The URL can be used to link to this page

Home My WebLink About206-140Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-140 6.50-029-20225-02-00 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 12302 11923 9038 8565 11897 11923 7551 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 41 - 121 41 - 121 Surface 2628 13-3/8" 39 - 2667 39 - 2667 4930 2670 Intermediate 9341 9-5/8" 38 - 9379 38 - 8229 6870 4760 Liner 916 7" 8849 - 9765 7785 - 8544 8160 7020 Liner 1497 4-1/2" 8616 - 10113 7593 - 8786 8430 7500 Perforation Depth: Measured depth: 9618 - 12250 feet True vertical depth:8425 - 9035 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 35 - 8623 36 - 7599 8565 7551Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP-T Packer Liner 3706 3-1/2" x 2-3/8" 8596 -12302 7576 - 9033 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2002000178 849847 850 11755 770 274 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: Noel Nocas Noel.Nocas@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5278 Treatment descriptions including volumes used and final pressure: 13. Sr. Area 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 measured9033 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Mill CIBPs Operations shutdown Change Approved Program 5 N/A 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 0028280 PBU G-04B 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 Meredith Guhl at 8:07 am, Jul 20, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.19 16:18:16 -08'00' Stan Golis (880) DSR-7/21/21 RBDMS HEW 7/22/2021 SFD 7/20/2021MGR27JUL2021 ACTIVITY DATE SUMMARY 7/6/2021 CTU6 1.5" CT Job Objective: Remove CIBP's at 10,060' & 11,535'. MIRU CTU6. Pull tested CTC and PT MHA. Begin making up Baker 1.69" motor & venturi burn shoe BHA. ***Job in Progress*** 7/7/2021 CTU6 1.5" CT Job Objective: Remove CIBP's at 10,060' & 11,535'. MU Baker milling BHA w/1.76" Venturi Burn Shoe. Bullhead 171 bbls of KCI w/SL while RIH. Dry tagged 2-3/8" WFD CIBP at 10,045' ctm, burn over CIBP and push to second CIBP at 11,529' CTMD. POOH and recovered most of plug in burn shoe. MU BOT 3 blade junk mill BHA and RIH. Milled 2nd CIBP at 11,529' ctm, pushed debris to 11,897' ctm. FP well with 38 bbls of diesel while Pooh w/BHA. RDMO CTU6. ***Job Completed*** Daily Report of Well Operations PBU G-04B • • pit3t( gro 4- S P16 266 4-00 Regg, James B (DOA) From: Herrera, Matthew F (DOA) Sent: Sunday, November 5, 2017 3:41 PM e 1111 II I To: Regg, James B (DOA) Subject: RE: PBU G-Pad Deficiency Report Attachments: G-Pad WH Signs .zip Went by G-Pad and all wells in question had the well house signs replaced with ones with PTD numbers. From: Regg,James B (DOA) Sent:Thursday, November 2, 2017 8:57 AM To: Herrera, Matthew F (DOA) <matthew.herrera@alaska.gov> Subject: RE: PBU G-Pad Deficiency Report Please confirm that these well signs have been installed. Deficiency rpt attached so you know which wells. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From:AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOpsCompRep@bp.com] Sent: Monday, September 25, 2017 8:59 AM To: Herrera, Matthew F(DOA) <matthew.herrera@alaska.gov>; Regg,James B (DOA)<jim.regg@alaska.gov> Cc:AK, OPS GC1 Field O&M TL<AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsCompRep( bp.com> Subject: PBU G-Pad Deficiency Report Matt and Jim, Enclosed is the completed Deficiency Report. The Well House signs have been ordered and are scheduled to ship to the Slope on Tuesday 9/26/17. Upon arrival we will schedule install. Reference the below email from our Data Controller to verify the sign orders. Please call with any questions or concerns that you may have. Vince 1 $EIP 1 • S .. i r p 1 • W Y" Cr i 4 Ifiqn ,..... ,,,, p Z CC N Iltill T — 0 H 4.0 Q 0 N T a= i Cl C CN (ro 0(.5 (.., X 0 0. 'a F',I qtr 7 i rix (0 .1,0014e 11 ,,...y '—'111:.:'.1:46::: : a. 3 1..... .. .. .. 1p it z 2 CC �- al. �` . 1,:arl: 1:: ,. CC 03 0 0 ; ' ' amij 1 1.--0.5 Z uniz • -.44;u4) � N � a � oc ,''',1. 1,..:.:::;,....,;•_,..,...:. 0 0 < cn v I �. ,. 0 • • Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Friday, October 13, 2017 1:40 PM 1`1 SDI To: Herrera, Matthew F (DOA); DOA AOGCC Prudhoe Bay Cc: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU G-Pad Deficiency Report Matt I was going through some emails and I couldn't find us fully closing out to the completion of the E-Pad wellhouse sign install from the deficiency report you initiated. Therefore, to ensure you have, please be v advised that all 8 WH signs have all been installed. Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony— 7187 (Alternate: Vince Pokryfki) From: Herrera, Matthew F (DOA) [mailto:matthew.herrera@alaska.gov] Sent: Monday, September 25, 2017 9:01 AM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU G-Pad Deficiency Report Thank you Sir From:AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOpsCompRep@bp.com] Sent: Monday, September 25, 2017 8:59 AM To: Herrera, Matthew F (DOA) <matthew.herrera@alaska.gov>; Regg,James B (DOA) <jim.regg@alaska.gov> Cc:AK, OPS GC1 Field O&M TL<AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsCompRep@bp.com> Subject: PBU G-Pad Deficiency Report Matt and Jim, Enclosed is the completed Deficiency Report. The Well House signs have been ordered and are scheduled to ship to the Slope on Tuesday 9/26/17. Upon arrival we will schedule install. Reference the below email from our Data Controller to verify the sign orders. Please call with any questions or concerns that you may have. Vince Vince Pokryfki Field Well Compliance Advisor 1 • • Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Monday, September 25, 2017 8:59 AM i / To: Herrera, Matthew F (DOA); Regg,James B (DOA) Cc: AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead;AK, OPS FF Well Ops Comp Rep Subject: PBU G-Pad Deficiency Report Attachments: Deficiency Report PBU G-Pad.xlsx Matt and Jim, Enclosed is the completed Deficiency Report. The Well House signs have been ordered and are scheduled to ship to the Slope on Tuesday 9/26/17. Upon arrival we will schedule install. Reference the below email from our Data Controller to verify the sign orders. Please call with any questions or concerns that you may have. Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony- 7187 Alternate:Lee Hulme From: Lastufka, Joseph N Sent: Friday, September 22, 2017 4:19 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU G-Pad Deficiency Report Ordered. Could possibly be ready on Monday. I'll keep you posted. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 • • BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788DIAnchorage, AK From:AK, OPS FF Well Ops Comp Rep Sent: Friday, September 22, 2017 1:21 PM To: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Cc:AK, OPS GC1 Field O&M TL<AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsCompRep@bp.com>; Cocklan- vendl, Mary E <mary.cocklan-vendl@bp.com>; Pomeroy, Glen<Glen.Pomeroy@bp.com> Subject: FW: PBU G-Pad Deficiency Report Joe, Can you please order new well house signs for the following G-Pad Wells: G-4, 5, 17, 19, 21, 23, 26, 31. Please utilize the bottom hole locations and Permit numbers found in DWF. GC1 Team, Once the signs arrive please ensure that they are installed asap as this is a "Compliance Issue"with a formal Deficiency Report submitted from the AOGCC. Thanks for the help, Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony- 7187 Alternate:Lee Hulme From: Herrera, Matthew F (DOA) [mailto:matthew.herrera©aalaska.gov] Sent: Friday, September 22, 2017 11:44 AM To: Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: PBU G-Pad Deficiency Report These were found during SVS testing on pad yesterday Nate gores a Petroleum Inspector 2 • • Alaska Oil & Gas Conservation Commission Matthew.herrera alaska.gov 907-659-2714 (Slope Office) 907-448-1227(Slope Cell) 907-953-7966 (Cell) 3 • • State of Alaska Oil and Gas Conservation Commission 10(1(1_7 Deficiency Report Location: PBU G-Pad Date: 9/21/2017 PTD: Multiple Operator: BPXA Type Inspection: SVS Operator Rep: Monty Owens Inspector: Matt Herrera Position: Lead OP S52— Op. Phone: 907-659-4084 Correct by(date): O Op. Email: AKOPSGC1Wellpadlead@bp.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Mutliple Wellhouse signs on the pad do not have the PTD numbers for that specific well. List of wells with deficient well house signs: PBU04,05,17,19,21,23,26 and31 Signs ordered on 9/22/17 and scheduled to ship to the BPXA North Slope on 9/26/17. 9/26/17 Sign install scheduled. See email concerning the Well House sign order. (dated: 9/22/17) Attachments: Monty Owens Operator Rep Signatures: Matt Herrera AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • • Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Monday, September 25, 2017 8:59 AM c"<66 (01.4i 61 To: Herrera, Matthew F (DOA); Regg,James B (DOA) Cc: AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead;AK, OPS FF Well Ops Comp Rep Subject: PBU G-Pad Deficiency Report Attachments: Deficiency Report PBU G-Pad.xlsx Matt and Jim, Enclosed is the completed Deficiency Report. The Well House signs have been ordered and are scheduled to ship to the Slope on Tuesday 9/26/17. Upon arrival we will schedule install. Reference the below email from our Data Controller to verify the sign orders. Please call with any questions or concerns that you may have. Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony-7187 Alternate:Lee Hulme From: Lastufka, Joseph N Sent: Friday, September 22, 2017 4:19 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU G-Pad Deficiency Report Ordered. Could possibly be ready on Monday. I'll keep you posted. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 1 • • Woiki BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788DIAnchorage, AK From:AK, OPS FF Well Ops Comp Rep Sent: Friday, September 22, 2017 1:21 PM To: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Cc:AK, OPS GC1 Field O&M TL<AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsCompRep@bp.com>; Cocklan- vendl, Mary E <mary.cocklan-vendl@bp.com>; Pomeroy, Glen <GIen.Pomeroy@bp.com> Subject: FW: PBU G-Pad Deficiency Report Joe, Can you please order new well house signs for the following G-Pad Wells: G-4, 5, 17, 19, 21, 23, 26, 31. Please utilize the bottom hole locations and Permit numbers found in DWF. GC1 Team, Once the signs arrive please ensure that they are installed asap as this is a "Compliance Issue"with a formal Deficiency Report submitted from the AOGCC. Thanks for the help, Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony- 7187 Alternate:Lee Hulme From: Herrera, Matthew F (DOA) [mailto:matthew.herrera@alaska.gav] Sent: Friday, September 22, 2017 11:44 AM To: Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: PBU G-Pad Deficiency Report These were found during SVS testing on pad yesterday Neat qevretet Petroleum Inspector 2 • State of Alaska Oil and Gas Conservation Commission Deficiency Report 10`10 Location: PBU G-Pad - Date: 9/21/2017 PTD: Multiple Operator: BPXA Type Inspection: SVS Operator Rep: Monty Owens Inspector: Matt Herrera Position: Lead OP • Op. Phone: 907-659-4084 Correct by(date): 101-7 (7,,017 Op. Email: AKOPSGC1WellpadLead@bp.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Mutliple Wellhouse signs on the pad do not have the PTD numbers for that specific well. List of wells with deficient well house signs: PBU-4,05,17,19,21,23,26 and31 Attachments: Monty Owens Operator Rep Signatures: Matt Herrera AOGCC Inspector *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI 1. Operations Performed Abandon 0 Plug Perforations H Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: Set CIB Plug H 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-140 3. Address: P.O.Box 196612 Anchorage, Development H Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20225-02-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number: PBU G-04B 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 12302 feet Plugs measured 11535/11923 feet true vertical 9033 feet Junkfeet measured Effective Depth: measured 11535 feet Packer measured 8566 feet OCT 19 2017 true vertical 9040 feet Packer true vertical 7552 feet r A®GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 41 -121 41-121 Surface 2628 13-3/8"72#N-80 39-2667 39-2667 4930 2670 Intermediate 9342 9-5/8"47#N-80 38-9379 38-8229 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10620-10700 feet 10830-10960 feet 11070-11500 feet 11550-11670 feet 12030-12250 feet True vertical depth: 9043-9039 feet feet 9035-9043 feet 9046-9040 feet 9040-9038 feet 9037-9035 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 35-8624 35-7600 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 201T SCM01E DE.C22 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: 263 19276 4 440 970 Subsequent to operation: 333 14934 34 400 676 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development H Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil H Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Oshiro,Joleen Contact Name: Oshiro,Joleen Authorized Title: G Pad Engiinne�er/New Wells Delivery PE(GC1/FS3 Contact Email: JOLEEN.OSHIRO©bp.com Authorized Signature: Ft.