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Home My WebLink About204-0427. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-06B Mill CIBP (2) Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-042 50-029-20294-02-00 10401 Conductor Surface Intermediate Liner Liner 9021 78 2661 7760 1187 1720 10281 20" 13-3/8" 9-5/8" 7" 4-1/2" 9022 28 - 106 28 - 2689 26 - 7786 7638 - 8825 8680 - 10400 28 - 106 28 - 2689 26 - 7616 7482 - 8453 8366 - 9021 10281 520 2670 4760 5410 7500 none 1530 4930 6870 7240 8430 8834 - 10305 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 23 - 8687 8460 - 9021 Structural 4-1/2" Baker S-3 , 8630 , 8295 No SSSV 8630 8295 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564 - 5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 23 - 8342 338 761 30510 26009 0 134 0 0 985 1006 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:58 am, Feb 23, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.02.20 18:35:58 - 09'00' Bo York (1248) WCB 2024-06-25 RBDMS JSB 022924 DSR-2/26/24 ACTIVITYDATE SUMMARY 1/20/2024 CTU 9 with 1.75" CT, Job Objective: Mill 2 CIBPs MIRU. MU YJ milling BHA RIH mill and push CIBP @ 9380' to 2nd CIBP @ 9583' . POOH Breakdown tools recover CIBP parts. Secure well for the night. ***Job in Progress*** 1/21/2024 CTU 9 with 1.75" CT, Job Objective: Mill 2 CIBPs MU YJ milling BHA. Remove night cap RIH to 2900' pump issues POOH laydown. Thaw frozen hardline and coil rig up MPF pump Return in the morning. ***Job in Progress*** 1/22/2024 CTU 9 with 1.75" CT, Job Objective: Mill 2 CIBPs RIH w/YJ Milling BHA, establish free spin mill w/BS not seeing any movement POOH at breakdown BS Venturi not much for returns BS pretty smooth. MU 5 blade junk RBIH Tag CIBP work for hour no stalls or footage . POOH FP coil stack down cut pipe and change packoffs. Plan to pick up new motor and BS venturi in the morning. ***Job in Progress*** 1/22/2024 (Assist coil with FL FP) TFS UNIT 3, Pumped 8 bbls 60/40 and 77 bbls Crude down FL for FP ***Job continued on 1/23/2024*** 1/23/2024 ***Job continued from 1/22/2024*** TFS UNIT 3 FL FP, Rig down and load fluid Coil in control of well upon TFS departure 1/24/2024 CTU 9 with 1.75" CT, Job Objective: Mill 2 CIBPs RIH w/ YJ 3-1/8" Venturi + 3.70" Burnshoe BHA. Knock wellhead gas down w/ 50 bbls water followed by 18 bbls 60/40. Tagged plug @ 9564' swapped coil over to water and begin milling. Not getting good motor work and unable to stall motor stacking weight. Worked burn shoe for 1.75 hrs on plug w/o any good indications. POOH to check tools. Coil swapped back to meth. Nothing retrieved in Venturi/BS and flutter cage was blown out (fingers all missing). Cutting structure of burnshoe still in good shape. Make 5-bladed Junk Mill and RBIH. Tag CIBP at 9573'. Attempt to mill plug not seeing any motorwork. After 45 mins of milling started to see motorwork. Continue trying to mill plug. After the ~ 10th stall, pulled heavy. Popped free then picked up 15' and pulled heavy and stalled. Attempt to work tools down with no luck. Freeze Protect Coil. Begin hitting down/up jar licks. Popped free after the 8th Jar lick. Pull OOH. ***Job Continued on 1/25/24 WSR*** 1/25/2024 CTU#9 1.75" CT. Job Scope: Mill CIBP's Continue Pooh with Milling BHA. Perform Weekly BOP Test. NU BOPs and stack lubricator and PT. RIH w/ YJ 2-7/8" Motor, 3-1/8" Venturi, 3.70" Burnshoe BHA. Tag at 9560'. Mill CIBP and Push to PBTD at 10281' CTMD. Appear to be at or near PBTD. Not making any further progress. Pooh. Freeze Protect Coil. Tbg Freeze Protected w/ 60/40 Meth. Rig Down CTU. ***Job Complete / SL up next to set Dream Catcher*** Daily Report of Well Operations PBU 07-06B Mill CIBP and Push to PBTD at 10281' CTMD Daily Report of Well Operations PBU 07-06B 1/29/2024 ***WELL S/I ON ARRIVAL*** (set dream catcher) RAN 4-1/2" BRUSH, 3.70 GUAGE RING BRUSH XN NIP @ 8675' MD MAKE 2 ATTEMPTS TO SET 4-1/2" DREAM-CATCHER IN XN-NIP @ 8,675' MD (see log) RAN 3.80" GAUGE RING, 4-1/2" BRUSH W/ BULL NOSE, BRUSH XN-NIP @ 8,675' MD SET 4-1/2" DREAM-CATCHER IN XN-NIP @ 8,675' MD (oal = 82" 4-1/2 g-fn, see log) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED*** The milled CIBP fish is correctly shown on the new WBS, below. -WCB Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-042 6.50-029-20294-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10401 9380 8861 8630 none 9380 , 9583 8295 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 28 - 106 28 - 106 1530 520 Surface 2661 13-3/8" 28 - 2689 28 - 2689 4930 2670 Intermediate 7760 9-5/8" 26 - 7786 26 - 7616 6870 / 8150 4760 / 5080 Liner 1187 7" 7638 - 8825 7482 - 8453 7240 5410 Perforation Depth: Measured depth: 8834 - 10305 feet True vertical depth:8460 - 9021 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 23 - 8687 23 - 8342 8630 8295Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 1720 4-1/2" 8680 - 10400 8336 - 9021 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1044056401 2220841 0 47793 338 920 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9021 Sundry Number or N/A if C.O. Exempt: n/a Junk Packer Printed and Electronic Fracture Stimulation Data 5 Set CIBP Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028309 PBU 07-06B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:08 am, Jan 19, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.17 19:01:08 -09'00' Bo York MGR20JAN2021 DSR-1/19/21 SFD 1/26/2021RBDMS HEW 1/27/2021 ACTIVITYDATE SUMMARY 12/26/2020 ...Well shut in on arrival... (AK EL - set cibp) DRIFT WITH 3.62" JUNK BASKET AND GAUGE RING TO 9,510' (target 9,583' but sat down in perfs, made past new cibp objective depth). SET 4-1/2" CIBP AT 9,380'. ***Job Complete. Well shut in on departure. DSO to POP.*** Daily Report of Well Operations PBU 07-06B D-1Zjj STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP 10 2Udq 1. Operations Performed Abandon ❑ PlugPerforations ❑ Fracture Stimulate °.q ❑ Pull Tubing ❑ Operations s Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair -Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 1 5. Permit to Drill Number: 204-042 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20294-02-00 7. Property Designation (Lease Number):ADL 028309 8. Well Name and Number: PBU 07-06B 9. Logs (List logsand submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10401 feet Plugs measured 9583 feet true vertical 9021 feet Junk measured None feet Effective Depth: measured 9583 feet Packer measured 8630 feet true vertical 8976 feet Packer true vertical 8295 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 77 20" 28-106 28-106 1530 520 Surface 2661 13-3/8" 28-2689 28-2689 4930 2670 Intermediate 7760 9-5/8" 26-7786 26-7616 6870/8150 4760/5080 Liner 1187 7" 7638-8825 7482-8453 7240 5410 Liner 1720 4-1/2" 8680-10400 8336-9021 8430 7500 Perforation Depth: Measured depth: 8834-8865 feet True vertical depth: 8460-9021 feet Tubing (size, grace, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 23-8687 23-8342 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 8630 8295 true vertical depth) No SSSV Installed 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: 392 34288 20 0 976 Subsequent to operation: 583 47508 1 0 1045 14. Attachments: (required per 20 MC 25.7025.71, &25.283) 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 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and comect to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Thompson, Ryan Contact Name: Thompson Ryan Authorized Title: Petroluem Engineer Contact Email: RYAN.THOMPSONAtip com Authorized Signature: Date: 11(0' / q Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 e "X//7 'U`i, RBDMS 0^'SEP 1 12019 Submit Original Only Daily Report of Well Operations PBU 07-06B ArTIVITVnATF ***WELL SHUT IN ON ARRIVAL*** (pre-eline) TAG TO AT9580' SLM W/ 35 x 2-7/8" DUMMY GUNS WITH 3.16" SWELL RINGS (no sample) 8/4/2019 ***WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED*** ***WELL S/I ON ARRIVAL*** LRS LOAD WELL WITH 200 BBLS CRUDE PERFORATE FROM 8834'-8865' WITH 2.875" MAXFORCE HMX, 6 SPF, 60 DEGREE PHASING. CORRELATED TO SLB MCNL LOG DATED 21 -JULY -2009. 8/20/2019 ***TURN WELL OVER TO DSO, JOB COMPLETE*** TREE= 5X7 FMC 120 L WELLHEAD =_ ACTUATOR= _ GRAY GEN2 BAKERC OKB. ELEV = —__—_ 64' REF ELEV = 65" BF. ELEV = 27.04' KOP= 5700' MaxL-= 91"a 10250' Dabxn MD= 9272' Dalian TVD = 8800' 5-6 07-06B 5-112TBGNPC, 29' 17#,13CR-80, D = 4.892" 13-3/8- CSG, 728, N-80, D = 12.347' 1 0! Minimum ID = 3.725" @ 8675' 4-1/2" HES XN NIPPLE j 1 7802' 1 IEZ DRILL SQ PKR I 9-5/8' CSG, 47#, N-80 8578' 7" LNR 29#, N-80 9253' 2-7/8' 4-1/2" TBG, 12.69, 13CR80, .0152 bpf, D = 3.958' 8687 7-12" LNR 2611, L-80,.0383 bpf, D = 6.276" 8825' l 12.6#, 13CR80, .0152 bpf,10 = 10312' 10400' SAFETY NOTES: WELL ANGLE> -70° 9630'. *" 4-112" CHROME TBG'** 295-12'X4-1/2'XO,D=4.892' HESX NP, D=3.813' GAS I FT MA KFIPR C ST MD PERFORATION SUMMARY TYPE VLV REF LOG: ON XX/XX/XX PORI pgTE ANGLE AT TOP PERF: 36° @ 8834' 3356 Note: ReiLrtn Production DB for Nstorimi perfdata SIZE SPF INTERVAL OprVSqz SHOT SQZ 2-7/8" 6 8834-8865 0 0820/19 0824/04 2-7/8" 6 9505-9517 O 03/01/14 BK 2-7/8" 6 9510-9520 O 0127/10 2-7/8" 4 9750-10020 C 08/18/04 2-7/8' 4 10080 -10305 C 08/18/04 l 12.6#, 13CR80, .0152 bpf,10 = 10312' 10400' SAFETY NOTES: WELL ANGLE> -70° 9630'. *" 4-112" CHROME TBG'** 295-12'X4-1/2'XO,D=4.892' HESX NP, D=3.813' GAS I FT MA KFIPR C ST MD ND DEV TYPE VLV LATCI-I PORI pgTE 3 3356 3356 1 MMG DOME RK 16 0824/04 2 5749 5746 11 MMG SO RK 20 0824/04 1 7799 7628 27 KBG2 DMY BK 0 08/05/04 DATE REV BY COMMENTS DATE REV BY COMMENTS 1120!/8 ORIGINAL COMPLETION 03/07/14 JCM/JMD ADPERFS (03/01114) 01107196 SDETRACK (A) 03/31/14 GC/JMD CORRECTED PERMIT# 08/19/04 JDMITLH SDETRACK )09/19/16 BWJMD SET CIBP 09/18/16) 09/01/04 JPK/rLH GLV C/O 0821/19 1 W WJMD ADPERFS (08/20/19) 02/03/10 JED/PJC PERFS 0127/10 09/10/19 I DD/JMD I ADDED OKB REF, 8 BF ELEV 09/11/13 RB/JMD TREE CIO (08/17/13) 9-5/8" X 7' BKR LNR HGR w MEBACK SLV, D = 6.276" MILLOUi WINDOW (07-06B) 7786'-7802' 8609' x--14-1/2" HES X NP, D = 3.813' 7" X 4-12" BKR S-3 PKR, D = 8654' H4-1/2" HES X NP, D = 3.813' 868T 4-12' WLEG D = 3.958' B680' 7" X 4-12" LNR TOP PKR w MEBACK SLV, D = 3.958" PRUDHOE BAY UNIT WELL: 07-068 PERMIT No: 2040420 API No: 50-029-20294-02 T11 N. R14E, 1450' FNL 8117 BP Expbra8on (Ahska) STATE OF ALASKA 0ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations I3 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well CIRe-enterSusp Well 0 Other:5Ct C i 3P 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-042 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory El AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20294-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-06B 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: RECEIVED !, Total Depth: measured 10401 feet Plugs measured 9583 feet O C T 10 2016 true vertical 9021 feet Junk measured feet Effective Depth: measured 9583 feet Packer measured 8631 feet GCC true vertical 8976 feet Packer true vertical 8295.55 feet �/ Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 77 20"94#H-40 29-107 29-107 1530 520 Surface 2668 13-3/8"72#N-80 28-2696 28-2696 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9505 9510 feet feet 9510-9517 feet 9517-9520 feet 9750-10020 feet 10080-10305 feet True vertical depth: 8936-8939 feet feet 8939-8943 feet 8943-8945 feet 9022-9025 feet 9024-9021 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: , � � NED FEC � 3 2j:?17, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 607 49719 68 300 1341 Subsequent to operation: 543 12000 16 300 1000 14.Attachments:(required per 20 AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ® Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature eoc../ Phone +1 907 564 4424 Date 10/10/16 Form 10-404 Revised 5/2015 v / ✓ Go l I Z- f i 0A-4RBDMS i-t- OCT 1 1 2016 Submit Original Only i r Q o 0 0 0 0 0 0 m I,- CO CO — O CO 0 CO I- O CC') N CC) p N V LO Lo r CO N- U O o 0 0 0 0 CD 0 L MCO N- CC) CO CO Cc) C)) c0 — N 't N- •-• V CO CO I- co I"- CO N CO I,- CO N • o) CO s- LO N CO C) CO O N CO N LC) I,- CO CA CO H V M O • oo co co co co N- N N N CA NrCO N N Ln I` CO 4.0 G� r COLO CO N- C) CA CON 1`.- CO CO CS) r- co O N co N LO N- oo co V 0 CO m 2 Q 0 a) cocorncOoovl- _~ N N N IO CO c N N ▪ 0 • M W ▪ 0. 0 Ooo oZ0? 0o °J? 0 a) ZOco Oo 9C o •� • N 0 ( N (o = N _ U O CMin (3)(.9 v t C N- CO C)) CO w N Cn N- CO W W Q Q CO W O o U U O u Ct a Z Z Z W W W W m m O D H H Z Z J OO) ZZJJI- H 0 • Packers and SSV's Attachment PBU 07-06B SW Name Type MD TVD Depscription 07-06B PACKER 7650.21 7493.14 7" Baker Packer 07-06B TBG PACKER 8630.68 8295.55 4-1/2" Baker S-3 Perm Packer 07-06B PACKER 8687.71 8342.43 4-1/2" Liner Top Packer 0 • E E k 0 k (N / 2 / \ - _ Cl) \ $ (N N: 0 - -o \ 0 c TD— w O « 0 / b_ \ 0 / / _1 0 & q 3 3 < m / a 0 fr / ƒ i § >- k o f 0 00 — ¢ E CC 0 °L / 0 § \ 0 7 ® \ ¢ \ Z 2 ® I- O CO / / J w / \ / Li/ a) 9 - co % Q- < CC % F- 2 : \Z _2 ± - < M E � �2 / 00- ° b t o, •k ) E - z o x z \ » - R � � A(0 \ W / 0 % k \ CL : « � / 9 / af ± ea >, \ �fCe ƒ a ƒ o co Lo --I . > 2 @ m R co a C ƒ 9 /ƒ w \ / � � 0 / W _ ± � > < \ $ 2 2 # 2 8 _ . 0 0 o R Z 5@ Z 2 / 2 0 / 0 2 \ / O L (1301(1- < b ¥ 2 2 II a_ - O & - 4 / Z % / R < 02 2 0 2 R / / e c < ± - O \ ® E \ , am > ± L & - L R e L - < _1 % e 2 c o I — $ O / / - / w / 0 / Z / G : O �: : k $ m O O D 3 : 5 ± < CO CO F- \ \ / n 5 * \ 0) y < "TREE= 5X7 FMC 120 L SA NOTES: WELL ANGLE>—70° 9630% ACTUATOR= GRAY 2 ACTUATOR= BAKER C 07-06 B S 4-1/2"CHROME TBG*** OKB.ELEV= 64' BF.ELEV= ? J KOP= 5700 / 29' H5-1/2"X 4-1/2"XO,D=4.892" Max Angle= 91"@10250' Datum MD= 9272' Datum ND= 8800'SS I I 2174' H4-1/2"HES X NP,D=3.813" 5-1/2"TBG-NPC,17#,13CR80,D=4.89T —j 29' lk . GAS LFT MANDRELS 13-3/8"CSG,72#,N-80,D=12.347" .1-- 2698' ST MD ND DEV TYPE VLV LATCH PORT DATE 411111111/11.1111111, 3 3356 3356 1 WAG DOME RK 16 08/24/04 2 5749 5746 11 MAG SO RK 20 08/24/04 1 7799 7628 27 KBG2 DMY BK 0 08/05/04 Minimum ID =3.725" @ 8675' 4-1/2" HES XN NIPPLE r-1 7638' H9-5/8"X7"BKRLNR HGRw/TM33ACKSLV,D=6.276" M LOUT 1 WOW (07-066) 7786'-7802' WHP8TOCK —{ 7802' EZ DRLL SQ PKR INN.......1•I WV. `OA4I.• �N 1/1.. .. 95/8"CSG,47#,N-80 H 8578' �111►1141144 , 8609' --{4-1/2"FES X NP,D=3.813" 111 111 111 11141114111. 7"LNR,29#,N-80 H 9253' 41111.1111 = = 8630' H7"X4-1/2"BKRS-3 FKR,D=3.875" 11,11114 2-7/8"LNR-CT,6.5#,L-80 —( 10123' 0 0.440, I 8654' H4-1/2"HES X NP,D=3.813" ' 8675' H4-1/2"HES XN N8',D=3.725" 4-1/2"TBG, 12.6#,13CR80,.0152 bpf,D=3.958" H 8687' li 8687' —14-1/2"WLEG D=3.958" 8680' —7'X 4-1/2"LNR TOP PKR 7-1/2"LNR,26#,L-80,.0383 bpf,D=6.276" H 8825' b. w/TACK SLV,D=3.958" PERFORATION SUI MARY I REF LOG: ON XX/XX/XX ' ANGLE AT TOP FERE 56"@9505' 9583' H4-1/2'WFD GBP(09/18/16) Note:Refer to Production DB for historical pert data SIZE SFF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 9505-9517 0 03/01/14 I 2-7/8" 6 9510-9520 0 01/27/10 ' 2-7/8" 4 9750-10020 C 08/18/04 2-7/8' 4 10080-10305 C 08/18/04 PBTD 10312' 4-1/2"LM,12.6#,L-80,.0152 bpf,D=3.958" H 104.00• ► i DATE REV BY COMuM3ITS DATE REV BY COM/ANTS FRUDHOE BAY UNIT 11/20/78 ORIGINAL COMPLETION 03/07/14 JC(WJMD ADPERFS(03/01/14) WELL: 07-068 01/07/96 SIDETRACK(A) 03/31/14 GC/JMD CORRECTED PERMIT# PB2MTNo:''2040420 08/19/04 JDM/TLH SIDETRACK(B) 09/19/16 BWJMD SET CBP(09/18/16) API Nb: 50-029-2029402 09/01/04 JPK/TLH GLV C/O SEC 33,T11N,R14E,1450'FNL&117'FD_ 02/03/10 JBYPJC PE2FS(01/27/10) 09/11/13 RB/JMD TREE C/0(08/17/13) BP Exploration(Alaska) e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d. 0 tt - 0 * ~ Well History File Identifier Organizing (done) o Two-sided 1111111111111I11111 o Rescan Needed 111111111111111I111 R,CAN \Ø' Color Items: o Greyscale Items: DIGITAL DATA ¿Diskettes, No. f o Other, NofType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: o Other:: BY: ~ Date q /17/60 151 vrtP Dale q/I cr/o~ a x 30 = it; 0 + Date q!lq/ b(, 11111111111111" 11/ Project Proofing BY: ~ 151 WlP BY: (Maria ) ;;L.0 = TOTAL PAGES Ç? (p (Count does not include cover sheet) í ¡)Á 10 151 V YfJ~ Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: ß 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: vçES ~_ Date:q/lq/D(P II 11/111111111 "III Stage 1 If NO in stage 1, page(s) discrepancies were found: YES I~ v11p NO BY: BY: Maria Date: 151 11/1/111111I11 "III Scanning is complete at this point unless rescanning is required. ReScanned 11111111111/11 ,,11/ BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA L RECEIVED. AL .:A OIL AND GAS CONSERVATION COMMI�.AON APR 0 1 Z Oi4 ` REPORT OF SUNDRY WELL OPERATIONSAO y�^�► 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other LI "C C Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ + 204-042-0 3.Address: P.O.Box 196612 Stratigraphicd Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20294-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: 4 ADL0028309 ' PBU 07-06B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured • 10401 feet Plugs measured None feet true vertical 9021.13 feet Junk measured None feet Effective Depth measured .' 8675 feet Packer measured See Attachment feet true vertical 8332.03 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 27-107 27-107 1530 520 Surface 2672 13-3/8"72#N-80 26-2698 26-2697.92 4930 2670 Intermediate None None None None None None Production 8553 9-5/8"47#N-80 25-8578 25-8252.1 6870 4760 Liner 1720 4-1/2"12.6#L-80 8680-10400 8336.12-9021.13 8430 7500 Perforation depth Measured depth 9505-9510 feet 9510-9517 feet 9517-9520 feet 9750-10020 feet 10080-10305 feet True Vertical depth 8936.33-8939.15 feet 8939.15-8943.03 feet 8943.03-8944.68 feet 9021.82-9025.07 feet 9024.37-9021.42 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): � NNEJUN hl Z014 F�BDMS MAY 14 2014 � ^ JU!� Treatment descriptions including volumes used and final pressure: LJ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 198 25298 84 0 2028 Subsequent to operation: 683 23493 117 0 1886 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil• ❑✓ Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCE 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhaysa.bp.com Printed Name Nita Su i merhays--_ / Title Data Coordinator Mr;AiiiiirAV Signat 7./Idrp,z /� , i/iy,L!/ - Phone 5644035 Date 3/31/2014 I"LF 5/2z//g- 44 1/5-z//9' Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028309 :�rnu•�✓lri.M,a' r� ,.. .vdlea.%f.r � ..• <i_� *0#4%;,,,x"/"T y / ./r,rir //47:".'44; DRIFTED TO DEVIATION @ 9,676' SLM WITH A2 7/8" DUMMY PERF GUN. 2/21/2014 ***WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** ***WELL SI ON ARRIVAL*** (ELINE ADPERF) INITIAL T/I/O =200/0/0 RIH. HEAD/ERS/UPCT/12' LOADED 2-7/8" PJO. LENGTH: 31' FN: 1.38" OD: 2.875" WEIGHT: 300# CCL STOP DEPTH: 9493.7' CCL-TOP SHOT: 11.3' INTERVAL:9505-9517' CONFIRMATION AT SURFACE. WELL LEFT SI ON DEPARTURE ***JOB COMPLETE*** 3/1/2014 FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL 0 N co r- (DNtoo • N- N CD f- C.) iy o o O O i M M N- MO �'O M co cs) m• co co co I- CO CO d) to NN to O r O co 00 CD f" O O 00 N- N M COM (v CDN c) N 00 CO CO CO N 00 QIIIIIIII N O N co CO • O) CD I. O N M M N N co N N M N M M CO N CO CO CO 4.1 CD 00 0) 0) 0000 N- I� to CO Is- C) CA 00 aOCO (D (Dto (DNCO .0 N00OOC N CO V oM ovrnvtn � N N (D1- (D (D (DNNNN C o 00N 000000 I � J 0 aa co ▪ Q o co a) a) a) n co °D U ano_ o. Z QnQ U �# ZZ MM co (/) �iXXXz � N ((D. U ONc‘i co NNNNO0M (V 000NtototLo (Dla (o O CO N CO Z O W 0U3 W W W w < 00 MOCe _I _J _J _Jpu_ ZZ z W O c E E O Z M M M M W D D D UJZZZZMWI- F- Packers and SSV's Attachment ADL0028309 SW Name Type MD TVD Depscription 07-06B PACKER 8630 8239.99 4-1/2" Baker S-3 Perm Packer 07-06B PACKER 8680 8281.12 4-1/2" Liner Top Packer TREE'= 5X7 FMC 120 L WELLHEAD= GRAY GEN2 SAFE. . ..1OTES: W ELL ANGLE>-70°(9630'. ACTUATOR= BAKER C 07-064-112"CHROME TBG`•' OKB.BEV= 64' BF.aEv= 9 29' --5--1/2"X 4-1/2"XO,D=4.892" KOP= 5700' Max Angle= 91°C11:10250", Datum au= 9272' Datum TVD= 8800'SS /V• 2174' -14-1/2"HES X NP,D=3.813' 5-1/2"TBG-NPC, 17#,13CR80,ID=4.892" - 29' GAS LFT MANDRELS ST MX) TVD D 13-3/8"CSG,72#,N-80,D=12.347" - 2698' • EV TYPE VLV LATCH FORT DATE- © 3 3356 3356 1 MMG DOME RK 16 08/24/04 2 5749 5746 11 MMG SO RK 20 08/24/04 1 7799 7628 27 KBG2 DMY BK 0 08/05/04 Minimum ID =3.725" @ 8675' 4-1/2" HES XN NIPPLE S or---{-7638' -9-5/8"X 7"BKR LNR HGR w/T1E3ACK SLV,D=6.276" FALLOUT WIDOW (07-06B) 7786'-7802' WHIPSTOCK - 7802' DRLL SO FKR F- 7827' Avffffeff . Iii11111,(!1.11 ••►`i'1'1'�nit 9-5/8"CSG,47#,N-80 H 8578' 4i111111111. ' �� 8609' H4-1/2"HES X NP,D=3.813" X1 1/111/1114 Ii/1114 7"LNR,29#,N-80J--I11114 9253' 11 11111 8630' -j T X 4-112"BKR 5 3 FKR ID=3.875' ti11114 2-7/8"LNR-CT,6.5#,L-80 -� 10123' .i 0•/ ' ■ 8654' -4-1/2"HES X NP,D=3.813' 8675' -4-1/2"HES XN NP,D=3.725" 4-112"TBG, 12.6#,13CR80,.0152 bpf,ID=3.958' - $687' l 8687' J4-1/2"WLEG ID=3.958' • 8680' -r X 4-1/2"LNR TOP PKR 7-1/2"LNR,26#,L-80,.0383 bpf,D=6.276" - 8825' w/TEBACK SLV,ID=3-958" PERFORATION SUMMARY REF LOG: ON XX/XX/XX ANGLE AT TOP F ERF:56°@ 9505' Note.Refer to A-oduction CB for historical perf data SIZE STV INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 9505-9517 0 03/01/14 2-7/8" 6 9510-9520 0 01/27/10 2-7/8" 4 9750-10020 0 08/18/04 2-7/8" 4 10080-10305 O 08/18/04 MID -1 10312' 14-1/2"LNR, 12.6#,L-80, 0152 bpf,D=3.958" - 10400' DATE REV BY COMMENTS DATE REV BY COMMENTS FR 1DHOEBAY UNIT 11/20/78 ORIGINAL COMPLETION 03/07/14 JCMJM) ADPERFS(03/01/14) WELL 07-06B 01/07/96 SIDETRACK(A) 03/31/14 GC/JM) CORRECTEDPEMIT# A3 MTNo:"2040420 08/19/04 JDMITLH SIDETRACK(B) AFI No: 50-029-20294-02 09/01/04 JFKfTLH GLV C/0 SEC 33,T11N,R14E, 1450'FM._&117'FEL 02/03/10 JEtYPJC FFRFS(01/27/10) 09/11/13 RB/JM) TREE CIO(08/17/13) BP Exploration(Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB O g 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ 8$vQ11$. CQt1NI1jSS r Performed: Alter Casin Pull Tubin Perforate New Pool Waiver Time Extension g ^ gp ^ ^ ^ Anchorage Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-en er Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^~ Exploratory ^ 204-0420 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-20294-02-00 8. Property Designation (Lease Ne`rriber) : 9. Well Name and Numbgr: \ ADLO-028309 PBU 07-06B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10401 feet Plugs (measured) None feet true vertical 9021.13 feet Junk (measured) None feet Effective Depth measured 10312 feet Packer (measured) 8630 true vertical 9021.37 feet (true vertical) 8295 Casing Length Size MD TVD Burst Collapse Structural Conductor 107 20" 94# H-40 SURFACE - 107 SURFACE - 107 1530 520 Surface 2698 13-3/8" 72# N-80 SURFACE - 2698 SURFACE - 2698 4930 2670 Intermediate 8578 9-5/8" 47# N-80 SURFACE - 8578 SURFACE - 8252 6870 4760 Production 1187 7" 26# L-80 7638 - 8825 7482 - 8453 7240 5410 Liner 2907 4-1/2" 12.6# L-80 8680 - 10400 8336 - 9021 8430 7500 Liner ~,/ Perforation depth: Measured depth: O 9750 - 10020 0 10080 - 10305 0 9510 - 9520 _ True Vertical depth: 9021.82 - 9025.07 9024.37 - 9021.42 8939.15 - 8944.68 _ _ Tubing: (size, grade, measured and true vertical depth)' 4-1/2" 12.6# 13CR80 29 - 8687 29 - 8342 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR S-3 PKR 8630 8295 12. Stimulation or cement squeeze summary: Intervals treated (measured): ((~y 1 ~~~~,, ~~ ~ ,,]] `: :; ~ U fry. is"'S.vc-1.3~~rw~ ra.. l.