .......... 12665.5 Last Reading For Entire File ........... 13411 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File