-- --- V Date: 14 1i I'1 Contact Phone: +1 907 564 4606 Form 10-404 Revised 04/2017 i/`7-"L- i Z ^ii..; ^3 �" z �' �� R�Sis�ui� �L. U�,� L � Llj II Submit Original Only /llsf/7 7 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 18, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Cast Iron Bridge Plug in Well G-04B, PTD # 206-140. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • Q. coo CO co O N O cooco (O N- O O 10 O N U 17) 00 0 (000 1- COO O N Ca 't CO CO CO CO N- O) CO (r) CO (n O CO N co co (p co CO N (n co f- in co N OO N- O 00 co N- _ • CO V (n 0) CO N CO O) CO 10 V' CO CO Ln • N- it N- O V' NO CO cr CO N- O CO N N O CO O N O N- O N d) CO Q) 00 V 0 MM I I I I ,4j W Q �- CA CO Cr) 'Cr V O 0) 1 V' CO CO (n CO CO (n CO 00 CO CO CO EL O O OO O co, 00 co00 co co 00 Z J J _I --I C d N Z N X 4- co CV *k N .0 O V CO U N co N N N CO CO N O CO N V V. .c co NCO O O (A C oo CO co O CO .4- co G) N co CO .- O 0) J W cm0 - c F- W 0 D < U ❑ tiaC Z Z 0 w W W W w 0D — Z Z Z Z D U (n z J J J J • 0 Packers and SSV's Attachment PBU G-04B SW Name Type MD TVD Depscription G-04B TBG PACKER 8566.33 7552.24 4-1/2" TIW HBBP-T Packer G-04B PACKER 8626.25 7601.17 7" Baker ZXP Top Packer G-04B PACKER 8889.28 7818.42 7" Top Packer • • 3 \ 4— ( c * = o f 2 .a oc ® a E .a & o / a) /$ 2 ®G ("' - - § Eo ._ r .9 0) (Y) / Q < o \ o-J � � # af ƒ .\ \ E » g z Cl. eg Amo = J - - 0 a "; as q- 46 2 / \ , c ± C y % / \\ f \ E k < \ N % o 2 5 \ % \ \ eGoz — m » 0 20 � 08 ?= «El 6 � @ - 2 $ # § o ® 2 7 \ \ / _j - 0 0 / / _ w G / _ ® ° ° a o n f k ° \ \ - \ 0 _ CO 2O » n / .2 oQ_ / « /\ k . 0 g t O E R / / _c 0 fp Ce /� � \ƒ \ �/ � / \ % / / 0 - u a) a \ m / '� _ $ A a O '$ •co = 'Cr) O o « ® o . G o e \ \ - \ e 2 / n = 2 ƒ 6 g - / O I / \ O L.,-) \ O o \ % D ° \ ± I o e / ° • E = U \ § \ \ ® E / » CO \ D E _ I % / / £ o k \ \ o m O QQo - 3- 0) OLI \ \ w H » » w \ r r / % c r--- ,- m c (3)`- l- 5 / \ \ < _ 10 LFFAD= 4"McEVOY G_0 4 B FLS sAilli NOTE '"*WELL ANGLE>70"@ 10517•"• ACCTUATOR= BAKER C t OKB.aef= 61.3 BF.ELEV= 36.62' 2184' —14-1/2"S-SSV FES HXO LAND NP,D=3.813" KOP= 3209' ( Q Max Angie= 98"@ 10620' 2204' —9-5/8"FOC j Datum MD= 10228' 1 Datum N D= 8800'SS —� 2684' 9-5/8"DV PKR 13-3/8"CSG,72#,N-80,D=12.347" —I 2667' GAS LET MANDRELS ST MO ND DEV TYPE VLV LATCH FORT DATE 2 B / 8/ Minimum ID = 1.920" @ 8604' 1 67824177 61694110 3733 F 5-1 HE TB SODOME RMRM zo16 0404/11810707 3-1/2" X 2-3/8" XO I 8554' H4-1/2"FES X NP,D=3.813" 2111 ��f 8565' —I9-5/8"X 4-1/2"1W FUBP T PKR,N3=3.916" 8589' —14-112"FES X NP,CI=3.813" 8596' —3.70"BOT DEPLOY SLV,D=3.00" H 8604' —13-1/2-X 2-3/8"STL XO PN,D=1.92" I 8611' —14-1/2'HES XN NP,MILLED ID=3.80"(10/07/06) 8616' —19-5/8"X 4-1/2"BKR TRACK SLV,D=3.958" 8623' —4-1/2"WLEG,D=4.00"(11 :WLE3G 4-1/2"TBG,12.6#,L-80 BTGAI� — 8621' ' NOT IMERTED IN TBC&MISALIGNED) .0152 bpf,13=3.958" r, 8622" —1 E LN D Tr LOGGED 03/25/96 8625' —19-5/8"X 7"BKR 2:XP PKR,D=6.375" TOP OF 4-1/2"LNR H 8369' TOP OF 7"LNR H 8840' 8630' --19-5/8"X 7"FMC LNFt HGR,D=6.188" :. 8637' H7"X 4-1/2"XO PHS,D=3.968" • 4 9-5/8"CSC,47#,N-80 B1RS,13=8.681" H 9370' I----11 4 F/. 4 1NLLOUT WINDOW(G-04A) 9765'-9815' 7'LNR,29#,N-80$TRS,.0371,D=6.184" —I� —9765' 14 4-1/2"VV PSTOCK(XX/XX/XX) —1 10113' 4`444444 .44414 w/RA TAG @ 10119' 4�444144�4 4-1/2"LNR,12.6#,L-80 BTC-M, -I —10113 `444 '4y 9710' — TOP of CEMENT .0152 bpf,D=3.953" 14 !441 IA ;IiiiutHivIt 104 P. LOUT VMDOW(G 04B) 10113'-10120' PERFORATION StMAARY `1,REF LOG:MGR/CCL/CM.on 04/06/07 4 11636' 12-3/8"CEP(09/17/17) ANGLE AT TOP PERF:98"@ 1062( 11923' --12-3/8"CEP(12/09/12) Note:refer to FYoduction DB for historical perf dat12266' SIZE SPF MTBR1lAL OFTYSQZ SHOT SQZ 444jlj+jlj Al 1.56" 6 10620- 10700 0 04/08/07 '•••4♦" �`!� 1.56" 6 10830- 10960 0 04/08/07 1.56" 6 11070-11500 0 04/08/07 4,44..4`+4. 1.56" 6 11550- 11670 C 04/08/07 2-3/8"LHR,4.7#,L-80 STL, H 12302' 1.56' 6 12030- 12250 C 04/08/07 .0039,D=1.995" TATE REV BY (X)I9. 4TS DATE REV BY C OMENTS FFRUDHOE BAY UNIT 12/0386 ISG 36 ORIGINAL COMPLETION 09/18/17 AC/JMD SET C IIP(09/17/17) WELL G-04B 12/05/95 N-28E SIDETRACK COMPLETION FIER IT No: 2061400 04/04/07r1ORDlC' CTD SIDETRACK(G-048) API No: 50-029-20225-02 12/14/12 DM5/JM7 SET 2-3/8'CEP(12/09/12) SEC 12,T11 N,R13E,2363'FT./&1974'FEL 02/21/14 RB/JM) TREE C/O(02/13/14) 08/19/14 PJC LNR/TBG/CSG/PEFF UPDATE BP E3cploration(Alaska) image Pject Well History File Cr 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. ~~ ~ - 1 ~- ~ Well History File Identifier Organizing (done) o..o,aea uiuiuiuimiiii o R„~.~~„aed IIIIIIIIINIIIIIIII RESCAN DIGI L DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ' ^ Maps: reyscale Items: ~ ~`~ ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: `~ ~ /s/ Pro"ect Proofing J III II'I'II'II) II III BY: Maria p Date: ~ ~ ~ ~) ~ !s/ i x 30 1 = ~ + ~ ~~ =TOTAL PAGES on Scanning Preparat ___ __ (Count does not include cover sheet) ~ /~ BY: Maria `~ Date: ' ~ ~/~) ~r `~ /s/ I ~/ ` Production Scanning Stage 1 Page Count from Scanned File: 'tea ~ (Count does include cover sheet) Pa a Count Matches Number in Scanning Pre aration: V YES NO ~' 9 BY: Maria Date: ~ ~ ~~ ~ J /sl Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scannin is complete at this point unless rescanning is required. II (II'I II I II II I I III 9 ReScanned III 111111 IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked 10!6!2005 Well History File Cover Page.doc RECEIVED • STATE OF ALASKA AlikA OIL AND GAS CONSERVATION COMMON JAN 112013 s REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon 11 Repair Weill Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number BP Exploration (Alaska), Inc Name: Development Q Exploratory ❑ ° 206 -140 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number:. Anchorage, AK 99519 -6612 50- 029 - 20225 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028280 - PBU G -04B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,. To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12302 feet Plugs measured 11923 feet true vertical 9033 feet Junk measured None feet Effective Depth measured 11923 feet Packer measured See Attachment feet true vertical 9037.64 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" x 30" 34 - 110 34 - 110 0 0 Surface 2634 13 -3/8" 72# N -80 33 - 2667 33 - 2666.95 4930 2670 Intermediate None None None None None None Production 9338 9 -5/8" 47# N -80 32 - 9370 32 - 8221.54 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10620 - 10700 feet 10830 - 10960 feet 11070 - 11500 feet 11550 - 11670 feet 12030 - 12250 feet True Vertical depth 9043.21 - 9038.54 feet 9035.3 - 9043.45 feet 9046.11 - 9039.54 feet 9040.07 - 9037.96 feet 9037.27 - 9035.11 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 31 - 8623 31 - 7598.51 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): SCANNED MAR 0 6 2013 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 22511 10 0 711 Subsequent to operation: 531 15146 20 0 739 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 A Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Q Gas ❑ WDSPUJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ 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 Nita Summerhays Email Nita.Summerhays( bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician I7 1- %A / Phone 564 -4035 Date 1/16/2013 Signatu - % / /a /� /iiiw�_._ i i ►_ ■ RBDMS JA ' 8 1811 .2 vi ,r ,1 . - %3 2 // 2 /13 Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028280 ,SUMMARY CTO $ wfl .5t tapered string • • -. wa . o • cope: e ® for water shut off. «InterAct Publishing» MIRU ...Continue WSR on 12/8/2012 12/9/2012... CTU #8 w /1.50" tapered siring .109" -.134" wall Job Scope: Set CIBP for water shut off. «InterAct Publishing» ...Continue WSR from 12/8/2012... Function test BOP and RIH w/ 1.75 drift OAL =9.50' Clean drift to bottom at 12248' CTM. RIH w /memory GR /CCL OAL= 11.72' Log up at 45 fpm from 12191'- 11400' stopped and painted yellow & red flag at 12000' for depth control. RIH with Weatherford 2 3/8" CIBP stopped at reference flag and corrected depth to center of element. Continued up hole and set CIBP at 11923' adjusted depth down 23' to avoid collar and put CIBP mid joint. POOH ...Continue WSR on 12/10/2012... 12/9/2012 CTU #8 w/1.50" tapered string .109 " - .134" wall. Job Scope: Set CIBP for water shut off. «InterAct Publishing» ...Continue WSR from 12/9/2012... Finish POOH and rig down CTU 12/10/2012 Well handed over to operations ** *Job Complete * ** FLUIDS PUMPED BBLS 111 SLICK 1% KCL 130 60/40 METH 241 TOTAL Casing / Tubing Attachment ADL0028280 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" x 30" 34 - 110 34 - 110 LINER 3706 2 -3/8" 4.7# L -80 8596 - 12302 7576.44 - 9033 11200 11780 LINER 1504 4 -1/2" 12.6# L -80 8616 - 10120 7592.78 - 8790.68 8430 7500 LINER 1545 7" 29# N -80 8840 - 10385 7777.4 - 8985.56 8160 7020 PRODUCTION 9338 9 -5/8" 47# N -80 32 - 9370 32 - 8221.54 6870 4760 SURFACE 2634 13 -3/8" 72# N -80 33 - 2667 33 - 2666.95 4930 2670 TUBING 8592 4 -1/2" 12.6# L -80 31 - 8623 31 - 7598.51 8430 7500 • • • • Packers and SSV's Attachment ADL0028280 SW Name Type MD TVD Depscription G -04B PACKER 8565 7480.59 4 -1/2" TIW HBBP -T Packer G -04B PACKER 8625 7529.57 4 -1/2" Baker ZXP Packer 1R>3 == 4" CAND20N • SAE IOTB "WELL ANGLE> 70° @ 1051T' �W 1L EAD= McEVOY � "'ORIGINAL WBLBORE AND G -04A NOT SHOWN ACTUATOR= _ Olt BELOW WHPSTOCK" KB. B-B/ = 70.57 ' BF B.EV = 36.62' I - I KOP= 3209' IVIau Angle = 98° , 10620' ( 2185' H4-1/2" SSSV HES HXO LAND NP D ' 3.813" 1 Datum MD= 10228' Datum ND = 8800' SS 1 1 2204' H9-5/8" FOC 113.3/8" CSG, 72#, N-80, D= 12.347" H 2667' 1 2684' 9-5/8" DV PKR GAS LIFT MANDRE S ST MD ND DEV TYPE VLV LATCH PORT (ATE 2 4178 4110 33 FES-TB DOPE RM 16 04/18/07 1 6783 6169 37 I#S-TB SO RM 20 04/18/07 Minimum ID = 1.920" @ 8604' 3-1/2" X 2 -318" XO I I I 8554' 1- 14 -1/2" ifiS x NIP, D= 3.813" I 171. 8565' 1- 19 -5/8" X 4-1/2" TNV /18/3P-T PKR, ID = 3.916" I I I i 8589' H4 HEM X NP, D = 3.813" I 8596' H3.70" BOT DEFLOY NENT SLV, ID= 3.00" I 8604' 113-11 2" @ 8604 /2'" X 2 -3/8" STL XO PIN I I 8611' 1--14 -1/2" I-ES XN mP, NILLE3) ID = 3.80" (10/07/06) 1 4-1/2" TBG, 12.6 #, L -80 BTC-M —1 8623' I 8616' -- 19 -518" X 41/2" BKR TRACK SLV, D = 3.958" 1 0152 bpf, D = 3.958" 8' ( 41/2" WLEG, D = 4.0" (/06: WI T NOT INSB2T ®tN TB 8 MISA I 8622 H ELMDTTLOGGB)03/25/96 TOP OF 41/2" LM H 8630' `�, 0 8625' 1 - 518" X 4-1/2" BKR ZXP PKR, ID= 3.958" I 1 TOP OF 7" LNR H 8840' 8630' I� 9-5/8" X 4-1/2" Far LN2 HGR, ID= 3.958" I ► 74 I9 -5/8' CSG, 47#, N-80 BTRS, ID= 8.681" —1 9370' ( �� .1 17" LNR, 29#, N-80 BTRS, .0371, ID= 6.184" H 10385' • v •• •• 4• ,.-, fl 9710' I T0C 14-1/2" WHPSTOCK N 10113' 0, ♦� 4-1/2" LNR, 12.6#, L -80 BTC-M 10113' : • : I 0152 bpf, ID= 3.953" 4 . MLLOUT WIsIDOW (G -04B) 10112 - 10120' I RA TAG H 10119' '' -I PBRFORATIDN SUMMARY ...... 11923' H 2 -3/8" CBP (12/09/12) I REF LOG: MGR/CCUCPL on 04106/07 ■ 4 / 1 4 4 4, ANGLE AT TOP PEF F: 98° Cio 10620" Note: Refer to Ffoduction DB for historical pert data 44 1 4 4.* SIZE SPF INTERVAL - OPNISOZ SHOT SQZ 1.56" 6 10620 -10700 0 04/08/07 d 1.56" 6 10830 -10960 0 04/08/07 I FWD — 12265' � ; ''. 1.56" 6 11070 -11500 0 04/08/07 •.�. . 1.56" 6 11550 - 11670 O 04 /08/07 2 -3/8" LN2, 4.7 #, L -80 STL, —1 12302' 1.56" 6 12030 - 12250 C 04 /08/07 _0039, U= 1.995" DATE REV BY COIWMNTS DATE REV BY COMMB4TS PRUDHOE BAY UMT 12/03/76 ORIGINAL COMPLETION 11/04/06 RACTTLH WLEG MISALIGIED WELL: G-04B 12/05/95 SIDETRACK COMPLETION 04/04107 NORDIC 1 CTD SIDETRACK (G -04B) PERMT No: "2061400 11/29/03 ATD/TL.P INDICATE 7" LIAR Q 10385' 12/14 /09 SM/JM) DRLG DRAFT CORRECTIONS AR Pb: 50 -029- 20225 -02 -00 03/06/06 DAV/TLH CSG COQ 12/14/12 DMS/JMD SET 2-3/8° CUP (12/09/12) SEC 12, T11N, R13E, 2163' FN.. & 1974' RI 03/16/09 RPWTLH WAIVER SFTY NOTEDELEItU 10/07/06 SRBTtLH XN 14PPLE MLLB7 BP Exploration (Alaska) DATE: 23- Aug -12 Stephanie Pacillo TRANS#: 6044 Data Delivery Services Technician 1/ � Makana K Bender Scblumberger Oilfield Services .� , ` Natural Resources Technician II ■ WIRELINE Alaska Oil & Gas Conservation Commission 2525 Gambell St, Ste. 400 3 5 3 W. 7'''• r `Ie, Sul tee 100 F2 chorage, AK ;0 i Anchorage, AK 99503 "'` 'N Office: (907) 273 -1770 .;: ~LI.