~ .' is W 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: 765 40287 65 1303 Subsequent to operation: 580 42401 49 1348 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL G TOR ^ WAG ^ GINJ ^ WINJ^ 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 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 2/8/2010 Form 10-404 Revd 7/2009 R~UMb FEB 11 Z01D ~'-7 ~~ ~ , /'y .r~- Submit Original Only - 'F/~~',f t~ • • 07-06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/27/2010"`*WELL SHUT IN UPON ARRIVAL"""' (E-LINE: PERFORATION) ;INITIAL T/I/O: 2280/1200/0 `' :RUN IN HOLE WITH 22' 2 7/8" TOOLSTRING 6 SPF, 60 DEGREE PERF ?GUN . E FROM 9510'-9520'. CORRELATED TO MEMORY CNL LOG DATED 21-JULY-2009 FINAL T/I/02280/1200/0 ***JOB COMPLETED**'` FLUIDS PUMPED BBLS 1 DIESEL 1 Total TREE = GRAY GEN 2 WELLHEAD°`- GRAY ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP = 5700' Max Angle = 91 @ 10250' Datum MD = 9272' Datum TV D = 8800' SS SAFETY ~: *** 4-1 i2" CHROME TBG *** ~~~0~~ 29' S-1/2" X 4-1/2" XO, ID = 4.892" (5-112" TBG-NPC, 17#, 13CR80, ID = 4.892" H 29' 13-318" CSG, 72#, N-80, ID = 12.347" 2698' Minimum ID = 3.725" @ 8675' 4-1 i2" HES XN NIPPLE `WHIPSTOCK H 7$02' EZ DRILL SQ PKR 7827' 9-5/8" CSG, 47#, N-80 ~ $578' 7" LNR, 29#, N-80~ 9253' 2-7/8" LNR - CT, 6.5#, L-80 10123 ~4-1/2" TBG, 12.6#, 13CR80, .0152 bpf, ID = 3.958" 7-1l2" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: ON XX/XX(XX ANGLE AT TOP PERF: 88 @ 9750' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 9750 - 10020 O 0$/18/04 2-718" 4 10080 - 10305 O 08/18/04 PBTD 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 8687' 8825' I 10312' I 8609' H 4-112" HES X NIP, 1D = 3.813"' 8630' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" $654' 4-1/2" HES X NIP, ID = 3.813" 8675' 4-1/2" HES XN N1P, ID = 3.725" 8687' 4-1l2" WLEG 8680' 7" X 4-1/2" LNR TOP PKR w /TIEBACK SLV, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/20/78 ORIGINAL COMPLETION 01/07/96 SIDETRACK (A) 08!19!04 JDM/TL SIDEI'RACK(B) 09/01/04 JPK/TLH GLV C/O PRUDHOE BAY UNIT WELL: 07-06B a,/-~~^ PERMIT No: ~ 'l 7~+ API No: 50-029-20294-02 SEC 34, T11 N, R14E, 3371.18' FEL & 2021.52' FNL BP 6cploration (Alaska) 74' t-14-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3356 3356 1 MMG DOME RK 16 08/24!04 2 5749 5746 11 MMG SO RK 20 08124/04 1 7799 7628 27 KBG2 DMY BK 0 08/05!04 7638' 9-5/8" X 7" BKR LNR HGR w 1TIEBACK SLV, ID = 6.276" MILLOUT WINDOW 7786' - 7802' ~~~ ~I~1~~~ Alaska Data & Consalting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 AITN: Beth Well Job # Log Description Date oai2~ios NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT ~-~ 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE ~~5~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK ~"' 07/16/09 1 1 M-06A AZCM-00034 PRODUCTION LOG j` 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (p ~ 07/21/09 1 1 02-11A AYS4-00084 LDL - j 07/20/09 1 1 W-212 B3SQ-0001 t iNJ PROFiLE W/WFL ' - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL ~ p- 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -(3C L 07/24/09 1 1 H-29A AY~Q-00027 RST ~ 05/19/09 1 03-28 B14B-00067 RST j- L•-( 07/17/09 1 1 B-27A AXBD-00029 MCNL 06/12l09 1 1 C-15A AWJI-00038 MCNL - O6/25/09 1 1 Q-04A 61JJ-00023 MCNL ' 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/08 1 1 07-O6B AWJI-00042 MCNL 07/21/09 1 1 02-33B 09AKA0149 OH MWD/LWD EDIT 06/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT 05/12/09 1 1 H-19B B2WY-00004 MCNL (REPLACEMEN~ - G 05/07/09 1 PLEA5E ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACN T0: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i • ~~ MICROFILMED. 03/01 /2008 DO NOT PLACE ~~ '~ ~~. ANY NEW MATERIAL UNDER THIS PAGE F:~I.aserFiche\C~rPgs_Inserts~Microfilm_Marker.doc lC{~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2040420 Well Name/No. PRUDHOE 8AY UNIT 07-068 Operator 8P EXPLORATION (ALASKA) INC ) 4-¿ It) t-, .1d)~tf API:e 50-029-20294-02-00 MD 10401 /' TVD 9021""- Completion Date 8/19/2004""-- Completion Status 1-01L Current Status 1-01L UIC N - REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ -- DATA INFORMATION Types Electric or Other Logs Run: DIR 1 GR 1 RES, DIR 1 GR / RES / DEN 1 NEU 1 ABI Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr /lata Digital Dataset T Med/Frmt Number Name 1 E~ D Asc Directional Survey ÁPt Directional Survey DirceJti(i1'\!1 ÛUI'W.¡· D +a,J t.t t 12783 Induction/Resistivity . vED jPt LIS Verification Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 7691 10401 9/14/2004 IIFR 7691 10401 9/14/2004 IIFR 7594 10347 Open 10/20/2004 MWD/MAD/GR/EWR4/RO P 7594 10347 Open 1 0/20/2004 MWD/MAD/GR/EWR4/RO PIDSN 12783 I 7786 10401 Open 2/22/2006 ROP DGR EWR SLD CTN plus Graphics ---~ Sample Interval Set Start Stop Sent Received Number Comments . Daily History Received? S~ Formation Tops ¡...ÆD C Lis 13563 Induction/Resistivity L.........._._ -~-_.~--- Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ ---" Chips Received? ~ Analysis Received? ~ - ~^~-- Comments: Permit to Drill 2040420 MD 10401 TVD 9021 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Well NamelNo. PRUDHOE BAY UNIT 07-06B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20294-02-00 )~ Cë;'"';O" D.t, 8/191200< Completion Status 1-01L Current Status 1-01L ~ UIC N Date: 13)~~' . . · . WELL LOG TRANS MITT AL :} 04- - tJ 4- ry 13Slß3 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Febmary 16, 2006 RE: MWD Formation Evaluation Logs 07-06B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 07-06B: LAS Data & Digital Log Images: 50-029-20294-02 1 CD Rom ~t{ì :¿ / 0,9!C(ß . . ;;<of- oc¡~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 71b. Avenue, Suite 100 Anchorage, Alaska 99501 October 12, 2004 RE: MWD Fonnation Evaluation Logs: 07-06B, AK-MW-3218817 1 LDWG formatted Disc with verification listing. )) ~) ~ ) API#: 50-029-20294-Q2 t rf-' l) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Iff I F<ECEIVED ') f.·.·.· <;'(104. , ~. L.v .;~ Gas Cons, Comrnisafon ó..ncllorage · STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1450' SNL, 117' WEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 976' SNL, 1561' EWL, SEC. 34, T11N, R14E, UM Total Depth: 113' SNL, 1146' EWL, SEC. 34, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676091 y- 5949473 Zone- ASP4 TPI: x- 677756 y- 5949986 Zone- ASP4 Total Depth: x- 677320 y- 5950839 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR I GR I RES, One Other 5. Date Comp., Susp., or Aband. 8/19/2004 6. Date Spudded 8/10/2004 7. Date T.D. Reached 8/15/2004 8. KB Elevation (ft): 55' 9. Plug Back Depth (MD+ TVD) 10312 + 9021 10. Total Depth (MD+TVD) 10401 + 9021 11. Depth where SSSV set (Nipple) 2174' MD 19. Water depth, if offshore NIA MSL CASING SIZE 20" 13-3/8" 9-518" DIR I GR I RES / DEN I NEU I ABI CASING, liNER AND CEMENTING RECORD SmlNG DEPTH MD SmlNGDEPTHTVD Top BOTtoM BOTTOM Surface 107' Surface 107' Surface 2698' Surface 2698' Surface 7786' Surface 7616' 7638' 8825' 7482' 8453' 8680' 10400' 8336' 9021' 22. Wr. PER Fr. 94# 72# 47# 26# 12.6# H-40 N-80 N-80 L-80 L-80 7" 4-1/2" 23. Perforations 0Ren to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Gun Diameter, 4 spf MD TVD MD TVD 9750' - 10020' 9022' - 9025' 10080' -10305' 9024' - 9021' 26. Date First Production: August26,2004 Date of Test Hours Tested 9/5/2004 3 Flow Tubing Casing Pressure Press. 332 1,069 PRODUCTION FOR TEST PERIOD ... CALCULATED ....... 24-HoUR RATE""" Oil -BBl 3,330 27. ~._-~_._-,'<: Form 10-407 Revised 12/2003 30" 17-1/2" 12-1/4" 8-112" 6-1/8" SIZE 4-1/2", 12.6#, 13Cr80 RECEIVED SEP 1 5 2004 1 b. ~1fI~~fla2~r: tÅ lì~$ COngo CÐmmì~.;i\tt, a DevelopmentAf§~Bgfatory o Stratigraphic 0 Service 12. Permit to Drill Number 204-042 13. API Number 50- 029-20294-02-00 14. Well Name and Number: PBU 07 -06B 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028309 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 230 sx Arcticset 6350 sx AS II 750 sx Class 'G' 247 sx Class 'G' 215 sx Class 'G' DEPTH SET (MD) 8687' PACKER SET (MD) 8630' DEPTH INTERVAL (MD) 2100' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 144 Bbls of Diesel GAs-McF 1,250 GAs-McF 9,999 W A TER-BBl 29 WATER-BBl 235 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-BBl 416 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". rëc~1i; ;·;:;~:L:;t··, NOne¡ ~~~~+ ~ ~i ORIGINAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO 81 3,003 Oil GRAVITY-API (CORR) ~;FP l' 6 ?tit"! .... \91'" G 28. -e GEOLOGIC MARKERS NAME MD TVD Sadlerochit I Zone 4B 8941' 854 7' Top CGL I Zone 3 9170' 8720' Base CGL I Zone 2C 9274' 8790' . 23SB I Zone 2B 9382' 8862' 21TS I Zone 2A 9560' 8966' Zone 1 B 10040' 9025' 29. e FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEI\/ED SEP 1 ij 2004 A!~~k~ Pil &, Gas Cans. Commis$ioo AnChUffJ~e 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubbl~~" ~ Title Technical Assistant Date OCf"/lf-.OL/ PBU 07-06B 204-042 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number DrillíngEngineer: Rob Tirpack, 564-4166 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 nR\G\NAL Submit Original Only Legal Name 07 -06 Common Name: 07-06 8/9/2004 FIT 8/12/2004 FIT 4,713 (psi) 11.91 (ppg) 4,182 (psi) 9.52 (ppg) e e Printed: 8/23/2004 9:24:49 AM 400 (psi 450 (psi 0.90 (ppg) 8.50 (ppg) 7,617.0 (ft) 8,453.0 (ft) 7,786.0 (ft) 8,825.0 (ft) e e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -06 07 -06 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 8/5/2004 8/19/2004 Spud Date: 10/13/1978 End: 8/19/2004 8/4/2004 21 :00 - 00:00 3.00 MOB N WAIT PRE Prepare for rig move - Stage camp and pit module on other side of K-pad - Bridle up, Lay down Cattle shute, Lay down derrick - Wait on security escort to move camp and mud pit module - Camp and pit ready to move at 2100 hrs 8/4/2004 8/5/2004 00:00 - 07:00 7.00 MOB N WAIT PRE Wait for security escort to move rig 07:00 - 17:00 10.00 MOB P PRE Move sub K-Pad to Drill site 7 - 13 miies 17:00 - 19:00 2.00 MOB P PRE Lay Herculite and spot sub over DS 7-6 19:00 - 00:00 5.00 MOB P PRE Close Cellar doors, Raise Derrick, Bridel down & Rig up floor - Spot Mud pits 8/6/2004 00:00 - 01 :00 1.00 RIGU P PRE Finish spotting mud pits, shop and camp 01 :00 - 02:00 1.00 RIGU P PRE Set Cutting tank and berm - Hook up service lines Accept rig at 1600 hrs 8/5/2004 - Back up rig acceptance 10 hrs due to delay in moving off of K-pad - lack of security personnel with two rigs moving at same time. 02:00 - 03:00 1.00 WHSUR P ABAN Take on Seawater in pits, Rig up lines to annulus and Tree 03:00 - 04:00 1.00 WHSUR P ABAN Rig up Drill Site Maintenance Lubricator, Pull BPV - SITP 700 psi, SICP 700 psi 04:00 - 04:30 0.50 KILL P ABAN Pre-Spud meeting with drill crew on rig floor 04:30 - 06:00 1.50 KILL P ABAN Prime pump - Test lines to 1500 psi - Circulate seawater down tubing 3 bpm 580 psi, Circulate through parted tubing at 1355', taking dry Gas returns out annulus through choke to cuttings tank - Fluid to surface at 90 bbls away - pump total 120 bbls- shut down, monitor well SITP 600, SICP 670 psi 06:00 - 06:30 0.50 KILL P ABAN Bullhead Tubing volume to bottom perf, 200 bbls at 7.5 bpm 2500 psi 06:30 - 07:00 0.50 KILL P ABAN Monitor well, ISIP 1400 psi - Pressure bled down to 650 psi, bled to 450 psi with choke 07:00 - 08:00 1.00 KILL P ABAN Circulate on choke at 2 bpm 150 psi, Taking fluid and gas returns to cuttings tank - Casing pressure decreased 450 to 220 psi 08:00 - 09:00 1.00 KILL P ABAN Monitor well, Take on seawater in pits - Pressure increased to 380 tubing, 400 casing 09:00 - 12:00 3.00 KILL P ABAN Circulate thur full open choke at 3 bpm, let gas migrate to surface - Shut down, Monitor well - SITP 30 psi, SICP 50 psi - Bled pressure to zero 12:00 - 14:00 2.00 KILL P ABAN Circulate hole volume through gas buster at 3 bpm 130 psi - No losses, No gain 14:00 - 16:00 2.00 WHSUR P ABAN Set Gray BPV with dry rod and test to 100 psi ok 16:00 - 18:00 2.00 WHSUR P ABAN Nipple down Gray 7" Tree and 135/8 x 71/16 Tubing head adapter - Install Gray blanking plug in BPV 18:00 - 21 :00 3.00 BOPSUF P ABAN Nipple up 135/8 5k Bop stack 21 :00 - 00:00 3.00 BOPSUP P ABAN Rig up & Fill stack and choke manifold with water - Test BOP, Test all valves, Blind and top pipe rams with 5 1/2" test jt to 250 low, 3500 psi high, Test hydrill250 / 2500 psi, Test Floor valves 250 / 3500 psi 8/7/2004 00:00 - 01 :30 1.50 BOPSUP P ABAN Finish testing Bop - Mr. John Crisp of AOGCC witnessed bop test 01 :30 - 02:30 1.00 BOPSUP N DPRB ABAN Attempt to pull blanking plug out of BPV - Can not 'J' into plug - Debris inside blanking plug 02:30 - 03:30 1.00 BOPSUF N DPRB ABAN Nipple down & Pick up Bop stack - Change out blanking plug, sheared pin on blanking plug trying to 'J' into plug 03:30 - 04:30 1.00 BOPSUF N DPRB ABAN Nipple up Bop stack - Test break to 250 low / 3500 psi high - Pull blanking plug Printed: 8/23/2004 9:24:56 AM e e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-06 07 -06 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 8/5/2004 Rig Release: 8/19/2004 Rig Number: Spud Date: 10/13/1978 End: 8/19/2004 8/7/2004 04:30 - 05:30 1.00 BOPSUP P ABAN Rig up Drill Site Maintenance Lubricator, Pull Gray 5" BPV through Bop stack with hydrill closed 05:30 - 06:30 1.00 PULL P ABAN With blind rams close, circulate through kill line down tubing for one hole volume at 4 bpm 200 psi - 70 bbls to fill hole 06:30 - 08:00 1.50 PULL P ABAN Spear 5 1/2" Tubing below tubing hanger, Backout lock down screws, unseat tubing hanger with 70k - Pull tubing hanger to rig floor P/U wt 50k - Lay down tubing hanger, Rig up to Lay down tubing 08:00 - 11 :30 3.50 PULL P ABAN Pooh laying down 51/2" 17# L-80 btc tubing - spooling up control liner, and removing rubber clamps - Lay down total 32 its - Tubing was parted at 1350' with pin coming out of box- Control line parted same place - Rig down tubing tong and spooling unit, Install wear bushing 11 :30 - 16:30 5.00 PULL P ABAN Rig up Schlumberger E-Line - RIH with 41/16" Chemical cutting, Cut tubing at 7,859' ELM - Cutter stuck in hole after firing - Rig up 'T' Bar and pull out of rope socket with 7k over pull - Pooh with E-Line, Rig down Schlumberger - Left +/- 30' chemical cutter tool string in hole 16:30 - 18:00 1.50 PULL P ABAN Make up Spear with 4.892" Grapple and pack-off - TIH picking up Drill pipe - Tag top of fish at 1381' dpm - engage and latch fish, Pull free at 185K, free pick up 150k 18:00 - 19:30 1.50 PULL P ABAN Circulate two bottoms up at 485 gpm 1200 psi 19:30 - 20:30 1.00 PULL P ABAN Pooh stand back drill pipe, Lay down Spear 20:30 - 23:00 2.50 PULL P ABAN Pooh laying down 5 1/2" tubing, Tubing has holes in tube - spooling control line - Lay down SSSV 23:00 - 00:00 1.00 PULL P ABAN Circulate to balance fluid while rigging down Spooling unit, - Clear rig floor 8/8/2004 00:00 - 04:30 4.50 PULL P ABAN Finish laying down 5 1/2" 17.0# L-80 btc tubing - Total 186 its + Cut off Jt. and SSSV with flow coupling - Recovered Schlumberger chemical cutter tool string in Cut jt of tubing 04:30 - 05:00 0.50 PULL P ABAN Rig down tubing tongs, Clear and clean rig floor 05:00 - 07:30 2.50 PULL P ABAN Rig up Schlumberger E-Line - RIH with 8.5 GR/JB / CCL - Tag tubing stub at 7,859' E-Line measurement - Pooh clean 07:30 - 10:30 3.00 PULL P ABAN Make up Halliburton 9 5/8 Ezsv cement retainer on E-Line - RIH and set retainer at 7,827' ELM - 4' above casing collar - Pooh, Rig down E-Line 10:30 - 11 :30 1.00 EVAL P ABAN Test 9 5/8 casing to 3500 psi for 30 minutes on chart -ok 11 :30 - 12:00 0.50 BOPSUP P ABAN Pull wear bushing 12:00 - 13:00 1.00 BOPSUPN SFAL ABAN Install Gray 135/8 test plug, Attempt to test pipe rams with 4" test it. - Test plug leaking, can not get test 13:00 - 13:30 0.50 BOPSUF P ABAN Install Wear bushing 13:30 - 19:00 5.50 PXA P ABAN Make up Halliburton Cement stinger on 4" drill pipe, TIH to Ezsv at 7,806 dpm - Rig up pump in sub and Halliburton valve on cement hose & Sting into Ezsv 19:00 - 20:30 1.50 PXA P ABAN Pre-Job safety meeting, Abandon DS7-06A perforation at 9,359 to 10,048' as follows: Pump 2 bbls fresh water, Test liner 3500, pump 13 bbls water ahead, (Injection rate 4.5 bpm 1700 psi) followed by 160 sx Class 'G' w/ .3% D167 + .06% B155 + .3% D-65, Yield 1.16 cf/sx, 33 bbls slurry mixed at 15.8 ppg on fly - Displace with 10 bbls fresh water + 68 bbls of seawater - Unsting from Ezsv - CIP at 2014 hrs 8/8/2004 - Final squeeze pressure 4 bpm 1700 psi 20:30 - 21 :00 0.50 PXA P ABAN Reverse out two drill pipe volume at 5 bpm 600 psi, +/-.5 bbls Printed: 8/23/2004 9:24:56 AM e . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-06 07-06 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 8/5/2004 Rig Release: 8/19/2004 Rig Number: Spud Date: 10/13/1978 End: 8/19/2004 8/8/2004 20:30 - 21 :00 0.50 PXA P ABAN cement reversed out 21 :00 - 22:00 1.00 PXA P ABAN Make up Top drive - Displace to 10.9 ppg LSND mud system at 11.0 bpm 1400 psi using both pumps 22:00 - 00:00 2.00 PXA P ABAN Slip and Cut drill line, Service top drive and grease crown 8/9/2004 00:00 - 03:00 3.00 PXA P ABAN Pump slug, pooh - Lay down cement stinger 03:00 - 03:30 0.50 BOPSUF P ABAN Pull wear bushing 03:30 - 04:30 1.00 BOPSUP P ABAN Test bottom, top rams 250 low / 3500 high, Test hydril 250/ 2500 with 4" test joint - ok 04:30 - 05:00 0.50 BOPSUF P ABAN Install wear buhsing 05:00 - 08:30 3.50 STWHIP P WEXIT Make up Whipstock BHA: Pick up Baker 9 5/8 window Master whipstock and 8" starter mill, 8" Lower mill & 8 1/2" Upper mill, MWD, 9 - 6 1/4" drill collars and 21 Hwt 08:30 - 11 :30 3.00 STWHIP P WEXIT TIH with whipstock on 4" drill pipe to 7,767' 11 :30 - 12:30 1.00 STWHIP P WEXIT Orient whipstock to 19 deg left of high side, Tag Ezsv at 7,810 dpm - Set anchor with 20k down wt, verify with 10k over pull - Shear off with 40k down wt. 12:30 - 20:30 8.00 STWHIP P WEXIT Mill 8 1/2" window in 9 5/8 47# casing 7,786 to 7,802' - 16' window - 8" pilot mill ended at 7,815' - Pumping 495 gpm at 1850 psi rotating at 80 to 100 rpm's with 5 -9k torque 20:30 - 21 :00 0.50 STWHIP P WEXIT Pump sweep and circulate hole clean with 525 gpm 2100 psi 21 :00 - 21 :30 0.50 STWHIP P WEXIT Test formation to 400 psi at 7617' Tvd with 10.9 ppg mud in hole 11.9 EMW - ok 21 :30 - 00:00 2.50 STWHIP P WEXIT Pump slug, Pooh for drilling BHA 8/10/2004 00:00 - 02:30 2.50 STWHIP P WEXIT Finish pooh, Lay down mills and MWD - 81/2" top milf in gauge - Clear rig floor 02:30 - 03:30 1.00 STWHIP P WEXIT Pull wear bushing, Wash out bop stack, Install wear bushing 03:30 - 05:30 2.00 STWHIP P WEXIT Make up Drilling BHA: P/U 7" Sperry drill motor set at 1.22 deg, 8 1/2" Hughes DP0912 PDC bit jetted with 5-15's, MWD/GR/Res, orient Mwd, Finish picking up steel dc & Hwt - Shallow test Mwd -ok 05:30 - 08:00 2.50 STWHIP P WEXIT TIH to 7,748', Fill pipe every 25 stands 08:00 - 08:30 0.50 STWHIP P WEXIT Orient motor tool face to 15 deg Left of high side, Slide through window with no problem - Ream under gauge hole 7,807 to bottom at 7,815' 08:30 - 21 :30 13.00 DRILL P INT1 Directional drill 7,815 to Top of Sag River formation at 8,825' - Art 6.8 hrs, Ast 1.8 hrs, Average Rop 117.4 ft/hr - Build angle 25 to 38 deg, turn well bore 85 to 91 deg - Pumping 550 gpm at 3400 psi, Rotate at 95 rpm's 6 -14k torque, Add lubricant to reduce torque, 10-12K wob - Maintain mud wt at 10.9 ppg- Lost partial returns when drilled into sag river 21 :30 - 22:30 1.00 DRILL P INT1 Circulate bottoms up, Reduce pump rate 550 to 450 gpm, Increase Rpm's 95 to 120 - losing mud to formation at rate of 240 bbls / hr . Static lost 36 bph 22:30 - 23:00 0.50 DRILL P INT1 Pooh, 8,825 to 50' below window at 7,850' - No problem - lost rate slowing to 12 bph 23:00 - 00:00 1.00 DRILL P INT1 MADD Pass 7,850 to 7,650' recorded mode at 300 ft/hr - Monitor well - Well static with no loss of mud to formation - Total mud lost to formation 315 bbls 8/11/2004 00:00 - 01 :00 1.00 DRILL P INT1 TIH slowly 7,650 to 8,775' - No Problem, Full returns 01 :00 - 02:30 1.50 DRILL P INT1 Circulate bottoms up - break Circulation slowly, Increase rate to 350 gpm, Rotate at 120 rpm - Wash to 8,820', Staying 5' off bottom while reciprocating pipe- Fluid lost to formation 12 bph - Spot liner running pill with 50 Ibs I bbl CaC03 Printed: 8/23/2004 9:24:56 AM e e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-06 07-06 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 8/5/2004 Rig Release: 8/19/2004 Rig Number: Spud Date: 10/13/1978 End: 8/19/2004 8/11/2004 02:30 - 03:00 0.50 DRILL P INT1 Drop Sperry ESS 03:00 - 04:00 1.00 DRILL P INT1 Pooh wet to 9 5/8 window - Monitor well - Static no loss - Pump slug 04:00 - 06:30 2.50 DRILL P INT1 Pooh for 7" Liner 06:30 - 10:00 3.50 DRILL P INT1 Lay down Bha, Retrieve ESS tool, flush and down load Mwd, Lay down motor and clear floor 10:00 - 10:30 0.50 CASE P INT1 Rig up Power tongs, 7" hand slips and 'YC' elevator 10:30 - 14:00 3.50 CASE P INT1 Pre-Job Safety meeting - run 28 jts 1160' 7" 26# L -80 Btc-m liner, Make up Baker 9 5/8 x 7" Liner hanger with Liner top packer and 10' tie back sleeve - Circulate liner volume 14:00 - 17:30 3.50 CASE P INT1 TIH with liner on 4" drill pipe to top of window - Full returns 17:30 - 18:00 0.50 CASE P INT1 Circulate liner volume 6 1/2 bpm 700 psi - Full returns 18:00 - 19:00 1.00 CASE P INT1 TIH open hole with 7" liner slowly to 8,800'- No problem, Make up Baker cement head 19:00 - 20:30 1.50 CEMT P INT1 Break circulate at 1 bpm, tag bottom at 8,825' - no fill - Stage pump up to 5 bpm 850 psi - Circulate bottoms up, reciprocate pipe 10 -15' strokes, Full returns 20:30 - 21 :30 1.00 CEMT P INT1 Cement drilling liner as follows: 2 bbl of fresh water, Test lines to 4500 psi, 20 bbl Mud push II mixed at 11.9 ppg followed by 247 sx Class 'G' w/ .08% B-155 + .3% D167 + .3% D65 + .2% D46 - yield 1.16 cf/sx, 51 bbls slurry mixed at 15.8 ppg on fly - 1.5 Ib/bbl of Cem net LCM added to last 15 bbls of spacer & first 15 bbls of cement, Drop wiper dart with 10 bbls of water, give to rig and displace with 10.9 ppg mud at 5 bpm 350 to 1200 psi - Bump plug to 4200 psi - Full returns, Reciprocated pipe - CIP at 2130 hrs 8/11/2004 21 :30 - 22:30 1.00 CEMT P INT1 Set liner hanger with 30k down wt. - Bled off pressure, check floats, ok - Rotate off hanger with 20 turns to right, Pressure drill pipe to 1000 psi, pull seal out of hanger and circulate 500 strokes at 11.5 bpm - Set liner top packer with 50k rotating down wt. - Circulate 1.5 bottoms up +/- 10 bbls of spacer to surface, no noticable cement - top of liner at 7,638', Bottom at 8,825' 22:30 - 00:00 1.50 CEMT P INT1 Break and Lay down cement head, Pump slug, Pooh 8/12/2004 00:00 - 02:00 2.00 CEMT P INT1 Finish pooh, lay down Baker liner running tool 02:00 - 05:00 3.00 DRILL P PROD1 Make up 6 1/8" BHA: Pick up Sperry 4 3/4" ABI motor, set motor at 1.83, M/U Hughes 6 1/8" MX18 insert bit jetted w/ 3-12's, MWD/GR/Res/Den/Neutron - Program tool and load source, 3- monel flex collars 05:00 - 06:00 1.00 DRILL P PROD1 TIH picking up 4" drill pipe from pipe shed - total 42 jts 06:00 - 08:30 2.50 DRILL P PROD1 TIH to top of 7" liner at 7,638' 08:30 - 09:30 1.00 DRILL P PROD1 Slip and cut drill line 09:30 - 10:00 0.50 DRILL P PROD1 Continue TIH, Tag top of cement at 8,707' 10:00 - 11 :00 1.00 DRILL P PROD1 Test casing to 3500 psi for 30 minutes on chart - ok 11 :00 - 13:00 2.00 DRILL P PROD1 Drlg cement and float equipment 8,707 to 8,821' - 3' above casing shoe 13:00 - 15:30 2.50 DRILL P PROD1 Displace to Flo-pro drilling fluid as follows: Pump 75 bbls fresh water + 30 bbls high vis spacer, followed by 8.5 ppg solids free Flo-pro at 250 gpm 2200 psi - Clean from under shaker and change screens 15:30 - 16:00 0.50 DRILL P PROD1 Drill Float shoe + 20' New formation to 8,845' - Pull into casing - Test formation to 450 psi at 8,453' Tvd with 8.5 ppg mud EMW 9.5 ppg - ok Printed: 8/23/2004 9:24:56 AM e e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-06 07 -06 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 8/5/2004 8/19/2004 Spud Date: 10/13/1978 End: 8/19/2004 8/12/2004 16:00 - 16:30 0.50 DRILL P PROD1 Directional drill 8,845 to 8,869' - Lost partial retruns 16:30 - 19:00 2.50 DRILL P PROD1 Monitor well - Static lost 85 bph - Mix LCM pill 19:00 - 19:30 0.50 DRILL P PROD1 Pump 97 bbls of LCM - 251bs per bbl concentration (15 ppb Mix-2 + 10 ppb CaCo3) Pump at 3.5 bpm, 1250 psi - Partial returns - Clear drill string with clean mud 19:30 - 23:00 3.50 DRILL P PROD1 Monitor well, Let LCM pill soak in, Static lost 35 bph improving to 14 bph - 68 bbl of pill soaking into formation 23:00 - 23:30 0.50 DRILL P PROD1 Hesitate squeeze 5 bbls away, pressure up to 500 psi and let bled down 23:30 - 00:00 0.50 DRILL P PROD1 Break circulation, Stage up to drilling rate - Drill ahead 8,869 to 8,875 - Slight lost of mud +/- 5 bph - Total lost to formation 314 bbls 8/13/2004 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill 8,875 to 9,591' -Art 5.98 hrs, Ast 11.15 hrs, Average Rop 41.8 ft/hr - Fluid lost to formation 10 -20 bbls / Hr - Pumping 250 gpm at 1800 psi, Rotating at 45 rpm's 4k torque - Mud wt. 8.4 ppg - Wob 20 - 25k - turn well bore 86 degrees Azimuth left to 352 degrees, Build angle from 35 to 58 degrees 8/14/2004 00:00 - 07:00 7.00 DRILL P PROD1 Continue directional drilling 9,591 to 9,683 -Art .2 hrs, Ast 4.67 hrs, Average Rop 18.9 ft/hr - Build angle and turning wellbore to left - Rop slowing down, motor stalling - lossing mud at 20 -25 bbls/ hr 07:00 - 07:30 0.50 DRILL P PROD1 Pooh to 7" casing shoe 07:30 - 09:00 1.50 DRILL P PROD1 Drop dart, open circulating sub at 8,620' - Circulate bottoms up pumping 420 gpm at 1000 psi, - monitor well - ok, pump slug, Blow down lines 09:00 - 11 :30 2.50 DRILL P PROD1 Pooh to BHA 11 :30 - 13:00 1.50 DRILL P PROD1 Pull BHA, remove source, Down load LWD, Change out MWD pulser, break bit 13:00 - 15:00 2.00 DRILL P PROD1 Make up BHA #3: Hughes 6 1/8# MX-20 insert bit jetted with 3-12's - Sperry 4 3/4" ABI motor set at 1.83, MWD/GR/RES/Den/Neu -Orient Mwd, Load source and program tool - Shallow test ok 15:00 - 18:00 3.00 DRILL P PROD1 TIH slowly to 7" shoe at 8,825', - Fill pipe every 3,000' - After fill pipe at 6,000', float not holding 18:00 - 19:00 1.00 DRILL P PROD1 Service rig & Top Drive, Inspect drawwork braks 19:00 - 19:30 0.50 DRILL N DFAL PROD1 Fill pipe and attempt to circulate, Drill string plugged, Pressure to 3000 psi, no circulation 19:30 - 23:30 4.00 DRILL N DFAL PROD1 Pooh, wet 23:30 - 00:00 0.50 DRILL N DFAL PROD1 Pull BHA, found drill cutting (sand) on top of MWD pulser - Lay down MWD tools Mud lost to formation last 24 hrs 351 bbls, Total lost to date 1111 bbls 8/15/2004 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 Continue Lay down BHA, float valve stem not closing - Pump through mud motor, ok - Check bit, ok 01 :00 - 03:00 2.00 DRILL N DFAL PROD1 Make up BHA: same bit and motor, Repair float valve, Change out Restivity tool, Orient, Load source and program tool - Shallow test mwd - ok 03:00 - 06:30 3.50 DRILL N DFAL PROD1 TIH to 7" shoe at 8,825', Fill pipe every 3,000' 06:30 - 07:00 0.50 DRILL P PROD1 Fill pipe, Pulse test Mwd, ok - Install blower hose 07:00 - 09:00 2.00 DRILL P PROD1 Tlh 8,825 to 9,560' - Wash and Ream under gauge hole 9,560 to bottom at 9,683 09:00 - 22:00 13.00 DRILL P PROD1 Directional drill 9,683 to TD at 10,401' - Art 6.93 hrs, Ast 3.34 Printed: 8/23/2004 9:24:56 AM e e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -06 07 -06 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 8/5/2004 8/19/2004 Spud Date: 10/13/1978 End: 8/19/2004 8/15/2004 09:00 - 22:00 13.00 DRILL P PROD1 hrs, Average Rop 69.9 ft/hr - At 9,780',finished building angle to 90 deg, and turning wellbore to 327 deg Azimuth - Maintain mud wt. at 8.4 ppg, Mud lost to formation 10-15 bbls / hr- Pumping 250 gpm at 1800 psi, Rotating at 55 rpm's with 4-6k torque 22:00 - 00:00 2.00 DRILL P PROD1 Pump high vis sweep and circulate 1.5 bottoms up at 280 gpm 1900 psi, Rotating at 60 rpm's - Mud lost to formation last 24 hrs, 320 bbls - Mud lost to formation todate 1431 bbls 8/16/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Pooh to 7" Casing shoe at 8,825' for wiper trip - 35k over pull at 10,010' - worked clean 01 :00 - 02:00 1.00 DRILL P PROD1 Slip and Cut drill line 02:00 - 02:30 0.50 DRILL P PROD1 Service top drive, Grease crown 02:30 - 03:00 0.50 DRILL P PROD1 TIH 8,825 to 10,380 - Break circulation and precautionary ream to bottom at 10,401' 03:00 - 05:30 2.50 DRILL P PROD1 Pump high vis sweep, Circulate 1.5 bottoms up - Spot 100 bbls of New mud with 5% Lubricants on bottom for liner running pill 05:30 - 06:30 1.00 DRILL P PROD1 Pooh to 7" Shoe at 8,825' - drop dart, open circulating sub, Pump slug, Blow down lines 06:30 - 09:00 2.50 DRILL P PROD1 Pooh stand back drill pipe 09:00 - 11 :00 2.00 DRILL P PROD1 Lay down BHA, Remove source, down load MWD, Clear rig floor 11 :00 - 11 :30 0.50 CASE P LNR2 Pre-Job Safety meeting - Rig up Power tongs, 4 1/2" elevators, Hand slips 11 :30 - 14:00 2.50 CASE P LNR2 Run 41 jts 41/2" 12.6# L-BO IBT liner 1,698' - Make up Baker 5 x 7" 'HMC' Liner hanger with 5 x7" 'ZXP' liner top packer & 6' tie back sleeve - total 1,720' liner and hanger 14:00 - 14:30 0.50 CASE P LNR2 Rig down tongs and clear floor - Circulate liner volume 14:30 - 18:00 3.50 CASE P LNR2 TIH with liner on 4" drill pipe, fill pipe every 10 stands 18:00 - 19:30 1.50 CASE P LNR2 Circulate Dp / liner volume 5 bpm 600 psi - P/U 160, S/O 155 19:30 - 20:30 1.00 CASE P LNR2 Run liner in open hole 8825 to 10,381' - no problem - Make up Baker top drive cement head 20:30 - 22:00 1.50 CEMT P LNR2 Break circulation at 2 bpm 300 psi, wash down and tag bottom at 10,401' - no fill - Increase rate to 5 bpm 700 psi, Circulate and reciprocate liner 15' stroke - Circulate bottoms up while batch mixing cement 22:00 - 23:00 1.00 CEMT P LNR2 Cement production liner as follows: 2 bbls CW 100, Test lines 4000 psi, 13 bbls CW 100 + 25 bbls Mud Push II mixed at 9.5 ppg followed by 215 sx Class 'G' w/ 2 gal/sx GasBlok + 3.0% D-176 + .15% D-800 + .3% D-65 - yield 1.20 cflsx, 46 bbls slurry batch mixed at 15.8 ppg - Wash out cement line, Drop wiper dart with 45 bbls Liner Perf pill and displace with 8.5 mud - Bump plug to 3500 psi - Good retums, Reciprocated pipe 15' stroke - CIP at 2250 hrs 8/16/2004 - Top of liner 8,680', PBTD 10,312', Shoe at 10,400' 23:00 - 00:00 1.00 CEMT P LNR2 Verify liner set with 35k down wt. - Check floats - ok - Rotate off liner with 20 right hand turns - pressure drill string to 1000 psi, Pull seal out of hanger, Circulate at 12 bpm for 30 bbls, slow pump to 1 bpm - Set liner top packer with 60k rotating down wt. - Increase pump rate to 12.5 bpm 2500 psi and circulate out excess cement, 10 -15 bbls cement to surface 8/17/2004 00:00 - 01 :30 1.50 CEMT P LNR2 Continue circulate 13.0 bpm 2500 psi until hole clean 01 :30 - 02:30 1.00 CEMT P LNR2 Displace to Seawater at 13.0 bpm 2600 psi, work pipe 02:30 - 04:30 2.00 CEMT P LNR2 Lay down Cement head, Pooh lay down 54 jts drill pipe Printed: 8/23/2004 9:24:56 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-06 07-06 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/5/2004 Rig Release: 8/19/2004 Rig Number: Spud Date: 10/13/1978 End: 8/19/2004 8/17/2004 04:30 - 06:30 2.00 CEMT P LNR2 Pooh stand back drill pipe - Lay down liner running tool 06:30 - 07:00 0.50 PERFOB P OTHCMP Test Casing 3500 psi for 30 minutes - ok 07:00 - 10:30 3.50 PERFOB P OTHCMP Pre-Job safety meeting, Rig up Floor, Pick up 601' of 2 7/8" Perf guns & blank - Pick up 35 jts 2 7/810.4# PAC drill pipe 10:30 - 13:30 3.00 PERFOB P OTHCMP TIH with gun on 4" drill pipe - Tag PBTD at 10,309' dpm - Pick up 4', position bottom shot at 10,305' dpm 13:30 - 14:00 0.50 PERFOB P OTHCMP Close Hydrill, Pressure both sides to 3000 psi, bled off pressure - Gun fired after 11 minutes - Perforate 9,750 to 10,020 and 10,080 to 10,305' with 2 7/8 HSD guns, 2906 PJ charge 4 SPF at 60 / 120 phasing 14:00 - 14:30 0.50 PERFOB P OTHCMP Pooh to 9,750' - monitor well, slight loss to formation 14:30 - 22:00 7.50 PERFOB P OTHCMP Pooh lay down drill pipe and 35 jts of 2 7/8 Pac drill pipe 22:00 - 00:00 2.00 PERFOB P OTHCMP Pre-Job safety meeting, Lay down perf guns 8/18/2004 00:00 - 01 :30 1.50 PERFOB P OTHCMP Finish laying down 2 7/8" perf guns - All shots fired - Clear and clean rig floor 01 :30 - 02:00 0.50 BOPSUF P RUNCMP Pull wear bushing 02:00 - 03:30 1.50 RUNCOMP RUNCMP Pre-Job Safety meeting - Rig up Stacked power tongs, Computer and compensator for 4 1/2" Chrome completion 03:30 - 06:00 2.50 RUNCOMP RUNCMP Make up 41/2" Tail pipe assembly & Baker 7 x 41/2" S-3 permanent packer, thread lock all connection below packer - Run 4 1/2" 12.6# 13CR Vam Top Tubing, Make up torque 4440 ft/lbs - 53 jts in hole 06:00 - 06:30 0.50 RUNCOMP RUNCMP Service Rig 06:30 - 15:00 8.50 RUNCOMP RUNCMP Continue running completion, Tag up at 8,686' - Space out and make up Gray 135/8 x 5.5" Gen II Tubing hanger with stainless steel insert 5 7/8 6TPllanding thread - Ran total 204 jts 41/2" 12.6# 13Cr80 Vam Top tubing 15:00 - 15:30 0.50 RUNCOMP RUNCMP Land tubing string & run in lock down screws - P/U 125K, S/O 115k 15:30 - 18:30 3.00 RUNCOMP RUNCMP Reverse Ci rculate 132 bbls filter seawater followed by 251 bbls filter seawater with 25 gal / 100 bbls of corrosion inhibitor displace with 180 bbls of filter seawater down to top GLM - Pumping at 3 bpm 18:30 - 19:30 1.00 RUNCOMP RUNCMP Drop 1 7/8" ball on rod & let fall to RHC seat in 'XN' nipple - Pressure tubing to 3500 psi and set packer at 8,630' - Test tubing 3500 psi for 30 minutes, Bled pressure to 1500 psi, Test annulus to 3500 psi for 30 minutes -ok, Bled tubing pressure and shear Circ valve, Bled all pressure to zero 19:30 - 21 :00 1.50 RUNCm.p RUNCMP Attempt to set Gray 5 3/16" type 'K' Bpv with dry rod, need more wt to push down, Pick up lubricator and set BPV - Test from below to 1000 psi -ok 21 :00 - 22:00 1.00 BOPSUP P RUNCMP Nipple down Bop stack and set back 22:00 - 00:00 2.00 WHSUR P RUNCMP Install BPV blanking plug, Nipple up New Gray 135/8 x 71/16 5K Tubing head adapter, Nipple up Gray 71/16 5K Tree - Test tubing hanger pack-off/ void area to 5000 psi, ok - Test tree to 5000 psi, ok 8/19/2004 00:00 - 01 :00 1.00 WHSUR P RUNCMP Rig up Drill site maintenance Lubricator, Pull blanking plug and Bpv 01 :00 - 04:00 3.00 WHSUR P RUNCMP Rig up lines and Hot oil truck, Test lines, Freeze protect by pumping 144 bbls diesel down annulus taking returns up tubing - Let Diesel 'U' tubing until balance for freeze protection to 2100' 04:00 - 05:00 1.00 WHSUR P RUNCMP Set Gray 5 3/16 type 'K' BPV, Test from below to 1000 psi Printed: 8/23/2004 9:24:56 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-06 07-06 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/5/2004 Rig Release: 8/19/2004 Rig Number: Spud Date: 10/13/1978 End: 8/19/2004 8/19/2004 05:00 - 06:00 1.00 WHSUR P RUNCMP Blow down and rig down lines, Secure well, install gauges Release rig at 0600 hrs 8/19/2004 Printed: 8/2312004 9:24:56 AM . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . 07 -Sep-04 DEFINITIVE Re: Distribution of Survey Data for Well 7-068 Deaf Deaf Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,691.00' MD 7,786.00' MD 10,401.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I cl ~~~ 'i Signed /Â·;LJ/' '·'\~'1' . ' ! ().! . i ,\;' , \, . #\ Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment(s) ?ùvl _' Ol-l Á- Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 07 07-06 - 7-06B e Job No. AKMW0003218817, Surveyed: 15 August, 2004 Survey Report 27 August, 2004 Your Ref: API 500292029402 Surface Coordinates: 5949472.56 N, 676091.08 E (700 16' 03.2007" N, 148034' 33.5980" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 - Surface Coordinates relative to Project H Reference: 949472.56 N, 176091.08 E (Grid) Surface Coordinates relative to Structure Reference: 1358.30 N, 1260.83 W (True) Kelly Bushing Elevation: 55.00ft above Mean Sea Level Kelly Bushing Elevation: 55.00ft above Project V Reference Kelly Bushing Elevation: 55.00ft above Structure Reference sp:a""""Y-SUI! DR 1 I... 1...1: N G S EAVI.c::^e S A Halliburton Company Survey Ref: svy4356 Halliburton Sperry-Sun Survey Report for P8U_EOA DS 07 - 07-06 - 7-068 Your Ref: API 500292029402 Job No. AKMW0003218817, Surveyed: 15 August, 2004 8PXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7691.00 24.500 84.500 7475.40 7530.40 255.58 N 763.20 E 5949745.93 N 676848.09 E 255.58 Tie On Point MWD Magnetic 7786.00 25.920 88.780 7561.35 7616.35 257.91 N 803.57 E 5949749.20 N 676888.40 E 2.432 257.91 Window Point 7814.52 29.000 88.580 7586.66 7641.66 258.22 N 816.72 E 5949749.81 N 676901.53 E 10.804 258.22 7846.97 30.920 88.380 7614.77 7669.77 258.65 N 832.92 E 5949750.62 N 676917.72 E 5.925 258.65 e 7875.08 32.560 88.210 7638.67 7693.67 259.09 N 847.70 E 5949751.41 N 676932.48 E 5.843 259.09 7908.78 34.840 88.040 7666.71 7721.71 259.70 N 866.38 E 5949752.46 N 676951.15 E 6.771 259.70 7939.69 36.920 87.880 7691.75 7746.75 260.35 N 884.49 E 5949753.53 N 676969.24 E 6.736 260.35 7968.39 38.990 87.750 7714.38 7769.38 261.02 N 902.13 E 5949754.61 N 676986.85 E 7.218 261.02 8061.78 38.690 87.390 7787.12 7842.12 263.50 N 960.64 E 5949758.46 N 677045.30 E 0.402 263.50 8155.25 37.030 87.390 7860.92 7915.92 266.12 N 1017.95E 5949762.42 N 677102.52 E 1.776 266.12 8248.72 38.370 91.010 7934.88 7989.88 266.89 N 1075.08 E 5949764.52 N 677159.62 E 2.768 266.89 8342.06 38.480 91.110 8008.00 8063.00 265.81 N 1133.08 E 5949764.81 N 677217.63 E 0.135 265.81 8435.53 37.110 91.060 8081.86 8136.86 264.73 N 1190.35 E 5949765.06 N 677274.91 E 1.466 264.73 8530.33 35.670 90.880 8158.17 8213.17 263.77 N 1246.58 E 5949765.42 N 677331 .15 E 1.523 263.77 8621.61 34.100 90.560 8233.05 8288.05 263.12 N 1298.78 E 5949765.99 N 677383.35 E 1.732 263.12 8714.38 35.630 90.840 8309.17 8364.17 262.47 N 1351.81 E 5949766.58 N 677436.38 E 1.658 262.47 8748.04 36.950 91.210 8336.30 8391.30 262.11 N 1371.73 E 5949766.68 N 677456.30 E 3.975 262.11 8849.77 36.180 86.960 8418.02 8473.02 263.06 N 1432.29 E 5949769.05 N 677516.82 E 2.601 263.06 8895.98 35.400 86.590 8455.50 8510.50 264.57 N 1459.27 E 5949771.20 N 677543.76 E 1.752 264.57 8941.05 34.110 86.160 8492.53 8547.53 266.20 N 1484.91 E 5949773.42 N 677569.36 E 2.913 266.20 9004.34 39.470 74.320 8543.26 8598.26 272.84 N 1522.06 E 5949780.93 N 677606.34 E 14.013 272.84 e 9035.21 40.740 67.920 8566.88 8621.88 279.28 N 1540.85 E 5949787.81 N 677624.98 E 13.969 279.28 9067.52 41 .650 60.260 8591.21 8646.21 288.57 N 1559.96E 5949797.54 N 677643.86 E 15.859 288.57 9100.12 42.190 55.590 8615.47 8670.47 300.14N 1578.40 E 5949809.54 N 677662.02 E 9.711 300.14 9128.17 44.510 50.050 8635.87 8690.87 311.78 N 1593.71 E 5949821.53 N 677677.06 E 15.876 311.78 9159.46 47.210 45.110 8657.67 8712.67 326.93 N 1610.26 E 5949837.07 N 677693.25 E 14.237 326.93 9194.05 47.810 37.840 8681.05 8736.05 346.02 N 1627.13 E 5949856.55 N 677709.67 E 15.590 346.02 9222.93 46.540 31.380 8700.69 8755.69 363.43 N 1639.16 E 5949874.23 N 677721.29 E 16.980 363.43 9256.88 47.600 25.160 8723.83 8778.83 385.31 N 1650.91 E 5949896.38 N 677732.52 E 13.769 385.31 9287.77 46.520 19.850 8744.88 8799.88 406.18 N 1659.57 E 5949917.45 N 677740.69 E 13.058 406.18 27 August, 2004 . 7:56 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-06 - 7-06B Your Ref: API 500292029402 Job No. AKMW0003218817, Surveyed: 15 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9316.40 46.800 18.450 8764.53 8819.53 425.85 N 1666.40 E 5949937.27 N 677747.06 E 3.688 425.85 9347.10 49.060 12.310 8785.11 8840.11 447.81 N 1672.41 E 5949959.37 N 677752.56 E 16.566 447.81 9377.30 52.140 7.180 8804.28 8859.28 470.79 N 1676.34 E 5949982.44 N 677755.95 E 16.617 470.79 9409.47 51 .120 359.760 8824.27 8879.27 495.94 N 1677.87 E 5950007.61 N 677756.89 E 18.354 495.94 9440.57 52.830 356.110 8843.43 8898.43 520.41 N 1676.98 E 5950032.06 N 677755.43 E 10.755 520.41 e 9472.03 53.730 355.540 8862.24 8917.24 545.56 N 1675.15 E 5950057.16 N 677753.01 E 3.208 545.56 9503.51 55.420 354.380 8880.49 8935.49 571.11 N 1672.89 E 5950082.65 N 677750.15 E 6.151 571.11 9537.39 58.280 352.190 8899.01 8954.01 599.28 N 1669.56 E 5950110.73 N 677746.17 E 10.027 599.28 9568.22 61.310 350.050 8914.52 8969.52 625.60 N 1665.45 E 5950136.94 N 677741.44 E 11 .513 625.60 9596.57 64.760 348.460 8927.38 8982.38 650.41 N 1660.73 E 5950161.65 N 677736.14 E 13.155 650.41 9629.60 68.530 343.690 8940.48 8995.48 679.83 N 1653.42 E 5950190.88 N 677728.14 E 17.491 679.83 9660.08 72.510 340.290 8950.64 9005.64 707.14 N 1644.53 E 5950217.98 N 677718.62 E 16.764 707.14 9690.25 76.550 336.910 8958.69 9013.69 734.20 N 1633.91 E 5950244.78 N 677707.37 E 17.200 734.20 9720.92 82.450 335.270 8964.28 9019.28 761.75 N 1621.69 E 5950272.04 N 677694.51 E 19.942 761.75 9753.05 88.020 332.940 8966.94 9021.94 790.54 N 1607.72 E 5950300.49 N 677679.86 E 18.781 790.54 9782.58 89.940 327.600 8967.47 9022.47 816.17 N 1593.08 E 5950325.77 N 677664.63 E 19.213 816.17 9875.30 88.770 329.410 8968.51 9023.51 895.22 N 1544.65 E 5950403.67 N 677614.36 E 2.324 895.22 9923.31 89.200 327.740 8969.36 9024.36 936.18 N 1519.62 E 5950444.03 N 677588.38 E 3.591 936.18 9970.62 89.440 326.890 8969.93 9024.93 976.00 N 1494.07 E 5950483.24 N 677561.91 E 1.867 976.00 10063.86 90.930 328.150 8969.62 9024.62 1054.65 N 1444.00 E 5950560.70 N 677510.02 E 2.093 1054.65 10156.44 90.430 327.190 8968.53 9023.53 1132.87 N 1394.50 E 5950637.74 N 677458.70 E 1.169 1132.87 e 10250.39 91.170 326.750 8967.21 9022.21 1211.63N 1343.29 E 5950715.28 N 677405.66 E 0.916 1211.63 10334.66 90.120 326.910 8966.27 9021.27 1282.16 N 1297.19 E 5950784.71 N 677357.92 E 1.260 1282.16 10401.00 90.120 326.910 8966.13 9021.13 1337.74 N 1260.97 E 5950839.43 N 677320.41 E 0.000 1337.74 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10401.00ft., The Bottom Hole Displacement is 1838.37ft., in the Direction of 43.308° (True). 27 August, 2004 - 7:56 Page 3 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-06 - 7-06B Your Ref: API 500292029402 Job No. AKMW0003218817, Surveyed: 15 August, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northin9s Eastings (ft) (ft) (ft) Comment 7691.00 7786.00 10401.00 7530.40 7616.35 9021.13 255.58 N 257.91 N 1337.74 N 763.20 E 803.57 E 1260.97 E Tie On Point Window Point Projected Survey e Survey tool program for 07-06 - 7-068 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 7691.00 0.00 7691.00 7530.40 10401.00 7530.40 Good Gyro - CB-Gyro-MS (07-06) 9021.13 MWD Magnetic (7-06B) e 27 August, 2004 - 7:56 Page 4 of 4 DrillQuest 3.03.06.006 TREE = GRA Y GEN 3 WELLHEAD = . d.C3~,( e ACTUA TOR = AXELSON KB. ELEV = 64' BF. ELEV = ? KOP = 5700' ,,··"u <0 ~w ^ "m~""'" Max Angle = 91 @ 10250' Datum MO = 9272' Datum TV D = 8800' SS 15-1/2" TBG-NPC, 17#, N-80/13CR80, ID = 4.892" H 113-3/8" CSG, 72#, N-80, ID = 12.347" H 2698' 07 -068 /- 27' I ~ ~OTES: *** 4·1/2" CHROME TBG *** I 27' H5-1/2" X 4-1/2" XO, ID=4.892" 2174' H4-1/2" HES X NIP, 10 = 3.813" , .. GAS LIFT Iv1ANDRELS ST MD TVD OEV TYÆ VLV LATCH PORT DATE 3 3356 3356 1 MMG OCR RKP 0 08/05/04 2 5749 5746 11 MMG OMY RK 0 08/05/04 1 7799 7628 27 KBG2 DMY BK 0 08/05/04 . Minimum ID = 3.725" @ 8675' 4-1/2" HES XN NIPPLE g ~ 7638' H 9-5/8" X 7" BKR LNR HGR w !TIEBACK SL V, 10 = 6.276'" MIL LOUT WINDOW 7786' - 7802' WHIPSTOCK H 7802' 1 EZ DRILL sa PKR H 7827' 1 9-5/8" CSG, 47#, N-80 H 8578' I 7" LNR, 29#, N-80 H 9253' g 12-7/8" LNR- CT, 6.5#, L-80 H 10123' 14-1/2" TBG, 12.6#, 13CR80, .0152 bpf, ID = 3.958" H 17-1/2" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 8687' r--l ~ L--i 8609' H4-1/2" HES X NIP, 10 = 3.813" I x-j 8630' H 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" I --i 8654' H4-1/2" HES x NIP, 10 = 3.813" I ----1 8675' H4-1/2" HES XN NIP, 10 = 3.725" I ;---4 8687' -4-1/2" WLEG I ~ 8680' ~ 7" X 4-1/2" LNR TOP PKR I ~ w!TIEBACK SLV, ID = 3.958" 8825' ÆRFORATION SUMMARY REF LOG: ON XXlXXIXX ANGLEATTOPÆRF: 88 @ 9750' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 4 9750 - 10020 0 08/18/04 2-7/8" 4 10080 - 10305 0 08/18/04 IPBTD H 10312' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" H 10400' ~ DA TE REV BY COMMENTS 11/20/78 ORIGINAL COMPLETION 01/07/96 SIDETRACK (A) 08/19/04 JDM/TLH SIDETRACK (B) DA TE REV BY COMMENTS PRUDHOE BA Y UNrT WELL: 07-06B ÆRMrT No: 1951970 API No: 50-029-20294-02 SEe 34, T11 N, R14E, 3371.18' FEL & 2021.52' FNL BP Exploration (Alaska) · l ¡ FRANK H. MURKOWSKI, GOVERNOR ! ;' ^',ASKA. ORAND GAS CONSERVATION COMMISSION í 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc_ P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 07 -06B BP Exploration (Alaska) Inc. Permit No: 204-042 Surface Location: 1450' SNL, 117' WEL, SEC. 33, TllN, RI4E, UM Bottomhole Location: 120' SNL, 4124' EWL, SEe. 34, TIIN, RI4E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you fÌom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (90 659 7 (pager). Sinc el BY ORDER OF THE COMMISSION DATED thislÞday of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALAS' OIL AND ~~T~g~S~L:;~ON IMMlssf~~ PERMIT TO DRILL 20 MC 25.005 f(; l' I,]"¡, !~"i..L ~~,~,~;~~~¡~.~/04/04 11 b. Current Well Class 0 Exploratory 111 Develop[l1¡:¡~~ Oi.I......O Multiple Zone o Stratigraphic Test 0 Service 0 Developitlént.Gå$"Ð Single Zone 5. Bond: !HI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 10401 TVD 9020 7. Property Designation: ADL 028309 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL):KBE = 55 feet 07-35 is 338' away 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3755 psig Surface: 2915 psig QuaQ~ity ( c.fiQr (includinç¡ staç¡e data) 241 sx Class 'G' r 214 sx Class 'G' / o Drill III Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1450' SNL, 117' WEL, SEC. 33, T11 N, R14E, UM Top of Productive Horizon: 867' SNL, 1568' EWL, SEC. 34, T11N, R14E, UM Total Depth: tJJet- ~ 120' SNL, 4124'.ÞWt, SEC. 34, T11N, R14E, UM 8. Land Use Permit: 9. Acres in Property: 2560 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676091 y- 5949473 Zone- ASP4 16. Deviated Wells: Kickoff Depth 18. CaS¡ingprogram Size Casinç¡ 7" 7800 ft Maximum Hole Angle Specifications Grade Couplinç¡ L-80 BTC-M L-80 IBT-M 91 Hole 8-1/2" 6-1/8" Weiç¡ht 26# 12.6# MD 7650' 8673' TVD MD TVD 7495' 8823' 8452' 8333' 10400' 9020' Lenç¡th 1173' 1727' 4-1/2" WGÆ t..:114-/2.