` r SERVICE ,' fJH ' RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR CD's . NAME. _ -_ : _. ORDER # _ f DIST DIST DIST DIST LOGGED PRINTS PRINTS G -258 _BAUJ�00145 -,. „ X • " _- MEMORY (PROF 25 - Jul - 1 1 CD • E -09C 6C00.00024 - X _ _ _ PPROF /IPROF MCNL 12- Jul -12 1 1 CD .. G -0413 C:6O0.00025 X MEMORY PPROF / IPROF MCNL 1 1 CD K -10C BAUJm00138 X _ __ _ MEMORY PPROF WI GHOST _ 29- Jun -12 1 1 CD V -202 0600 =00031 X MEMORY LbL 22- Jul -12 1 1 CD i Z -06A 05X1.00016 X MEMORY PPROF 13- Jul -12 1 1 CD W -02A CBXI.000i8 X MEMORY LEAK DETECTION 15- Jul -12 1 1 CD 14 -33A CSXI -00006 X MEMORY PPROF 13- Jun -12 1 1 CD 05 -23B BAUJa00140 X MEMORY PPROF W/ GHOST _ 3- Jul -12 1 _ 1 CD H -09 C2JC -00027 X (PROF 23- Jun -12 1 1 CD MPS -016 E281 -00021 X PDC CORRELATION 9- Jul -12 1 1 CD MPS -01 B i5 81=00021 _ __ _ X USIT 11- Jul -12 1 1 CD 05 -2212 i CRC =00196 X MEMORY PPROF 9- JuI -12 1 1 CD P1 BYS4a00048 X XFLOW W/ 113P SET RECORD 20- Jun -12 1 1 CD L1-09 BVYC- 00041 _ - X PPROF 16- Jul -12 1 1 CD • L1 - 21 • -- - -_ _ _ __ _ __ _ - _ _ _ - ___ ___ ___ _ PPROF 26- Jun -12 1 1 CD _ N -12 APf8SURVEEL X PPROF 19- Jul -12 1 1 CD 05 -22B BCRC.00196 X MEMORY PPROF WI GHOST 9- Jul -12 1 1 CD 18 -28A 11996389 X SCMT 13- Mar -08 1 1 CD G -25B BAUJf00145 X MEMORY PPROF WI GHOST 24- Jul -12 1 1 CD Z -13A BAUJ -00142 X MEMORY LEAK DETECTION 7- Jul -12 1 1 CD Please return a signed copy to: Please return a signed copy`to: BP PDC LR2 -1, DCS 2525 Gambell St, Suite 400 900 E Benson Blvd "\1 `i Anchorage AK 99503 Anchorage AK 99508 i B oq i " 0 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PAB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 50414ED AUG zu2 333 West 7 Avenue Anchorage, Alaska 99501 ©� j L Subject: Corrosion Inhibitor Treatments of GPB G -Pad O Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) G -Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na qal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G -02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 I G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 --* G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G -06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G-08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -148 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -19B 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -235 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA _ 0.5 NA 2.6 5/30/2010 G -298 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 n ~, 4 •' ~ ~ » - +'~Y~s; a~~~~ .. ~~ 4;: `~* ,,? 4Y ~yy,~ .~" m ,~~_ ~..: ~ MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc '"~~ DATA SUBMITTAL COMPLIANCE REPORT 517/2009 Permit to Drill 2061400 Well Name/No. PRUDHOE BAY UNIT G-04B MD 12302 TVD 9033 Completion Date 4/9/2007 REQUIRED INFORMATION Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20225-02-00 Completion Status 1-OIL Current Status 1-OIL UIC N Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, CNL / GR /CCL Well Log Information: Log/ Electr Data Digital Dataset T Med/Frmt Number Name E D Asc Directional Survey ~ p Diy~ctional Survey I D C Las 15677 nduction/Resistivity og Neutron D C Li " s 15893 Neutron LIS Verification ED C Lis 17296 Induction/Resistivit y ~iog Induction/Resistivity r~og __ Induction/Resistivity ~ og Gamma Ray // ~iLog See Notes Well C ores/Sampl es Information: Name .~' Directional Survey Y (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 10065 12302 Open 5/8!2007 10065 12302 Open 5/8/2007 10065 12301 Open 11/9/2007 RPM, GR, RAM, ROP w/PDS and PDF graphics 5 Blu 1 8207 12242 Open 1/22/2008 MCNL, CCL, GR, CNL 6- Apr-2007 8207 12244 Open 1/22/2008 LIS Veri, GR, CNT 9935 12302 Open 12/15/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 9935 12302 Open 12/15/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 25 Col 10110 42302 Open 12/15/2008 MD MPR, GR 1-Apr-2008 j(5 Cot 10110 12302 Open 12/15/2008 TVD MPR, GR 1-Apr-2008 25 Col 10110 12302 Open 12/15/2008 MD GR 1-Apr-2008 2 Col 8207 12302 Open 12/15/2008 Depth Shift monitor Plot Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2061400 Well Name/No. PRUDHOE BAY UNIT G-04B MD 12302 TVD 9033 ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? '~-/~ Analysis ~-- Y / N Received? Completion Date 4/9/2007 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20225-02-00 Completion Status 1-OIL Current Status 1-OIL UIC N Daily History Received? ,~N Formation Tops ~" • • • .~ ~: BAKER' MV6ME5 COMYAN Y WELL NAME FIELD Baker Atlas PRINT DISTRIBUTION LIST BY EXYLURA'1'lUN (ALASKA) 1NC COUNTY NUK1'H SLUYE BURUUGH G-04B STATE ALASKA PRUDHOE BAY UNIT DATE 12/12/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1391543 Copia of Copia Digital Copia of Copis Digital Each Log of Fihn Data Each Log of Fihn Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~(o-1Lly Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: G-04B Contains the following: 1 LDWG Compact Disc' (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 1391543 ~bCo -/y0 ~ I~~96 Sent by: Catrina Guidry Date: 12/12/08 Received by Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (9U7) 267-6623 Baker Hughes INTEQ 7260 Homer Drive ~~~ Anchorage, Alaska 99518 Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 k/~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastufka at (9071564-4091 Date 11-25-2008 Transmittal Number:93017 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion NS16A 10-21-2008 SCH PL ADVISOR NS16A 10-21-2008 SCH CD-ROM - PL ADVISOR NS34A 09-16-2008 SCH 1 18788.5 19099.5 PERFORATION RECORD NS34A 09-16-2008 SCH CD-ROM -PERFORATION RECORD NS16A 10-20-2008 SCH 1 14190 14390 PRODUCTION PROFILE NS16A 10-20-2008 SCH CD-ROM -PRODUCTION PROFILE /~ i ~~~ ~ ` I , / f ,~ Please Sigh an~Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC Murphy Exploration DNR MMS 1 `~ ~ (~ ~~ ~ ~ ~~ ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvde PO Box 196612 Anchorage; ~~K 99S 19-6612 • David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski 01 /18/08 N0.4560 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Well Jnh ~ 1 nn rloscrinfinn - Iln4n RI Rnlnr Cr1 L-219 11966240 MDT ~}- IC 12/22/07 1 L-114A 11970807 LDL "- 12/30/07 1 L-116 11962777 LDL (- ( 12/31!07 1 V-211 12021135 MEM INJECTION PROFILE - a(~ 12/29/07 1 V-216 12021136 MEM INJECTION PROFILE U 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL _ L, 01/02/08 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL ~} - 01/04/08 1 15-04B 12005202 MEM CEMENT BOND LOG 12128107 1 G-31A 11962778 SCMT j - C 01/01108 1 S-26 11978425 USIT 12/29/07 1 02-16C 11628793 MCNL '~- ~ 08/28/07 1 1 G-046 11628765 MCNL - t st 04/06/07 1 1 K-02D 11209613 MCNL 16 L 07/21106 1 1 17-076 11649940 MCNL - ~ / 02/17/07 1 1 L2-28 11975742 RST = 12/05/07 1 1 Z-06 11968821 RST ~ - 12/13!07 1 1 YLtASt AGKNUWLtUGE KtGEIPT 6Y SIGNING AND RETURNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. _.., ~ ., Petrotechnical Data Center LR2-1 ~ ' ~ `~--~ 900 E. Benson Blvd. ~ ~~' l~~ r `~- - ~ll ~ ~ `'~°" Anchorage, Alaska 99508 Date Delivered: a~,~4.~~ ~, rN" 'Q~~~3 Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: 1~ Date I 1-09-2007 Transmittal Number:92919 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have any questtons, please contact uouglas 1~ortcn at the rli~., at ~o4-~+y i 3 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 05-10C ~'~~~' ~'~ ~,_ C-046, _c~_Q~_-_~~___t :~:.~ =~.~_.-__ G-0.8A urn. ~~. ~.:e~, ~.. P2-1.5Q 1.J~.:~ _c~z~`i -0:-~_. i 5`_~. '',1~ Please ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 49501 ',; ,~ ; '~,i' ~'~~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 (/ . '~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~E~EI~/ED MAY 0 2 2007 WELL COMPLETION OR RECOMPLETION REPORT AND L.kO~ ~Ias a it & Gas Cons. GOmmission Anrhnr~ne 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ~ 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date om , Susp., or Aban 4/9/2007 12. Permit to Drill Number Z06-140 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/29/2007 13. API Number 50-029-20225-02-00 ~ 4a. Location of Well (Governmental Section): Surface: 2363' FNL 1974' FE S 7. Date T.D. Reached 4/1/2007 14. Well Name and Number: PBU G-04B , L, EC. 12, T11 N, R13E, UM Top of Productive Horizon: 893' FNL, 1704' FEL, SEC. 13, T11 N, R13E, UM 8. KB Elevation (ft): 70.57 ' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 5147' FNL, 3140' FEL, SEC. 12, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 12266 + 9034 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 658248 y- 5969286 Zone- ASP4 10. Total Depth (MD+TVD) 12302 + 9033 Ft 16. Property Designation: ADL 028280 ~ TPI: x- 658599 y- 5965483 Zone- ASP4 Total Depth: x- 657142 y- 5966478 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: //YDD MWD DIR, GR, RES, CNL / GR / CCL / , J''Y 9 ~ 3 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD: SETTING DEPTH'TVD HOLE AMOUNT SIZE WT. PER FT. GRADE .TOP BOTTOM S TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 270 cu ft Cement 13-3/8" 72# N-80 Surface 2667' Surface 2667' 17-1l2" 6004 cu ft Permafrost II 9-5/8" 47# N-80 Surf 9 7 ' Surface 8222' 12-1 /4" 1480 Howco Lite, 250 cu ft'G', 149 cu ft PF'C' 7" 29# N-80 8840' 9765' 7777' 8544' 8-1/2" 558 cu ft Class'G' 4-1/2" 12.6# L-80 8630' 1 112' 7604' 8786' 6" 460 cu ft Class'G' 2-3/8" 4.7# L-80 8 9' 12 2' 7576' 9 33' 4-1 /8" 9 u lass 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 1.56" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 8623' 8566' MD TVD MD TVD 10620' - 10700' 9043' - 9039' 10830' - 10960' 9035' - 9043' 25; ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11070' - 11500' 9046' - 9040' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11550' -11670' 9040' - 9038' 12030' - 12250' 9037' - 9035' 2500' Freeze Protect with 60/40 McOH 26. PRODUCTION TEST Date First Production: April 26, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 4/27/2007 Hours Tested 6 PRODUCTION FOR TEST PERIOD OIL-BBL 423 GAS-MCF 269 WATER-BBL 9 CHOKE SIZE 176 GAS-OIL RATIO 637 FIOW TUbing Press. 150 CaSing PreSSUre O CALCULATED 24-HOUR RATE• OIL-BBL 1,690 GAS-MCF 1,076 WATER-BBL 37 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate gYtt;~f'~g~sary). Submit core chips; if none, state "none". ~~ - ~~ None ~~ ~O Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~~1G~{~A~. ~ 28. GEOLOGIC MARKE 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 23S6 /Zone 26 10171' 8826' None 22TS 10234' 8875' 21TS /Zone 2A 10298' 8926' Zone 1 B / 14N 10457' 9022' 30. list of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~/ ~~ Signed Terrie Hubble Title Technical Assistant Date PBU G-04B 206-140 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal N Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-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). IreM 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 28: 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". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 3/25!2007 08:00 - 08:30 08:30 - 10:00 10:00 - 15:00 Operations Summary Report G-04 G-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours ! Task ~ Code' 0.50 RIGU P 1.50 RIGU P 5.001 RIGU I P Page 1 of 12 Spud Date: 7/23/1976 Start: 11 /15/2006 End: Rig Release: 4/9/2007 Rig Number: N1 NPT ~ Phase ~ Description of Operations PRE PJSM with Nordic, SLB, and Veco for reel swap PRE Remove 2-3/8 cementing coil and pick up 2" eline reel #14702 - PRE 15:00 - 17:00 2.00 RIGU P PRE 17:00 - 00:00 7.00 RIGU P PRE 3/26/2007 00:00 - 07:00 7.00 RIGU P PRE 07:00 - 07:15 0.25 RIGU P PRE 07:15 - 08:30 1.25 RIGU P PRE 08:30 - 10:15 1.75 10:15 - 11:15 1.00 11:15 - 13:00 1.75 13:00 - 15:00 2,00 15:00 - 16:00 1.00 16:00 - 21:30 5.50 P PRE N RREP PRE P PRE N RREP PRE P PRE N SFAL PRE 21:30 - 21:45 0.25 BOPSU~ N SFAL PRE 21:45 - 00:00 2.25 BOPSU N SFAL PRE 3/27/2007 100:00 - 04:00 I 4.00 I BOPSUR N I SFAL I PRE Coil Details: 2" x 14880'. Vol: 39.8 bbl. 340k RF Pad prep and tree platform maintence to be done on G-046. Empty and clean pits, cuttings box, and tiger tank. SLB swapping out injector blocks and packoff. SLB sent out a third hand to help with the conversion. Nordic swapping ROPE to 2". This is the first time for this crew working on this BOPE equipment. During pad inspection on G-046 the toolpusher noticed 150 psi on the IA and OA. Will bleed before moving over. The pad prep is in progress and work platform is in the shop for handrail work. Finish up swapping BOPE. Install test cap and test with diesel. SLB is finished with the injector. Turnkey move to G-04B. The rig move will be 7.1 miles. Prep to move rig and leave location 23:00 hrs Continue rig move to G-46. PJSM for backing rig over the well. Back Rig over well. Complete move at 0830, restart Nordic charges. Spot equipment on pad, NU BOPE, Nordic measured the tree at 11' and thought there would not be a problem rigging up. However, the BOP stack will hit the hand rails without adding flanged riser. There is a 3' and 1' riser on the rig. Can't find the 5' riser. Wells group will bring one out for us. Nordic will search for theirs at price pad later Grease tree and choke valves for BOPE test. MU tree adapter flange. Fill Pits with 338 BBL of 2% KC1. Short 12 bolts to finish nipple up, The wrong size bolt came out 2x got it right on the third. Finish nipple up and ru of lubricator. Test BOPE, Trouble getting tree to hold. Call grease crew out. un able to get test. Put heat on valves swab not fully opening maybe frozen apply steam. Still no test. decide to replace BPV with TW C. PJSM to RU of lubricator to Pull BPV and set TW C. Pull BPV with lubricator. Grease crew to pump open SSV. BPV hanging up in swab valve. Reset BPV. Close master valve. Pump down stack to visually inspect. Pull bonnet off swap. Rebuild valve found grease plate bent. The grease plates can get frozen to the gate and the gate pulles it past the seats which float. Subsequently the grease plate can be left partially blocking the opening. The is a common and the grease plates are not used when rebuilding CIW valves. After rebuilding the swab valve. The BPV was pulled with a lubricator. No problem. Attempt to run TWC with lubricator No Go. Cant get centered. LD lubricator. Attempt to set TWC with "TEE" bar. Hanging up in tree. Blinding flash of the obvious. With a rebuilt swab we don't need TWC. Good job Cody.Test against rebuilt & greased swab valve. OK. Good test. Printed: 4/12/2007 10:37:40 AM r 1.50 RIGU N 3.00 ZONISO P 0.42 ZONISO P 0.17 ZONISO P Operations Summary Report Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLETE Start: 11/15/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/9/2007 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours ' Task ~' Code ~_ 3/27/2007 04;00 - 14:00 10.00 ~ BOPSUF~ P 14:00 - 16:00 I 2.001 BOPSUR P 16:00 - 18:30 2.50 BOPSUFj P 18:30 - 19:00 0.50 RIGU I P 19:00 - 21:00 I 2.001 RIGU I P 21:00 - 23:00 I 2.001 RIGU I P 23:30.