-0c')4 JlJN t 4.. ·'004· J ~. ['. 11. Well Name and Number: / PBU 07-06B (,j11c4 12. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 13. Approximate Spud Date: August 16,2004 14. Distance to Nearest Property: 32,000' PRESENT WEL,L.GONDITION$(JMMARY (To be completed forR~drill~NPRe..Elntry Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD 10123 9029 8000' 8000' 7807 Structural Conductor 107' 20" 230 sx Arcticset 107' 107' Surface 2698' 13-3/8" 6350 sx Arcticset II 2698' 2698' Intermediate 8578' 9-5/8" 750 sx Class 'G' 8578' 8299' Production Liner 993' 7" 500 sx Class 'G' 8260' - 9253' 8032' - 8849' Liner 1974' 2-7/8" 59 sx LARC 8149' - 10123' 7936' - 9029' perfOration Depth TVD (ft): 8920' - 9027' !HI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report !HI Drilling Fluid Program !HI 20 MC 25.050 Requirements Perforation Depth MD (ft): 9359' - 10048' 20. Attachments 0 Filing Fee, $100 !HI BOP Sketch !HI Property Plat 0 Diverter Sketch 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Isaacson Title Senior Drilling Engineer Phone Date: Contact Rob Tirpack, 564-4166 Permit Date: Mud Log Directional Survey Required 5' lip. øoo . See cover letter for other requirements ~es ~NO ~ ,es DNo O L! , ~. , ~\' ~\ \ ¡ " . BY ORDER OF THE COMMISSION Date ~/~e . . To: Winton Aubert - AOGCC Date: June 3, 2004 From: Rob Tirpack - BPXA GPB Rotary Drilling Subject: 7-06A Request for Revision to Drilling Permit #204-042 Convert from CTD Sidetrack to Rotary Sidetrack Approval is requested to revise the Approved Drilling Permit (#204-042) for 7-068. The original drilling permit was written for a CTD sidetrack with Nordic #2. Since this time, the decision has been made to perform a rotary sidetrack due to a parted tubing string. The rotary bottom hole location is -450' away from the CTD bottom hole location. The wellbore configuration will also change substantially. After the existing tubing has been fished and recovered, a window will be cut in the 9-5/8" production casing. Next, an 8-1/2" hole will be drilled to the top of the Sag River and a 7" drilling liner will be set and fully cemented. Then a 6-1/8" hole will be drilled horizontally in the Ivishak Zone 2A128 and a 4-1/2" production liner will be set and fully cemented. The completion will consist of a new string of 4-1/2" chrome tubing. The 7-068 sidetrack is currently scheduled for Nabors 2ES beginning around August 16, 2004. Rob Tirpack Operations Drilling Engineer 564-4166 7-06A Application for Drilling Permit Revision · . IWell Name: 17-068 Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer Surface Location: As Built Target Location: Ivishak Zone 2A Bottom Hole Location: x = 676,091 Y = 5,949,473 / 1449' FNL 117' FEL Sec. 33, T11 N, R14E Umiat X = 677,760 Y = 5,950,095 TVDss 8,899' 867' FNL 3712' FEL Sec. 34, T11 N, R14E Umiat /' X = 677,329 Y = 5,950,832 TVDss 8,965' 120' FNL 4124' FEL Sec. 34, T11N, R14E Umiat / I AFE Number: 1 PBD4P2241 1 I Estimated Start Date: 1 08/16/04 I Rig: 1 Nabors 2ES ~. I Operating days to complete: 116.3 I MD: 110,400' 1 I TVD: 19,020' I I GL: 126.5' I KB: 128.5' 1 I KBE: 155.0' I Well Design (conventional, slim hole, etc.): 1 Dual String Horizontal Sidetrack I Objective: 1 Ivishak Zone 2A and 2B Formation Markers (Sperry wp06) Formation Tops MD TVD TVDss CM1 7,380' 7,235' 7,180' KOP 7,800' 7,629' 7,574' THRZ 7,897' 7,713' 7,658' BHRZ 8,083' 7,865' 7,810' TKNG 8,120' 7,895' 7,840' T JB 8,581' 8,260' 8,205' T JA 8,709' 8,362' 8,307' TSGR 8,823' 8,452' 8,397' TSHU 8,864' 8,485' 8,430' TSAD 8,960' 8,561' 8,506' TCGL 9,179' 8,725' 8,670' BCGL 9,289' 8,801' 8,746' 23SB 9,378' 8,861' 8,806' 25N 9,398' 8,874' 8,819' 24N 9,447' 8,905' 8,850' 22TS 9,457' 8,911' 8,856' 22N 9,527' 8,951' 8,896' 21TS 9,558' 8,967' 8,912' TD 10,401' 9,020' 8,965' TZ1 B N/A 9,025' 8,970' HOT N/A 9,027' 8,972' TD Criteria: Based on 400' of perfable Zone 2A and 2B. 7-06B Permit to Drill Comments 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Not Penetrated Not Penetrated (0. q 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW Q ~. õ·", Page 1 . . Directional - Sperry wp06 KOP: 7,800' MD Maximum Hole Angle: -380 in 8-1/2" Intermediate section _910 in 6-1/8" horizontal section. Close Approach Wells: There are no close approach issues. The closest well to 7-06B is 7-35 with a center to center distance of 338'. Survey Program: Standard MWD Nearest Property Line: 32,000' CasingITubing Program Hole Size CsgfTbg O.D. WtlFt Grade Conn Length Top Btm MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 1,173' 7,650'/7,495' 8,823'/8,452' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1 ,727' 8,673'/8,333' 10,400'/9,020' Tubing 4-1/2" 12.6# 13Cr80 YAM-Top 8,645' GL 8,673'/8,333' Mud Program Window Milling Mud Properties: LSND Whip Stock Window 9 5/8" Density (ppg) I Viscosity I PV YP I MBT Chlorides I PH I API FI 10.9 45 - 55 12 - 18 30 - 40 <20 <500 9.0 - 9.5 4-6 Intermediate Mud Properties: LSND 8-1/2" hole section DensC') I Viscosity I PV YP I MBT Chlorides I PH IAPI FII 38-45 15 - 22 20 - 25 <20 <500 9.0 - 9.5 2-4 Production Mud Properties: Flo-ProSF 6-1/8" hole section Density (ppg) I PV I YP LSRV I pH APIFI 8.4 - 8.5 8 - 15 30 - 40 >40,000 9.0 - 9.5 4-6 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlRes- Real time Open Hole: None Cased Hole: None 6-1/8" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GRlRes/Den/Neu/ABI - Real time None None Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 7-06B Permit to Drill Page 2 . . Cement Program I Casing Size 17" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 1,023' of 7" X 8-1/2" open hole with 40% excess, 80' shoe track, 150' 7" X 9-5/8" Liner lap, and 200' 4" DP X 9-5/8" casing excess. Tail TOC: 7,650' MD (TaL) _ I Total Cement Volume: I Lead I None ') ¿ ) Tail 50 bbls, 280 ftÿYsacks Class G @ 15.8 ppg, 1.16 ft3/sack I Casing Size 14.5" 12.6#, L-80 Production Liner I Basis: Lead: None Tail: Based on 1577' of 4-1/2" X 6-1/8" open hole with 40% excess, 80' shoe track, 150' 4-1/2" X 7" Liner Lap, and 200' of 7" X 4" DP excess. Tail TOC: 8,673' MD (TaL) I Total Cement Volume: I Lead Tail I None /) 46 bbls, 257 f)(1fYSacks Class G @ 15.8 ppg, 1.20 ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear 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 the AOGCC. Intermediate Interval Maximum anticipated BHP _ Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole 7" Drilling Liner Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 7 -06B Permit to Drill 3,755 psi (8.6 ppg @ 8,397' TVDss) 2,!µ&psi (.10 psi/ft gas gradient to surface) ~e with a 11.9 ppg FIT . s test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure / 11.9 ppg FIT after drilling 20' outside window The VBRs will not be changed to accommodate the 570-ft 7" drilling liner. Instead, the current and best practice of picking up a joint of drillpipe, with crossover to the casing thread, will be employed in the event of a kick. This practice provides two rams capable of closing on the pipe across the BOP stack instead of just a single 7" ram. 3,377 psi (7.2 ppg @ 9,020' TVDss) 2'æp,Si (.10 psi/ft gas gradient to surface) In mit with 9.5ppg FIT R s test to 3,500 psi/250 psi. .-/ Annular test to 2,500 psi/250 psi 3500 psi surface pressure 9.5 ppg EMW FIT 8.4 ppg Seawater / 6.8 ppg Diesel Page 3 . . 7-068 Sidetrack and Complete Procedure Summary NOTE: The 5-1/2" tubing is parted at 1355' MD. The two stubs are believed to be matched up fairly close. Several successful slickline runs have been made through the parted tubing. The largest 00 tool to pass has been a 4.35" tapered swedge. Pre-Riq Work: 1. Rig up slickline, pulllBP from 8,000' MD. 2. Make additional slick line runs as necessary to recover rubber packer elements. 3. Fluid pack tubing and inner annulus. 4. P&A perfs from the PBTD to -8,060' MD. RIH with coil to PBTD. lay in 13 bbls of cement to -8,060' MD. Obtain Squeeze with 5 additional bbls. POH with coil. 5. Rig up slickline, tag TOC. 6. Fluid pack T X IA with seawater and freeze protect same with diesel. 7. Pressure test T X IA to 1000 psi. 8. Test the 9-5/8" pack-off to 5000 psi and tubing hanger seals to 5000 psi. 9. Function all lock-down screws. Repair or replace as needed. 10. Bleed casing and annulus pressures to zero. 11. Set a BPV in tubing hanger. Secure well. 12. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull Ty:¡e. 4. Pull 5-1/2" tubing from part at about 1355' MD. . 5. RIH with overshot on 5-1/2" tubing. Engage fish. /' 6. RU e-line. Chemical cut 5-1/2",17#, N-80 tubing at -7850' MD. 7. Pull 5-1/2" tubing from chern cut. 8. RU e-line. Run GR/JB for 9-5/8",47# casing with CCl to just above top of tubing stub. 9. RIH with CIBP on e-line. Set CIBP to avoid cutting a casing collar during window milling operations......-- 10. Pressure test wellbore to 3500 psi for 30 mins. 11. PU 9-5/8" Baker bottom trip whipstock assembly. RIH, orient whipstock and set on CIBP. 12. Swap over to 10.9 ppg lSND milling and drilling fluid (HRZ KOP). / 13. Mill window in 9-5/8" casing at 7,800' MD (top of window) plus 20' past middle of window. Perform FIT. POOH. 14. MU 8-1/2" drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 8-1/2" inter~iate interval, building and turning at 4°/100' to a 37° hold angle. 15. Drill ahead to casing point at Top Sag River to an estimated depth of 8,823' MD. 16. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing with 150)f-.everlap. Displace cement with mud. POOH. 17. MU 6-1/8" BHA with Dir/GR/RES/Den/Neu/ABI and RIH to the landing collar. 18. Pressure test wellbore to 3500 psi for 30 minutes. / 19. Drill shoe track. Swap over to 8.5 ppg mud and drill 20' of new formation. Perform FIT. 20. Drill the 6-1/8" production interval building at 14°/100' to horizontal, targeting Z2 Ivishak. Drill ahead to an estimated TO of 10,400' MD. ' , 21. Run and cement a 4-1/2" liner throughout the 6-1/8" wellbore and back into the 7" dril~liner to place top of liner with 150' of overlap. Displace cement with perf pill and mud. 22. Release from liner, displace well to clean seawater. 23. RIH with DPC perf guns. Perf intervals to be determined from lWD logs. 24. POOH. lD DP and perf guns. 25. Run 4-1/2",12.6#, 13Cr80 completion tying into the 4-1/2" liner top. 7-06B Permit to Drill Page 4 . . 26. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 27. Set and test TWC. /. 28. ND BOPE. NU and test the tree to 5000 psi. 29. Freeze protect the well to -2200' and secure the well. 30. RDMO Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 7-06B Permit to Drill Page 5 . . 7-068 Drilling Program Job 1: MIRU Hazards and Contingencies > No wells will require well house removal or shut-in for the rig move onto 7-068. The closest neighboring wells are spaced as follows: 7-07 at -117' and 7-05 at -116'. Care should be taken while moving onto the well. Spotters will be used at all times. > Drill Site 7 is not designated as an HzS site. However, Standard Operating Procedures for H2S precautions sfioufdbe followed at all times. Recent H2S data from the pad is as follows: #1 Closest SHL with H2S Reading #2 Closest SHL with H2S Reading #1 Closest BHL with H2S Reading #2 Closest BHL with H2S Reading Max H2S Reading on Pad Well Name 7-05 7-07 7-17 7-18 7-09 H2S Reading 2ppm 2 ppm 4ppm 2 ppm 42 ppm Date 05/10/92 02/13/95 02/12/01 11/02/95 3/09/01 > Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. > IA Pressure Barriers: 1) cement P&A plug with kill weight fluid above 2) wellhead/tree with BPV. > OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies > The perforations in 7-06A have been isolated with a cement plug set during pre-rig operations. Monitor well for any signs of pressure or flows. > Note and record required PU weight to pull tubing at cut point. > NORM test all retrieved well head and completion equipment. > Verify the hanger type and connection. Be prepared with necessary equipment to remove. > IA Pressure Barriers: 1) cement P&A plug with kill weight fluid above 2a) wellhead with TWC during ND tree and NU BOPE or 2b) wellhead and BOPE. > OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RP .:. "De-completions" RP 7-06B Permit to Drill Page 6 . . Job 3: Window Mill HazardsandConüngencœs þ> Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ~ IA Pressure Barriers: 1) kill weight milling fluid 2) BOPE. þ> OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RP .:. "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies þ> The intermediate section will kick off in the CM1 formation, drill through the HRZ and Kingak intervals to the top of the Sag River. For this well, due to the tangent at 38° inclination at a 89° azimuth, maintain mud weight at 10.3 ppg, from the KOP to the 7" liner point. Follow all shale drilling practices to minimize potential problems. þ> There are no fault crossings in the intermediate section. þ> There are no close approach issues in the intermediate hole section. þ> KICK TOLERANCE: In the worst-case scenario of 9.6 ppg pore pressure at the Sag River depth, a fracture gradient of 11.9 ppg at the 9-5/8" casing window, and 10.3 ppg mud in the hole, the kick tolerance is infinite. þ> IA Pressure Barriers: 1) kill weight drilling fluid 2) BOPE. þ> OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies þ> Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. þ> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. þ> IA Pressure Barriers: 1) kill weight drilling fluid 2) BOPE. þ> OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. 7-06B Permit to Drill Page 7 . . Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ There are no fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ There are no close approach issues in the production hole section. ~ KICK TOLERANCE: In the worst-case scenario of 8.6 ppg pore pressure in the Ivish , a frad,ture gradient of 9.5 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance i Infinit~: ~ IA Pressure Barriers: 1) kill weight drilling fluid 2) BOPE. '___/ ~ OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. ~ IA Pressure Barriers: 1) kill weight drilling fluid 2) BOPE. ~ OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Halliburton Cement Program 7-06B Permit to Drill Page 8 . . Job 10: DPC Perforate Production CasinCl Hazards and Contingencies > Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. > IA Pressure Barriers: 1) kill weight completion fluid 2) BOPE. > OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RPs .:. Follow Schlumberger's perforating practices and recommendations. .:. "DPC Perforating" RP -~-<~ Job 12: Run Completion Hazards and Contingencies > Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. > IA Pressure Barriers: 1) kill weight completion fluid 2) BOPE. > OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP -'>.",.-.>',..'<J Job 13: ND/NU/Release RiCl Hazards and Contingencies > No wells will require well house removal or shut-in for the rig move from 7-06B. The closest neighboring wells are spaced as follows: 7-07 at -117' and 7-05 at -116'. Care should be taken while moving onto the well. Spotters will be used at all times. > IA Pressure Barriers: 1) kill weight completion fluid on top of ball/rod and packer 2a) wellhead with BOPE or 2b) wellhead with TWC or 2c) wellhead with tree and BPV. > OA Pressure Barriers: 1) CITOA 2) wellhead with double valves. Reference RP .:. "Freeze Protecting an Inner Annulus" RP .TI:-.~_=;;"-'"~.-","", 7-06B Permit to Drill Page 9 . . 7-068 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no close approach issues in the intermediate hole section. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · There are no fault crossings expected in the intermediate hole section. · Lost circulation while drilling the intermediate hole has not been problematic at Drill Site #7. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 10.9 ppg to ensure shale stability in the Kingak and HRZ. · Kick tolerance is Infinite with a 11.9 ppg FIT. Production Hole Section: · There are no fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · There are no close approach issues in the production hole section. · Kick tolerance is Infinite with a 9.5 ppg FIT. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S / · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE Drill Site #7 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 7-068 Permit to Drill Page 10 ·TREE = . GRA Y GBI 3 . WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = ? KOP = 5700' Max Angle = 92 @ 9873' Datum MO = 9272' Datum TVD = 8800' SS I 13-3/8" CSG. 72#, N-80.1D= 12.347" H 2698' ~ . 07-06A . SAFETY NOTES: PULLED UPPER is' OF 7191' POGLM; LEFT 6' TO S' AT XO (5124/00) - 2228' H5-1/2" CAMCO BAL-O SSSV NIP. ID = 4.562" I .. Minimum ID = 2.440" @ 8157' I I 7865' K 5-1/2" BAKERL SLIDI\IG SLV I 4-1/2" X 2-7/8" XO 'J-¡ 7955' - 5-1/2" BAKERR LAND NIP, 10=4.472" l 7992' H 5-1/2" BAKER SBR ASSY 1 8000' - 3-3/8" IBP SET (06/17/03) I 8: ~ 8054' - 9-5/8" X 5-1/2" BAKER SAB A<R I 15-1/2" TBG-NR:;. 17#, N-80, .0232 bpf, ID = 4.892" I., 8066' ~ I I 8066' - 5-1/2" X 4-1/2" XO I TOP OF 4-1/2" TBG-NR:; - 8066' ¡---... I - 4-1/2" BAKER R LAND NIP. ID = 3.812" I 8127' TOPOF2-7/8" LNR- CT - 8149' H I 8149' - 4-112" GS PBR, 10 = 3.00" 1 I 8157' H 4-1/2" X 2-7/8" XO. ID = 2.440 I I 8189' - 4-1/2" BAKER SHEA ROUT SUB (BEHIND CT) 14-1/2" TBG-NR:;, 12.6#. N-80, .0152 bpf, ID = 3.958" H 8190' t-- 8190' - 4-1/2" TUBING TA R.. (BEHIND CT) 1 I TOP OF 7" LNR - 8260' ~ 1 8174' - ELMO TT LOGGED 11/28nB I 9-5/8" CSG. 47#, N-80, ID = 8.681" 1-1 8578' ~ I TOP OF CEMENT - 922T I 7" LNR, 29#. N-80. .0371 bpf.ID= 6.184" - 9253' I-- MlLLOUT WINDOW 9253' - 9263' I PBTD H 10057' 2-7/8" LNR - CT, 6.5#, L-80. .00579 bpf, 10 = 2.441" ÆRFORA TION SUMMARY REF LOG: BHes ON 11/14178 ANGLE AT TOP ÆRF: 58@9359' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2-1/8" 4 9359 - 9365 0 02/23/98 2-1/8" 4 9447 - 9455 0 02/23/98 2-118" 4 9748 - 9833 0 01/06/96 2-1/8" 4 9853 - 9938 0 01/06/96 2-1/8" 4 9958 - 10048 0 01/06/96 DATE 11/20178 01/07/96 07/08/00 09/22/01 06/17103 09/10/03 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK MHlTLP PULL POGLM @ 7191' RNITP CORRECTIONS BJIv1IKK SET IBP CMOITLP PERF ANGLE CORRECTION DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 07 -06A PERMIT No: 1951970 API No: 50-029-20294-01 SEC 34, T11 N, R14E, 3371.18' FEL & 2021.52' FNL BP Exploration (Alaska) 1355' 2228' 2698' .4 7865' 7992' 8000' 8054' :8 8060' 8066' 8149' 8190' 8260' I 8578' ~ ~ - I I l- · 7 -06A Pre-ftig Parted Tubing (4.35" pass with tapered swedge) 5-1/2" Camco Bal-O SSSV ~ 13-3/8", 72#, N-80 - 5-1/2", 17#, N-80 Tbg, ID=4.892" 5-1/2" Baker Sliding Sleeve J 5-1/2" Baker SBR X 9-5/8" X 5-1/2" Baker SAB packer TOC 4-1/2" X 5-1/2" Crossover ,:~¡ H __4-1/2",12.6#, N-80 Tbg 2-7/8" Liner WLEG I 7",29#, N-80 Liner Top .. 9-5/8", 47#, N-80 TREE = GRAY GEN 3 WELLHEA D = GRAY ·ACTUATOR = AXELSÒN KB. ELEV = 64' BF. ELEV = ? KOP = 5700' Max Angle = 92 @ 9873' Datum MD = 9272' Datum TVD = 8800' SS 9253' Top of Winow 9263' PBTD @ 10057' 10123' 2-7/8",6.5#, L-80 Liner Date 04-29-04 Rev By Comments RBT Pre-Rig Work PRUDHOE BAY UNIT WELL: 7 -06A API NO: Permit NO: GPB Rotary Drilling 7-06B~roposed Ctmpletion . I 2698' ~ 7650' :- 7800' " 7820' 7850' ~ I I ~w;f H 8260' I 8578' · X nipple @ 2200' ~ 13-3/8", 72#, N-80 ,.......,. 4-1/2", 12.6#, 13Cr80, Vam-Top TREE = GRA Y GEN 3 WELLHEAD = GRAY . . .. -. ACTUA TOR = AXELSON KB. ELEV = 64' BF. ELEV :: ? KOP = 5700' Max Angle :: 92 @ 9873' Datum M) :: 9272' DatumTVD= 8800' SS ., 9-5/8" X 7" Saker HMC Liner Hanger .. with ZXP and C-2 running tool 4 Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG GI M Design: #3 - 3350' TVD - 4-1/2" X 1-1/2" - SV #2 - 5750' TVD - 4-112" X 1-1/2" - DV #1 - 7625' TVD - 4-1/2" X 1" - DV Top of window 8,623' - 7 X 4-1/2" Saker 5-3 Packer 8,673' - 7" X 5" Saker HMC Liner Hanger ZXP and C-2 running tool 8,823' - 7", 26#, L-80, STC-M 4-1/2", 12.6#, L-80, 1ST . 7",29#, N-80 Liner Top .. 9-5/8", 47#, N-80 9263' 10123' 2-7/8",6.5#, L-80 Liner Date 05-03-04 Rev By Comments RBT Proposed Completion 10,409' / PRUDHOE BAY UNIT WELL: 7-06B API NO: Permit NO: GPB Rotary Drilling ; ! / -N- ..,.... f"1-::;a¡ """"\\ .. --.... OF.4· '.. ..:' ~t{.,..··..·.f4~ .. - 6...~.... - ... 'Lf. ~. . ..:r " ~ :. TH 1....~.~~·· :::...... ,.~ .. LOREN M. SElBE. . .- r~ ."!. .... _ tA ~ eo NO. 3622-5 .. ~ _ ~·t ~ -. .,- ~ AI' ." 'i:: .. .0· ~.... _ 't 4"~ .......... :\"- . \ \,!lrlSmlL~ \\.t......_ r 10.\.,,,,,-,, _h ORAWIVßY.· ~ 83 . CHECKE06Y: ..___. OA TE: rEB. ê3.I<¡83 ... - .. ... JOB NO. Z5Z¿> .. - . , 28 27 .33 .34-. , ' ~~ ~~. .. ~ ~ ~ --' /3ðJ ,. .", . I --r - -$- ~ ~.7AI 0. S.7 WEST PAO ~ ..- , -\ ...=.:'\ . Ù~;^'\. e~F;'- ."~' ~~ ~ ¡¿.!~r\ " ~~ .~ '"'I' ~. . ~ =--. zðZ7 p f D'S.7~ ~'<ì --. f ", _. 33-- ~. .54_ - .:~ . N TII. R 14& ._- VICINITY #A~·-=--~~·m sC4L.e: I = 4000' . . \ 0.5. 7 weLL 7A . y= 5,.94-9,574.79 " ~: '·X = ('47(#" O(P7: 2(:) .. ."_ .. LA7:" 70°/6 '04. 2// '~. LONG. /48ØS4-'54,22311 ...' ELEYATlON OP NJ1/ COÆ:. Or ceLLA~ _ BOX = 26.57. PROTRACTED sec. 33 ¿f 34 TflN, R /4-£3 t.l.M. SCAL€': I" = 400' ./ -~ ~ (Æ;j~ \ \ ~. ~'~·Ui . ~.-....- ~ ~~-~Ih' '.~. .-.-...---.... · I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND 'SURVEYING IN THE STATE· OF : ALASKA AND THAT THIS. PLAT · REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS · AR~_ C~RRECT,~S Of: 2~3 -8.3 _ 5H7:.- OS 7/7A AS-BUILT --. -- - , ~ ... ----- - -.._---_. - - ARGO Alaska, Inc. ·.SubsldíQry of Allantic Richfield Company NORTH SLOPE DRILLING-PRUDHOE BAY ..4-... " - OF -1- ~:-=~:, . S E (TiC'r--.; .., - ~ ~ ~;:-:;:.:-:.: -;-¡-n¡;-¡¡ ; ..... í~---·-- s::: - .:" L!~:: - ---_._~---- -----.-..- - - ---.....,... - ~ -~--: -~.,-. ~-=::;,-~ -;::::~- -- :-r ..' w Z ~\ -\ >- 1\ ~ ~\ g :c ë; -;\ \ , (' .... .' ~ . . ~, : ì i· , . ~ , I z o , . I 1 14 : ...:.- . . ; - . ,'~ ~.:.:. ¡ . , T 13 1-. I :·0 ~ ¡~ , ~ l- I'.:> .... .... 10 )- :~ : Í 1 , I >- ~ '-' ¡ UJ .<J1 :;~ILL SITE NO.7 T Ii"', R 14 E. U.M. , ' , 25v - ~ ; 12 r . , i ; · I · , , ..-..- 265' ., , ..., '.:> ; ~ . .. II ¡~ ---. y ¡= ~2';C'~;; J;:: 1l\ t... Pt.V' 'V ;1 \pD \À.1'V· {:" lo ~t>,:.)... D.. ~/ '.. 10 . ; ¡ ; ! ; , ' ,,~ ,0 :", I ~2¡5 -+-j I I J 9 . o T · ; i ..... 2 ,---- ! 9 2' +--' 8 . '~ tr¿, cP' '61/ \.i0 t¡}' ~1 . \o...<b -(" tf\'A "\~ -.., .('-,¿ '66 ,. 7 . --J 14'· 6 ~ o ---- i ." -. .... r ,·0 "' , .,. ~~ !~7 - T 5 ' . "'1 ~ 92· L..- , I 4 t . I .... ------! 6 7' ~ .;> .r> r i··'" ; ¡ ;~ : I T- ; ¡-~ ,0 ¡'" y- 'm C> · - 3: !¡~ ..~3·~~ 2¡ . ... 18~'_ I I ..... -. - ~-- ...._~ ¿--: '..... ... o N ..... 7·~,~ ¡~, - .-- 1.---..: ~ ' , ./ ' -:......--::::::::: I ___-::.~ . ~- "_...C:-,::::=::Z:::::::::::-- S=CTlON 34 .Å SECT iON 33 r&TI ; J:'~~':"~~ ¡t, 1978 - ::;~::CT=:'J :J,:,:; CCNFJGUR~T;ON CE..'HlFICAE Or SURVEYOR I HEREBY CERTIFY THAT I t..'.1 ?ROPERLY REGISTËRED . AND LICENSED TO PRACTICE LAND SURVEYING IN ". -HE STATE 0F ALASKA AND THAT TH:S PLAT .EPRESENTS A LOCATION SURVEY MADE BY ME./ -;:~. J OR UNDER MY SUPERVISION. AND ALL DIMEI"/' - SIONS AND OTHER DETAILS ARE CORRECT, - - . : ~ .,; , f' DATE '-"~ -." - ; .- -; . :.... ,.. SURVEYOR 27 --=- T OF COORD/NATES FOR WELLS :#./ - #/4 AS -BUlL T WELL NO.. / - LAT. -¡d' /5·5742'· L1J!