- 00:00 0.50 RIGU P 3/28/2007 00:00 - 00:15 0.25 RIGU P 00:15 - 00:30 0.25 RIGU P 00:30 - 00:45 0.251 RIGU P 00:45 - 01:45 I 1.00 ~ RIGU I N 01:45 - 02:15 0.50 RIGU N 02:15 - 02:25 0.17 RIGU N 02:25 - 02:40 0.25 RIGU N 02:40 - 05:30 2.83 RIGU N 05:30 - 07:00 07:00 - 10:00 10:00 - 10:25 10:25 - 10:35 10:35 - 12:00 12:00 - 12:15 12:15 - 12:30 12:30 - 14:40 14:40 - 17:30 17:30 - 18:15 ,,~~,, ~~ QQ 18:15 - 21:00 C 'u"4D 21:00 - 21:30 21:30 - 22:00 1.42 ZONISO P 0.25 ZONISO X 0.25 ZONISO X 2.17 ZONISO X 2.83 ZONISO X 0.75 WHIP P BP EXPLORATION Page 2 of 12 Spud Date: 7/23/1976 End: NPT ~ Phase ' Description of Operations PRE Test BOP. Upper 2" Combi P/S not holding. Inspect them and they look fine. Grease a few valves in the choke. Reposition and try again. Need to rebuild 15 choke valve. PRE PU injector. Change out packoff. Thread cable thru injector ,install grapple, and pull back to reel. Install PRE Prep reel and pump slack management. PRE PJSM, discussed operational procedures on RU, cut and handle CT PRE Blow back CT w/ air, RU hydraulic CT cutter, cut 37' of 2" CT, e-line cable exposed, cut additional 20' leaving 8' of a-line hanging, installed CTC, pull test 35k PRE Head up thru Baker upper quick connect, Megger E Line.OK (2000+ Meg Ohms, & 46 Ohms continuity test), SLB installed two RA tags, 7.35' from top of whipstock PRE PJSM on handling BHA, MU tools on cat walk PRE Install bull plug and circ line on CT, test CTC to 4000psi PRE PJSM on handling BHA, PU Baker tools to rig floor, PU, MU CIBP BHA, OAL 56' PRE Lined up tiger tank for returns, spot vac trks on pits and tiger tank, RIH w/ BHA to 154', CT jumped out of alignment with top gooseneck roller scrapping metal to metal causing damage to CT peeling off metal shavings SFAL PRE Unpinned roller housing, reposition CT in roller slot, adjust roller height, pinned roller housing SFAL PRE POH to BHA, PU injector, brk out UOC, RU circ line, circ CT SFAL PRE Blow down BHA, POH, Std back in derrick SFAL PRE Adjust top and btm gooseneck roller alignments SFAL PRE Blow back CT w/ air, cut off CTC, RU hydraulic CT cutter, cut 136' of CT and a-line cable leaving 8' of a-line hanging, offload to metal dumpster, installed CTC, pull test 35k, CTC separated down about 1/4" from end of pipe, cut off CTC, installing second CTC, set screws were stripped in dipple press, tapped out and chased threads, finished installing dipple CTC, pull test to 35k SFAL PRE Head up a-coil, Megger E Line. OK, 2000+ Meg Ohms, & 46 Ohms continuity test WEXIT RIH with CIBP to 9950 WEXIT Tie- in log -4' correction WEXIT RIH to settimg depth 10136. Up Wt 32K, Dn Wt 24K, Close EDC. Pressure to 4100 psi. Set down 3K. to confirm BP set. WEXIT POH swapping to clean KCL. WEXIT LD BHA. WEXIT PJSM for RIH and LD CSH tubing. WEXIT RIH stands from derrick CSH tubing. WEXIT POH LD CSH tubing. WEXIT PJSM. Pu WS and CoilTrax ~., ., ... ~~. .. ".~ , , ... ~ ..~.~ ~ .... ........... , ..r ... ~.,,., ......, ..,.,,,. 0.50 WHIP P WEXIT Run tie-in strip, log down from 9950' to 10050' at 150fph, correlate back to tie-in log from SLB MGR/CCUCNL dated 05 June 2003, correction of -8' 0.50 WHIP P WEXIT RIH with WS to 10123', Up wt 31.6k, Dn wt 19.7k at 15 fpm, PU, position TOWS at 10110', BOWS 10123', orient WS to 180 degrees LS, Close EDC. Circ at 0.3bpm for 2mins to set the Printed: 4/12/2007 10:37:40 AM BP EXPLORATION Operations Summary Report Page 3 of 12 ~ Legal Well Name: G-04 Common Well Name: G-04 Spud Date: 7/23/1976 Event Name: REENTER+COMPLETE Start: 11/15/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 4/9/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ;From - To I~' Hours Task li Code NPT Phase Description of Operations 1 ~ ~ ~ 3/28/2007 21:30 - 22:00 0.50 WHIP P WEXIT whipstock. Pressure up & shear off WS at 2000psi. S/D pumps & set down 5k & WS held. 22:00 - 22:30 0.50 WHIP P WEXIT Circ well to 2# Biozan w/ 2 percent KCL at 100 degrees 22:30 - 00:00 1.50 WHIP P WEXIT POH to WS setting BHA #1, displaced well to Biozan 3/29/2007 00:00 - 00:30 0.50 WHIP P WEXIT Set Back Inj, POH LD WS setting tool, offload from rig floor 00:30 - 01:30 1.00 STWHIP P WEXIT MU window milling assy 01:30 - 04:00 2.50 STWHIP P WEXIT RIH w/ window milling assy, tag whipstock without pumps at 10125'. Correct depth to 10110' 04:00 - 04:35 0.58 STWHIP P WEXIT PU to 9950', run tie-in pass from 9950' to 10035' to confirm WS setting depth. no correction 04:35 - 04:45 0.17 STWHIP P WEXIT RIH tagged WS at 10113', PU to 10103', 1.5 bpm, 2375 psi., RIH to 10113', PVT 286bb1s 04:45 - 10:08 5.38 STWHIP P WEXIT Mill 2.74" window thru 4-1/2", L-80 liner. 1.54 bpm, 2700/2650 psi, 1 k W OB. Milled to 10120 10:08 - 14:15 4.12 STWHIP P WEXIT Mill open hole to 10130'.1.67/1.66 bpm C~2 3050 psi. WOB 2.3K Made three reaming passes. Dry tag. OK. 14:15 - 14:30 0.25 STWHIP P WEXIT Swap to Flo Pro circulate mud to mill. 14:30 - 16:10 1.67 STWHIP P WEXIT POH lay in new Flo Pro. 16:10 - 17:00 0.83 STWHIP P WEXIT LD milling assy.Mill 2.74 Go/ 2.73 No Go. 17:00 - 18:00 1.00 DRILL P PROD1 PU drilling BHA. 18:00 - 21:15 3.25 DRILL P PROD1 RIH, tagged at 10130', tie-in strip with -6.5' correction, FS 1.53 bpm at 2700 psi, Up wt 28.5k, Dn wt 20k, PVT 344 bbls. 21:15 - 00:00 2.75 DRILL P PROD1 Directionally drill to 10235', 1.50/1.45 bpm, 2867/2816 psi, TF 162 - 103R, Dn Wt 20k, Annular pressure 4264 psi, DH well bore pressure 4806 psi, ECD 9.33, DWOB .1.98K, ROP 32 - 65fph, TOWS 10111.6' at 180degs LS, TOW 10112', BOW 10120', RA tags 10119' 13/30/2007 00:00 - 01:35 1.58 DRILL P PROD1 Drill to 10300', 1.55 bpm, 2760 psi, TF 103 - 70R, Annular pressure 4305 psi, DH well bore pressure 4850 psi, ECD 9.35, DWOB 1K, ROP 30fph 01:35 - 01:50 0.25 DRILL P PROD1 Wiper trip to window, overpull of 3k at 10250' 01:50 - 02:45 0.92 DRILL P PROD1 Drill to 10338', 1.55 bpm, 2790 psi, TF 70 - 60R, Annular pressure 4320 psi, DH well bore pressure 4690 psi, ECD 9.39, DWOB 1.3K, ROP 26fph 02:45 - 03:10 0.42 DRILL P PROD1 Short wiper trip to 10250', ratty hole from 10340' - 10310' 03:10 - 04:30 1.33 DRILL P PROD1 Drill to 10444', 1.52 bpm, 2970 psi, TF 60R - 100L, Annular pressure 4327 psi, DH well bore pressure 5011 psi, ECD 9.4, DWOB 2.93K, ROP 75 - 110fph 04:30 - 05:05 0.58 DRILL P PROD1 Wiper trip to window, Up wt 32.3k at 28fpm, Dn wt 16k at 36fph, PVT 341 bbls, hole ratty f/ 10340' -10310' w/ 3 - 5k overpulls through interval, no problems RIH, losing in rate from pump rate, clean out C screen, plugged up with fish eyes 05:05 - 08:50 3.75 DRILL P PROD1 Drill to 10600', 1.55 bpm, 3021 psi, TF 80 - 49L, Annular pressure 4381 psi, DH well bore pressure 5095 psi, ECD 9.44, DWOB 3.56K, ROP 85 - 22fph 08:50 - 11:15 2.42 DRILL P PROD1 Wiper to window pumping up samples to determine existence of primary target interval. Decision to continue 100+' MD to north and land ~ 8969 TVD to see if target sand develops. 11:15 - 14:00 2.75 DRILL P PROD1 Directionally drill 1.55/1.45 bpm at 3021 psi, FS = 2600 psi. DW DP pressure 5050, DH annular pressure 4396 psi ECD = 9.42 WOB 5K, ROP 100+, Drill to 10690'. Geo OK with primary Printed: 4/12/2007 10:37:40 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 i Date II From - To Hours Task . Code NPT I 3/30/2007 11:15 - 14:00 2.75 DRILL P 14:00 - 15:30 1.50 DRILL P 15:30 - 18:00 2.50 DRILL P Start: 11 /15/2006 Rig Release: 4/9/2007 Rig Number: N1 Phase PROD1 PROD1 PRODt 18:00 - 22:45 4.751 DRILL N DFAL PROD1 22:45 - 23:00 0.25 DRILL N DFAL PROD1 23:00 - 00:00 1.00 DRILL N DFAL PROD1 3/31/2007 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 03:00 1.00 DRILL P PRODi 03:00 - 03:30 0.501 DRILL P PROD1 03:30 - 04:00 I 0.501 DRILL I P I I PROD1 04:00 - 05:20 ~ 1.331 DRILL N I DFAL ~ PROD1 05:20 - 05:30 0.17 DRILL N DFAL PROD1 05:30 - 05:50 0.33 DRILL N DFAL PROD1 05:50 - 06:45 I 0.921 DRILL I P I I PROD1 06:45 - 07:45 I 1.001 DRILL I P I I PROD1 07:45 - 08:40 0.92 DRILL P PROD1 08:40 - 09:45 1.08 DRILL P PROD1 09:45 - 10:40 0.92 DRILL P PROD1 10:40 - 11:20 0.67 DRILL P PROD1 11:20 - 11:30 0.17 DRILL P PROD1 11:30 - 12:00 0.50 DRILL P PROD1 12:00 - 13:20 1.33 DRILL P PROD1 13:20 - 14:30 1.17 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 16:45 1.25 DRILL P PROD1 16:45 - 19:00 2.25 DRILL P PROD1 19:00 - 19:50 I 0.831 DRILL I P I I PROD1 Page 4 of 12 ~ Spud Date: 7/23/1976 End: Description of Operations target intervel . POH for lateral assy. POH to Drlg BHA LD building assembly and PU lateral assembly with restivity, stab inj, megger test a-coil, failed Lost signal when surface test coiltrak tools w/ resistivity tool, Troubleshooting problem, Std back injector, found short between lower and upper quick connect, changed out and tested LOC, ok, UOC failed test, attempt to blow back CT, CT jumped top roller assy when pulling injector off well, cut 40' of 2" CT, install kendall dimple CTC, pull test 35k, Head up a-coil, Megger E Line, ok, 2000+ Meg Ohms, 47 Ohms continuity test, attempt to circ, CT frozen MU injector, RIH to thaw out CT to 790', brk circ POH to BHA, brk out inj and UOC, install base plate plug, test CTC to 4000psi, MU UOC, Stab injector, surface test a-coil, ok RIH with Drlg BHA # 4 to 10131' Tie-in pass to 10156', no correction, madd pass to btm at 750fph, ratty hole f/ 10470' to 10482' Circ while MW D switched sample rates from logging to drilling to 12 second sample rates Dril- to 10737' w/ 1.64bpm, 2800psi, TF 90L, FS 2750psi at 1.60bpm, ROP 120fph, MWD data captured but not able to display realtime POH to 10400' while troubleshoot rig link software problem w/ Houston, corrected units in data base for 2" tools, RIH to btm, PVT 324bb1s Drill to 10752' with 1.6bpm 2805/2853 psi, FS at 1.61 bpm, 2500/2550psi, TF 90L, troubleshoot rig link software, system crashed Troubleshoot rig link software problem, PUH to 10635', slowly circ at 1.59bpm, 2500psi, reboot system, RBIH to btm Drill to 10850' with 1.61 bpm 2825/2886 psi, FS at 1.61 bpm, 2500/2550psi, TF 95L, wob 1.27k, annular 4342psi, DH 5010psi, ECD 9.33ppg, ROP 118fph. Wiper to window. 29K Up wt. 2530 psi C~? 1.58 bpm. Motor work (2650psi) 10590 Directionally drill at 1.6/1.57 bpm 2809 psi FS 2680. Wiper to window cir ~ 1.6 bpm and 2680 psi. Clean trip. Directionally drill at 1.6/1.57 bpm 2930 psi FS 2680. W iper to window. Tie-in log added 1.5'. Wiper back to bottom OK. Directionally drill at 1.6/1.57 bpm 2809 psi FS 2680. 1.1 K wob 1, annular 4451 psi, DH 5060 psi, ROP 112fph. drill to 11,300'. Wiper to window. Directionally drill at 1.63/1.54 bpm 3020 psi FS 2775. While swapping to new mud. 2.OK wob , DH annular 4507 psi, DH 5358 psi, ROP 180fph. Drill to 11,450'. Wiper to window. Directionally drill at 1.57/1..49 bpm 2666 psi FS=2470psi 1.2K wob , DH annular 4343 psi, DH 4790 psi, ECD 9.35, ROP 190fph. ROP dropped to 15 - 10 from 11500 - 11536' Wiper to 10141', no hole problems, up wt 31 k Printed: 4/12/2007 10:37:40 AM ~ ~ BP EXPLORATION Operations Summary Report '.Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: G-04 G-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code ~ NPT 3/31/2007 19:50 - 20:00 0.17 DRILL P 20:00 - 20:30 0.50 DRILL P 20:30 - 22:30 2.00 DRILL P 22:30 - 00:00 1.50 DRILL P 4/1/2007 00:00 - 00:50 0.83 DRILL P 00:50 - 01:10 0.33 DRILL N STUC 01:10 - 02:10 1.00 DRILL P 02:10 - 05:00 2.83 DRILL P 05:00 - 06:50 1.83 DRILL P 06:50 - 08:30 1.67 DRILL P 08:30 - 09:30 1.00 DRILL P 09:30 - 09:45 0.25 DRILL P 09:45 - 10:30 0.75 DRILL P 10:30 - 11:35 1.08 DRILL P 11:35 - 13:45 2.17 DRILL P 13:45 - 15:15 1.50 DRILL P 15:15 - 16:20 I 1.081 DRILL I P 16:20 - 16:30 0.17 DRILL P 16:30 - 18:00 1.50 DRILL P 18:00 - 20:15 2.25 DRILL N DPRB 20:15 - 20:45 0.50 DRILL N DPRB Page 5 of 12 ~ Spud Date: 7!23/1976 Start: 11 /15/2006 End: Rig Release: 4/9/2007 Rig Number: N1 Phase ' Description of Operations PROD1 Tie-in log added 2.7' PROD1 Wiper back to bottom, do wt 18k, ratty formation at 10460', FS 2400psi, 1.56bpm PROD1 Directionally drill to 11678', TF 49 - 92L, 1.57/1.47 bpm, 2500 psi, 1.2k wob , ROP 54 -200fph, ECD 9.40 ppg, annular psi 4375, bore psi 4786, PVT 329bb1s PROD1 Wiper to window, up wt 34.5k, do wt 17.6k, slight overpulls of 2-3k at 11245', 11065' and 10470' PROD1 Directionally drill to 11712', TF 93L, 1.57/1.47 bpm, 2500 psi, 1.2k wob , ROP 100 - 40fph, ECD 9.33 ppg, annular psi 4375, bore psi 4786, PVT 329bb1s, hole sticky on btm PROD1 Shut down pumps, relaxed hole, PU with pumps, orienting pipe pulled free with normal PU wt at 35k PROD1 Wiper trip to 10700', no hole problems, circw/ 1.5bpm, 2400psi, cleaning and wiping hole, Up wt 35k PROD1 Directionally drill to 11844', TF 102E - 92R, 1.63/1.56 bpm, 3146 psi, 1.3 - 2.62k wob , ROP 83 - 117fph, ECD 9.47 ppg, annular psi 4393, bore psi 5098, PVT 328bb1s, hole sticky on btm with overpulls of 47 and 50k PROD1 Wiper trip to window PROD1 Directionally drill to 12000', TF 100R - 92R, 1.66/1.59 bpm, 3025 psi, 1.6k wob , ROP 83 - 117fph, ECD 9.47 ppg, annular psi 4419, bore psi 5152, PVT 312bb1s. Drilled 14N shale 11780 - 11850'. Faulted into zone 2 @ 11880'. PROD1 Wiper to window. PROD1 Tie-in to RA. Correction = +5.5' PROD1 Wiper to bottom. PROD1 Directionally drill to 12150', TF 105R, 1.68/1.57 bpm, 3025 psi, .6k wob ,ECD 9.69 ppg, annular psi 4512, bore psi 5169, PVT 302bb1s. ROP 200+. Unable to time drill due to sticking. PRODi Wiper to window. PROD1 Directionally drill to 12302', Planned TD .TF 45R, 1.68/1.57 bpm, 3115 psi, FS=2888, 1.5k wob ,ECD 9.74 ppg, annular psi 4535, bore psi 5169, PVT 297 bbls.ROP 200+. Unable to time drill due to sticking. PROD1 Wiper to window. Pump up last samples to determine the need to extend the well. PROD1 Tie-in to RA. Correction ZERO PROD1 Wiper MAD pass to TD, Set down 10460'. Attempt to work through NO GO. Discuss with Anch Engr. decided to POH for high bent motor. PRODi POH to BHA, std back injector PROD1 POH with BHA, LD Res tool, mtr and bit, bit grade 7-2-BT-N-X-I-CT-TD 20:45 - 21:30 0.75 DRILL N DPRB PROD1 Reprogram MWD tool string without Res, changed out bit, adjusted mtr to a 2.1 deg bend 21:30 - 22:10 0.67 DRILL N DPRB PROD1 PU, MU Cleanout BHA w/ used Hycalog bit, 2.1 deg mtr 22:10 - 00:00 1.83 DRILL N DPRB PROD1 RIH to 10140' 4/2/2007 00:00 - 00:35 0.58 DRILL N DPRB PROD1 Tie-in pass from 10140' - 10155', repeat tie-in pass from 10125' - 10166', correction -17' 00:35 - 02:00 1.42 DRILL N DPRB PROD1 RIH to 10465' w/ TF 70L, stacking weight, several attempts to work past with and without pumps, at various pump rates and running speed, no luck, PU Wt 29k, Dn Wt 15.6k Printed: 4/12/2007 10:37:40 AM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Spud Date: 7/23/1976 Start: 11 /15/2006 End: Rig Release: 4/9/2007 Rig Number: N1 Date 1 From - To I Hours i Task I Code I NPT 4/2/2007 102:00 - 07:00 I 5.001 DRILL I N I DPRB 07:00 - 08:15 1.25 DRILL P 08:15 - 09:30 1.25 DRILL P 09:30 - 09:40 0.17 DRILL P 09:40 - 10:30 0.83 DRILL P 10:30 - 11:30 1.00 DRILL N WAIT 11:30 - 12:00 0.50 DRILL N DPRB 12:00 - 15:00 3.00 DRILL P 15:00 - 15:30 0.50 DRILL P 15:30 - 15:45 0.25 CASE P 15:45 - 21:00 5.25 CASE P 21:00 - 22:00 I 1.001 CASE I P 22:00 - 23:40 I 1.671 CASE I P 23:40 - 00:00 0.33 CASE P 4/3/2007 00:00 - 01:00 1.00 CASE P Phase ', Description of Operations PROD1 Drill from 10465' to 10484', 1.63/1.55bpm, 2720/ 2772psi, stacking weight and stalling motor, ROP 13 - 18fph, no problems PU off bottom. Worked thru 14N shale. PROD1 RIH to TD at 12302 PRODi Wiper to window. PROD1 Tie-in to RA. +1.4' correction. PRODi RIH tag at 12302'. PROD1 Circulate wait on 9.2 Flo Pro C~ 1.6 bpm. 4600 DH annular pressure, 5045 DH CT pressure PROD1 Circulate 9.2 to bit PROD1 POH laying in mud. 11890, 11525 & 11220 7k over pull, little motor work. PROD1 LD BHA RUNPRD PJSM for runing liner. RUNPRD RU floor for the liner job. PU Baker liner equipment. PU 2 3/8" 4.7# L-80 STL liner with cemtralizers, All tubulars were strapped and drifted on piperack in pipeshed, MU torque 1100ft/Ibs, Drifted first 9 joints to confirm joint are not being over torqued. RIH with shoe track, 55 jts liner, 10' pup jt, filled liner with water, continued PU, RIH with 60 jts of liner, ran total of 115 joints of 2 3/8" liner, filled liner with water, MU x-o w/ liner deployment sleeve and 3 1/2" pup jt RUNPRD MU GS Spear, DPS, EDC, powercomms, WS, LOC, UPO, CTC, stab Injector RUNPRD RIH with liner assy on a-coil, Up Wt 35k, Dn wt 19k at 10050', continue RIH set do at 11515', .41 bpm, 1117psi, do wt 18k at 10500' RUNPRD RIH, working pipe thru tight hole at 11515', 11530' RUNPRD RIH w/ liner to bottom at 12302', working thru intermittent tight spots at 11530', 11724', 11738', 11865', 11974', 12060', 12070' 01:00 - 01:25 0.42 CASE P RUNPRD Circ five OH volumes w/ 9.2 ppg Flo-Pro mud 01:25 - 03:15 1.83 CASE P RUNPRD POH to BHA, std bk injector 03:15 - 03:30 0.25 CASE P RUNPRD POH with BHA, LD Baker coil trak and GS running tool 03:30 - 04:30 1.00 CASE P RUNPRD RU N2 unit, Cut off CTC, secure end of a-line cable w/ rubber boot, stab inj 04:30 - 05:35 1.08 CASE P RUNPRD PJSM on N2 blow down operations, lined up N2 returns to tiger tank, bkr Circ thru 2" kill line, Test lines, Blow down E-Coil with N2, RD N2 unit, Offload Baker tools from rig floor 05:35 - 11:00 5.42 CASE P RUNPRD Std Bk injector, install internal CTC, pull test. Spool back pipe and Swap reels, change out packoff in stuffing box 11:00 - 14:30 3.50 CASE P RUNPRD Change out stripper elements to 2 3/8" and swap out 2" combi to 2 3/8", change out middle rams to 3 1/2" VBRs 14:30 - 15:30 1.00 BOPSU P RUNPRD PJSM testing rams, securing area, Install 2 3/8" test jt, Test all 2 3/8" rams and VBR to 350 - 3500psi for 5 min each, LD test joint 15:30 - 18:30 3.00 CEMT P RUNPRD Install internal grapple, ru hardlines, adjust roller assy for 2 3/8" coil, mu stuff box to injector, string cable thru injector, pull test internal CTC, pull coil over stab inj. S/B injector. 18:30 - 19:20 0.83 CEMT P RUNPRD Install dart catcher. Pump 5bbls of McOH spacer ahead followed with 5bbls of water. Close inner reel valve. P/test hardline to reel & inner reel valve to 600psi low & 4000psi high. Circ & fill CT with mud. Printed: 4/12/2007 10:37:40 AM BP EXPLORATION Page7of12~ Operations Summary .Report Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 11 /15/2006 Rig Release: 4/9/2007 Rig Number: N1 Spud Date: 7/23/1976 End: Date !From - To ~~' Hours ! Task !Code 4/3/2007 ~ 19:20 - 20:00 ~ 0.67 ~ CEMT ~ P 20:00 - 20:15 0.25 CEMT P 20:15 - 21:00 0.75 CEMT P 21:00 - 23:30 2.50 CEMT P 23:30 - 00:00 0.50 CEMT P 4/4/2007 00:00 - 00:30 00:30 - 02:30 02:30 - 03:45 03:45 - 04:00 04:00 - 06:00 0.50 CEMT P 2.00 CEMT P 1.25 CEMT P 0.25 CEMT P 2.00 CEMT P 06:00 - 08:00 2.00 CEMT P 08:00 - 08:30 0.50 CEMT P 08:30 - 09:55 1.42 CEMT P 09:55 - 10:30 0.58 CEMT N 10:30 - 11:00 0.50 CEMT P 11:00 - 16:30 5.50 CEMT P 16:30 - 17:30 1.00 CEMT P 17:30 - 18:30 1.00 CEMT N NPT Phase ~, Description of Operations RUNPRD Load & launch wiper dart. Chase dart with mud & pig CT. Dart bumped on catcher C~ 57.3bbls. P/test CTC to 3500psi. RUNPRD PJSM for M/U &RIH with Baker CTLRT. RUNPRD M/U Baker CTLRT BHA with LW P, Hyd disconnect, Swivel, XO, & 1 jt of 2-3/8" PH6 tbg, OAL - 51.42'. M/U injector. RUNPRD RIH with CTLRT BHA circ ~ min rate. Wt check ~ 8500': Up = 33k. Run-in wt = 18k. Continue RIH smoothly & tag TOL 8596'. Set down 10k down C~ 8604' & latch CTLRT into deployment sleeve. P/U ~ 40k & confirm engagement. RUNPRD Establish circ. Load 5/8" steel ball &circ with mud ~ 2.5/2.2bpm & 3200psi. Set down 10k down on CTLRT. RUNPRD Continue circ ball to seat. Slow down to 0.45/ 0.35bpm & 1020psi C~ 40bbls away. Ball on seat @ 56.3bbls. Pressure up to 4100psi & release CTLRT. P/U ~ 33k & confirm release. RUNPRD Line up to pump via the cementing high-pressure line. Circ well to 2% KCL water with double friction reducer @ 2.60/2.10bpm & 2670psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers. RUNPRD Load balance KCL into pits & mix KCL-bio displacement pill. Meanwhile continue circulating KCL @ 1.52/1.28bpm &1140psi. RUNPRD PJSM with all personnel concerning cementing operations. Continue circulating 2% KCL ~ 1.52/1.28bpm & 1140psi. RUNPRD Batch mix 20bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt ~ 04:40hrs. Flush/PT lines to 4k. Pump 16bbls cmt slurry ~ 2.00/1.60bpm & 1920psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Zero MM in & out total. Chase with 30bbls bio-KCL @ 2.15/1.70bpm & 3450psi. Slow down pumps to 1.46/1.31 bpm &1780psi ~ 50bbls. CTW P engage LW P C~ 57.3bbls away. Shear plug with 4000psi. Continue displacing LW P @ 1.46/1.16bpm, 2930psi & bump 71.5bbls away with 1000psi over. Bleed off & check floats held. Pressure up to 500psi & sting out of liner. 13.4bbls cmt pumped around shoe. CIP ~ 06:OOhrs. RUNPRD POH to BHA, std bk injector RUNPRD POH, LD, offload Baker CTLRT and handling tools from rig floor RUNPRD PJSM on handling and running cleanout assy, MU Baker motor and 1.86" mill, Lower MHA, 122 jts of 1"CSH, SLB Upper MHA, XO, Baker CTC, Stab Injector RREP RUNPRD Lost rig power when attempting to bring gen #1 on line, troubleshoot problem, changed out PWM board, still would not start, cause of why generator shut down is unknown. Found metering module switch on each generator in the BUS position instead of a PHASE position which would not recognize the generators trying to start. Switch both metering module switches to a Phase position, started both generators RUNPRD POH, LD 17 jts to retorqued connections with Kelco K-30 hand tongs instead of 18" pipe wrench RUNPRD PU, RIH with 1"CSH, ran a total of 122jts of 1"CSH, mu upper MHA, CTC, Stab injector RUNPRD RIH w/ cleanout BHA to 8269', Generator #2 problems SFAL RUNPRD Troubleshooting voltage irregularities with Gen #2, found Printed: 4!12/2007 10:37:40 AM • BP EXPLORATION Operations Summary Report .Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLETE (Contractor Name: NORDIC CALISTA 'I Rig Name: NORDIC 1 i Date 'From - To Hours ~~ Task I Code NPT 14/4/2007 17:30 - 18:30 1.00 CEMT N SFAL 18:30 - 00:00 5.50 CEMT N SFAL 14/5/2007 100:00 - 00:45 I 0.751 CEMT I N 00:45 - 02:45 I 2.001 CEMT I N 02:45 - 03:15 ~ 0.50 ~ CEMT ~ N 03:15 - 03:30 I .0.251 CEMT I N 03:30 - 03:45 I 0.251 CEMT I N 03:45 - 06:00 2.25 CEMT N 06:00 - 06:30 0.50 CEMT N 06:30 - 17:00 10.501 CEMT ~ N 17:00 - 18:00 18:00 - 19:30 19:30 - 00:00 4/6/2007 00:00 - 01:30 01:30 - 05:00 05:00 - 05:15 05:15 - 06:00 1.00 I CEMT I N 1.50 CEMT N 4.50 CEMT N 1.50 CEMT N 3.50 CEMT N 0.25 CEMT N 0.75 CEMT N SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL SFAL Page 8 of 12 ~ Spud Date: 7/23/1976 Start: 11 /15/2006 End: Rig Release: 4/9/2007 Rig Number: N1 Phase I Description of Operations __ _ _ _ __ RUNPRD exciter assy broken, still investigating cause RUNPRD Prep for swapping out Gen-2 set. Remove stairs, exhaust, airlines, electrical control wiring. Mobilize spare new Gen set from Price-pad and a portable 125 KVA, 480 Volts/188 Amps Gen set from Peak for possible emergency heating & lighting. Meanwhile review situation with BP & Nordic ANC teams & conduct THA for continuing operations with only one gen set. Decide to FP well & CT before attempting to swap out Gen-2 set. Call for 60/40 McOH for FP. RUNPRD W. O. McOH transport to arrive onsite. Meanwhile continue prepping for Gen-2 swap out.0 RUNPRD Circ down 60/40 McOH with MP #2 @ 1.2bpm while POOH C~3 90fpm. Freeze protect CT & wellbore down to 3700' with 60/40 McOH. Freeze protect MP #1 lines with 60/40 McOH. RUNPRD Flowcheck well -stable. Set 2-3/8" CT across BOP stack & S/D pumps. Suspend well operations pending when Gen set #2 is replaced. RUNPRD Conduct THA & risk assessment for powering down rig & swapping fuel lines. RUNPRD Shut in air compressor. Shut down Gen set #1. Disconnect fuel lines to Gen set #2. Hook up by-pass hoses. Bleed air thru pressure line. Restart Gen set #1. RUNPRD Continue prepping for Gen-2 swap out. RUNPRD PJSM, discussed and reviewed plan forward on generator isolation, ND, removal, checking out equipment, safety hazards and precautions. RUNPRD Continue prepping for Gen-2 swap out, Troubleshooting power fluctuation with Gen #1, swapped out Gen #2, secure in place, RU exhaust, air, electrical and fuel lines, bolt and weld down 6 floor mounts to secure generator skid. RUNPRD Shut down rig power, tie-in fuel supply line, RU new fuel line to Gen #1 Troubleshoot power fluctuation with Gen #1, changed out Gen #1 metering module and voltage regulator cards, voltage meter stabilized RUNPRD Attempt to start new Gen Set #2 -not starting. W.O. Mike Schick -Nordic-2 Electrician (Ex NC/Cat Mech) to arrive rig. RUNPRD Troubleshoot 24 volt starting motor on Gen Set #2 with Mike Schick & NC/Cat Mech. RUNPRD Continue troubleshooting. Rectify problem with 24 volt electrical system orrGen Set #2 & finally start Gen #2. RUNPRD Trace back Gen Set #2 to PWM voltage regulator in SCR room & changeout burnt fuses on PWM. S/D Gen Set #2 & program digital display outputs. Bring Gen Set #2 