>I6 '480 .34' 29 963" WELL NO 2 - LAT 70· !5' 58 580 .. LONó/48° 34' 30. 668" WELL NO,3- LAT 70° /5' 59 737" __ ___{..OIIG wi' 34' 3'. 4U'· WELL No 4 - LAT 70' /b· '00. 891 ,. LoNG /48·34· 32 /4b" WELL:NO. 5 - LAr 70' /b' oz. 045" uJl/G /4B' 34' 32. B 78·· ~ WELL NO., 6 ~/t LAr 70' /b' 03.20/ " ~ LalfG, /48· 34 ' 33.598 .. .' WELL NO. 7 - !.AT. 70· /6' 04.354 ., Lolf6 14 e' 34' 34.327·· WELL NO 8 LAT 70· Ib' 05.506' Lolf& /48' 34' 35.048" 41 WELL NO. 9 LAT 70·/6'06.664'· lrJlfG. 148 ° 34' 35. 799" WELL NO. 10 - r.lA LAT. 70' 16' 07. 8/b·' .~."... /48' 34' 36 -u;· tJ0...l¥ LONG, . :> C\~ WELL NO.I/ - <:Q;;I§!T..J LAr 70·/b'08968" /,d'" LONG 148·34'37.239" ~ <X¡¿,( WELL NO. /2 - Lm". 70' /6' /0, /25" L()'I/G. 148' 34' 37. 957" ZONE: 4- r 5 948 887.99 X 676 229,68 r 5 949 005, 23 X 676 202 ' 03 'f 5 949 IZZ. /9 X ó7b /74,00 Y 5 949 238, 97 X 676 /4(, . 44 '( 5 949 355. 70 X 6 7 6 / I 8 . 57 '( 5 949 472. . 56 X 67b 09/ . 08 'f 5 949 589. 16 X 676 063.31 Y 5 949 705. 67 X 676 035 . 82 Y5949822 82 x 67b 007 25 Y 5 949 939 _ 3/ X 675 979 ,55 '( 5 950 055 .80 x 675 952 .33 Ý 5 950 /72. 87 X 675 924- 93 WELL NO. 13 - LAT 70· /b' 11.279" '( 5 950 289 .52 LON&. 148· 34' 38 699" X 675 8% .71 WEL L NO. /4 - LAT 70 . /6' 12 434" Y 5 950 40b . 37 L01l6 /48034' 39 4/2" X 675 669 .48 SURVEY DATE ARCO No. AFE JANUARY 5 I 1978 HVL No. ATLANTIC RICHFIELD CO. AS - BUILT DRILL SITE No.7 WELLS: I THRU 14 LOCATED IN PROTRACTED SECTION 33,TIIN, RI4 E,U.M. PREPARED BY HEWITT V. LOUNSBURY 8 ASSOC. 723 W. 6TH. AVE., ANCHORAGE, ALASKA DATE JAN 6, 1978 SCALE I" = 300' CHKD. BY G.D. '. j '" j ¡.:;, § I { co (It') o N c WELL PRODUCER WELL INJECTOR : I DATE: 09/21/2001 SCALE: 1" = 250' I MAP DATE: 1997 I 7 bs14495.dgn REFERENCE fNPORMA TION SURVEY PROGRAM Plan: 1-{)6B WPOól{)7-û6!Plan 07-0613) Depth Fm Dt.-pth To Sun<ey!P!an Too! Created By: Troy Jakabosky Date: 5/6/2004 7800.00 !OMXL99 Pianm.-æ 1-ooB WPflli V40 MWD Checked: Date Reviewed: Date-_ WELL DETAILS FORMATION TOP DETAILS ""'" 'N/..g -i-E/_W Nonhmg Broiting Latitude Longituo:k S!Ú! No. TVDPath MDPath Formation 07.06 l357.62 -!259.94 5949412.25 616090.79 7(1"!(j'03J98N !4Sº34'33.607W NlA 1 TARGET DETAILS 2 3 Name TVO +NI-S +E/~W Northing Eastìng Shape 4 5 595 .00 6 59~ .00 7 595 .51 595 .00 8 59: .74 9 595 .00 10 595 .00 11 12 13 SECTION DETAILS 14 IS See MD rue Azi TVD +NI-S +EI-W DLeg TFace VSec Target 16 1 7 2 7 3 8 4 8 5 9 6 9 7 9 07..o6B TI C 8 9 9 9 W 9 T2C I1 9 12 W T3C / ; """ ; ¡Z" T - ,1HZ , , 900 1200 ¡800 12' 600 Si.lß COMPANY DETAILS BPAII);0Çj) CASING DETAILS MD Name 7' 4 300 TVD 7500 8100 8400 8700 9000 No. 7!: ;¡"§ <:> <:> ~ oS Iì' o "ill " 1~ >- " e ¡-. Plan: 7¥06B WP06 (07.06/Plan 07·Q6B) Created By: Troy Jak1Ibosky Date: 516/2004 Cheçkcd: Date: WELL DETAILS SURVEY PROGRAM Depth Fm Depth To SurveyiP!an Too! 7800JJO H)4{J0.99 Planmxt 7..06B WP06 V40 MWD REFERENCE !NFORMA T!ON COMPANY DETAILS Sf> Amœü NaJre ->-Ní-S .fl·W Northing EMting Latitude .,.ongitucl:e SI, 07-Q6 1357,62 ,.1259.94 5949472.25 676ú9{}.79 70"1(j'{)3.198N !$"34'33.601W NfA TARGET DETAILS TVD +N!~S +EI-W Northing Eastìng Shape SECTION DETAILS TVD "N!~S +EI-W DLeg TFaee VSec Target 07-06B T! C 07-06B T2 C 07-06B T3 C FORMATION TOP DETAILS No. TVDPath MDPath FOffilation I 2 3 4 5 6 7 8 9 IO II 12 13 14 15 16 CASING DETAILS No. TVD MD Name Size I 7" 2 4I!2" III #2 Azi. Name Ine MD Sec I 2 3 4 5 6 7 8 9 IO II 12 "- >~, --- \ \ .-- ~~ \ 12' \ I \ v \ , , \ "'< J\ \ \ \\\: \\ \ \ \ \ \ . , \ \ \ \. . . . . \ \ , \ \. \ ~ - ^~ ~k \ \ ~~, \ v , "ç 'UD ~ , , \. \ \ \ . ,1:1<1 U· , \ \ , \ \\ \ ) \ \ k'U 23' - VI ,\ \ .'\ '.: ¿: q«r '\ \ / 9(~ ~- , \ ~ \ ¡tmt ~- \ I \\ \ , , \ \\ , ; \ \ I . ! \ > F- .. ,," - ....~ . k_.... . Æ I();, . . ;-1.. I , , j j 1 1 1 ! I J , , I I þ" I I 600 1800 500 900 800--- 300--- 600 90¡¡ o :? ¢: "" "" ~ +' l '" ~ :¡g- o " '" . BP Planning Report . Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 07 07-06 Plan 07-068 Date: 5/612004 Tune: 13:32:22 Page: Co-ordinate(NE) Reference: Well: 07-06, True North Vertical (TVD) Reference: 2ES 26.5 + 28.5 55.0 Section (VS) Reference: Well (0.OON,O.00E,13.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 7-068 WP06 Date Composed: Version: Tied-to: Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: P8 DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft 677382.28 ft Latitude: 70 15 Longitude: 148 33 North Reference: Grid Convergence: Well: 07-06 Slot Name: 07-06 Well Position: +N/-S 1357.62 ft Northing: 5949472.25 ft Latitude: +E/-W -1259.94 ft Easting: 676090.79 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan 07-068 500292029402 Current Datum: 2ES 26.5 + 28.5 Magnetic Data: 9/9/2003 Field Strength: 57576 nT Vertical Section: Depth From (TVD) ft 28.00 Height 55.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Casing Points 4/9/2004 40 From: Definitive Path Alaska, Zone 4 Well Centre bggm2003 49.847 N 56.934 W True 1.35 deg 70 16 3.198 N 148 34 33.607 W 07-06 7800.00 ft Mean Sea Level 25.61 deg 80.85 deg Direction deg 13.00 MD TVD Diameter Hole Size Name ft ft in in 8822.62 8452.00 7.000 8.500 7" 10400.00 9020.01 4.500 6.125 41/2" Formations MD TVD Formations Lltlaology DipAng1e Pip Qirèction ft ft deg deg 7896.63 7713.00 THRZ 0.00 0.00 8082.63 7865.00 BHRZ 0.00 0.00 8120.45 7895.00 TKNG 0.00 0.00 8580.58 8260.00 TJB 0.00 0.00 8709.16 8362.00 TJA 0.00 0.00 8822.62 8452.00 TSGR 0.00 0.00 8864.22 8485.00 TSHU 0.00 0.00 8960.03 8561.00 TSAD 0.00 0.00 9179.11 8725.00 TCGL 0.00 0.00 9289.29 8801.00 8CGL 0.00 0.00 9378.00 8861.00 23S8 0.00 0.00 9397.91 8874.00 25N 0.00 0.00 9447.04 8905.00 24N 0.00 0.00 9456.88 8911.00 22TS 0.00 0.00 9526.59 8951.00 22N 0.00 0.00 9557.67 8967.00 21TS 0.00 0.00 0.00 TZ1B 0.00 0.00 0.00 HOT 0.00 0.00 CQmpany: Field: Site: Well: Wellpath: Targets . . BP Planning Report 8P Amoco Prudhoe 8ay P8 DS 07 07-06 Plan 07-068 Date: 5/612004 Time: 13:32:22 Page: Co-ordinate(NE) Reference: Well: 07-06, True North Vertical (TVD) Reference: 2ES 26.5 + 28.5 55.0 SeetiQn (VS) Reference: Well (0.00N,O.OOE,13.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map ~ap ~Latitude ..--.> "'-~Dgitude Name Description TVD +N/-S +E/-W Northing Easting Deg M¡ø See pegMin See Dip. Dir. ft ft ft ft ft 07-068 T1 C 8954.00 583.57 1683.43 5950095.00 677760.00 70 16 8.935 N 148 33 44.603 W 07-068 Poly 9005.00 671.48 1560.44 5950180.00 677635.00 70 16 9.800 N 148 3348.183 W -Polygon 1 9005.00 671.48 1560.44 5950180.00 677635.00 70 16 9.800 N 1483348.183W -Polygon 2 9005.00 1351.75 1131.21 5950850.00 677190.00 70 16 16.491 N 148 34 0.675 W -Polygon 3 9005.00 1447.87 1298.52 5950950.00 677355.00 70 16 17.436 N 148 3355.803 W -Polygon 4 9005.00 753.30 1697.40 5950265.00 677770.00 70 16 10.605 N 148 33 44.195 W 07-068 T3 C 9020.00 1330.00 1270.00 5950831.51 677329.25 70 16 16.277 N 148 3356.634 W 07-06B Fault #3 9021.00 1621.11 1162.52 5951120.00 677215.00 70 16 19.140 N 148 33 59.762 W -Polygon 1 9021.00 1621.11 1162.52 5951120.00 677215.00 70 16 19.140 N 148 33 59.762 W -Polygon 2 9021.00 1810.31 771.81 5951300.00 676820.00 70 16 21.002 N 148 3411.136 W 07-068 T2 C 9024.00 899.00 1530.00 5950406.74 677599.24 70 16 12.038 N 148 33 49.068 W 07-068 Fault #1 9026.00 975.42 1182.42 5950475.00 677250.00 70 16 12.790 N 1483359.185W -Polygon 1 9026.00 975.42 1182.42 5950475.00 677250.00 70 16 12.790 N 148 33 59.185 W -Polygon 2 9026.00 164.48 1638.61 5949675.00 677725.00 70 16 4.814 N 148 3345.911 W 07-068 Fault #2 9028.00 1073.82 1679.89 5950585.00 677745.00 70 16 13.757 N 148 3344.703 W -Polygon 1 9028.00 1073.82 1679.89 5950585.00 677745.00 70 16 13.757 N 148 33 44.703 W -Polygon 2 9028.00 1809.98 1427.03 5951315.00 677475.00 70 1620.998 N 148 33 52.060 W Plan Section InfQrmatiQn MD ft 7800.00 7820.00 8044.87 8946.16 9161.77 9189.10 9532.18 9786.01 9887.98 9897.62 9899.64 10400.99 Survey MD ft 7800.00 7820.00 7896.63 7900.00 7904.12 8000.00 8044.87 8082.63 8100.00 8120.45 8200.00 8300.00 8400.00 8500.00 8580.58 Incl Azim TV» +N/-S +E/-W DLS 8.lIild Turn TFO deg deg ft ft ft deg/1QOftdegl10OO deg/10OO d~ 26.20 89.14 7628.93 258.02 809.72 0.00 0.00 0.00 0.00 28.54 87.93 7646.69 258.26 818.91 12.00 11.67 -6.08 -14.00 37.51 89.09 7835.04 261.29 941.29 4.00 3.99 0.52 4.53 37.51 89.09 8550.00 270.00 1490.00 0.00 0.00 0.00 0.00 46.79 45.47 8713.13 327.48 1614.54 14.00 4.30 -20.23 -89.82 46.79 45.47 8731.84 341.45 1628.74 0.00 0.00 0.00 0.00 57.75 344.95 8954.00 583.57 1683.43 14.00 3.20 -17.64 -98.03 89.99 329.11 9024.01 803.23 1587.30 14.00 12.70 -6.24 -28.01 89.99 329.11 9024.04 890.73 1534.95 0.00 0.00 0.00 0.00 90.46 329.00 9024.00 899.00 1530.00 5.00 4.86 -1.16 -13.39 90.46 328.90 9023.98 900.73 1528.96 5.00 0.00 -5.00 -90.00 90.46 328.90 9020.00 1330.00 1270.00 0.00 0.00 0.00 0.00 Target 07-068 T1 C 07-068 T2 C 07-068 T3 C Incl Azim TV» N/S E/W DLS Build Turn deg deg ft ft ft deg/10OO deg/100ft deg/~OOO 26.20 89.14 7628.93 258.02 809.72 0.00 0.00 0.00 Start Dir 12/100' : 7800' 28.54 87.93 7646.69 258.26 818.91 12.00 11.67 -6.08 Start Dir 10/100' : 7820' 31.59 88.39 7713.00 259.48 857.27 4.00 3.99 0.60 THRZ 31.73 88.41 7715.87 259.53 859.04 4.00 3.99 0.55 MWD 31.89 88.43 7719.37 259.59 861.21 4.00 3.99 0.54 End Dir : 7904.12' MD, 7 35.72 88.90 7799.03 260.82 914.53 4.00 3.99 0.49 MWD 37.51 89.09 7835.04 261.29 941.29 4.00 3.99 0.42 MWD 37.51 89.09 7865.00 261.66 964.28 0.00 0.00 0.00 8HRZ 37.51 89.09 7878.78 261.82 974.85 0.00 0.00 0.00 MWD 37.51 89.09 7895.00 262.02 987.31 0.00 0.00 0.00 TKNG 37.51 89.09 7958.10 262.79 1035.73 0.00 0.00 0.00 MWD 37.51 89.09 8037.43 263.76 1096.61 0.00 0.00 0.00 MWD 37.51 89.09 8116.75 264.72 1157.50 0.00 0.00 0.00 MWD 37.51 89.09 8196.08 265.69 1218.38 0.00 0.00 0.00 MWD 37.51 89.09 8260.00 266.47 1267.43 0.00 0.00 0.00 TJB . . BP Planning Report Company: BP Amoco Date:· 5/6/2004 Time: 13;32:22 Page: 3 Field: Prudhoe Bay Co-Orciinate(NE) Jlef~re!,-ee: Well: ONI6,Jru13North Site: PB DS 07 Vert¡eal (TVD) Refere!Jee: 2ES26~5+.~8.5 55.0 Well: 07-06 Seetion (VS) Referenee~ Well (0~OQN.0;0()E,13.00Azi) Wellpath: Plan 07 -06B Survey Calculation ~~hod: MinimomCorvature Db: Oracle Survey MD Inel Azim TVD N/S EIW DLS Bond Torn Tool/Comment ft deg deg ft ft deg/1 00ft i~eg/100ft degl100ft 8600.00 37.51 89.09 8275.41 266.65 1279.26 0.00 0.00 0.00 MWD 8700.00 37.51 89.09 8354.73 267.62 1340.14 0.00 0.00 0.00 MWD 8709.16 37.51 89.09 8362.00 267.71 1345.72 0.00 0.00 0.00 TJA 8800.00 37.51 89.09 8434.06 268.59 1401.02 0.00 0.00 0.00 MWD 8822.62 37.51 89.09 8452.00 268.81 1414.79 0.00 0.00 0.00 7" 8864.22 37.51 89.09 8485.00 269.21 1440.11 0.00 0.00 0.00 TSHU 8900.00 37.51 89.09 8513.38 269.55 1461.90 0.00 0.00 0.00 MWD 8945.66 37.51 89.09 8549.60 270.00 1489.70 0.00 0.00 0.00 Start Dir 14/100' : 8945. 8946.16 37.51 89.09 8550.00 270.00 1490.00 0.00 0.00 0.00 MWD 8950.00 37.51 88.21 8553.05 270.06 1492.34 14.00 0.13 -22.99 MWD 8960.03 37.56 85.90 8561.00 270.37 1498.44 14.00 0.44 -22.97 TSAD 8975.00 37.71 82.48 8572.86 271.29 1507.53 14.00 0.99 -22.87 MWD 9000.00 38.17 76.84 8592.58 274.06 1522.64 14.00 1.87 -22.57 MWD 9025.00 38.90 71.34 8612.14 278.33 1537.60 14.00 2.92 -21.98 MWD 9050.00 39.88 66.04 8631.47 284.09 1552.37 14.00 3.91 -21.19 MWD 9075.00 41.09 60.98 8650.49 291.34 1566.88 14.00 4.84 -20.24 MWD 9100.00 42.51 56.18 8669.13 300.03 1581.09 14.00 5.68 -19.20 MWD 9125.00 44.12 51.65 8687.32 310.13 1594.93 14.00 6.44 -18.13 MWD 9150.00 45.90 47.39 8705.00 321.61 1608.37 14.00 7.11 -17.06 MWD 9158.25 46.52 46.04 8710.71 325.69 1612.70 14.00 7.52 -16.36 End Dir : 9158.25' MD, 8 9161.77 46.79 45.47 8713.13 327.48 1614.54 14.00 7.65 -16.12 MWD 9179.11 46.79 45.47 8725.00 336.34 1623.55 0.00 0.00 0.00 TCGL 9184.44 46.79 45.47 8728.65 339.06 1626.31 0.00 0.00 0.00 Start Dir 14/100' : 9184. 9189.10 46.79 45.47 8731.84 341.45 1628.74 0.00 0.00 0.00 MWD 9200.00 46.59 43.39 8739.32 347.11 1634.29 14.00 -1.78 -19.08 MWD 9225.00 46.29 38.58 8756.55 360.78 1646.16 14.00 -1.21 -19.25 MWD 9250.00 46.19 33.73 8773.85 375.35 1656.81 14.00 -0.39 -19.38 MWD 9275.00 46.30 28.89 8791.14 390.77 1666.19 14.00 0.42 -19.38 MWD 9289.29 46.45 26.13 8801.00 399.94 1670.96 14.00 1.07 -19.29 BCGL 9300.00 46.61 24.08 8808.37 406.98 1674.26 14.00 1.47 -19.19 MWD 9325.00 47.12 19.33 8825.47 423.92 1681.00 14.00 2.04 -18.98 MWD 9350.00 47.82 14.68 8842.38 441.53 1686.38 14.00 2.80 -18.62 MWD 9375.00 48.70 10.14 8859.02 459.74 1690.38 14.00 3.54 -18.16 MWD 9378.00 48.82 9.60 8861.00 461.96 1690.77 14.00 3.93 -17.87 23SB 9397.91 49.66 6.09 8874.00 476.89 1692.82 14.00 4.24 -17.61 25N 9400.00 49.76 5.73 8875.35 478.48 1692.99 14.00 4.54 -17.36 MWD 9425.00 50.98 1.47 8891.30 497.69 1694.19 14.00 4.88 -17.04 MWD 9447.04 52.18 357.84 8905.00 514.95 1694.08 14.00 5.44 -16.47 24N 9450.00 52.35 357.36 8906.81 517.29 1693.98 14.00 5.73 -16.15 MWD 9456.88 52.75 356.26 8911.00 522.75 1693.68 14.00 5.83 -16.03 22TS 9475.00 53.85 353.41 8921.83 537.21 1692.37 14.00 6.10 -15.72 MWD 9500.00 55.49 349.62 8936.29 557.37 1689.36 14.00 6.52 -15.19 MWD 9525.00 57.23 345.97 8950.14 577.71 1684.95 14.00 6.98 -14.58 MWD 9526.59 57.34 345.74 8951.00 579.01 1684.62 14.01 7.20 -14.28 22N 9532.18 57.75 344.95 8954.00 583.57 1683.43 14.01 7.26 -14.19 07-068 T1 C 9550.00 59.96 343.60 8963.22 598.25 1679.29 14.00 12.40 -7.59 MWD 9557.67 60.92 343.03 8967.00 604.64 1677.38 14.00 12.46 -7.35 21TS 9575.00 63.08 341.80 8975.14 619.22 1672.75 14.00 12.50 -7.13 MWD 9600.00 66.23 340.09 8985.84 640.57 1665.38 14.00 12.58 -6.81 MWD 9625.00 69.39 338.47 8995.28 662.22 1657.19 14.00 12.65 -6.49 MWD 9650.00 72.56 336.92 9003.43 684.08 1648.21 14.00 12.70 -6.22 MWD 9655.35 73.24 336.59 9005.00 688.78 1646.20 14.00 12.73 -6.09 07-06B Poly . Company: BP Amoco Field: Prudhoe Bay Site: PB DS 07 Well: 07-06 Wellpath: Plan 07-06B Survey MD Incl Azim TVD ft deg deg ft 9675.00 75.75 335.41 9010.25 9700.00 78.95 333.95 9015.73 9725.00 82.15 332.53 9019.83 9750.00 85.36 331.12 9022.55 9775.00 88.57 329.72 9023.87 9785.49 89.92 329.14 9024.01 9786.01 89.99 329.11 9024.01 9800.00 89.99 329.11 9024.02 9887.46 89.99 329.11 9024.04 9887.98 89.99 329.11 9024.04 9897.62 90.46 329.00 9024.00 9899.11 90.46 328.93 9023.99 9899.64 90.46 328.90 9023.98 10000.00 90.46 328.90 9023.19 10100.00 90.46 328.90 9022.39 10200.00 90.46 328.90 9021.60 10300.00 90.46 328.90 9020.80 10400.00 90.46 328.90 9020.01 10400.46 ~.46 328.90 9020.00 10400.99 90.46 328.90 9020.00 . BP Planning Report Date: 5/6/2004 Time: 13:32:22 Page: 4 Co-ordiJIate(NE) Reference: Well: 07-06, True North Vertical (TVD) Reference: 2ES 26.5 + 28.5 55.0 Section (VS) Reference: Well (0.00N,O.00E,13.00Azi) Survey Calculadon Method: Minimum Curvature Db: Oracle N/S E/W DLS BuDd Turn ft ft deg/100ft deg/1000 degl100ft 706.08 1638.49 14.00 12.76 -5.99 MWD 728.12 1628.06 14.00 12.79 -5.84 MWD 750.14 1616.96 14.00 12.81 -5.72 MWD 772.04 1605.23 14.00 12.83 -5.63 MWD 793.75 1592.90 14.00 12.84 -5.58 MWD 802.78 1587.57 14.00 12.85 -5.56 End Dir : 9785.49' MD, 9 803.23 1587.30 14.00 12.85 -5.56 MWD 815.23 1580.12 0.00 0.00 0.00 MWD 890.29 1535.22 0.00 0.00 0.00 Start Dir 5/100' : 9887.4 890.73 1534.95 0.00 0.00 0.00 MWD 899.00 1530.00 5.00 4.86 -1.16 07 -06B T2 C 900.28 1529.23 5.00 0.00 -5.00 End Dir : 9899.11' MD, 9 900.73 1528.96 5.00 0.00 -5.00 MWD 986.66 1477.12 0.00 0.00 0.00 MWD 1072.29 1425.47 0.00 0.00 0.00 MWD 1157.91 1373.81 0.00 0.00 0.00 MWD 1243.53 1322.16 0.00 0.00 0.00 MWD 1329.16 1270.51 0.00 0.00 0.00 4 1/2" 1329.55 1270.27 0.00 0.00 0.00 Total Depth: 10400.46' M 1330.00 1270.00 0.00 0.00 0.00 07-06B T3 C WELL DETAIL') Name ~·N!··S Northing ¡~sciflg Latitude Longitutk Slot 07-<)(, !35Hi2 -1259.94 594947:2,25 676090.79 70"16'Ú],198N !4W'J4'J3.607W NlA -640 -600 --SOO -400 -300 -200 ~ '" '" -100 ,.:. s '" '" ,.:. <:> 0 -100 -200 -300 -400 --SOO -600 -640 ANTI-COLLlSION SETTINGS COMPANY DETAILS lnterpolation Mcthod:MD Depth Range From: 7800.00 Maximum Range: 1237.30 BP Amoco Interval: 25.00 To: 10400.99 Reference: PIan: 7-06B WP06 SURVEY PROGR)\M 1À)!h Fm Depth To Su:rv¡.-"y,fj)!an 7800.00 !û4M.99 ?1ann;.>d: 7-06B WPO(í V4{} -- - -------------------1 Too' MWD WELLpA TH DETA,IU From Colour ToMD Plan07-iJóB 500292029402 0 0 P'øe¡-¡IWcl!path: 07-06 0 500 Tie¡m¡-"fi); 7800.00 500 1000 Rig; 1000 1500 Ref Datum: 1ES26.5 ",235 55.00f!: 1500 2000 O!igin Origìu Sœrting 2000 2500 "w·s -E,i-W FfOlnTVD 2500 3000 B.ow' 0.00 n.oo 28.00 3000 3500 3500 4000 4000 4500 LEGEND 4500 5500 5500 6500 6500 7500 o 7500 8500 8500 9500 9500 10500 10500 11500 90 s" MD illc Azi , , 3 4 5 6 7 . 9 10 IJ 12 TVD SECTiON DE-TAILS +N!-$ -¡-E/..W DLcg TFaœ VSÜC Target 07-ð6B 1'1 C 07..Q6BTl-G Q7..fi6BT3C . . BP Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB DS 07 07-06 Plart07-06B Date:5/612004 Time: ··13:44:09 Co-ordinate(NE) Reference: Well: 07-06, True North Vertical (TVD) Reference: 2ES 26.5 + 28.5 55.0 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ar~"ells in thB~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 7800.00 to 10400.99 ft Scan Method: Trav Cylinder North Maximum Radius: 1237.30 ft Error Suñace: Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/9/2003 Validated: No Version: 4 Planned From To Survey Toolcode ft ft 91.00 7800.00 1 : Camera based gyro multisho (91.00-966G;~0-MS 7800.00 10400.99 Planned: 7-06B WP06 V40 MWD Tool Name Camera based gyro multishot MWD - Standard Casing Points MD TVD Diameter Hole Size Name. ft ft in in 8822.62 8452.00 7.000 8.500 7" 10400.00 9020.01 4.500 6.125 41/2" Summary < Offset Wellpath ~ Reference Offset Or-Ctr No-Go AlIøw~~W Site Well Wellpath MD MD Distance Area Deviation \yanî~g ft ft ft ft ft PB DS 07 07-06 07-06 V3 7816.00 7825.00 0.22 0.00 0.22 Pass: NOERRORS PB DS 07 07-06 07-06A V1 7816.00 7825.00 0.22 0.00 0.22 Pass: NOERRORS PB DS 07 07-08 07-08 V2 Out of range PB DS 07 07-08A 07-08A V2 Out of range PB DS 07 07-15 07-15 V1 Out of range PB DS 07 07-15A 07-15A V5 Out of range PB DS 07 07-17 07-17 V1 Out of range PB DS 07 07-21 07-21 V1 Out of range PB DS 07 07-35 07-35 V4 8103.59 8050.00 338.36 134.68 203.68 Pass: Major Risk Site: PB DS 07 Well: 07-06 Rule Assigned: NOERRORS Wellpath: 07-06 V3 Inter-Site Error: 0.00 ft Referenèe Offset Semi-Major Axis . ... . . çtr-Ctr NO-Go Allowablê MD TVD MD TVD Ref Offsèt TFO+AZI TFO-HS CasingIHS)i$ta~ce Ar~ DeViation )V'rning ft ft ft ft ft ft deg deg in ft ft ft 7816.00 7643.16 7825.00 7652.26 37.63 37.82 248.04 159.88 9.625 0.22 0.00 0.22 Pass 7840.97 7665.04 7850.00 7674.57 37.64 38.32 248.39 160.32 9.625 1.16 0.00 1.16 Pass 7865.91 7686.67 7875.00 7696.76 37.61 38.82 248.92 160.70 9.625 2.30 0.00 2.30 Pass 7890.83 7708.06 7900.00 7718.84 37.58 39.33 249.38 161.02 9.625 3.63 0.00 3.63 Pass 7915.71 7729.19 7925.00 7740.85 37.55 39.88 250.52 162.03 9.625 5.23 0.00 5.23 Pass 7940.53 7750.04 7950.00 7762.81 37.52 40.42 252.29 163.67 9.625 7.15 0.00 7.14 Pass 7965.30 7770.61 7975.00 7784.74 37.50 40.97 254.12 165.38 9.625 9.39 0.00 9.39 Pass 7989.99 7790.88 8000.00 7806.62 37.47 41.52 255.82 166.97 9.625 11.97 0.00 11.97 Pass 8014.59 7810.83 8025.00 7828.47 37.44 42.08 257.07 168.11 9.625 14.91 0.00 14.91 Pass 8039.10 7830.46 8050.00 7850.27 37.41 42.64 257.79 168.72 9.625 18.21 0.00 18.21 Pass 8063.77 7850.04 8075.00 7872.04 37.42 43.23 258.08 168.99 9.625 21.76 0.00 21.76 Pass 8088.52 7869.67 8100.00 7893.77 37.43 43.83 257.96 168.87 9.625 25.27 0.00 25.27 Pass 8113.28 7889.31 8125.00 7915.45 37.45 44.44 257.59 168.50 9.625 28.73 0.00 28.73 Pass 8138.05 7908.96 8150.00 7937.10 37.47 45.05 257.07 167.98 9.625 32.14 0.00 32.14 Pass 8162.82 7928.61 8175.00 7958.70 37.49 45.66 256.45 167.36 9.625 35.51 0.00 35.51 Pass 8187.59 7948.26 8200.00 7980.26 37.51 46.27 255.74 166.65 9.625 38.83 0.00 38.83 Pass 8212.37 7967.91 8225.00 8001.77 37.53 46.90 254.95 165.86 9.625 42.10 0.00 42.10 Pass 8237.16 7987.58 8250.00 8023.21 37.56 47.54 254.06 164.97 9.625 45.29 0.00 45.28 Pass 8261.95 8007.24 8275.00 8044.57 37.59 48.18 253.08 163.99 9.625 48.41 0.00 48.40 Pass 8286.74 8026.91 8300.00 8065.87 37.61 48.82 252.04 162.95 9.625 51.46 0.00 51.46 Pass 8311.54 8046.58 8325.00 8087.11 37.64 49.47 250.92 161.83 9.625 54.49 0.00 54.49 Pass 8336.32 8066.24 8350.00 8108.30 37.67 50.13 249.73 160.64 9.625 57.55 0.00 57.55 Pass . . BP Anticollision Report Company: BP Amoco Date: 5/6/2004 Time:/.t3:44;09 Page: Z Field: Prudhoe Bay Reference Site: PB DS 07 Co-ordinaJe(NEJReference: Well: 07-06, True~orPj Reference Well: 07..Q6 Vertic"('J'YJ» Reference: 2ES26.S + 28.S/S.S:0 Reference Wellpath: Plan 07-06B Site: PB DS 07 Well: 07-06 Rule Assigned: NOERRORS Wellpath: 07-06 V3 Inter-Site Error: 0.00 ft Referenee Offset Semi-Major~is MD TVD MD TVD Ref OØšèt TFO+AZI TFO-HS ft ft ft ft deg deg in 8361.10 8085.89 8375.00 8129.45 37.71 50.79 248.48 159.39 9.625 60.64 0.00 60.64 Pass 8385.86 8105.54 8400.00 8150.56 37.74 51.46 247.18 158.09 9.625 63.77 0.00 63.77 Pass 8410.61 8125.17 8425.00 8171.61 37.77 52.13 245.83 156.74 9.625 66.93 0.00 66.93 Pass 8435.35 8144.80 8450.00 8192.59 37.81 52.82 244.41 155.32 9.625 70.11 0.00 70.11 Pass 8460.07 8164.41 8475.00 8213.49 37.85 53.50 242.94 153.85 9.625 73.33 0.00 73.33 Pass 8484.78 8184.01 8500.00 8234.31 37.89 54.18 241.43 152.34 7.000 76.59 0.00 76.59 Pass 8509.47 8203.60 8525.00 8255.06 37.93 54.89 239.90 150.81 7.000 79.89 0.00 79.89 Pass 8534.16 8223.18 8550.00 8275.74 37.97 55.61 238.38 149.29 7.000 83.21 0.00 83.21 Pass 8558.83 8242.75 8575.00 8296.33 38.02 56.32 236.86 147.77 7.000 86.57 0.00 86.57 Pass 8583.49 8262.31 8600.00 8316.85 38.06 57.04 235.34 146.25 7.000 89.96 0.00 89.96 Pass 8608.13 8281.86 8625.00 8337.31 38.11 57.78 233.85 144.76 7.000 93.40 0.00 93.40 Pass 8632.77 8301.40 8650.00 8357.71 38.16 58.53 232.40 143.31 7.000 96.91 0.00 96.91 Pass 8657.39 8320.93 8675.00 8378.07 38.21 59.27 230.98 141.89 7.000 100.49 0.00 100.48 Pass 8682.00 8340.45 8700.00 8398.39 38.26 60.02 229.61 140.51 7.000 104.13 0.00 104.13 Pass 8706.58 8359.96 8725.00 8418.69 38.32 60.76 228.26 139.17 7.000 107.94 0.00 107.94 Pass 8731.13 8379.42 8750.00 8439.00 38.37 61.51 226.97 137.88 7.000 112.00 0.00 112.00 Pass 8755.63 8398.86 8775.00 8459.34 38.43 62.25 225.72 136.63 7.000 116.31 0.00 116.31 Pass 8780.08 8418.26 8800.00 8479.68 38.48 63.00 224.51 135.42 7.000 120.88 0.00 120.88 Pass 8804.50 8437.63 8825.00 8500.05 38.54 63.72 223.38 134.29 7.000 125.65 0.00 125.65 Pass 8828.90 8456.98 8850.00 8520.45 38.60 64.44 222.34 133.25 7.000 130.57 0.00 130.57 Pass 8853.27 8476.32 8875.00 8540.88 38.67 65.16 221.37 132.28 7.000 135.64 0.00 135.64 Pass 8877.63 8495.64 8900.00 8561.35 38.73 65.89 220.48 131.39 7.000 140.85 0.00 140.85 Pass 8901.99 8514.96 8925.00 8581.81 38.79 66.62 219.66 130.57 7.000 146.10 0.00 146.10 Pass 8926.36 8534.29 8950.00 8602.24 38.86 67.36 218.88 129.79 7.000 151.29 0.00 151.29 Pass 8949.70 8552.81 8975.00 8622.64 38.97 68.12 217.97 129.69 7.000 156.42 0.00 156.42 Pass 8968.27 8567.53 9000.00 8643.01 39.25 68.90 216.23 132.21 7.000 162.08 0.00 162.08 Pass 8986.41 8581.87 9025.00 8663.38 39.46 69.53 214.34 134.45 7.000 168.61 0.00 168.61 Pass 9004.05 8595.76 9050.00 8683.78 39.60 70.01 212.36 136.43 7.000 176.08 0.00 176.08 Pass 9021.14 8609.13 9075.00 8704.21 39.67 70.37 210.34 138.17 7.000 184.48 0.00 184.48 Pass 9037.65 8621.96 9100.00 8724.68 39.66 70.61 208.31 139.68 7.000 193.80 0.00 193.79 Pass 9053.56 8634.20 9125.00 8745.16 39.61 70.72 206.29 140.99 7.000 203.99 0.00 203.98 Pass 9068.86 8645.85 9150.00 8765.66 39.50 70.73 204.31 142.11 7.000 215.02 0.00 215.02 Pass 9083.53 8656.89 9175.00 8786.18 39.35 70.65 202.38 143.07 7.000 226.87 0.00 226.87 Pass 9097.58 8667.34 9200.00 8806.72 39.17 70.50 200.52 143.89 7.000 239.49 0.00 239.49 Pass 9110.99 8677.19 9225.00 8827.24 38.94 70.28 198.73 144.57 7.000 252.89 0.00 252.89 Pass 9123.75 8686.42 9250.00 8847.74 38.71 70.00 197.00 145.13 7.000 267.07 0.00 267.07 Pass 9135.86 8695.07 9275.00 8868.20 38.43 69.69 195.35 145.59 7.000 281.98 0.00 281.98 Pass 9147.35 8703.15 9300.00 8888.63 38.16 69.35 193.78 145.96 7.000 297.59 0.00 297.58 Pass 9158.26 8710.71 9325.00 8909.03 37.88 68.97 192.29 146.26 7.000 313.79 0.00 313.79 Pass 9173.75 8721.33 9350.00 8929.40 37.81 69.21 191.23 145.76 7.000 330.42 0.00 330.42 Pass 9190.98 8733.12 9375.00 8949.74 37.80 69.65 190.30 145.19 7.000 347.15 0.00 347.15 Pass 9203.61 8741.80 9400.00 8970.05 37.45 69.33 188.75 146.06 7.000 364.12 0.00 364.12 Pass 9215.69 8750.12 9425.00 8990.32 37.08 68.93 187.23 146.86 7.000 381.42 0.00 381.42 Pass 9227.23 8758.09 9450.00 9010.56 36.71 68.63 185.74 147.60 7.000 399.05 0.00 399.05 Pass 9238.23 8765.70 9475.00 9030.77 36.33 68.41 184.29 148.28 7.000 417.00 0.00 417.00 Pass 9248.73 8772.96 9500.00 9050.95 35.97 68.12 182.89 148.91 7.000 435.26 0.00 435.26 Pass 9258.73 8779.89 9525.00 9071.09 35.58 67.89 181.52 149.48 7.000 453.82 0.00 453.82 Pass 9268.26 8786.48 9550.00 9091.21 35.21 67.67 180.20 150.01 7.000 472.66 0.00 472.66 Pass 9277.35 8792.76 9575.00 9111.29 34.85 67.46 178.93 150.50 7.000 491.78 0.00 491.78 Pass 9286.00 8798.73 9600.00 9131.33 34.49 67.27 177.70 150.94 7.000 511.16 0.00 511.16 Pass 9294.25 8804.42 9625.00 9151.36 34.14 67.13 176.52 151.34 7.000 530.78 0.00 530.78 Pass . . BP Anticollision Report Company: BP Amoco Date: 3 Field: Prudhoe Bay Reference Site: PB DS 07 Reference Well: 07-06 Reference Wellpath: Plan 07-06B Site: PB DS 07 Well: 07-06 Rule Assigned: NOERRORS Wellpath: 07-06 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis ...... . .Ctr-Ctr . ...I.'