online without problems. Check load sharing between Gens #1 & #2 - OK. Conduct high water temp test, low oil pressure test, over speed test & Gen Set #2 ESD test -all OK. RUNPRD Held PJSM for resuming operations. RUNPRD Bring on SLB power pack. Line up to pump down the CT taking McOH returns to the tiger tank. Displace out McOH FP fluid to tiger tank. Printed: 4/12/2007 10:37:40 AM BP EXPLORATION Operations Summary Report Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT 4/6!2007 ~ 06:00 - 07:00 ~ 1.00 ~ CEMT ~ N ~ SFAL 07:00 - 08:00 1.001 CEMT I P Page 9 of 12 Spud Date: 7/23/1976 Start: 11 /15/2006 End: Rig Release: 4/9/2007 Rig Number: N1 Phase Description of Operations RUNPRD RIH w/ cleanout assy to 8269', do wt 15.3k, Up wt 24k above liner at 8550', .97/.99bpm, 1900/1890 RUNPRD RIH w/ cleanout assy f/ 8269' to 11300' 122 jts of 1" 2.25#, N-80, CSH -Tool Jt OD - 1.60", ID - .864", Tube OD - 1.315", ID - .957" = 3713' 115 jts of 2 3/8" 4.4# L-80 STL - ID 1.995" = 3669' Hole Angle 35 - 92 degrees 08:00 - 12:30 4.50 CEMT P RUNPRD RIH to 11300' - 12055', do wt 16.3k, up drag 41 k, do drag increasing by 4-6k, continue RIH to 12045', with additional do drag at 8 - 1 Ok, working pipe and pumps while RIH, down drag progressively worsened ', 12:30 - 14:00 1.50 CEMT P RUNPRD Treated one drum of safe tube to pit #3, pumping down hole, '~, treating second drum on the fly, UP wt 41 k, Dn wt 16.3k, once safe guard rounded corner, do wt at 18.5k, up wt 37k at 12050' 14:00 - 14:40 0.67 CEMT P RUNPRD RIH f/ 12055' - 12259'(uncorrected), corrected depth from tag at 12265', tagged btm several times to confirm PBTD, circ at 1.05bpm, 2439psi with .60 percent concentration of safe tube to 2 percent double slick KCL system, do wt 18.6k, no drag, returns showed a trace of cement in biozan pill at 8.4 ppg with a PH of 12.5 14:40 - 18:00 3.33 CEMT P RUNPRD POH to BHA, EOP flag at 8432' with BHA 100' off btm, Up wt off btm 38k, brk out injector and CTC, drop 1/2" ball, std back injector, MU head pin, RU 1" handling tools, open circ sub w/ 3000psi, RD head pin 18:00 - 18:15 0.25 CEMT P RUNPRD PJSM & THA for R/B CSH & UD motor/mill. 18:15 - 20:30 2.25 CEMT P RUNPRD R/B 61 stands of 1" CSH & UD cleanout motor/mill. 20:30 - 21:15 0.75 CEMT P RUNPRD M/U swizzle stick & stab injector on well. Close MV & jet BOP stack @ 4.03bpm/1910psi. Flush surface lines. S/B injector & UD swizzle stick. 21:15 - 21:45 0.50 CEMT P RUNPRD R/U dry rod to make dummy BPV run thru tree. Drift BPV thru tree valves without problems. Did not set BPV in THS as DSM did not have an extra 2' T-bar extension to reach the THS. R/D dry rod. 21:45 - 22:00 0.25 EVAL P LOWERI PJSM on P/U &RIH MGR/CCL logging tools & 1" CHS tbg. 22:00 - 22:15 0.25 EVAL P LOW ERi Initialize & test logging tools. P/U tool into rig floor. 22:15 - 00:00 1.75 EVAL P LOWERI M/U logging BHA #9 with SWS MCNUCCUGR logging tool, lower MHA, XO & 6lstds of 1" CSH tbg. 4/7!2007 00:00 - 00:30 0.50 EVAL P LOWERi Continue M/U 1" CSH tbg, XO & upper MHA. M/U injector. 00:30 - 01:30 1.00 EVAL P LOWERI RIH with logging BHA to 8200'. 01:30 - 04:00 2.50 EVAL P LOWERI Log down ~ 30fpm from 8200' to PBTD tagged @ 12258'. Meanwhile pump down 15bbls of pert pill. 04:00 - 05:15 1.25 EVAL P LOWERI Log up ~ 60fpm from PBTD to 10500' while laying-in 150kcps pert pill in liner. Meanwhile conduct fire drill with good response by the crew. 05:15 - 07:40 2.42 EVAL P LOW ER1 POOH to logging BHA #9 from 8200', Std Bk injector 07:40 - 09:10 1.50 EVAL P LOWERI POH w/ logging BHA #9, Std Bk 61 Stds of 1" CSH, LD lower MHA and MCNL tools, offload tools from rig floor. Download log data & fax to ANC Geo -OKs pert picks. From log data, PBTD = 12254' & TOL = 8591'. 09:10 - 10:30 1.33 EVAL P LOWERI PJSM on pressure testing liner lap, secured work area, IA Opsi, OA 68psi, no increase on IA and OA during test, Pressure Printed: 4/12/2007 10:37:40 AM • BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ;From - To Hours ;< Task ;~ Code 4/7/2007 ~ 09:10 - 10:30 1.33 ~ EVAL 10:30 - 11:00 0.50 PERFO P 11:00 - 11:25 0.42 PERFO P 11:25 - 13:20 1.92 PERFO P 13:20 - 15:15 1.92 PERFO P 15:15 - 16:15 I 1.001 PERFOBI P 16:15 - 17:50 17:50 - 19:30 19:30 - 00:00 Spud Date: 7/23/1976 Start: 11 /15/2006 End: Rig Release: 4/9/2007 Rig Number: N1 NPT Phase Description of Operations LOW ERi testliner lap from surface to 2000 psi, pressure dropped to 1875 psi in 30 minutes, lost 118 psi in first 15 mins, lost 7 psi in the last 15 mins, Total lost 125 psi in 30 minutes, Test passed. RD circ lines ISIP 1970 psi 15 min 1882 psi 30 min 1875 psi LOWERI PJSM on handling and running pert gun assy, RU handing tools LOWERI PU perf gun assy, BHA # 10, 11 - 1.56" 6spf 1606pj 60deg phase perf guns with partial blanks and BCF firing hd, OAL 237.77 LOWERI Ran hyd disconnect, 57 stds of 1" CSH, upper MHA, CTC, stab injector LOWERI RIH with perf gun assy BHA #10, tagged btm at 12255', 3x, corrected depth on up stroke at PU wt to 12258' do to a +4' splicing correction, See CCL/GR/CNL memory log dated 6 April 2007, PU, position btm shot at 12250', top shot at 12030', PU wt 37k, Dn wt 19k, PVT 278bb1s LOWERI Load & launch 1/2" AL ball, 1.35bpm, 3700psi, pumped 42bbls, slow rate to .49bpm, 557psi, ball on seat at 56.7 bbls, pressured up to 3000psi, observed guns fire with good surface indication from sonogram and pressure drop. Perforated at 12030' to 12250' 1.58 PERFO P LOW ER1 POH with perf gun assy BHA #10 to 11700', paint EOP flag at 7987', POH to perf gun assy BHA #10, monitor well at TOL 1.67 PERFO N SFAL LOW ER1 05:50 smoke was coming from Schlumberger Power pack generator, shut down power pack, found bearing package on traction motor failed. Open the door to the power pack unit, a small flash fire appeared when the door from the reel house to the power pack unit was opened. Discharged a fire extinguisher to cool down the traction motor. Notified GC-1 Acting Area Manager Randy Lewis, Fire Chief Doug Frey, Drilling HSE Advisor Allen Graff, CTD Engineer Sean McLaughlin, CTD Manager Lowell Crane. No emergency response was needed. Allen Graff, HSE Advisor and Asst Fire Chief Theo Melton came out to rig and did a site investigation of the scene. Schlumberger mechanic troubleshooting equipment 4.50 PERFO N SFAL LOWER? SLB Mech recommends to C/O power-pack traction motor before cont well operations. Mobilize new traction motor from SLB yard. Check on crane availability -none from Veco & Peak. Mobilize a zoom boom forklift from Airport Rentals to pick new traction motor. Request lumber and plywood from Tool Service. Held PJSM & THA for C/O traction motor. Unbolt failed traction motor & pull motor with come-along winch to open area adjacent to power pack. Clear pipe shed & load out run #2 perf guns off the rack. Prep reel house end of pipe Printed: 4/12/2007 10:37:40 AM BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: G-04 Common Well Name: G-04 Event Name: REENTER+COMPLET Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To i; Hours ! Task Code i 4/7/2007 ~ 19:30 - 00:00 ~ 4.50 ~ PERFOt~ N 4/8/2007 100:00 - 04:45 I 4.751 PERFOBI N 04:45 - 05:00 0.25 PERFO N 05:00 - 06:00 1.00 PERFO N 06:00 - 10:30 4.50 PERFO N 10:30 - 12:00 1.50 PERFO P 12:00 - 13:00 1.00 PERFO P 13:00 - 15:00 2.00 PERFO P 15:00 - 15:30 0.50 PERFO P 15:30 - 15:45 0.25 PERFO P 15:45 - 17:00 1.25 PERFO P 17:00 - 18:00 1.00 PERFO P 18:00 - 20:25 2.42 PERFO P 20:25 - 22:20 4/9/2007 22:20 - 22:50 22:50 - 23:55 23:55 - 00:00 00:00 - 00:25 00:25 - 00:40 00:40 - 01:45 01:45 - 02:00 02:00 - 04:20 04:20 - 04:55 04:55 - 06:00 1.921 PERFOBI P 0.50 PERFO P 1.08 PERFO P 0.08 PERFO P 0.42 PERFO P 0.25 PERFO P 1.08 PERFO P 0.25 PERFO P 2.33 PERFO P 0.58 WHSUR P 1.08 WHSUR P Spud Date: 7/23/1976 E Start: 11 /15/2006 End: Rig Release: 4/9/2007 Rig Number: N1 NPT Phase Description of Operations - - - - _ _ _- SFAL LOW ER1 shed for building a wooden slide rack from the elevator door to the catwalk. Load in lumber & plywood into pipeshed. Prep & i build crib with lumber & level with pipe shed door & catwalk. SFAL LOWERI Simulate zoom boom forklift reach to ensure boom can extend into the pipe shed door with the new 40" raise of rig. Source steel plates & finally locate 2 pieces around rig & 2 pieces from SLB yard. Install steel plates on wooden crib to aid in sliding traction motor. Install & weld fabricated steel ramp from catwalk to power pack base. SFAL LOW ER1 Held PJSM & THA for picking up & installing new traction motor. SFAL LOW ER1 Prep zoom boom forklift, pick new traction motor & set it onto the steel slide plate thru the pipe shed door. Sling & slide traction motor across ramp & onto catwalk in front of power pack with come along winches. SFAL LOWERI Winch motor in front & back & slide down ramp onto base. Slide motor into position NU motor and grease coupler, RU electricial wiring, perform load and emergency shut down test. LOW ER1 POH to pert gun assy #1, BHA #10, Std Bk Injector LOWERI PJSM w/ crew on RU and handling 1"CSH, Std Bk in derrick, RU handling tools, Monitor well for 30 min LOWERI POH w/ BHA #10 R/B 57 Stds of 1"CSH LOWERI LD 11jts of 1.56" pert guns, ASF LOW ER1 PJSM on handling and running perf gun assy, RU handing tools LOWERI PU perf gun assy, BHA # 11, 50jts - 1.56" 6spf 1606pj 60deg phase perf guns with blanks and BCF firing hd, OAL 1069' LOWERI MU hydualic disconnect, 34 stds of 1"CSH, X-O w/ 3.65" OD no go, upper MHA, CTC, stab injector LOWERI RIH with perf gun assy #2, BHA #11. Tagged TOL(no-go) at 8591', correcting depth to 11735.4'. -2' correction, See CCL/GR/CNL memory log dated 6 April 2007, PU, position btm shot at 11670', top shot at 10620'. Note 4 separate gun sections. LOWERI Load & launch 1/2" AL ball, 1.63bpm, 3800psi, pumped 45bbls, slow rate to .54bpm, 750psi -slowly climbed to 1050psi prior to ball seat, ball on seat at 60.8 bbls, pressured up to 3600psi, guns travelling upward, observed guns fire with good surface indication from sonogram and pressure drop. POOH to TOL for flow check. Perf intervals: 10620-10700, 10830-10960, 11070-11500, 11550-11670. LOWERI Flow check at the TOL. Well stable. LOW ER1 Continue to POOH to lay down perf guns. LOWERI Flow-check well. LOWERI Flow check well at surface. Well stable. LOWERI PJSM for racking back CSH. LOWERI Stand back 1"CSH. Secure pipe to derrick LOW ER1 PJSM to LD perf guns. LOWERI LD perf guns. POST Load out spent guns from pipeshed. PU nozzle for FP ops. POST RIH to FP to 2500' Printed: 4/12/2007 10:37:40 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: G-04 G-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11 /15/2006 Rig Release: 4/9/2007 Rig Number: N1 Date ;From - To Hours Task Code NPT Phase 4/9/2007 06:00 - 06:30 0.50 W HSUR P POST 06:30 - 07:30 1.00 W HSUR N SFAL POST 07:30 - 08:20 0.83 WHSUR P POST 08:20 - 09:30 1.17 W HSUR P POST 09:30 - 10:40 1.17 W HSUR P POST 10:40 - 12:00 I 1.331 WHSUR I P I (POST 12:00 - 16:00 I 4.001 WHSUR I P I I POST 16:00 - 17:00 I 1.001 WHSUR I N I SFAL I POST Page 12 of 12 Spud Date: 7/23/1976 End: Description of Operations POH, FP 4 1/2" tubing, laying 60/40 McOH Waiting on SLB N2 unit, had to switch out tractor due to mechanical problems RU N2 unit and lines, cool down unit PJSM reviewing operational proceedures for N2 RU, blowdown and RD, thawed out ice plug in cmt line, blow down CT with 7 bbls McOH followed by N2, Std bk injector SAFETY MEETING. Review procedure, hazards and mitigation for setting BPV, RU lubricator, set BPV in 4-1/2" tubing hanger, RD lubricator, secured tree, offload lubricator and tools from rig floor PJSM on pull CT across and securing to reel, Cut off CTC, install internal CTC, pull across pipeshed roof, secure to reel N/D BOP stack, secure stack for rig move, NU, test tree cap with diesel while clean rig pits and cuttings tank PJSM w/ crane operator and rig personnel, discussed lifting operations, safety hazards, concerns and precautions, Spot crane, several attempts to open roof, hydraulic cylinder ram closest to the reel house is opening faster than the hydraulic cylinder ram closest towards the rig floor, estimated opening of 6' on reel house end x 4' on rig floor end, hanging up on upper wind wall, not allowing it to open, closed roof, shut down lifting operation. Prep for rig move to P2-19A. Troubleshoot problem over at P2-19A Released Rig at 17:00 hours on 04/09/2007 Printed: 4/12!2007 10:37:40 AM • by BP Alaska s Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 4/2/2007 Time: 16:01:09 page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: G-04, True North Site: PB G Pad Vertical (1'VD) Reference: 7:04 5!31/1996 12:22 70.6 Well: G04 Section (VS) Reference: Well (O.OON,O.OOE,202.70Azi) Wellpath: G-04B Survey C:~Iculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagrtetic Model: bggm2006 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Fasting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-04 Slot Name: 04 G-04 WeII Position: +N/-S 2412.25 ft Northing: 5969286.00 ft Latitude: 70 19 21.933 N +E/-W 1997.40 ft Fasting : 658248.00 ft Longitude: 148 43 0.718 W Position Uncertainty: 0.00 ft Wetlpath: 6-046 Drilled From: G-04A Tie-on Depth: 10065.56 ft Current Datum: 7:04 5/31/199612:22 Height 70.57 ft Above System Datum: Mean Sea Level Magnetic Data: 9/15/2006 Declination: 24.22 deg Field Strength: 57648 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.57 0.00 0.00 202.70 Survey Program for Defmitive Wellpath Date: 9/15/2006 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 109.27 9770.00 1 : Camera based gyro multisho CB-GYR0.MS Camera based gyro multishot 9801.84 10065.56 2: MWD -Standard (9801.84-119 MWD MWD -Standard 10111.65 12302.00 MWD (10111.65-12302.00) MWD MWD -Standard Annotation MD TVD ft ft 10065.56 8756.87 Tie In Point 10111.65 8785.34 KOP 12302.00 9033.00 TD Survey: MWD Start Date: 3/30/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path x,06-t~lc~ • • bP BP Alaska ~ Baker Hughes INTEQ Survey Report LNTEQ Company: BP Amoco Date: 4/2/2007 Time: 16:01:09 Page: 2 Field: Pr udhoe Bay Co-ordinate(NE) Reference: Well: G-04, True North Site: PB G Pad Vertical (TVD) Reference: 7:04 5/31 /1996 12:22 70. 