í~ MD TVD MD TVD Ref Offset TFG+AZI TFo-ns Casii1g/HS>lstance A.rea ft ft ft ft ft ft deg deg in ft ft 9302.13 8809.84 9650.00 9171.40 33.79 67.02 175.38 151.72 7.000 550.63 0.00 550.63 Pass 9309.66 8815.00 9675.00 9191.43 33.45 66.93 174.30 152.06 570.71 0.00 570.71 Pass Site: PB DS 07 Well: 07-06 Rule Assigned: NOERRORS Well path: 07-06A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis çtr,.ç~ ·No-Gô ,Allowable MD TVD MD TVD Ref Offset TFG+AZlTFO-HS CasinglllS>istance ·A.te. Deviation ft ft ft ft ft ft deg deg in ft ft 7816.00 7643.16 7825.00 7652.26 37.63 37.82 248.04 159.88 9.625 0.22 0.00 0.22 Pass 7840.97 7665.04 7850.00 7674.57 37.64 38.32 248.39 160.32 9.625 1.16 0.00 1.16 Pass 7865.91 7686.67 7875.00 7696.76 37.61 38.82 248.92 160.70 9.625 2.30 0.00 2.30 Pass 7890.83 7708.06 7900.00 7718.84 37.58 39.33 249.38 161.02 9.625 3.63 0.00 3.63 Pass 7915.71 7729.19 7925.00 7740.85 37.55 39.88 250.52 162.03 9.625 5.23 0.00 5.23 Pass 7940.53 7750.04 7950.00 7762.81 37.52 40.42 252.29 163.67 9.625 7.15 0.00 7.14 Pass 7965.30 7770.61 7975.00 7784.74 37.50 40.97 254.12 165.38 9.625 9.39 0.00 9.39 Pass 7989.99 7790.88 8000.00 7806.62 37.47 41.52 255.82 166.97 9.625 11.97 0.00 11.97 Pass 8014.59 7810.83 8025.00 7828.47 37.44 42.08 257.07 168.11 9.625 14.91 0.00 14.91 Pass 8039.10 7830.46 8050.00 7850.27 37.41 42.64 257.79 168.72 9.625 18.21 0.00 18.21 Pass 8063.77 7850.04 8075.00 7872.04 37.42 43.23 258.08 168.99 9.625 21.76 0.00 21.76 Pass 8088.52 7869.67 8100.00 7893.77 37.43 43.83 257.96 168.87 9.625 25.27 0.00 25.27 Pass 8113.28 7889.31 8125.00 7915.45 37.45 44.44 257.59 168.50 9.625 28.73 0.00 28.73 Pass 8138.05 7908.96 8150.00 7937.10 37.47 45.05 257.07 167.98 9.625 32.14 0.00 32.14 Pass 8162.82 7928.61 8175.00 7958.70 37.49 45.66 256.45 167.36 9.625 35.51 0.00 35.51 Pass 8187.59 7948.26 8200.00 7980.26 37.51 46.27 255.74 166.65 9.625 38.83 0.00 38.83 Pass 8212.37 7967.91 8225.00 8001.77 37.53 46.90 254.95 165.86 9.625 42.10 0.00 42.10 Pass 8237.16 7987.58 8250.00 8023.21 37.56 47.54 254.06 164.97 9.625 45.29 0.00 45.28 Pass 8261.95 8007.24 8275.00 8044.57 37.59 48.18 253.08 163.99 9.625 48.41 0.00 48.40 Pass 8286.74 8026.91 8300.00 8065.87 37.61 48.82 252.04 162.95 9.625 51.46 0.00 51.46 Pass 8311.54 8046.58 8325.00 8087.11 37.64 49.47 250.92 161.83 9.625 54.49 0.00 54.49 Pass 8336.32 8066.24 8350.00 8108.30 37.67 50.13 249.73 160.64 9.625 57.55 0.00 57.55 Pass 8361.10 8085.89 8375.00 8129.45 37.71 50.79 248.48 159.39 9.625 60.64 0.00 60.64 Pass 8385.86 8105.54 8400.00 8150.56 37.74 51.46 247.18 158.09 9.625 63.77 0.00 63.77 Pass 8410.61 8125.17 8425.00 8171.61 37.77 52.13 245.83 156.74 9.625 66.93 0.00 66.93 Pass 8435.35 8144.80 8450.00 8192.59 37.81 52.82 244.41 155.32 9.625 70.11 0.00 70.11 Pass 8460.07 8164.41 8475.00 8213.49 37.85 53.50 242.94 153.85 9.625 73.33 0.00 73.33 Pass 8484.78 8184.01 8500.00 8234.31 37.89 54.18 241.43 152.34 7.000 76.59 0.00 76.59 Pass 8509.47 8203.60 8525.00 8255.06 37.93 54.89 239.90 150.81 7.000 79.89 0.00 79.89 Pass 8534.16 8223.18 8550.00 8275.74 37.97 55.61 238.38 149.29 7.000 83.21 0.00 83.21 Pass 8558.83 8242.75 8575.00 8296.33 38.02 56.32 236.86 147.77 7.000 86.57 0.00 86.57 Pass 8583.49 8262.31 8600.00 8316.85 38.06 57.04 235.34 146.25 7.000 89.96 0.00 89.96 Pass 8608.13 8281.86 8625.00 8337.31 38.11 57.78 233.85 144.76 7.000 93.40 0.00 93.40 Pass 8632.77 8301 .40 8650.00 8357.71 38.16 58.53 232.40 143.31 7.000 96.91 0.00 96.91 Pass 8657.39 8320.93 8675.00 8378.07 38.21 59.27 230.98 141.89 7.000 100.49 0.00 100.48 Pass 8682.00 8340.45 8700.00 8398.39 38.26 60.02 229.61 140.51 7.000 104.13 0.00 104.13 Pass 8706.58 8359.96 8725.00 8418.69 38.32 60.76 228.26 139.17 7.000 107.94 0.00 107.94 Pass 8731.13 8379.42 8750.00 8439.00 38.37 61.51 226.97 137.88 7.000 112.00 0.00 112.00 Pass 8755.63 8398.86 8775.00 8459.34 38.43 62.25 225.72 136.63 7.000 116.31 0.00 116.31 Pass 8780.08 8418.26 8800.00 8479.68 38.48 63.00 224.51 135.42 7.000 120.88 0.00 120.88 Pass 8804.50 8437.63 8825.00 8500.05 38.54 63.72 223.38 134.29 7.000 125.65 0.00 125.65 Pass 8828.90 8456.98 8850.00 8520.45 38.60 64.44 222.34 133.25 7.000 130.57 0.00 130.57 Pass 8853.27 8476.32 8875.00 8540.88 38.67 65.16 221.37 132.28 7.000 135.64 0.00 135.64 Pass . . BP Anticollision Report Cømpany: BP Amaro 5/6/2004 Field: Prudhoe Bay Reference Site: PB DS 07 Reference Well: 07-06 Reference Wellpath: Plan 07-06B Site: PB DS 07 Well: 07-06 Rule Assigned: NOERRORS Wellpath: 07-06A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis ctr-Ctr;ii~~ø ..w0wable MD TVD MD TVD Ref Offset TFo+AZI TFO-HS CasingIH!ÐÎ$tance,Area Deviation ft ft ft ft ft ft deg deg in ft ft ft 8877.63 8495.64 8900.00 8561.35 38.73 65.89 220.48 131.39 7.000 140.85 0.00 140.85 Pass 8901.99 8514.96 8925.00 8581.81 38.79 66.62 219.66 130.57 7.000 146.10 0.00 146.10 Pass 8926.36 8534.29 8950.00 8602.24 38.86 67.36 218.88 129.79 7.000 151.29 0.00 151.29 Pass 8949.70 8552.81 8975.00 8622.64 38.97 68.12 217.97 129.69 7.000 156.42 0.00 156.42 Pass 8968.27 8567.53 9000.00 8643.01 39.25 68.90 216.23 132.21 7.000 162.08 0.00 162.08 Pass 8986.41 8581.87 9025.00 8663.38 39.46 69.53 214.34 134.45 7.000 168.61 0.00 168.61 Pass 9004.05 8595.76 9050.00 8683.78 39.60 70.01 212.36 136.43 7.000 176.08 0.00 176.08 Pass 9021.14 8609.13 9075.00 8704.21 39.67 70.37 210.34 138.17 7.000 184.48 0.00 184.48 Pass 9037.65 8621.96 9100.00 8724.68 39.66 70.61 208.31 139.68 7.000 193.80 0.00 193.79 Pass 9053.56 8634.20 9125.00 8745.16 39.61 70.72 206.29 140.99 7.000 203.99 0.00 203.98 Pass 9068.86 8645.85 9150.00 8765.66 39.50 70.73 204.31 142.11 7.000 215.02 0.00 215.02 Pass 9083.53 8656.89 9175.00 8786.18 39.35 70.65 202.38 143.07 7.000 226.87 0.00 226.87 Pass 9097.58 8667.34 9200.00 8806.72 39.17 70.50 200.52 143.89 7.000 239.49 0.00 239.49 Pass 9110.99 8677.19 9225.00 8827.24 38.94 69.88 198.73 144.57 7.000 252.89 0.00 252.89 Pass 9123.75 8686.42 9250.00 8847.74 38.71 69.21 197.00 145.13 2.875 267.07 0.00 267.07 Pass 9135.50 8694.81 9275.00 8867.49 38.44 68.33 195.14 145.31 2.875 282.26 0.00 282.25 Pass 9145.67 8701.97 9300.00 8885.26 38.20 67.50 192.91 144.80 2.875 298.63 0.00 298.63 Pass 9154.43 8708.07 9325.00 8901.25 37.98 66.76 190.52 143.87 2.875 315.81 0.00 315.81 Pass 9162.02 8713.30 9350.00 8915.81 37.78 66.11 188.15 142.68 2.875 333.86 0.00 333.86 Pass 9173.40 8721.09 9375.00 8929.04 37.81 66.12 186.18 140.71 2.875 352.72 0.00 352.72 Pass 9182.84 8727.55 9400.00 8940.96 37.83 66.12 184.30 138.83 2.875 372.58 0.00 372.58 Pass 9190.02 8732.47 9425.00 8951.58 37.83 66.06 182.47 137.18 2.875 393.19 0.00 393.19 Pass 9193.87 8735.11 9450.00 8961.07 37.72 65.79 180.57 136.01 2.875 414.40 0.00 414.39 Pass 9196.96 8737.23 9475.00 8970.07 37.64 65.58 178.87 134.90 2.875 436.15 0.00 436.15 Pass 9199.49 8738.96 9500.00 8978.74 37.57 65.40 177.35 133.86 2.875 458.36 0.00 458.36 Pass 9201.38 8740.26 9525.00 8987.00 37.51 65.27 176.01 132.89 2.875 481.01 0.00 481.01 Pass 9202.70 8741.17 9550.00 8994.70 37.47 65.17 174.81 131.94 2.875 503.96 0.00 503.96 Pass 9203.58 8741.77 9575.00 9001.77 37.45 65.11 173.71 131.01 2.875 527.05 0.00 527.04 Pass 9203.96 8742.04 9600.00 9008.20 37.43 65.09 172.71 130.08 2.875 550.30 0.00 550.30 Pass 9203.77 8741.91 9625.00 9013.30 37.44 65.10 171.75 129.09 2.875 573.40 0.00 573.40 Pass 9203.09 8741.44 9650.00 9016.86 37.46 65.15 170.79 128.00 2.875 596.18 0.00 596.18 Pass 9202.19 8740.82 9675.00 9019.51 37.49 65.22 169.86 126.89 2.875 618.80 0.00 618.79 Pass 9200.00 8739.32 9700.00 9022.49 37.56 65.38 169.09 125.70 2.875 641.71 0.00 641.70 Pass 9200.00 8739.32 9725.00 9025.54 37.56 65.38 168.25 124.87 2.875 664.77 0.00 664.77 Pass 9199.93 8739.27 9750.00 9028.11 37.56 65.39 167.46 124.06 2.875 687.84 0.00 687.84 Pass 9198.84 8738.52 9775.00 9029.78 37.59 65.47 166.73 123.12 2.875 710.78 0.00 710.78 Pass 9197.52 8737.61 9800.00 9030.50 37.62 65.57 166.03 122.17 2.875 733.52 0.00 733.52 Pass 9196.03 8736.59 9825.00 9030.62 37.66 65.68 165.36 121.21 2.875 756.23 0.00 756.23 Pass 9194.28 8735.39 9850.00 9030.07 37.71 65.80 164.75 120.27 2.875 778.90 0.00 778.90 Pass 9192.13 8733.91 9875.00 9029.21 37.77 65.96 164.26 119.37 2.875 801.75 0.00 801.75 Pass 9189.69 8732.24 9900.00 9028.31 37.83 66.13 163.89 118.53 2.875 824.79 0.00 824.79 Pass 9184.17 8728.46 9925.00 9027.75 37.84 66.17 163.48 118.01 2.875 848.05 0.00 848.05 Pass 9177.79 8724.10 9950.00 9027.65 37.82 66.17 163.10 117.63 2.875 871.53 0.00 871.53 Pass 9171.03 8719.46 9975.00 9027.54 37.80 66.17 162.76 117.29 2.875 895.02 0.00 895.02 Pass 9163.79 8714.51 10000.00 9027.49 37.79 66.17 162.48 117.01 2.875 918.53 0.00 918.53 Pass 9160.03 8711.93 10025.00 9027.59 37.83 66.33 162.34 116.59 2.875 942.04 0.00 942.03 Pass 9157.63 8710.28 10050.00 9027.78 37.89 66.54 162.29 116.15 2.875 965.55 0.00 965.55 Pass 9155.32 8708.69 10075.00 9028.03 37.96 66.75 162.23 115.72 2.875 989.13 0.00 989.13 Pass 9153.38 8707.35 10100.00 9028.72 38.01 66.92 162.15 115.32 2.875 1013.01 0.00 1013.00 Pass 9151.96 8706.36 10123.00 9030.50 38.05 67.04 162.08 115.01 1035.33 0.00 1035.32 Pass . . BP Anticollision Report Company: BP Amoco Date: 5/6/2004 Time: ·.·...13:44:09 P~gli: 5 Field: Prudhoe Bay Reference Site: PB DS 07 Co-ordinate(NE) R.eferenêe: W~II: 07-0!?,"T'ru~ North Reference Well: 07-06 Vertical (TVJ» Jieference: 2ES.26.5.+26.555.0 Reference Wellpath: Plan 07-06B Db:.. ·Otacle Site: PB DS 07 Well: 07-35 Rule Assigned: Major Risk Wellpath: 07-35 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis .. . .ç(r.Ctr~o-Go AII!I\Vable MD TVD MD TVD Ref Offset TFQ+AZI TF()"HSCasingtH9>i$t~nceArea I)e~~tion/ing ft ft ft ft ft ft dE!Q dE!Q in ft ft 7804.13 7632.62 7575.00 7555.50 37.52 2.70 160.05 71.17 546.03 155.21 390.82 Pass 7826.13 7652.07 7600.00 7579.33 37.66 2.71 161.11 73.14 535.22 155.79 379.44 Pass 7847.95 7671.11 7625.00 7602.87 37.64 2.73 162.38 74.27 523.75 155.72 368.03 Pass 7868.84 7689.20 7650.00 7626.13 37.61 2.74 163.72 75.49 511.75 155.63 356.12 Pass 7889.00 7706.49 7675.00 7649.16 37.59 2.76 165.12 76.78 499.38 155.48 343.90 Pass 7908.59 7723.17 7700.00 7672.06 37.56 2.77 166.60 78.15 486.95 155.41 331.54 Pass 7927.73 7739.32 7725.00 7694.95 37.54 2.80 168.18 79.62 474.76 155.11 319.64 Pass 7946.09 7754.68 7750.00 7717.68 37.52 2.85 169.88 81.23 462.59 154.73 307.86 Pass 7963.44 7769.07 7775.00 7740.12 37.50 2.91 171.72 82.99 450.34 154.25 296.09 Pass 7979.66 7782.43 7800.00 7762.12 37.48 2.99 173.70 84.89 437.83 153.66 284.17 Pass 7994.74 7794.75 7825.00 7783.53 37.46 3.09 175.81 86.93 424.88 152.93 271.96 Pass 8008.76 7806.13 7850.00 7804.33 37.45 3.19 178.04 89.10 411.61 152.12 259.49 Pass 8021.98 7816.78 7875.00 7824.61 37.43 3.30 180.40 91.41 398.19 151.05 247.14 Pass 8034.63 7826.90 7900.00 7844.69 37.42 3.41 182.95 93.90 385.27 149.72 235.55 Pass 8046.79 7836.57 7925.00 7864.88 37.41 3.52 185.73 96.64 373.58 148.13 225.45 Pass 8058.65 7845.97 7950.00 7885.24 37.42 3.63 188.78 99.69 363.59 146.08 217.51 Pass 8070.14 7855.09 7975.00 7905.68 37.42 3.76 192.07 102.98 355.33 143.83 211.50 Pass 8081.31 7863.95 8000.00 7925.97 37.43 3.90 195.53 106.44 348.34 141.20 207.14 Pass 8092.40 7872.75 8025.00 7946.22 37.44 4.04 199.12 110.03 342.65 138.17 204.48 Pass 8103.59 7881.62 8050.00 7966.52 37.44 4.16 202.82 113.73 338.36 134.68 203.68 Pass 8115.04 7890.71 8075.00 7987.00 37.45 4.27 206.57 117.48 335.65 130.83 204.82 Pass 8126.92 7900.13 8100.00 8007.80 37.46 4.39 210.32 121.23 334.69 126.68 208.01 Pass 8138.91 7909.64 8125.00 8028.70 37.47 4.51 214.08 124.98 335.33 122.27 213.06 Pass 8150.95 7919.19 8150.00 8049.63 37.48 4.65 217.79 128.70 337.37 117.70 219.67 Pass 8163.16 7928.88 8175.00 8070.54 37.49 4.78 221.44 132.35 340.46 113.03 227.43 Pass 8175.68 7938.81 8200.00 8091.38 37.50 4.93 225.01 135.92 344.26 108.34 235.93 Pass 8188.29 7948.81 8225.00 8112.16 37.51 5.07 228.49 139.40 349.00 103.68 245.32 Pass 8201.08 7958.96 8250.00 8132.87 37.52 5.22 231.87 142.78 354.54 99.15 255.39 Pass 8213.99 7969.20 8275.00 8153.48 37.54 5.37 235.15 146.06 360.85 94.83 266.02 Pass 8226.98 7979.50 8300.00 8174.11 37.55 5.51 238.30 149.21 368.24 90.81 277.42 Pass 8240.04 7989.87 8325.00 8194.89 37.56 5.65 241.29 152.20 376.94 87.22 289.71 Pass 8253.17 8000.28 8350.00 8215.83 37.58 5.78 244.11 155.02 386.92 84.20 302.73 Pass 8266.46 8010.82 8375.00 8237.04 37.59 5.91 246.73 157.64 398.20 81.84 316.36 Pass 8279.90 8021.48 8400.00 8258.37 37.60 6.04 249.17 160.08 410.32 80.15 330.17 Pass 8293.41 8032.20 8425.00 8279.72 37.62 6.18 251.47 162.38 423.08 79.15 343.92 Pass 8307.03 8043.00 8450.00 8301.05 37.64 6.32 253.64 164.55 436.29 78.82 357.47 Pass 8320.81 8053.93 8475.00 8322.33 37.65 6.47 255.71 166.61 449.74 79.08 370.66 Pass 8334.62 8064.89 8500.00 8343.56 37.67 6.61 257.66 168.57 463.59 79.85 383.74 Pass 8348.35 8075.78 8525.00 8364.72 37.69 6.76 259.51 170.42 477.92 81.02 396.90 Pass 8361.93 8086.56 8550.00 8385.84 37.71 6.91 261.25 172.16 492.84 82.47 410.37 Pass 8375.37 8097.21 8575.00 8406.91 37.72 7.06 262.89 173.80 508.32 84.10 424.21 Pass 8388.74 8107.82 8600.00 8427.93 37.74 7.21 264.44 175.35 524.17 85.86 438.32 Pass 8402.10 8118.42 8625.00 8448.94 37.76 7.36 265.90 176.81 540.38 87.66 452.72 Pass 8415.49 8129.04 8650.00 8469.96 37.78 7.51 267.27 178.18 556.92 89.48 467.44 Pass 8428.88 8139.66 8675.00 8490.99 37.80 7.66 268.56 179.47 573.75 91.28 482.47 Pass 8442.29 8150.30 8700.00 8512.03 37.82 7.80 269.78 180.69 590.85 93.04 497.81 Pass 8455.83 8161.04 8725.00 8533.18 37.84 7.94 270.91 181.82 608.20 94.72 513.48 Pass 8469.55 8171.92 8750.00 8554.47 37.87 8.08 271.96 182.87 625.77 96.31 529.46 Pass 8483.45 8182.95 8775.00 8575.90 37.89 8.21 272.94 183.85 643.54 97.84 545.70 Pass 8497.51 8194.10 8800.00 8597.47 37.91 8.35 273.84 184.75 661.46 99.27 562.19 Pass 8511.63 8205.31 8825.00 8619.11 37.93 8.48 274.69 185.60 679.55 100.64 578.91 Pass . . . BP Anticollision Report Company: BP Amoco Date: 5/6/2004 Time: 13:44:09 'age: 6 Field: Prudhoe Bay Reference Site: PB DS 07 Co-ordlnate(NE) Reference: Well: 07-06,TnJel.orth Reference Well: 07-06 Vertical (TVD) RefereJlce: 2ES 26.5 +28.555.0 Reference Wellpath: Plan 07-o6B Db: Site: PB DS 07 Well: 07-35 Rule Assigned: Major Risk Wellpath: 07-35 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr. . No-Go Allowable MD TVD MD TVD Ref Offset TFo+AZI TFO-HS CaslngIIJS>lstance Area Deviation ft ft ft ft ft ft deg deg in ft ft ft 8525.56 8216.35 8850.00 8640.69 37.96 8.62 275.49 186.40 697.96 101.96 596.01 Pass 8538.85 8226.90 8875.00 8661.96 37.98 8.77 276.26 187.17 716.85 103.27 613.57 Pass 8551.00 8236.53 8900.00 8682.52 38.01 8.94 277.05 187.96 736.28 104.63 631.65 Pass 8561.99 8245.26 8925.00 8702.32 38.03 9.13 277.85 188.75 756.19 106.01 650.18 Pass 8572.40 8253.51 8950.00 8721.73 38.04 9.33 278.62 189.53 776.41 107.37 669.04 Pass 8582.23 8261.31 8975.00 8740.76 38.06 9.53 279.37 190.28 796.94 108.70 688.25 Pass 8591.30 8268.51 9000.00 8759.33 38.08 9.75 280.10 191.01 817.87 109.99 707.88 Pass 8599.68 8275.15 9025.00 8777.48 38.09 9.98 280.80 191.70 839.17 111.23 727.94 Pass 8607.17 8281.09 9050.00 8795.10 38.11 10.21 281.46 192.37 860.89 112.42 748.46 Pass 8614.58 8286.97 9075.00 8812.71 38.12 10.44 282.09 193.00 882.77 113.54 769.23 Pass 8622.19 8293.01 9100.00 8830.48 38.14 10.66 282.68 193.59 904.74 114.58 790.17 Pass 8629.74 8299.00 9125.00 8848.27 38.16 10.89 283.23 194.14 926.89 115.57 811.32 Pass 8636.53 8304.39 9150.00 8865.63 38.17 11.13 283.75 194.66 949.38 116.52 832.86 Pass 8642.00 8308.72 9175.00 8882.13 38.18 11.39 284.25 195.16 972.28 117.43 854.85 Pass 8645.98 8311.88 9200.00 8897.64 38.19 11.66 284.72 195.63 995.57 118.29 877.27 Pass 8648.55 8313.92 9225.00 8912.11 38.19 11.95 285.18 196.09 1019.09 119.11 899.98 Pass 8650.16 8315.19 9250.00 8925.82 38.20 12.25 285.63 196.54 1042.72 119.90 922.82 Pass 10146.36 9022.02 9275.00 8939.48 16.79 14.51 243.47 274.57 1060.46 125.80 934.66 Pass 10166.33 9021.86 9300.00 8952.99 16.97 14.83 242.71 273.81 1065.73 127.51 938.22 Pass 10186.70 9021.70 9325.00 8965.70 17.16 15.17 242.00 273.10 1071.58 129.23 942.35 Pass 10207.60 9021.54 9350.00 8977.22 17.36 15.51 241.36 272.46 1078.18 131.01 947.17 Pass 10228.86 9021.37 9375.00 8987.54 17.57 15.87 240.79 271.89 1085.71 132.83 952.88 Pass 10250.48 9021.20 9400.00 8996.59 17.79 16.22 240.29 271.39 1093.93 134.65 959.27 Pass 10272.38 9021.02 9425.00 9004.25 18.01 16.58 239.87 270.98 1102.93 136.47 966.45 Pass 10294.39 9020.85 9450.00 9010.58 18.24 16.94 239.53 270.63 1112.73 138.28 974.45 Pass 10316.46 9020.67 9475.00 9015.70 18.48 17.30 239.25 270.36 1123.18 140.11 983.07 Pass 10338.61 9020.50 9500.00 9019.75 18.72 17.65 239.04 270.14 1133.94 141.94 992.00 Pass 10360.68 9020.32 9525.00 9022.46 18.97 18.00 238.89 269.99 1145.31 143.74 1001.57 Pass 10382.73 9020.15 9550.00 9023.56 19.21 18.34 238.83 269.93 1157.01 145.52 1011.50 Pass · rrïì lllJ r', ~l Æ\ ~:(( LJù .=:J Lrü r:iv - ~ ,ø f I I I I I ¡ / FRANK H. MURKOWSKI, GOVERNOR AI/A.SIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay 07-06B BP Exploration (Alaska) Inc. Permit No: 204-042 Surface Location: 1450' SNL, 117' WEL, SEC. 33, T11N, R14E, UM Bottomhole Location: 460' SNL, 1449' EWL, SEC. 34, TI1N, R14E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you fÌ'om obtaining additional permits or approvals required by law fÌ'om other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to 'tness any required test. Contact the Commission's North Slope petroleum field inspector 5 3607 (pager). Sin r /' BY ORDER OF THE COMMISSION DATED this lfit day of March, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 'vJ6 It;- L/2 T /2.ðotl I STATE OF ALASKA .~=, ALASKA· IL AND GAS CONSERVATION COMm'SSloM~ PERMIT TO DRILL FEB 2 [) 2004 o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1450' SNL, 117' WEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 1290' SNL, 1265' EWL, SEC. 34, T11N, R14E, UM Total Depth: 460' SNL, 1449' EWL, SEC. 34, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-676091 y-5949473 Zone-ASP4 16. Deviated Wells: Kickoff Depth tß>Casing Program Size Hole Casinç¡ Weiç¡ht 3-3/4" x 4-1/8" 3-3/16" x 2-7/8" 6.4# I 6.5# I'b. C""..tW~'?C~~':~:~ rost 8 ~:=to/ ~~~::~;a=P'~~~'cn 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU 07-06B / 6. Proposed Depth: 12. Field I Pool(s): MD 10140 TVD 8969 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028309 8. Land Use Permit: 13. Approximate Spud Date: April 15, 2004 / 14. Distance to Nearest Property: 23,750' 9. Acres in Property: 2560 8912 ft Maximum Hole Angle 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 64' feet 07-17 is 1295' away 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) / Downhole: 3300 psig Surface: 2420 psig 90° Grade L-80 Coupling Lenç¡th TCI!I STL 2190' MD 7950' TVD MD TVD (includinç¡ staç¡e data) 7699' 10140' 8969' 74 sx Class 'G' ,r 19. PRESENT )WELl_ÇC)ND'TICW$VMMARY(Tobecomplete(ff()rRedrilIANP~~qt!YOp8råtiôÔ$ Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD 10123 9029 8000' 8000' 7807 Structural Conductor 107' 20" 230 sx Arcticset 107' 107' Surface 2698' 13-3/8" 6350 sx Arcticset II 2698' 2698' Intermediate 8578' 9-5/8" 750 sx Class 'G' 8578' 8299' Production Liner 993' 7" 500 sx Class 'G' 8260' - 9253' 8032' - 8849' Liner 1974' 2-7/8" 59 sx LARC 8149' - 10123' 7936' - 9029' . Perforation Depth MD (ft): 9359' - 10048' . 20. Attachments 181 Filing Fee 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8920' - 9027' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the is true and correct to the best of my knowledge. Printed Name Dan Title CT Drilling Engineer Date: Contact Dan Kara, 564-5667 Phone 564-5667 Permit To Drill API Number: Number:.2o 9 - o~.1 50-029-20294-02-00 Conditions of Approval: Samples Required Hydrogen ulfide Measures c" ~ ., fÇ(. DYes g¡ No ~ Yes 0 No Permit Date: Mud Log Required Directional Survey Required See cover letter for other requirements DYes ..1XJ No ~ Yes 0 No dRlGINAL BY ORDER OF THE COMMISSION Date a{ ~t/ s%//n :~cate . . BP Prudhoe Bay 7-06B RWO/CTD Sidetrack Summary of Operations: Well 7-06A is scheduled for a through tubing sidetrack with coiled tubing drilling rig Nordic 2. Prior to CTD sidetracking, the perforations will be isolated with a permanent bridge plug in the 2-7/8' liner, the upper portion of the 2-7/8" liner will be cut and pulled and the corroded 5-112" L-80 production tubing will then be replaced with 4-112" 13-Chrome tubing, stacker-packer completion. A mechanical whipstock will be installed for window milling. The sidetrack, 7-06B, will target Zone 2 reserves. Approximately 1228' of 3-3/4" to 4- 118" open hole is planned to access the target. The well will be completed with a cemented/perforated 3-3/16" x 2-7/8" liner. Pre-rig Prep work. Beginning April 01, 2004. 1. Mechanical integrity test of 9-5/8" casing to 3500 psi. 2. Install permanent bridge plug at 8960' md to isolate perforations. 3. Chemical cut and pull 2-7/8" liner at 8940' md. 4. Underream 7" liner 5. Run calliper log across liner and tubing. 6. Chemical cut 5-112" tubing at 7980' md. 7. Circulate well over to kill weight fluid. Nordic 2 RWO - Tubing Swap (late April 2004) 1. RU Nordic 2 with 13-5/8" BOPE. Test stack. 2. Pull 5-112" L-80 tubing. 3. RIH with casing drift down to tubing stub at 7980' md. 4. Complete well with 4-112" 12.6# 13Cr-80 tubing stacker-packer. 5. PT completion. RD 13-5/8" BOPE. NU tree and 7-1116" CTD BOPE. Test. Nordic 2 CTD - Install WS, Mill window, Drill and Complete sidetrack: 1. E-line install mechanical WS at 8912' md, 8507' TV~ 2. Mill 3.8" window at 8912' md, through the 7" liner. 3. Directionally drill-1228' of 3-3/4" to 4-118" open hole to a planned TD of 10140 md, 8969' TVD. / 4. Run 3-3/16" x 2-7/8" lin~r ~TD up to 7950' md. /. 5. Cement liner in place wit~bls Class G cement. 6. CNL log cased hole. Pressure test liner lap. Perforate pay zones. 7. RD Nordic 2. Mud Program: · RWO: 2% KCl. / · CTD: 2ppb Biozan for milling, PIo-Pro (8.6 - 8.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 1950' of 3-3/16" TCll 6.4# L-80 from 9900' up into the 4-112" ~il to 7950' md. · 240' of 2-7/8" STL 6.5# L-80 from TD up to 9900' md. ./ · Cemented in place with 15 bbls Class G Well Control: · 13-5/8" and 7-1116" BOP diagrams are attached · Pipe rams, blind rams and the CT pack-off will be pressure tested to 250 psi and to 3500 psi./ · The annular preventer will be tested to 250 psi and 2500 psi. . . Directional · See attached directional plan, 1228' planned horizontal. Max. planned hole angle is approx. -90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray will be run over the open hole section. · Cased hole logs to include memory GR/CNL/CCL Hazards · H2S testing on 7-06 is less than 10 ppm. DS-7 is not an H2S pad. · Lost circulation risk is considered medium. Reservoir Pressure · Pore pressure is estimated to be 3300 psi at 8800'TVDss (7.2 ppg emw). . · Maximum surface pressure with gas (0.1 psi/ft) to surface is 2420 psi / TREE = GRA Y GEN 3 WELLHEAD = GRA Y ACTUATOR = AXELSON . 07 -06A / aETY NOTES: PULLED UPPER 18' OF 7191' POGLM; LEFT 6' TO 8' AT XO (5/24/00) Max Angle = Datum MD = Oatum TVD = 92 @ 9873' A'W""'...., ~"mm____m"" 9272' 8800' SS . 2228' H5-1/2" CAMCO BAL-O SSSV NIP, 10 = 4.562" I I 13-3/8" CSG, 72#, N-80, ID = 12.347" H 2698' r-----J. ~ I I 7865' H 5-1/2" BAKER L SLlOING SLV 1 Minimum ID = 2.440" @ 8157' 4-1/2" X 2-7/8" XO - ~ 7955' H 5-1/2" BAKER R LANO NIP, ID = 4.472" ~ 7992' H 5-1/2" BAKER SBR ASSY 1 8000' 1--1 3-3/8" IBP SET (06/17/03) I 8: ~ 8054' 1--1 9-5/8" x 5-1/2" BAKER SAB A<R 1 I 5-1/2" TBG-NPC, 17#, N-80, .0232 bpf, 10 = 4.892" H 8066' !--, I 8066' H 5-1/2" X 4-1/2" XO 1 TOPOF 4-1/2" TBG-NPC H 8066' ¡.--- I H 8127' 4-1/2" BAKER R LAND NIP, 10 = 3.812" TOPOF 2-7/8" LNR- CT H 8149' H I 8149' H 4-1/2" GS PBR, 10 = 3.00" I 8157' H 4-1/2" X 2-7/8" XO, ID = 2.440 I I 8189' H 4-1/2" BAKER SHEA ROUT SUB (BEHIND CT) 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" H 8190' I-- I 8190' H 4-1/2" TUBING TAIL (BEHINO CT) I TOPOF 7" LNR H 8260' r--. . 8174' H ELMD TT LOGGED 11/28/78 I 9-5/8" CSG, 47#, N-80, ID = 8.681" H 8578' ~ .. I TOP OF CEMENT H 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" H 9227' I 9253' r- MILLOUT WINDOW 9253' - 9263' PERFORA TION SUMMARY REF LOG: BHCS ON 11/14/78 ANGLEATTOPPERF: 59 @ 9359' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz OATE 2-1/8" 4 9359 - 9365 0 02/23/98 2-1/8" 4 9447 - 9455 0 02/23/98 2-1/8" 4 9748 - 9833 0 01/06/96 2-1/8" 4 9853 - 9938 0 01/06/96 2-1/8" 4 9958 - 10048 0 01/06/96 1 PBTD H 10057' 2-7/8" LNR - CT, 6.5#, L-80, .00579 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/20/78 ORIGINAL COMPLETION 06/17103 BJMlKK SET IBP 01/07/96 SIDETRACK 07/08/00 MHlTLP PULL POGLM @ 7191' 12/11/00 SiS-MD CONVERTED TO CANVAS 02/08/01 SIS-LG REVISION 09/22/01 RNlTP CORRECTIONS PRUDHOE BA Y UNIT WELL: 07-06A PERMIT No: 95-1970 API No: 50-029-20294-01 SEC 34, T11 N, R14E, 3371.18' FEL & 2021.52' FNL BP Exploration (Alaska) TREE = ' GRA Y GEN 3 WELLHEAD = GRAY ACTUA TOR = AXELSON KB ELEV = 64' 8F. ELEV ? KOP 5700' Max Angle 92 @ 9873' Datum MD 9272' Datum TVD = 8800' SS I 13-3/8" CSG, 72#, N-80, 10 12347" H 2698' 15-1/2" TBG-NPC. 17#, N-80. .0232 bpf, 10 4.892" H I TOP OF 4-1/2" TBG-NPC H 14-1/2" T8G-NPC, 126#, N-80, 0152 bpf, 10 = 3,958" H I TOP OF 7" LNR H ... 8066' 8066' r- I 8190' 8260' 9-5/8" CSG, 47#. N-80, 10 = 8.681" H 8578' .. ÆRFORA TION SUMMA RY REF LOG: SHCS ON 11/14/78 ANGLE AT TOP ÆRF: 59 @ 9359' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 9359 - 9365 2-1/8" 4 9447 - 9455 2-1/8" 4 9748 9833 2-1/8" 4 9853 - 9938 2-1/8" 4 9958 10048 7" LNR, 29#, N-80, .0371 bpf. 10 6.184" 2-7/8" LNR CT, 6.5#, L-80, .00579 bpf, 10 = 2.441" DATE 11/20/78 01/07/96 07/08/00 12/11100 02/08101 09/22/01 REV BY COMMENTS MH/TLP SiS-MD SIS-LG RNlTP SIDETRACK PULL POGLM @ 7191' CONVERTËD TO cANVAS REVISION CORRECTIONS 9253' r-t 10057' 10123' DA TE REV BY 06/17/03 BJMlKK SET 18P COMMENTS NOTES: H 5-1/2" 8054' H 9-5/8" X 8066' H 5-1/2" X 4-1/2" XO 4-1/2" BAKER 8189' 8190' 8174' NIP,ID= H 4-1/2" BAKER H H 8950' Top Of Cement MILLOUT WINDOW 9253' - 9263' UNrf WELL: 07 -06A 95-1970 API No: 50-029-20294-01 SEC 34, T11 N, (A!aska) BP-GDB Baker Hughes INTEQ Planning Report ObP . Company: Field: Site: Well: Wellpath: 8P Amoco Prudhoe 8ay P8 DS 07 07-06 Plan#5 07-068 Field: Prudhoe 8ay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: P8 DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft 677382.28 ft . ... BAKU IIUGHIS INIEJ:Q Date: 9/9/2003 Time: 15:07:11 Page: Co-ordinate(NE) Reference: Well: 07-06, True North Vertical (TVD) Reference: System: Mean Sea Level Seetion (VS) Referente: Well (0.OON.0.00E,13.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Latitude: 70 15 Longitude: 148 33 North Reference: Grid Convergence: Alaska. Zone 4 Well Centre bggm2003 49.847 N 56.934 W True 1.35 deg Well: 07-06 Slot Name: 06 07-06 Well Position: +N/-S 1357.71 ft Northing: 5949472.34 ft Latitude: 70 16 3.199 N +E/-W -1260.21 ft Easting : 676090.52 ft Longitude: 148 34 33.614 W Position Uncertainty: 0.00 ft Wellpath: Plan#507-068 500292029402 Current Datum: 10: 065/30/199613:30 Magnetic Data: 9/9/2003 Field Strength: 57576 nT Vertical Section: Depth From (TVD) ft 37.00 Targets Name Description Dip. Dir. 07-068 Polygon5.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 TVD ft 0.00 0.00 0.00 0.00 0.00 07-068 Polygon5.2 -Polygon 1 -Polygon 2 ·Polygon 3 -Polygon 4 ·Polygon 5 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 07-068 Fault 2 -Polygon 1 ·Polygon 2 07-068 Fault 1 ·Polygon 1 -Polygon 2 07-068 Fault 3 (Well cuts fit) ·Polygon 1 -Polygon 2 07-068 Fault 3 (Deep Poly) -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 0.00 0.00 0.00 0.00 0.00 0.00 07-068 Fault 4 (Deep Poly) Height 64.00 ft +N/-S ft 0.00 +N/-S ft 473.26 473.26 554.18 587.54 501.62 651.50 651.50 1082.50 1231.38 945.71 749.17 438.65 438.65 270.06 240.77 240.77 97.98 662.67 662.67 363.29 1258.54 1258.54 655.71 238.66 655.71 546.73 +E/-W ft 1691.12 1691.12 1653.00 1723.81 1761.81 1555.54 1555.54 1305.24 1568.81 1721.58 1699.28 1460.23 1460.23 1611.34 1580.65 1580.65 1612.32 1505.49 1505.49 1688.55 1049.27 1049.27 1375.28 1670.63 1375.28 1757.86 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Map Map Northing Easting ft ft 5949985.00 677770.00 5949985.00 677770.00 5950065.00 677730.00 5950100.00 677800.00 5950015.00 677840.00 5950160.00 677630.30 5950160.00 677630.30 5950585.00 677370.00 5950740.00 677630.00 5950458.00 677789.40 5950261.00 677771.70 5949945.00 677540.00 5949945.00 677540.00 5949780.00 677695.00 5949750.00 677665.00 5949750.00 677665.00 5949608.00 677700.00 5950170.00 677580.00 5950170.00 677580.00 5949875.00 677770.00 5950755.00 677110.00 5950755.00 677110.00 5950160.00 677450.00 5949750.00 677755.00 5950160.00 677450.00 5950060.00 677835.00 07-06 8900.00 ft Mean Sea Level 25.61 deg 80.85 deg Direction deg 13.00 <-- Latitude __-> Deg M in See 70 16 7.851 N 70 16 7.851 N 70 16 8.647 N 70 16 8.975 N 70 16 8.130N 70 16 9.605 N 70 16 9.605 N 70 16 13.844 N 70 16 15.308 N 70 16 12.498 N 70 16 10.565 N 70 16 7.511 N 70 16 7.511 N 70 16 5.853 N 70 16 5.565 N 70 16 5.565 N 70 16 4.161 N 70 16 9.715 N 70 16 9.715 N 70 16 6.770 N 70 16 15.576 N 70 16 15.576 N 70 16 9.646 N 70 16 5.544 N 70 16 9.646 N 70 16 8.574 N <-- Longitude --> Deg Min See 148 33 44.388 W 148 33 44.388 W 148 3345.497 W 148 33 43.436 W 148 3342.330 W 148 33 48.333 W 148 33 48.333 W 148 33 55.617 W 148 33 47.944 W 148 3343.498 W 148 3344.149 W 148 3351.109 W 148 3351.109 W 148 33 46.711 W 148 33 47.605 W 148 33 47.605 W 148 3346.684 W 148 3349.790 W 148 3349.790 W 148 33 44.464 W 148 34 3.068 W 148 34 3.068 W 148 33 53.581 W 148 3344.986 W 148 33 53.581 W 148 33 42.445 W ObP . . II.. BAJCaa IIUGHIS INn~.() BP-GDB Baker Hughes INTEQ Planning Report Company: Field: Site: Well: Wellpath: Targets BP Amoco Prudhoe Bay PB DS 07 07-06 Plan#507-06B Date: 9/9/2003 Time: 15:07:11 Page: 2 Co-ordinate(NE) Reference: Well: 07-06, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,13.00Azi) Survey Calèulation Method: Minimum Curvature Db: Oracle Map Map <--- Latitude --> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min· Sec DegMin See Dip. Dir. ft ft ft ft -Polygon 1 0.00 546.73 1757.86 5950060.00 677835.00 70 16 8.574 N 148 33 42.445 W -Polygon 2 0.00 227.70 1925.46 5949745.00 678010.00 70 16 5.436 N 148 33 37.569 W 07-06B Fault 6 0.00 795.10 1403.55 5950300.00 677475.00 70 16 11.017 N 148 33 52.757 W -Polygon 1 0.00 795.10 1403.55 5950300.00 677475.00 70 16 11.017 N 148 33 52.757 W -Polygon 2 0.00 1470.16 1624.42 5950980.00 677680.00 70 16 17.656 N 148 33 46.323 W -Polygon 3 0.00 1177.41 1737.61 5950690.00 677800.00 70 16 14.777 N 148 33 43.030 W -Polygon 4 0.00 608.17 2124.42 5950130.00 678200.00 70 16 9.177 N 148 3331.774 W -Polygon 5 0.00 1177.41 1737.61 5950690.00 677800.00 70 16 14.777 N 148 3343.030 W -Polygon 6 0.00 1470.16 1624.42 5950980.00 677680.00 70 16 17.656 N 148 3346.323 W 07-06B Fault 5 0.00 871.89 1755.47 5950385.00 677825.00 70 16 11.772 N 148 33 42.512 W -Polygon 1 0.00 871.89 1755.47 5950385.00 677825.00 70 16 11.772 N 148 33 42.512 W -Polygon 2 0.00 974.53 1857.90 5950490.00 677925.00 70 16 12.781 N 148 33 39.529 W 07-06B Fault 4 (Int Poly) 0.00 594.96 1834.02 5950110.00 677910.00 70 16 9.048 N 148 33 40.228 W -Polygon 1 0.00 594.96 1834.02 5950110.00 677910.00 70 16 9.048 N 148 33 40.228 W -Po1Y90n 2 0.00 266.52 1976.38 5949785.00 678060.00 70 16 5.817 N 148 33 36.086 W 07-06B Fault 3 (Int Poly) 0.00 745.23 1397.38 5950250.00 677470.00 70 16 10.527 N 148 3352.937 W -Polygon 1 0.00 745.23 1397.38 5950250.00 677470.00 70 16 10.527 N 148 33 52.937 W -Polygon 2 0.00 297.95 1702.02 5949810.00 677785.00 70 16 6.127 N 148 33 44.072 W 07-06B T5.1 8893.00 532.86 1688.97 5950044.53 677766.46 70 16 8.438 N 148 3344.450 W -Plan out by 5.71 at 8893.00 527.26 1690.09 5950038.96 677767.70 70 16 8.382 N 148 3344.418 W 07-066 T5.2 8968.00 732.89 1625.17 5950243.00 677698.00 70 16 10.405 N 148 33 46.306 W 07-066 T5.3 8969.00 989.82 1564.55 5950498.42 677631.39 70 16 12.932 N 148 33 48.069 W Annotation MD TVD ft ft 8900.00 8497.35 TIP 8912.00 8507.17 KOP 8932.00 8523.36 3 8997.00 8566.37 4 9097.00 8618.31 5 9197.00 8668.55 6 9297.00 8718.86 7 9397.00 8769.22 8 9497.00 8819.43 9 9597.00 8869.71 10 9617.53 8880.00 11 9637.53 8890.04 12 9687.53 8915.31 13 9890.40 8967.93 14 9990.40 8968.20 15 10140.00 8968.99 TO Plan: Plan #5 Date Composed: 9/9/2003 Identical to Lamar's Plan #5 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim 'fVD +N/·S +E/-W DLS Build Turn TFO l' arget ft deg deg ft ft ft deg/10OO deg/1000 deg/100ft deg 8900.00 35.00 111.00 8497.35 162.51 1376.09 0.00 0.00 0.00 0.00 8912.00 35.06 110.85 8507.17 160.05 1382.52 0.87 0.50 -1.25 304.81 8932.00 36.86 110.85 8523.36 155.87 1393.50 9.00 9.00 0.00 0.00 8997.00 59.61 110.85 8566.37 138.73 1438.51 35.00 35.00 0.00 0.00 ObP Company: Field: Site: Well: Wellpath: BP Amoco PrudhOe Bay PB DS 07 07-06 Plan#5 07 -06B Plan Section Information MD ft 9097.00 9197.00 9297.00 9397.00 9497.00 9597.00 9617.53 9637.53 9687.53 9890.40 9990.40 10140.00 Survey MD ft 8900.00 8912.00 8925.00 8932.00 8950.00 8975.00 8997.00 9000.00 9025.00 9050.00 9075.00 9097.00 9100.00 9125.00 9150.00 9175.00 9197.00 9200.00 9225.00 9250.00 9275.00 9297.00 9300.00 9325.00 9350.00 9375.00 9397.00 9400.00 9425.00 9450.00 9475.00 9497.00 9500.00 9525.00 9550.00 9575.00 9597.00 9600.00 9617.53 Incl deg 59.98 60.07 59.90 60.00 60.09 59.92 59.92 59.81 59.57 90.00 89.69 89.71 Incl deg 35.00 35.06 36.23 36.86 43.16 51.91 59.61 59.43 58.40 58.18 58.79 59.98 59.95 59.78 59.74 59.86 60.07 60.03 59.80 59.70 59.75 59.90 59.87 59.70 59.67 59.78 60.00 59.97 59.80 59.77 59.88 60.09 60.06 59.82 59.72 59.77 59.92 59.92 59.92 Azim deg 70.13 52.80 35.46 18.11 0.78 343.45 347.01 350.48 341.79 341.79 356.79 334.35 Azim deg 111.00 110.85 110.85 110.85 110.85 110.85 110.85 109.65 99.50 89.21 78.97 70.13 69.61 65.28 60.94 56.60 52.80 52.28 47.95 43.61 39.27 35.46 34.94 30.60 26.26 21.92 18.11 17.59 13.26 8.92 4.59 0.78 0.27 355.94 351.60 347.26 343.45 343.97 347.01 . . BP-GDB Baker Hughes INTEQ Planning Report TVD ft 8618.31 8668.55 8718.86 8769.22 8819.43 8869.71 8880.00 8890.04 8915.31 8967.93 8968.20 8968.99 Sys TVD ft 8497.35 8507.17 8517.74 8523.36 8537.14 8554.00 8566.37 8567.89 8580.83 8593.99 8607.09 8618.31 8619.81 8632.37 8644.96 8657.54 8668.55 8670.05 8682.59 8695.19 8707.80 8718.86 8720.36 8732.95 8745.57 8758.18 8769.22 8770.72 8783.27 8795.85 8808.43 8819.43 8820.93 8833.46 8846.05 8858.65 8869.71 8871.21 8880.00 +N/-S ft 138.07 179.23 241.02 317.85 402.83 488.13 505.31 522.27 564.11 747.89 845.86 989.82 N/S ft 162.51 160.05 157.36 155.87 151.76 145.20 138.73 137.84 132.45 130.83 133.03 138.07 138.97 147.26 157.02 168.22 179.23 180.81 194.67 209.73 225.91 241.02 243.14 261.30 280.27 299.97 317.85 320.32 341.16 362.35 383.81 402.83 405.43 427.05 448.51 469.73 488.13 490.62 505.31 Bií. BAKDt IUGHIS IN'TEQ Date: 9/9/2003 Time: 15:07:11 Page: 3 Co-ordinate(NE) Reference: Well: 07-06, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,13.00Azi) SurveyCaJculation Method: Minimum Curvature Db: Oracle +E/-W ft 1522.14 1597.81 1657.76 1696.54 1710.67 1698.88 1694.35 1690.97 1680.65 1620.19 1601.66 1564.61 EIW ft 1376.09 1382.52 1389.60 1393.50 1404.31 1421.52 1438.51 1440.93 1461.61 1482.77 1503.93 1522.14 1524.58 1544.54 1563.80 1582.27 1597.81 1599.87 1616.46 1631.94 1646.22 1657.76 1659.25 1670.95 1681.22 1690.03 1696.54 1697.33 1703.09 1707.24 1709.78 1710.67 1710.70 1709.98 1707.64 1703.68 1698.88 1698.15 1694.35 DLS Build Turn deg/100ft deg/100ft deg/100ft 35.00 0.37 -40.72 15.00 0.09 -17.33 15.00 -0.17 -17.34 15.00 0.10 -17.35 15.00 0.09 -17.33 15.00 -0.17 -17.33 15.00 -0.03 17.33 15.00 -0.56 17.33 15.00 -0.47 -17.37 15.00 15.00 0.00 15.00 -0.31 15.00 15.00 0.02 -15.00 MapN ft 5949666.99 5949664.68 5949662.15 5949660.76 5949656.89 5949650.74 5949644.67 5949643.83 5949638.93 5949637.81 5949640.50 5949645.97 5949646.92 5949655.68 5949665.89 5949677.52 5949688.88 5949690.51 5949704.76 5949720.17 5949736.68 5949752.05 5949754.21 5949772.63 5949791.84 5949811.74 5949829.77 5949832.26 5949853.22 5949874.50 5949896.01 5949915.05 5949917.65 5949939.24 5949960.64 5949981.76 5950000.05 5950002.52 5950017.11 MapE ft 677462.34 677468.83 677475.97 677479.90 677490.80 677508.17 677525.30 677527.74 677548.54 677569.73 677590.83 677608.92 677611.34 677631.10 677650.12 677668.32 677683.59 677685.62 677701.88 677717.00 677730.90 677742.08 677743.53 677754.79 677764.61 677772.96 677779.05 677779.79 677785.05 677788.71 677790.75 677791.19 677791.16 677789.94 677787.09 677782.64 677777.40 677776.62 677772.47 TFO deg 260.00 266.00 265.00 266.00 266.00 265.00 91.00 93.00 266.00 0.00 91.20 270.00 VS ft 467.90 466.95 465.92 465.35 463.77 461.25 458.77 458.44 457.84 461.03 467.93 476.94 478.36 490.93 504.78 519.84 534.06 536.07 553.31 571.46 590.43 607.75 610.16 630.48 651.28 672.46 691.34 693.93 715.53 737.11 758.59 777.32 779.86 800.76 821.15 840.94 857.78 860.05 873.50 Target DLS deg/100ft 0.00 0.87 9.00 9.00 35.00 35.00 35.00 35.00 35.00 35.00 35.00 35.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 TFO deg 0.00 304.81 0.00 360.00 0.00 360.00 0.00 260.00 260.61 265.86 271.28 276.64 266.00 266.26 268.44 270.62 272.80 265.00 265.26 267.43 269.61 271.80 266.00 266.26 268.44 270.64 272.82 266.00 266.26 268.43 270.62 272.80 265.00 265.26 267.43 269.61 271.80 91.00 90.74 Tool TIP KOP MWD 3 MWD MWD 4 MWD MWD MWD MWD 5 MWD MWD MWD MWD 6 MWD MWD MWD MWD 7 MWD MWD MWD MWD 8 MWD MWD MWD MWD 9 MWD MWD MWD MWD 10 MWD 11 ObP . BP-GDB . B.. BADII IIUGIIII Baker Hughes INTEQ Planning Report INfUQ Company: BP Amoco Date: 9/9/2003 Time: 15:07:11 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-06, True North Site: PB DS 07 Vertical (TVD) Refer.ence: System: Mean SeaLevel Well: 07-06 Section (VS) Reference: Well (0.00N,0.00E,13.00Azi) Wellpath: Plan#5 07 -06B Survey Calculation Meth_Od:. Minimum Curvature Db: Oracle Survey MD Incl Azim Sys TVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1 OOft deg 9625.00 59.87 348.30 8883.75 511.62 1692.97 5950023.39 677770.95 879.34 15.00 93.00 MWD 9637.53 59.81 350.48 8890.04 522.27 1690.97 5950033.98 677768.70 889.27 15.00 92.35 12 9643.40 59.75 349.46 8893.00 527.26 1690.09 5950038.96 677767.70 893.94 15.00 266.00 07-068 9650.00 59.69 348.31 8896.33 532.85 1688.99 5950044.52 677766.47 899.14 15.00 266.51 MWD 9675.00 59.58 343.97 8908.97 553.79 1683.83 5950065.33 677760.82 918.37 15.00 267.09 MWD 9687.53 59.57 341.79 8915.31 564.11 1680.65 5950075.58 677757.40 927.72 15.00 269.29 13 9700.00 61.44 341.79 8921.45 574.42 1677.25 5950085.80 677753.77 937.00 15.00 0.00 MWD 9725.00 65.19 341.79 8932.68 595.64 1670.28 5950106.85 677746.30 956.10 15.00 0.00 MWD 9750.00 68.94 341.79 8942.42 617.50 1663.08 5950128.54 677738.59 975.79 15.00 0.00 MWD 9775.00 72.69 341.79 8950.63 639.93 1655.70 5950150.78 677730.70 995.98 15.00 0.00 MWO 9800.00 76.44 341.79 8957.28 662.82 1648.18 5950173.49 677722.63 1016.59 15.00 0.00 MWD 9825.00 80.19 341.79 8962.35 686.07 1640.53 5950196.55 677714.44 1037.52 15.00 0.00 MWD 9850.00 83.94 341.79 8965.80 709.58 1632.79 5950219.88 677706.16 1058.70 15.00 0.00 MWD 9875.00 87.69 341.79 8967.62 733.27 1625.00 5950243.37 677697.82 1080.02 15.00 0.00 MWD 9890.40 90.00 341.79 8967.93 747.89 1620.19 5950257.87 677692.67 1093.18 15.00 0.00 14 9900.00 89.97 343.23 8967.93 757.05 1617.30 5950266.96 677689.57 1101.46 15.00 91.20 MWD 9925.00 89.89 346.98 8967.96 781.20 1610.88 5950290.96 677682.58 1123.55 15.00 91.20 MWD 9950.00 89.81 350.73 8968.03 805.73 1606.05 5950315.36 677677.18 1146.36 15.00 91.20 MWD 9975.00 89.74 354.48 8968.13 830.51 1602.83 5950340.06 677673.38 1169.79 15.00 91.19 MWD 9990.40 89.69 356.79 8968.20 845.86 1601.66 5950355.38 677671.85 1184.48 15.00 91.17 15 10000.00 89.69 355.35 8968.26 855.44 1601.00 5950364.94 677670.97 1193.67 15.00 270.00 MWD 10025.00 89.69 351.60 8968.39 880.28 1598.16 5950389.70 677667.55 1217.22 15.00 270.01 MWD 10050.00 89.69 347.85 8968.53 904.87 1593.70 5950414.18 677662.51 1240.18 15.00 270.03 MWD 10075.00 89.70 344.10 8968.66 929.12 1587.64 5950438.28 677655.89 1262.45 15.00 270.05 MWD 10100.00 89.70 340.35 8968.79 952.92 1580.01 5950461.90 677647.70 1283.92 15.00 270.07 MWD 10125.00 89.71 336.60 8968.92 976.17 1570.84 5950484.93 677637.99 1304.52 15.00 270.09 MWD .- 10140.00 89.71 334.35 8968.99 989.82 1564.61 5950498.42 677631.45 1316.41 15.00 270.11 TO BP þ........tW~npath: 1'1..o::>n MD' WEUÞAíH DETAILS FlI1I:n#501-IHH! 500292029402 07-61) 89"00.00 Rig: R<IIf.Oatllm, 10,0651301199613,30 v.s~:~ O:~:: <;~~~ ~::~~1ro REFERENCE JNFORMA TION 64.00 SEC110NI:IETA!LS t>1,,"g TF.u"e VS<>c T"'g<Ot WO MO .Am.oblt!.:," 64$~"35 $900,on- '" i;HIO'T,l1 891.2.00 KOP $$23.36 *932.00 , as<i6,37 89i17,1)0 · 841&,31 1$0'$1'.00 · &1-9-1,00 · 9297,00 T 9-;},$7,O¡¡ · $4$1 Aio · 9597,00 .. 9$17,53 " S637,53 1. 9$.$1.5:t 13 .Q8.jj:OÆJ: ,. 9$$OAO 15 1614t1,OO ro 8250 8300 8350 8400 ~ 2 8800 (- 8850 - 8900 8950 9000 Plan i07-0BP!an#507·,068) 8rij Potnìs 919/2003 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 o -100 -200 -300 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 250 300 350 400 450 500 550 600 650 700 750 800 850 900 950 10001050 1100 1150 1200 1250 1300 13501400 1450 1500 1550 1600 1650 1700 1750 1800 1850 1900 19502000205021002150 Vertical Section at 13.0«:»" 9/9/2003 3:06 PM · , ~ Blind ram~ Choke line HCR valve Pipe ram ~ Empty Cavity --r--i or VBRs '-I........J I 2¡:==®~ I DTK 12/08/03 Nordic 2 ,. & 13-5/8" Workover BOP Stack «5000 psi) , 11" or 13-5/8" Annular Preventer o ~ 11" or 13-518" BOP ~ \ Kill line HCR valve J0==®~ I 11" or 13-5/8" BOP o o 11" or 13-518" tubing head þ= ~ I ~JZn=®~ I J0~ . . CHANGES TO A PROGRAM IN A PERMIT TO DRILL 20 AAC 25.015 ( a) To change a program approved in a Permit to Drill (Form 10-401) before drilling operations start, the operator shall (1) submit and obtain the commission's approval of a new application for a Permit to Drill if the surface location is changed, if the bottom-hole location or the location of an objective formation is changed by more than 500 feet laterally or vertically, or if the change requires a spacing exception under 20 AAC 25.055; however, no additional fee is required. . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME~ðÚ ß?- c>h".B PTD# 20 Lj - (') <¡- 2- X Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn The permit is for a new weUbore segment of existing well Permit No, API No. Production. should continue to be reported as a function ·of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), an records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of S'! conservation order approving a spacing e:JC epti on. _ (Company Name) assumes tbe liability of any protest to tbe spacinge:Jception that may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. . . D D Well bore seg Annular Disposal Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNILOJ-O!iB Program DEV PTD#: 2040420 Company BP EXPLORATION (ALASKA) INC nitial Class/Type DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Administration 1 P~rm it fee attached. - - - - - - - - · . . .Y~s - - - - - - - - 2 .Leas~numberapRrORriate . - - - - - - - - - - - - - · . . .Yßs 3 _U_nique welln.a!T1~_a!ld oumb_er _ . _ . . . . . _ _ _ _ _ _ _ _ _ . . . _ . _. _. _. . - _Y~s - - - - - - - - - -- 4 Well Joc¡:¡t~d ina d_efinedpool. - - - - - - · . . Xes 5 WeIlJoc¡:¡t~d proper _distance_ from driJling unit.b.ound.ary. . · Xes 6 WeIUoc¡:¡t~d proper .distance. from otber w~lIs_ . . . . .Yßs - - - - 7 .S.ufficient.acreageayailable [ndrilJiog unjt. . . . _ . . _ . . . . .Yßs 8 Jf.d~viated, js. weJlbore platincJuded . - - - - - - - - - . . Xes 9 .Qperator onl}' affected party . - - - - - - - - - - - - - - ~ · .Yßs 10 _O-perator bas.appropriate.Qond inJorce . _ _ _ _ _ . _ . _ . . . . . . . _ _ _ . _ . . _ .Yßs - - - - -- 11 Pßrmit call be issued wjtbout co.nserva.tion order _ . ......Xes Appr Date 12 P~rmit call be issued wjtbout ad.ministratilleapprovaJ _ . · Xes - - - - - - - RPC 6/14/2004 13 Can permit be approved before 15-day wait Yes 14 Well Joc¡:¡t~d within area and.strat¡:¡ .authQrized by l!ljectioo o.rder # (put 10.