6 Well: G-04 Sectio n (VS) Reference: Well (O.OON,O.OOE,202.70Azi) Wellpath: G-04B Survey Calculatio n Method: Minimum Curvature Db: O rade Survey ivlD Ind Azim TVA Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 10065.56 53.20 213.80 8756.87 8686.30 -3841.74 457.61 5965455.04 658786.48 3367.58 0.00 MWD 10111.65 50.49 215.91 8785.34 8714.77 -3871.49 436.91 5965424.87 658766.41 3403.01 6.89 MWD 10140.05 48.84 217.30 8803.72 8733.15 -3888.86 424.01 5965407.22 658753.88 3424.02 6.90 MWD 10174.40 40.18 229.11 8828.24 8757.67 -3906.47 407.74 5965389.28 658737.98 3446.54 34.80 MWD 10204.02 37.91 246.06 8851.31 8780.74 -3916.45 392.15 5965378.98 658722.61 3461.76 36.76 MWD 10233.70 38.27 263.85 8874.74 8804.17 X921.14 374.62 5965373.91 658705.19 3472.86 36.90 MWD 10262.68 36.57 283.52 8897.84 8827.27 -3920.08 357.24 5965374.60 658687.79 3478.59 41.52 MWD 10293.39 37.40 302.16 8922.44 8851.87 -3912.96 340.40 5965381.37 658670.80 3478.51 36.51 MWD 10323.41 43.24 310.23 8945.34 8874.77 -3901.45 324.81 5965392.55 658654.97 3473.91 26.06 MWD 10353.81 48.74 316.70 8966.46 8895.89 -3886.39 309.00 5965407.27 658638.85 3466.12 23.68 MWD 10388.84 56.83 329.21 8987.69 8917.12 -3864.12 292.39 5965429.19 658621.78 3451.98 36.57 MWD 10424.08 59.88 342.82 9006.24 8935.67 -3836.79 280.30 5965456.25 658609.11 3431.43 33.97 MWD 10455.49 60.92 337.19 9021.76 8951.19 -3811.14 270.96 5965481.70 658599.24 3411.38 15.93 MWD 10485.87 67.43 327.09 9035.01 8964.44 -3787.05 258.15 5965505.51 658585.92 3394.10 36.78 MWD 10517.35 77.55 321.52 9044.48 8973.91 -3762.74 240.63 5965529.45 658567.90 3378.43 36.29 MWD 10547.79 88.96 317.23 9048.05 8977.48 -3739.84 220.98 5965551.92 658547.76 3364.89 40.00 MWD 10585.49 94.27 307.48 9046.99 8976.42 -3714.49 193.18 5965576.67 658519.44 3352.23 29.43 MWD 10620.47 98.35 310.71 9043.14 8972.57 -3692.58 166.20 5965598.01 658492.01 3342.42 14,84 MWD 10660.45 91.93 326.95 9039.54 8968.97 -3662.70 140.11 5965627.33 658465.29 3324.93 43.51 MWD 10710.40 90.71 335.12 9038.39 8967.82 -3619.05 115.95 5965670.46 658440.22 3293.98 16,53 MWD 10745.19 92.24 332.38 9037.49 8966.92 -3587.86 100.57 5965701.32 658424.19 3271.15 9.02 MWD 10777.45 92.58 329.34 9036.13 8965.56 -3559.71 84.88 5965729.13 658407.90 3251.23 9.47 MWD 10822.15 89.75 327.90 9035.22 8964.65 -3521.56 61.61 5965766.77 658383.84 3225.02 7.10 MWD 10853.26 87.08 327.30 9036.08 8965.51 -3495.31 44.95 5965792.67 658366.63 3207.23 8.80 MWD 10888.67 .86.56 324.69 9038.05 8967.48 -3466.00 25.17 5965821.55 658346.25 3187.82 7.50 MWD 10921.73 85.17 323.31 9040.43 8969.86 -3439.33 5.79 5965847.81 658326.31 3170.69 5.92 MWD 10955.04 85.67 320.83 9043.09 8972.52 -3413.14 -14.61 5965873.56 658305.35 3154.41 7.57 MWD 10986.14 87.70 320.29 9044.89 8974.32 -3389.16 -34.34 5965897.11 658285.13 3139.90 6.75 MWD 11018.87 88.65 318.25 9045.93 8975.36 -3364.37 -55.68 5965921.44 658263.27 3125.27 6.87 MWD 11049.29 90.15 317.38 9046.25 8975.68 -3341.83 -76.11 5965943.54 658242.38 3112.36 5.70 MWD 11082.46 90.92 315.87 9045.94 8975.37 -3317.73 -98.89 5965967.17 658219.10 3098.90 5.11 MWD 11112.88 92.09 314.65 9045.14 8974.57 -3296.13 -120.29 5965988.31 658197.24 3087.24 5.56 MWD 11143.38 92.55 313.31 9043.91 8973.34 -3274.97 -142.22 5966009.00 658174.87 3076.18 4.64 MWD 11174.48 91.72 311.18 9042.75 8972.18 -3254.07 -165.22 5966029.40 658151.43 3065.78 7.35 MWD 11205.91 91.29 309.62 9041.93 8971.36 -3233.71 -189.15 5966049.25 658127.09 3056.23 5.15 MWD 11237.81 91.23 307.06 9041.22 8970.65 -3213.93 -214.16 5966068.50 658101.66 3047.63 8.03 MWD 11280.07 92.07 304.12 9040.01 8969.44 -3189.35 -248.51 5966092.35 658066.81 3038.21 7,23 MWD 11310.69 92.09 302.37 9038.90 8968.33 -3172.57 -274.10 5966108.58 658040.87 3032.61 5.71 MWD 11341.76 89.91 298.83 9038.35 8967.78 -3156.76 -300.83 5966123.82 658013.81 3028.34 13.38 MWD 11373.10 90.31 296.47 9038.29 8967.72 -3142.22 -328.59 5966137.78 657985.76 3025.63 7.64 MWD 11411.52 89.85 293.58 9038.24 8967.67 -3125.97 -363.40 5966153.29 657950.61 3024.07 7.62 MWD 11444.76 88.93 290.48 9038.59 8968.02 -3113.50 -394.21 5966165.10 657919.55 3024.46 9.73 MWD 11474.98 89.23 289.32 9039.08 8968.51 -3103.22 -422.62 5966174.78 657890.93 3025.94 3.96 MWD 11511.01 88.41 286.48 9039.82 8969.25 -3092.15 -456.90 5966185.13 657856.43 3028.95 8.20 MWD 11544.00 90.52 285.38 9040.13 8969.56 -3083.09 -488.61 5966193.51 657824.53 3032.84 7.21 MWD 11592.41 91.44 282.83 9039.30 8968.73 -3071.30 -535.55 5966204.31 657777.36 3040.07 5.60 MWD 11621.47 91.47 281.76 9038.56 8967.99 -3065.11 -563.94 5966209.90 657748.85 3045.32 3.68 MWD 11653.69 90.31 280.21 9038.06 8967.49 -3058.97 -595.56 5966215.37 657717.11 3051.86 6.01 MWD 11682.35 90.43 277.99 9037.88 8967.31 -3054.44 -623.86 5966219.30 657688.72 3058.60 7.76 MWD 11714.40 89.79 274.72 9037.82 8967.25 -3050.90 -655.71 5966222.18 657656.81 3067.62 10.40 MWD 11744.32 89.26 276.46 9038.06 8967.49 -3047.98 -685.48 5966224.46 657626.98 3076.42 6.08 MWD 11774.94 90.55 279.84 9038.11 8967.54 -3043.64 -715.79 5966228.16 657596.59 3084.11 11.81 MWD 11806.51 90.15 283.12 9037.92 8967.35 -3037.36 -746.72 5966233.79 657565.54 3090.25 10.47 MWD ! +~ ~ bP BP Alaska Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 4/2/2007 Time: 16:01:09 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Refereuce: Well: G-04, True North Site: PB G Pad Verti cal (TVD) Reference: 7:04 5/31/1996 12:22 70. 6 R'ell: G-04 Section (VS) Reference: Well {O.OON,O.OOE,202.70Azi) Wellpath: G-04B Survey Calculatio n Method: Minimum Curvature Db: Orade Survev Dill focl Azim TVD SysTVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/10 0ft 11838.61 90.12 286.34 9037.85 8967.28 -3029.20 -777.76 5966241.29 657534.33 3094.70 10.03 MWD 11884.23 90.71 290.28 9037.51 8966.94 -3014.87 -821.06 5966254.71 657490.74 3098.19 8.73 MWD 11916.86 89.17 292.54 9037.55 8966.98 -3002.96 -851.44 5966265.97 657460.13 3098.92 8.38 MWD 11950.71 88.74 294.19 9038.17 8967.60 -2989.54 -882.51 5966278.74 657428.78 3098.53 5.04 MWD 11991.72 91.54 297.76 9038.07 8967.50 -2971.58 -919.36 5966295.91 657391.56 3096.19 11.06 MWD 12030.53 90.83 300.02 9037.26 8966.69 -2952.84 -953.33 5966313.93 657357.20 3092.00 6.10 MWD 12067.14 89.44 301.84 9037.18 8966.61 -2934.02 -984.74 5966332.08 657325.41 3086.76 6.26 MWD 12127.49 89.75 306.60 9037.60 8967.03 -2900.09 -1034.62 5966364.95 657274.83 3074.71 7.90 MWD 12159.71 89.57 308.33 9037.80 8967.23 -2880.49 -1060.20 5966384.00 657248.85 3066.50 5.40 MWD 12195.78 91.87 310.56 9037.34 8966.77 -2857.58 -1088.04 5966406.32 657220.52 3056.11 8.88 MWD 12227.87 92.62 313.09 9036.08 8965.51 -2836.20 -1111.94 5966427.19 657196.19 3045.61 8.22 MWD 12262.19 92.31 315.19 9034.61 8964.04 -2812.32 -1136.54 5966450.54 657171.09 3033.07 6.18 MWD 12302.00 92.31 315.19 9033.00 8962.43 -2784.10 -1164.58 5966478.16 657142.47 3017.86 0.00 MWD WELLHEAD = ACTUATOR = KB. ELEV = 70.57 BF. E1EV = 36.62' KOP = 3209' Max Angle = 98 @ 10620' Datum MD = 10259' Datum ND = 8800' SS 4" CAMERON ~' ~ _O Mc EV OY BAKER FROM CTDIDRLG -DRAFT 13-3/8" CSG, 72#, N-80, ID = 12.347" I~ 2667' Minimum ID = 3.8" @ 8611' 4-1 /2" HES XN NIPPLE (milled to 3.8'`) I I4-1/2" SSSV HES HXO LAND NIP, ID = 3.813" I 9-5/8" DV PKR GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 4178 6783 4109 6168 32 37 HES-TB HES-TB RA RA ~ 4-1/2" HES X NIP, ID = 3.813" ~ 8566 -j 9-5/8" X 4-1/2" TMJ HBBP-T PKR, ID = 3.916" 8596' Top of 2-3~8" Llner 8590' 4-1 /2" HES X NIP, ID = 3.813" 114-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I~ 8623' TOP OF4-1/2" LNR I-~ $630' Top of 7" LNR ~ 8840 9-5/8" CSG, 47#, N-80 BTRS, ID = 8.681" 9370' 7" SIDETRACK WINDOW - 9765-9815' 7" LNR, 29#, N-80 BTRS 10385' / 8611' -~ 4-1/2" HES XN NIP, ID = 3.8" 8616 9-518" X 4-1 /2" BAKER TIEBACK SLV, ID = 7.5" 8623' 4-112" WLEG, ID = 4.0" 8622' ELMD TT LOGGED 03/25/96 $~25' ~ 9-518" X 4-1(2" BAKER ZXP PKR, ID = 6.375" 9710' -~ Top of Cement ~ Mechanical w hipstock 10111' PERFORATION SUMMARY MGR/CCL/CNL 6 April 2007 ANGLEATTOPPERF:88° @ 10620' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPWSOZ DATE 1.56" 6 10620 - 10700 O 04/08/07 1.56" 6 10830 - 10960 O 04/08/07 1.56" 6 11070 - 11500 O 04/08!07 1.56" 6 11550 - 11670 O 04/08/07 1.56" 6 12030 - 12250 O 04/07/07 PBrD 11891' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11979' 2-3/8" cmt'ed and perfed ~~ 12302' 1/2" Baker K-1 CIBP 10135' 10700' SET4-1/2"BAKERK-1 CIBP 07/06/03 11200' IBP WlSTRIPPED FN - 08/31 /00 11258' IBP SET 8/25/96 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/03176 ORIGINAL COMPLETION 03/06/06 DAV/TLH CSG CORRECTIONS 12105195 SIDETRACK COMPLETION 03/16/06 RPH/TLH WANER SFTY NOTE DELETED 09/21/01 RN/TP CORRECTIONS 04/04/07 RB CTD Sidetrack 07/06/03 TMNITLP SET CIBP 04110!07 /PAG DRLG DRAFT CORRECTIONS 09/22/03 CMO/TLP PERF ANGLE CORRECTION 11/29/03 ATD/TLP INDICATE 7" LNR@ 10385' PRUDHOE BAY UNff WELL: G-04A PERMff No: 1951630 API No: 50-029-20225-01 SEC 12, T11 N, R13E, 2363' FNL & 1974' FEL BP Exploration (Alaska) a ~,'~~ ~ ~ ~~ ~- ~ ~ r ~ ~ ~ ~~s ~ ~ gam; `pp ~. -,~ ~ [@~¢¢ ~..w~ K,.s .a.. .. .~ ~w4 iM.«.v: °~u...J &..d dri ~ 3.rs.~ :.w7~~; lIw "~.,~.+J ~tm.~~ ~ ~ m.~ C1D1'~TSIERQ~I~`lC~ C® SSI~D~T Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 M f ,~ FRANK H. MURKOWSKI, GOVERNOR r ~ 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-04B BP Exploration (Alaska) Inc. Permit No: 206-140 Surface Location: 2363' FNL, 1974' FEL, SEC. 12, T11N, R13E, UM Bottomhole Location: 5139' FNL, 3124' FEL, SEC. 12, TI 1N, R13E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 653607 (pager). DATED this day of October, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . ~ ~~D~ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 WU~C~tI V C~ `~ F P 2 9 2006 Alaska Dii $i Gas Cons. Commi si0tt 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposl@d¢~pfa~f: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU G-046 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12300 TVD 8954ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2363' FNL 1974' FEL SEC 12 T11 N R13E UM 7. Property Designation: ADL Z $ Z~O Pool , , . , , , Top of Productive Horizon: 725' FNL, 1412' FEL, SEC. 13, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 15, 2006 Total Depth: ,3"f ~ ~ ~~/1/~~ 3/~, ~ ~fE~. xxx' FNL, xxx' FEL, SE T11 N, R13E, UM ~G 9• Acres in Property: 2560 14. Distance to Nearest Property: 13,800' 4b. Location of Well (State ase Plane Coordinates): Surface: x-658248 y-5969286 Zone-ASP4 10. KB Elevation (Height above GL): 70.57 feet 15. Distance to Nearest Well Within Pool: 675' 16. Deviated Wells: Kickoff Depth: 10110 feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3200 Surface: 2320 ~ 18. Casin ' P Fam: S " cificatio ns To -Settin De th -Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 3-3/16" x2-7/8" 6.2# / 6.16# L-80 TCII / STL 2450' 9850' 8541' 12300' 8954' 152 cu ft Class 'G' 1g. PRESE NT WELL CONDiTIOtJ SUMMARY (Tq be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11979 Total Depth TVD (ft): 8898 Plugs (measured): 10700 Effective Depth MD (ft): 10700 Effective Depth TVD (ft): 9007 Junk (measured): 11200 Casing ; Length ize Cement Volume MD TVD Conductor /Structural 110' 20" x 30" 270 cu ft Cement 110' 110' Surface 2667' 13-3/8" 6004 cu ft Permafrost II 2667' 2667' Intermediate 9370' 9-5/8" 1480 Howco Lite 250 cu ft'G' 149 cu ft PF'C' 9370' 8222' Production Liner 925' 7" 558 cu ft Class'G' 8840' - 9765' 7777' - 8544' Liner 3349' 4-1/2" 460 cu ft Class'G' 8630' - 11979' 7604' - 8998' Perforation Depth MD (ft): 10608' - 10640' Perforation Depth TVD (ft): 9005' - 9006' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Name/Number. c /~, ~~~% Terrie Hubble, 564-4628 Si nature ~V ~~~/ ~, Phon+e 564-4387 Date ~ G~~ .:~ Commission Use ~Jnl Permit To Drill Number: .