# in. c.O!T1!T1~!lts). (For. NA - - - - - - - - - -- 15 AJI WelJs.Within J(4J!lìle_are.a_of reyieW jdß!ltified (For servjc.e.weU onl}'L . . _ . _ _ _ _ _ _ . . . . NA + - - - - - - - - -- 16 Pre-produced i!ljector; duratio.n.of pre-pro.duGtioo Ißss than 3. months. (For.ser:vice well onJy) . .NA - - - - - - - - 17 AÇMP. finding of Consi$te!lcyhas been issued. for. tbis project. . _. .NA -~ Engineering 18 _Co!lduçtor stril1g.provided . - - - - - - - - - - - ~ - NA 19 .S.urface.casin9PJotects all known USDWs . . . . _ _ ...... .NA - - - - - - - 20 CMT vol adeQuate_ to circulate.o.n .cond.uctoc & SUJtC$g _ ... NA 21 .CMT vol adeQuate_ to tie-in Jongstri!lg to .surf ~g. . ...... .NA - - - - - - - - 22 CMTwill coyer.aU ]<oown.pro.duGtiye borizons - - - - - - - .......Xes 23 .C.asi!lg desig!ls adeQuate tor C,T, B&:!ermafrost. - - - - - - · .Yß$ 24 _Adequ¡:¡tetankage_or re_serye pit. . . . - - - - - . . . . . . .Yß$ t-Iabors.2ES, _ 25 Jf.a.re-drill~ has a 10-403 for abandOl1me.nt be~o ¡:¡RProved . - - .Yßs 6/1/200.4, . 26 Adequate.'^1eUbore. sep~lr¡:¡tjo.n.pro-pose.d. . _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ . . _ . _ . .Yß$ . . . - - - - - - -- 127 Kdiverter require.d, does iLrneet reguJations. . _ _ . . ..... .NA Sidetrack.. . . . _ Appr Date 28 .Drilliog fJujd. program $chematic& equip Jist.adequ¡:¡te _ . . . . . . . . .Yß$ Max MW.1.Q,9.ppg. WGA 6/14/2004 29 BOPEs, do they meetreguJatioo . . . . - - - - - - - - - - - - - - - - - - - . . . . . . . .Yß$ 30 .BOPE.pre.ss ratiog appropriate; test to.(pu.t psig in_commeots) . · .Yß$ Test to.3500.:!si 31 .C.hokemanjfold compJies w/APIRf>-53 (May 84). - - - - - - - - - · . . . . .Yß$ 32 Work will occur without.operation .shutdown. . . - - - - - - - · . . . . .Yßs 33 .Is prese!lce of H2S gas_ prob.able. . . . . . _ - - - - - - - - - - - _ . . . . . . N.o_ 34 Mecba.nic¡:¡l.C9odilion ot we.lIs within ,6.0~ yerified (for s_ervice welJ onJy) . ... _ NA ~ Geology 35 P~rmit cao be issued wfo hydrogen sulfide meas.ure~. _ - - - -- · . . . . N.o_ 36 _D_ata.preseoted on. pote.ntial pyeJRres.sl.lreZooe$_ - - - - - - - - -- NA Appr Date 37 .Sßi.smic.analysis. Qf ~ha-'Iow gaszooes · NA RPC 6/14/2004 38 S~abe.dcOllditipo survey (if off-shore) . .NA - - - - - - - 39 . ContactllameLp!1one.fQrWeelsly progre~sreRort$ [exp1or¡:¡tpry .D!lly]. .. .NA Geologic Date: Engineering Date f!ð ~~y Commissioner: Commissioner: er DTS 3/2/2004 I ."Y~.I~ ...1 ;.;.;.;.:.;.:.;.:.;.;.:-:.;.;.;-:.; lªt.§PºPP~.....···. .............................'...... .................. ........... I, I, I, ··......·.>...............i..~ ... ... I·.·.·:·:·:·:·:·:·j .: I .:.;-:.;-: I ;:;: I . . BOP-Tree I :;:::::::::::::::;:::::;::::::::.;.:.;.:::::::.;.;.:.;.;.;.;.:.:.:.:.;.:.:.:.:.:.;.:.;.;.;.:.:-:-:.:.:.:.: I ~~... "':;~~::,,a; KB Elevation ~..................................·······:···:·····:·····::··1 ..................... ...........-...-.-.-..,.,........'..... .....-.-...-.-.-.-.-.-,.. .'............'",. ,',-.-,',-.-.-.-.-.-,', ............. .-.-.-.-.......'. ......-.-. .......... ........ ..........................'.. ...............'...........'.'............ Rig Floor I GJ$tidktói1Ö¥$.;3iá"Withi);'QWbhí8@) i:i¡¡¡~::¡:i:i:::i~~~:I~i::··':!·:·!'::::: ~ [",,:,:,¡¡·¡r;::·::: I;:);: ]!:!:i~ll~i¡'¡ij¡~:::::: I I .. .:.:.:. ........ ... 11/4t\JrriWtVi:J.I\l~ I ~i:I:~rIB1~11¡;¡:1 .... ··7 ~6" 5000 psi RX-46/1 ,.:.. I '. ~ ...80H1,>.......:.:..:=4:.: .: IfiRlli·:::::: - '.·___·0····· :::m::: : ..... ,:,', · I ChOke Line I::::¡::·;:q·:··· I. I Kill Line . j:¡:j:¡. t--m::ær ~l..1:ö."!rWI!i.....J¡~ / .~ .. I . ..: ,:':":::.:::::::::":\:::::::::::$:::::11 l~jÌ16" 5000 psì , RX-24. ':~~:;':;'¡:~;I· / ~ I I:¡.¡:t::¡:::¡t*~¡:¡:¡t:¡:¡:¡:¡ . 17 1/16" 5000 P$¡ (RX'"46) Qr /::::.::::::::::::::::::::::::::::::::::1 ~ 4 1/16" 5000 psi (RX-39) a····:·;:;:;;;;i::·:;~·· Þ :::i::.:. ":.::::::: 1 Swab Valve I ....:.:.:;.::::.:.. I ~- ~ ssv I 1?#)§¡@þþqp~i,R*~M>1 ::<'1 / I Tree Size I I Master Valve I I I Base Flange I Page 1 p055223 DATE INVOICE / CREDIT MEMO 1/6/2004 PR010504G DESCRIPTION PERMIT TO DRILL THE AlTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ..... BP EXPLORATIQN,(ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGI;, AK995Jß-6612 PAY: 1111I1, t,UI" TO THE ORDER OF: STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE ANCHORAGE, AK 99501-3539 DATE I 1/6/2004 CHECK NO. 055223 GROSS VENDOR DISCOUNT NET :p 01.-0\9 NATiONAL CITY BANK Ashland. Ohio No. P 055223 56-389 412 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT ***!'~t~$1 00 .00******i II- 0 5 5 2 2 311- I: 0 ~ . 20 3 8 11 5 I: O. 2 ? 8 11 b II- H . . . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME$q 07- ob'A PTD# 20' <f-07'ñ X Development Service CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic ·'CLUE" Tbe permit is for a new well bore segment of existing well Permit No, API No. Production. sbould continue to be reported as a function· of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(1), aU records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for well (name on permit). SPACING EX CEPT1 ON DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumestbe liability of any protest to tbe spacing exception that may occur. AI) dry ditch sample sets submitted to tbe Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample inter:vals through target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 07-06B Program DEV _ Well bore seg PTD#: 2040420 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / 1-01L GeoArea 890 Unit 11650 On/Off Shore On _ Annular Disposal 0 Administration 1 Pß(miUee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Leasßn\Jmber _appropriate _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_niq\Je weltn_arnß_a!ld o~mb_er _ _ _ . . _ _ . _ _ _ . _ . . . _ . . . _ _ . _ _ _ _ . _ _ _ _ _ _ . . . _ Yßs. . . _ _ _ _ _ . . . . _ . _ _ _ . _ _ . _ . . _ _ . _ _ _ . . _ _ _ _ _ _ . _ . . . . . _ . _ _ _ _ _ . . _ _ _ . . . _ . _ _ _ _ _ . . _ _ _ . _ _ 4 WeIlJQcatßdina.defined_pool_ ____._ YßS____._._ _____.__ ______._. _________. 5 WelUQcated proper distance_ from drilling unitb_ound.a(y_ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ . . . _ _ _ _ _ . _ _ 6 WellJQcatßd pcoper _distanceJrom other welJs_ .. _ _ _ _ _ . _ _ _ _ _ _ _ Yßs _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . . . _ . _ _ _ _ . . . _ _ _ _ . _ 7 _Sutficien!acreageayailable indJilJi09 unj! _ _ _ _ . . _ _ _ _ _ _ _ . . . _ Yes _ _ _ _ . . _ _ _ _ _ _ _ .. . _ _ _ _ _ _ . _ _ _ _ _ . _ _ 8 Jtdßviated, js weJlbQre platiocluded _ . _ _ _ _ . . . . YßS _ _ _ _ _ .. _ _ _ _ . _ _ _ _ . . _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ 90J)er_ator ooly" affected party _ _ . _ _ _ . . . _ _ _ _ _ _ . . _ YßS _ _ . . . _ _ _ _ _ _ _. _ _ _ _ . _ _ _ 10 .OJ)ecator has.appropriate_b.ond inJorce . . _ _ _ _ _ _ . _ . . . . . _ . . . . _ _ . . . . _ _ . _ . . . YßS. _ _ _ . . . _ . . _ _ _ _ . _ _ _ _ . _ _ _ . _ _ . _ . _ _ _ _ . _ _ _ . _ . . . _ _ . _ _ _ . . _ _ _ _ . _ . _ _ . . _ _ _ _ _ _ _ _ . _ . . _ . 11 Pß(mit ~ao be iss~ed wJthQut co_nservation order _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ Yß$ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _' _ _ _ _ . . . . . _ _ _ . . . . . _ _ _ _ . _ _ _ _ . _ . . _ _ _ _ _ . Appr Date 12 Pßr:mitca!l be iS$~ed wJthQut actmioist(atille.approvaJ _ . _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ Ye$ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ . . _ _ _ _ . . . _ RPC 2/26/2004 13 Can permit be approved before 15-day wait Yes 14 WelUQcated within area and.strata.authorized byl!ljectioo Ordß(# (p\JtlO# in_co01rn.e!lts) (For NA _ _ _ _ . . . . _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . 15 All welJs.wit/liJUl4J·uite_area.of (eyiew jd~otified (FO( serv.ic.ewell oolY"L _ _ _ . . _ _ _ . . . . . _ _NA _ _ . . _ _ _ _ _ _ _ . _ . . _ _ . . _ _ _ . . . _ _ _ _ _ _ . . . _ _ _ _ . _ . _ _ _ _ _ _ . . . _ _ _ _ . . . _ . . _ . . _ _ _ _ _ . . _ _ . . _ 16 PJe-producecti!ljector; duratiQn.ofpre-J)roductiootessthan3months.(For_seryicewellonly) _ _ NA _ _ _... _ _ _ _ _ _ _.. _ _ _ _ _.. _ _ _ _ _... _ _ _ _ _.. _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _._ 17 _ACMP_ Fjodjngof Con.si$tency_h_as beeJ1Ïss\Jed. forJhis pcoject _ _ _ _ _ _ . _ _ _ _ _ _ _NA _ _ _ _ _ _ _ . . . _ _ . _ _ . _ _ _ . _ . _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Engineering Appr Date WGA 2/27/2004 Geology Appr RPC Date 2/26/2004 Geologic Commissioner: IJÌJ 18 _C9!ldu.ctor st(ing_pJQvided _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ NA. . . _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ _ . . . . _ _ _ _ _ . _ _ 19 _S_uúaœcasing.PJote~ts alLknown_ USQWs _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ NA _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 20 .CMTvotadequ.ateto circutate.oncood_uctor_& surfcsg . _ _ _ _ . _ _ _ _ _ . . _NA _ _ . . . . _ _ _ _ _ . .. _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ 21 _CMT vol adeq~ateto tie-inJQng _string to_s\JÚ ~g_ _ _ _ _ . _ _ _ _ _ _ _ NA _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ _ _ _ _ _ _ _ 22 _CMTwilJ coyeraJl (oow_n.pro_d\JctiYe hQrizons . _ _ _ _ _ . . _ _ _ _ _ _ . . . _ _ _ _ _ . _ _ _ YßS. _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ 23Casiog desigos ad_eQua.te for C,.T, B .&. perITJafr.ost _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ . _ _ _ _ Yes _ _ _ _ _ _ . . . _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ . _ . _ _ _ _ _ _ . _ . _ _ _ _ _ . . _ _ _ _ _ _ . _ 24 .ÄdequateJan.kageoJ re_serye pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yß$ _ _ CTQU. _ _ _ _ . . _ . _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ 25 Jf.aJe-drilL has_a. to-403 fQr abandonme_nt beßO apPJoved _ _ _ _ . . _ Yß$ _ _ _ _ _ . _ _ _ . _ . _ _ _ _ . _ . _ _ _ _ . _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 26 Adequatewellboreseparatjo_nJ)roposed. _ _ . _ _ _ _ . _ . _ . . _ _ . _ _ _ _ _ . . _ _ . _ . . . . _ Yß$. . . _ _ _ _ _ . _ _ . . . . . _ _ _ _ _ . . . . . . . . . _ . _ _ _ . . _ . . . . . _ . . _ _ _ _ _ . . . _ _ _ .. _ _ _ _ _ _ _ _ _ _ . . _ _ _ 27 Jtdjverter JequiJed, dQes jt meet reguJatioos. . _ _ _ _ . . _ _ _ _ _ _ _ NA _ _ Sidetrack. _ _ _ _ _ . .. _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ . _ . _ _ _ _ _ . . _ _ _ _ . . _ _ _ _ _ _ . _ _ 28 _DJillio9fJujd_programs~hemat¡c.&equipJistadequatß_. _. _ _ _ _ _. _ _ _ _ _ _ _.. _ _ _ _. _YßS_ . MaxMW8J.ppg.. . _ _ _ _ _ _ _.. _ _ _ _ _. _. _ _ _ _. _ _ _ _ _ _.... _ _ _ _.. __ 29 .BOPEs,_d.o_they meetreguJation _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ Yßs. _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ . _ . _ _ _ . _ _ _ _ _ _ . _ 30 .BOPEpress ra.tiog appropriate; .test to_(pu.t psig in_commeots)_ _ _ _ . _ . Yß$ _ _ Test to 3500_ psi. . _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ 31 .ChokelTJanjfold cQmplies w/APt R:)-53(May 84)_ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ Yes _ _ _ _ . . . _ _ _ _ _ _ _ . . _ _ _ _ . . . _ 32 WQrk will occur withoutoperationshutdown _ _ _ _ _ _ _ . . _ _ _ . _ Yßs . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ . . _ 33 Js prese!lce_ Qf H2S gas_ prob.able _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ No. . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ 34 Mechanical_coodjlio!l of well$ within ,ð.OR yerifiect (foaervjœ wßIJ only) _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ . _ _ - - - - - ~ . - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - 35 Pßrmit GaO be iS$~ed w/Q hydrogen s.ulfide measures _ _ _ _ _ . . _ _ _ _ _ _ _ . . 36D_ata.PJeseotect on_ pote_ntial oveJpres.sure _zones_ 37 _Sßis01ic_analysjs Qf shaJlow gaszooes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ 38 _Sßabedcondjtipo $~rvey(if off-shore) _ _ 39 _ CQnta_ct oamelp/loneJorweekly prpgressreport$ [explorato(yonIYl . . . _ No _ NA_ _' .NA.. __ .NA_ _NA ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date Public Commissioner Date c/27( R e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the me under APPENDIX. No special effort has been made to chronologically organize this category of information. r . Sperry-Sun Drilling Services LIS Scan Utility . ~ôcf () 12- $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 11 17:05:29 2004 tþ/~7f) Reel Header Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/11 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. . . . . . . . . . . . . . . . . . . . .04/10/11 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 PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 7-06B 500292029402 BP Exploration Sperry-Sun Drilling Services 11-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003218817 J. BOBBITT J. RALL MWD RUN 2 MW0003218817 J. BOBBITT J. RALL MWD RUN 3 MW0003218817 J. SACK R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003218817 J. SACK R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 IlN 14E 1215 ~;'.~.f.'I>E· ·'VE····. ·D. . . ~.","' .'>wI. 141 ') r\ I)On LÎ :.-. /...,,;¡ ~ 55.00 26.50 "Ì\1;~Gas Col'Is.Co~n ¡\ndtomge # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 8.500 6.125 SIZE (IN) DEPTH (FT) 9.625 7786.0 7.000 8825.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK (THE TOP OF WHICH WAS AT 7786'MD AND THE BOTTOM WAS AT 7802'MD) ¡ MILL THE WINDOW¡ AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED FOR RUN 1. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD TIE-IN SGRC DATA ARE MERGED WITH RUN 2 MWD DATA. 5. MWD RUNS 3 & 5 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ COMPENSATED THERMAL NEUTRON POROSITY (CTN) ¡ AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD)¡ AND AT-BIT INCLINATION (ABI). NO DATA WERE ACQUIRED ON MWD RUN 4. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 2' UPHOLE PER E-MAIL FROM K. COONEY (SIS/BP) DATED 8/24/04. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 5 REPRESENT WELL 7-06B WITH API#: 50-029-20294-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10401'MD/9021'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. . . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 - 8.6 PPG MUD FILTRATE SALINITY: 2200 - 9000 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name..... ....... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/11 Maximum Physical Record. .65535 File Type.. ......... .....LO Previous File Name. ......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPX RPS RPM RPD ROP NCNT NPHI FCNT PEF DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7594.0 7773.5 7773.5 7773.5 7773.5 7773.5 7784.0 8735.0 8735.5 8735.5 8743.5 8743.5 8743.5 STOP DEPTH 10347.0 10354.0 10354.0 10354.0 10354.0 10354.0 10399.0 10310.0 10310.0 10310.5 10318.5 10318.5 10318.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 7594.0 10399.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: GR 7596.0 10401. 0 BIT RUN NO 1 2 3 5 MERGED MAIN PASS. $ MERGE TOP 7786.0 7815.0 8825.0 9683.0 MERGE BASE 7815.0 8825.0 9683.0 10401.0 # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction......... ....... . Down Optical log depth units.......... .Feet . . Data Reference Point............. . Undefined Frame Spacing. . . . . . . . . . . . . . . . . . . . .60 .lIN Max frames per record....... ..... .Undefined Absent value.............. ....... .-999 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7594 10399 8996.5 5611 7594 10399 ROP MWD FT/H 0.74 253.55 94.0718 5231 7784 10399 GR MWD API 14.71 576.9 88.5227 5507 7594 10347 RPX MWD OHMM 0.52 1757.42 18.6179 5162 7773.5 10354 RPS MWD OHMM 0.53 1842.74 20.4273 5162 7773.5 10354 RPM MWD OHMM 0.52 2000 36.5609 5162 7773.5 10354 RPD MWD OHMM 0.55 2000 53.5347 5162· 7773.5 10354 FET MWD HOUR 0.21 50.29 2.61476 5162 7773.5 10354 NPHI MWD PU-S 8.67 55.15 23.2231 3150 8735.5 10310 FCNT MWD CNTS 143 1916 722.058 3151 8735.5 10310.5 NCNT MWD CNTS 16479 45248 29918.1 3151 8735 10310 RHOB MWD G/CM 0.97 3.213 2.33157 3151 8743.5 10318.5 DRHO MWD G/CM -2.004 0.812 0.0281288 3151 8743.5 10318.5 PEF MWD BARN 0.91 14.83 2.92894 3151 8743.5 10318.5 First Reading For Entire File......... .7594 Last Reading For Entire File.......... .10399 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/10/11 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...... .04/10/11 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name..... ..STSLIB.001 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 7786.0 STOP DEPTH 7815.0 # 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 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ....... ..0 Data Specification Block Type.....O Logging Direction...... .......... . Down Optical log depth units.......... .Feet Data Reference Point........ ......Undefined Frame Spacing............... ......60 .1IN Max frames per record..... ....... .Undefined 09-AUG-04 Insite o Memory 7815.0 7786.0 7815.0 .0 .0 TOOL NUMBER 8.500 7786.0 LSND 10.90 58.0 9.4 2700 5.5 .000 .000 .000 .000 .0 94.0 .0 .0 . Absent value....... .............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 7786 2.12 Max 7815 16.2 Mean 7800.5 9.46576 Nsam 59 59 First Reading For Entire File......... .7786 Last Reading For Entire File.......... .7815 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation.... ...04/10/11 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 Number..... .... ..1.0.0 Date of Generation. ......04/10/11 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 3 . First Reading 7786 7786 Last Reading 7815 7815 header data for each bit run in separate files. 2 .5000 START DEPTH 7596.0 7775.5 7775.5 7775.5 7775.5 7775.5 7815.5 STOP DEPTH 8792.5 8785.0 8785.0 8785.0 8785.0 8785.0 8825.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 10-AUG-04 Insite 66.37 Memory 8825.0 . TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction........ ... .... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing....... ... .......... .60 .1IN Max frames per record.. .......... . Undefined Absent value........... .......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 7815.0 8825.0 34.1 39.0 TOOL NUMBER 149205 145654 8.500 7786.0 LSND 10.90 58.0 9.4 2700 5.5 1.300 .730 1. 000 2.600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name Service Unit DEPT FT Min 7596 Max 8825 Mean Nsam 8210.5 2459 . 72.0 133.0 72.0 72.0 First Reading 7596 Last Reading 8825 · .815.5 ROP MWD020 FT/H 1. 61 253.55 137.513 2020 8825 GR MWD020 API 63.8 403.47 145.017 2394 7596 8792.5 RPX MWD020 OHMM 0.52 1757.42 5.00026 2020 7775.5 8785 RPS MWD020 OHMM 0.53 1842.74 4.58119 2020 7775.5 8785 RPM MWD020 OHMM 0.52 1866.71 4.90384 2020 7775.5 8785 RPD MWD020 OHMM 0.55 2000 16.9399 2020 7775.5 8785 FET MWD020 HOUR 0.21 22.33 1.37715 2020 7775.5 8785 First Reading For Entire File. ..... ... .7596 Last Reading For Entire File... .... ....8825 File Trailer Service name.. ....... ....STSLIB.003 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.. .....04/10/11 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...... .04/10/11 Maximum Physical Record. .65535 File Type....... ........ .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT DRHO RHOB PEF RPM RPD FET RPX RPS GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 8737.0 8737.5 8737.5 8745.5 8745.5 8745.5 8785.5 8785.5 8785.5 8785.5 8785.5 8793.0 8825.5 # 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): STOP DEPTH 9593.0 9593.0 9593.5 9602.0 9602.0 9602.0 9637.5 9637.5 9637.5 9637.5 9637.5 9630.5 9683.0 14-AUG-04 Insite 66.37 Memory 9683.0 8825.0 . BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN ASLD EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Azimuthal Litho-Den 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 .1IN Max frames per record......... ....Undefined Absent value.... .............. ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 9683.0 . 34.1 64.8 TOOL NUMBER 151107 116332 193134 148579 6.125 8825.0 Flo-Pro 8.60 50.0 9.5 9000 6.4 .650 .280 .600 .850 67.0 163.0 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 . BARN 4 1 68 14. 52 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8737 9683 9210 1893 8737 9683 ROP MWD030 FT/H 0.74 197.69 50.705 1716 8825.5 9683 GR MWD030 API 15.6 576.9 57.6408 1676 8793 9630.5 RPX MWD030 OHMM 0.75 1191. 47 38.3406 1705 8785.5 9637.5 RPS MWD030 OHMM 0.77 142.68 43.9576 1705 8785.5 9637.5 RPM MWD030 OHMM 0.82 2000 92.1357 1705 8785.5 9637.5 RPD MWD030 OHMM 0.89 2000 129.544 1705 8785.5 9637.5 FET MWD030 HOUR 0.74 50.29 4.05511 1705 8785.5 9637.5 NPHI MWD030 PU-S 8.67 55.15 22.9315 1712 8737.5 9593 FCNT MWD030 CNTS 143 1916 760.106 1713 8737.5 9593.5 NCNT MWD030 CNTS 16479 45248 29515.4 1713 8737 9593 RHOB MWD030 G/CM 0.97 3.213 2.30064 1714 8745.5 9602 DRHO MWD030 G/CM -2.004 0.525 0.0102602 1714 8745.5 9602 PEF MWD030 BARN 0.91 14.83 3.20196 1714 8745.5 9602 First Reading For Entire File......... .8737 Last Reading For Entire File.......... .9683 File Trailer Service name......... ....STSLIB.004 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .04/10/11 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...... .04/10/11 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR RPX RPS RPM 5 header data for each bit run in separate files. 5 .5000 START DEPTH 9593.5 9593.5 9593.5 9602.5 9602.5 9602.5 9631. 0 9638.0 9638.0 9638.0 STOP DEPTH 10312.5 10312.0 10312.0 10320.5 10320.5 10320.5 10349.0 10356.0 10356.0 10356.0 RPD FET ROP $ . 9638.0 9638.0 9683.5 10356.0 10356.0 10401. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN ASLD EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Azimuthal Litho-Den 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 .1IN Max frames per record........ .....Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 15-AUG-04 Insite 66.37 Memory 10401.0 9683.0 10401.0 76.6 91.2 TOOL NUMBER 184054 116332 193134 159436 6.125 8825.0 Flo-pro 8.50 47.0 9.6 4500 6.8 .750 .350 .750 .900 70.0 156.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel . . DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9593.5 10401 9997.25 1616 9593.5 10401 ROP MWD050 FT/H 3.72 220.3 88.2622 1436 9683.5 10401 GR MWD050 API 14.71 120.81 30.4223 1437 9631 10349 RPX MWD050 OHMM 3.39 38.3 14.3594 1437 9638 10356 RPS MWD050 OHMM 3.38 33.63 14.7837 1437 9638 10356 RPM MWD050 OHMM 3.57 32.7 15.1218 1437 9638 10356 RPD MWD050 OHMM 3.9 28.86 14.7915 1437 9638 10356 FET MWD050 HOUR 0.36 29.92 2.6455 1437 9638 10356 NPHI MWD050 PU-S 11. 73 48.92 23.5703 1438 9593.5 10312 FCNT MWD050 CNTS 263 1498 676.676 1439 9593.5 10312.5 NCNT MWD050 CNTS 17832 40967 30397.8 1438 9593.5 10312 RHOB MWD050 G/CM 1.894 3.017 2.36846 1437 9602.5 10320.5 DRHO MWD050 G/CM -0.059 0.812 0.0494419 1437 9602.5 10320.5 PEF MWD050 BARN 1.17 5.13 2.60329 1437 9602.5 10320.5 First Reading For Entire File... ..... ..9593.5 Last Reading For Entire File.... ..... ..10401 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation. .... ..04/10/11 Maximum Physical Record..65535 File Type........... ... ..LO Next File Name..... .... ..STSLIB.006 Physical EOF Tape Trailer Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............ ....UNKNOWN Continuation Number. .....01 Next Tape Name...... ... ..UNKNOWN Comments........... .... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ... ........ ....UNKNOWN Continuation Number. ... ..01 Next Reel Name.......... .UNKNOWN comments................~ LIS Writing Library. SCient~ Technical Servicee Physical EOF Physical EOF End Of LIS File