~ API Number: - 50-029-20225-02-00 Permit-Approval See cover letter for Date: other re uirements Conditions of Approval If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ^ •~ ~ ~- ~ 0 ~ E -~'O 3 SD d r ,~` , Samples Req'd: ^ Yes ^ No u Log Req'd: ^ Yes ^ No HZS Measures: ^ Yes ^ N Dire urvey Req'd: ^ Yes ^ No Other: P OVED BY THE COMMISSION Date ~~ ~ ~ ~ ,COMMISSIONER Form 10-401 Revised 12!2005 t Submit In Duplicate ~1~~~ gp Prudhoe Bay G04BCTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: 1. O AC-LDS; AC-PPPOT-IC, T 2. C Mill XN nipple and obstruction at liner top to 3.8" 3. S Dummy whipstock drift 4. E Set WS-R-BB Packer at 10,122' 5. O Establish an injection rate 6. O Bleed gas lift and production flowlines down to zero and blind flange 7. O Remove wellhouse, level pad The pre CTD work is slated to begin on October 10, 2006. Rig Work: 1. MIRU and test BOPS to 250 psi low and 50 psi high. ~ 2. Latch whipstock into WS-R-BB packer. WS at 10,110' 3. Mi113.8" window at 1 O 110' and 10' of rathole. Swap the well to Flo-Pro. 4. Drill Build: 4.125" OH, 535' (28 deg/100 planned) 5. Drill Lateral: 4.125" OH, 1680' (12 deg/100 planned), with resistivity 6. MAD pass with resistivity tools in memory mode 7. Run 3-3/16" 2-7/8" solid liner leaving TOL at 0' 8. Pump primary cement leaving TOC at 9850', 7 bls of 15.8 ppg cmt 9. Cleanout liner and MCNL/GR/CCL log 10. Test liner lap to 2000 psi. 11. Perforate liner per asset instructions (600') 12. Freeze protect well, RDMO Mud Program: • Well kill: 8.6 ppg 'ne • Milling/drilling: ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: fully cemented liner • 3-3/16", L-80 6.2# TCII 9850' and - 10600' and • 2-7/8", L-80 6.16# STL 10600'md - 12300'md • A minimum of 27 bbls 15.8 ppg cement will be used for liner cementing. TOC planned at 9800' Well Control: BOP diagram is 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. Max. planned hole angle is 95 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 13,800 ft. • Distance to nearest well within pool - 675 ft. (G-27) Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. • A cased hole CNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on G pad is 25 ppm • Lost circulation risk is below average Reservoir Pressure • The max res. press. is estimated to be 3200 psi at 8800'ss (7 pg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 32 psi. TREE = 4" CAMERON WELLHEAD = McEVOY ACTUATOR= KB. E1EV = BAKER 70.57' BF. ELEV = KOP = 36.62' 3209' Max Angle = Datum MD = 93 @ 11585' 10259' Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" • Minimum ID = 3.725" @ 8611' 4-1/2" HES XN NIPPLE 8555' I-j 4-1/2" HES X NIP, ID = 3.813" I $566' 9-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.916" 8590' ~ 4-1/2" HES X NIP, ID = 3.813" 8611' 4-1/2" HES XN NIP, ID = 3.725" 1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 8623' TOP OF4-1/2" LNR 8630' TOP OF 7" LNR 8840' 9-5/8" CSG, 47#, N-80 BTRS, ID = 8.681" ~ 70 PERFORATION SUMMARY REF LOG: BRCS ON 08/25/96 ANGLEATTOPPERF:88 @ 10608' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPWSOZ DATE 2-1/2" 6 10608 - 10640 O 03/04/97 2-3/4" 4 10750 - 11150 C 03/27/97 2-314" 4 11450 - 11880 C 08/25/96 7" LNR, 29#, N-80 BTRS PBTD 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 8616' 9-5/8" X 4-1/2" BAKER TIEBACK SLV, ID = 7.5" 8623' 4-1/2" WLEG, ID = 4.0" $622' ELMD TT LOGGED 03/25/96 8625' 9-5/8" X 4-1/2" BAKER ZXP PKR, ID = 6.375" 7" SIDETRACK WINDOW - 9765-9815' \\ 10700' SET 4-1/2" BAKER K-1 CIBP 07/06/03 11200 ~--~ IBP W/STRIPPED FN - 08/31 /00 ~ ~ 11258' I-i IBP SET 8/25!96 ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 12/03/76 ORIGINAL COMPLETION 03/06/06 DAV/TLH CSG CORRECTIONS 12/05/95 SIDETRACKCOMPLETION 03/16/06 RPHITLH WANERSFTY NOTE DELETED 09/21/01 RNITP CORRECTIONS 07/06/03 TMNITLP SET CIBP 09/22/03 CMO/TLP PERF ANGLE CORRECTION 11!29/03 ATD/TLP INDICATE 7" LNR @ 10385' PRUDHOE BAY UNIT WELL: G-04A PERMfT No: '1951630 API No: 50-029-20225-01 SEC 12, T11 N, R13E, 2363' FNL & 1974' FEL BP Exploration (Alaska) G -0 4A SAF~f~OTE: TBG TAIL/LINER TOP RESTRICTION, MAX OD FOR GUNS, BAILERS, ETC. IS 2.7". MAX OD FOR SWEDGES IS 3.06",SEE TELEX 8/15-18/96. 2185' 14-1/2" SSSV HES HXO LAND NIP, ID = 3.813" 2684' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4178 6783 4109 6168 32 37 HES-TB HES-TB RA RA TREE= ~ 4" CAMERON WELLHEAD= McEVOY ACTUATOR = BAKER KB. ELEV = 70.57' BF. ELEV = 36.62' KOP = 3209' Max Angle = 93 @ 11585' Datum MD = 10259' Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" Minimum ID = 3.8" @ 8611' 4-1/2" HES XN NIPPLE (milled to 3.8") ® 2185' -i4-1/2" SSSV HES HXO LAND NIP, ~ = 3.813" 2684' 9-5/8" DV PKR C;A S I IFT MA N~RF1S ST MD TV D DEV TYPE V LV LATCH PORT DATE 2 1 4178 6783 4109 6168 32 37 HES-TB HES-TB RA RA 8555' ~ 4-1 /2" HES X NIP, ~ = 3.813" 856 9-5/8" X 4-1/2" TM/ HBBP-T PKR, D = 3.916" 8590' -j 4-1/2" HES X NIP, ID= 3.813" 8611' 4-1/2" HES XN NIP. ID = 3 S' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I O 4 B SAFETY NOTE TBG TAIULINER TOP RESTRICTION, Proposed CTD Sidetrack MAX OD FOR GUNS, BAILERS, ETC. Is z.~". nnAx OD FOR SWEDGES IS 3.06", SEE TELEX 811 5-1 819 6. TOP OF4-1/2"LNR ~-~ 8630' Top of 7" LNR 8840' 9-5/8" CSG, 47#, N-80 BTRS, ID = 8.681" 9370' 7" SIDETRACK WINDOW - 9765-9815' 7" LNR, 29#, N-80 BTRS 10385' / PERFORATION SUMMARY REF LOG: BRCS ON 08/25!96 A NGLE AT TOP PERF: 88 @ 10608' Note: Refer to Production DB for historical oerf data SQE SPF INTERVAL OPWSOZ DATE 2-1/2" 6 10608 - 10640 isolated proposed 2-3/4" 4 10750 - 11150 isolated proposed 2-3/4" 4 11450 - 11880 isolated proposed 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 8616' ~ 9-5/8" X 4-1/2" BAKER TIEBACK SLV, ID = 7.5" 8623' 8622' 4-1/2" WLEG, ID=4.0" ELMO TT LOGGED 03/25!96 8625' 9-5/8" X 4-1/2" BAKER ZXP PKR, ID = 6.375" 9840' Liner top packer 9850' Top of Cement 9850' Top of 3-t;~" Liner 9865' 3- v2" X NiF ID = 10600' 11~ 3/16 x Z-7/8 X-over 3-3116" X 2-718" cmt'ed and perfed11 12300' I Mecharncal '~o!low whipstock 10110' 10700' SET4-1/2"BAKERK-1CIBP07/O6/03 11200' IBP W/STRIPPED FN - 08!31 /00 11258' IBP SET 8/25/96 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/03/76 ORIGINAL COMPLETION 03/06/06 DAV/TLH CSG CORRECTIONS 12105/95 SIDETRACK COMPLETION 03/16/06 RPH/TLH WANER SFTY NOTE DELETED 09/21/01 RN/TP CORRECTIONS 07/06/03 TMN/TLP SET CIBP 09/22/03 CMO/TLP PERF ANGLE CORRECTION 11/29/03 ATD/TLP INDICATE 7" LNR @ 10385' PRUDHOE BAY UNIT WELL: G-04A PERMff No: 1951630 API No: 50-029-20225-01 SEC 12, T11 N, R13E, 2363' FNL 8 1974' FEL BP Exploration (Alaska) by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~~~ siucNU^~~ INTEQ Company: BP Amoco Date: 9/15/2006 Time: 16:49:19 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: G-04, True North Site: PB G Pad Vertical (TVD) Reference: 7:04 5/31/199612:22 70.6 Well: G-04 Section (VS)13eference: Well (O.OON,O.OOE,300.OOAzi) Wellpath: Plan 3, G-04B Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB G Pad TR-11-13 UNITED STATES :North Sl ope Site Position: Northing: 5966832 .87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301 .39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-04 Slot Name: 04 G-04 Well Position: +N/-S 2412.25 ft Northing: 5969286 .00 ft Latitude: 70 19 21-.933 N +E/-W 1997.40 ft Easting : 658248 .00 ft Longitude: 148 43 0.718 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, G-046 Drilled From: G-04A Tie-on Depth: 10065.56 ft Current Datum: 7:04 5/31/1996 12:22 H eight 70 .57 ft Above System Datum: Mean Sea Level Magnetic Data: 9/15/2006 Declination: 24.39 deg Field Strength: 57605 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.57 0.00 0.00 300.00 Plan: Plan #3 Date Composed: 9/15/2006 copy Lamar's plan3 Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map .Map <--- Latitude ----> <--- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min 'Sec Deg Min Sec Dip. Dir. ft ft ft ft ft G-046 Polygon 70.57 -2644.57 -1338.15 5966614.00 656966.00 70 18 55.923 N 148 43 39.758 W -Polygon1 70.57 -2644.57 -1338.15 5966614.00 656966.00 70 18 55.923 N 148 43 39.758 W -Polygon 2 70.57 -2950.77 -1332.61 5966308.00 656978.00 70 18 52.911 N 148 43 39.595 W -Polygon 3 70.57 -3429.40 -740.53 5965842.00 657580.00 70 18 48.205 N 148 43 22.320 W -Polygon 4 70.57 -3632.59 -117.63 5965652.00 658207.00 70 18 46.207 N 148 43 4.149 W -Polygon 5 70.57 -3989.99 322.97 5965304.00 658655.00 70 18 42.692 N 148 42 51.297 W -Polygon 6 70.57 -3619.66 454.81 5965677.00 658779.00 70 18 46.334 N 148 42 47.450 W -Polygon 7 70.57 -2901.73 -717.39 5966370.00 657592.00 70 18 53.394 N 148 43 21.647 W -Polygon 8 70.57 -2569.64 -1096.50 5966694.00 657206.00 70 18 56.660 N 148 43 32.708 W G-046 Faultl 70.57 -3141.59 -1438.66 5966115.00 656876.00 70 18 51.034 N 148 43 42.688 W -Polygon 1 70.57 -3141.59 -1438.66 5966115.00 656876.00 70 18 51.034 N 148 43 42.688 W -Polygon 2 70.57 -2931.26 -740.02 5966340.00 657570.00 70 18 53.104 N 148 43 22.307 W G-04B Target4 9024.57 -2764.96 -1131.63 5966498.00 657175.00 70 18 54.739 N 148 43 33.732 W G-046 Target2 9035.57 -3349.89 -573.80 5965925.00 657745.00 70 18 48.987 N 148 43 17.457 W G-046 Target3 9035.57 -3154.48 -827.75 5966115.00 657487.00 70 18 50.909 N 148 43 24.866 W G-04B Target1 9045.57 -3806.04 185.81 5965485.00 658514.00 70 18 44.501 N 148 42 55.297 W by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~.r s ~i~s INTEQ Company; BP Amoco Date: 9/15/2006 Time: 16:49:19 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference:: .Well'. G-04, True North Site: PB G Pad Vertical (TVD) Reference: 7:04 5/31/199612:22 70.6 We1L G-04 Section (VS) Reference: Well (O.OON,O.OOE,300.OOAzi) Wellpath: .Plan 3, G-04B Survey Calculation Method: Minimum Curvature Dhi Oracle Annotation MD TVD ft ft 10065.56 8756.87 TIP 10110.00 8783.20 KOP 10130.00 8795.18 End of 9 Deg/100 DLS 10170.00 8822.55 4 10480.33 9034.86 5 10569.62 9046.42 End of 2 8 Deg/100 DLS 10644.62 9039.81 7 10719.62 9036.45 8 10919.62 9036.33 9 11194.62 9036.20 10 11444.62 9036.09 11 11794.62 9035.97 12 11894.62 9034.94 13 12300.00 0.00 TD Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 10065.56 53.20 213.80 8756.87 -3841.74 457.61 0.00 0.00 0.00 0.00 10110.00 54.12 214.08 8783.20 -3871.44 437.63 2.13 2.07 0.63 13.86 10130.00 52.32 214.08 8795.18 -3884.71 428.65 9.00 -9.00 0.00 180.00 10170.00 41.12 214.08 8822.55 -3908.79 412.36 28.00 -28.00 0.00 180.00 10480.33 70.00 323.30 9034.86 -3868.33 232.09 28.00 9.31 35.20 117.30 10569.62 95.00 323.30 9046.42 -3797.92 179.61 28.00 28.00 0.00 0.00 10644.62 95.09 314.27 9039.81 -3741.78 130.43 12.00 0.13 -12.05 271.00 10719.62 90.03 306.81 9036.45 -3693.14 73.55 12.00 -6.75 -9.94 236.00 10919.62 90.03 282.81 9036.33 -3609.81 -106.66 12.00 0.00 -12.00 270.00 11194.62 90.03 315.81 9036.20 -3477.02 -343.15 12.00 0.00 12.00 90.00 11444.62 90.02 285.81 9036.09 -3350.42 -555.41 12.00 0.00 -12.00 270.00 11794.62 90.02 327.81 9035.97 -3145.35 -829.38 12.00 0.00 12.00 90.00 11894.62 91.16 339.76 9034.94 -3055.80 -873.47 12.00 1.14 11.95 84.50 12300.00 91.52 291.10 9024.87 -2775.68 -1149.38 12.00 0.09 -12.00 271.00 Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft .deg .deg ft ft ft ft ft deg/100ft ft deg 10065.56 53.20 213.80 8686.30 -3841.74 457.61 5965455.04 658786.48 0.00 -2317.17 0.00 MWD 10100.00 53.91 214.02 8706.76 -3864.74 442.16 5965431.72 658771.51 2.13 -2315.29 13.86 MWD 10110.00 54.12 214.08 8712.63 -3871.44 437.63 5965424.93 658767.12 2.13 -2314.71 13.73 MWD 10130.00 52.32 214.08 8724.61 -3884.71 428.65 5965411.47 658758.43 9.00 -2313.57 180.00 MWD 10140.00 49.52 214.08 8730.91 -3891.14 424.30 5965404.95 658754.22 28.00 -2313.02 180.00 MWD 10160.00 43.92 214.08 8744.61 -3903.19 416.14 5965392.73 658746.32 28.00 -2311.99 180.00 MWD 10170.00 41.12 214.08 8751.98 -3908.79 412.36 5965387.06 658742.65 28.00 -2311.51 180.00 MWD 10180.00 39.90 217.96 8759.59 -3914.04 408.54 5965381.72 658738.95 28.00 -2310.83 117.30 MWD 10200.00 37.88 226.29 8775.17 -3923.35 400.15 5965372.24 658730.75 28.00 -2308.22 114.35 MWD 10220.00 36.49 235.27 8791.11 -3930.99 390.82 5965364.41 658721.59 28.00 -2303.95 107.86 MWD 10240.00 35.82 244.70 8807.27 -3936.88 380.63 5965358.30 658711.53 28.00 -2298.08 100.70 MWD 10260.00 35.90 254.27 8823.49 -3940.98 369.69 5965353.98 658700.67 28.00 -2290.65 93.08 MWD 10280.00 36.72 263.63 8839.62 -3943.23 358.09 5965351.48 658689.13 28.00 -2281.73 85.32 MWD 10300.00 38.25 272.49 8855.50 -3943.63 345.96 5965350.83 658677.00 28.00 -2271.42 77.77 MWD 10320.00 40.39 280.66 8870.99 -3942.16 333.39 5965352.03 658664.41 28.00 -2259.80 70.73 MWD 10340.00 43.05 288.07 8885.92 -3938.84 320.52 5965355.08 658651.48 28.00 -2247.00 64.41 MWD 10360.00 46.15 294.72 8900.17 -3933.70 307.47 5965359.94 658638.32 28.00 -2233.13 58.87 MWD 10380.00 49.59 300.68 8913.59 -3926.79 294.36 5965366.57 658625.07 28.00 -2218.32 54.13 MWD 10400.00 53.31 306.04 8926.06 -3918.18 281.32 5965374.90 658611.85 28.00 -2202.72 50.13 MWD 10420.00 57.24 310.89 8937.45 -3907.95 268.47 5965384.86 658598.79 28.00 -2186.48 46.79 MWD 10440.00 61.35 315.32 8947.67 -3896.20 255.93 5965396.35 658586.01 28.00 -2169.74 44.02 MWD 10453.86 64.27 318.19 8954.00 -3887.22 247.49 5965405.15 658577.38 28.00 -2157.94 41.75 G-04B by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~~~ s INTEQ Company: BP Amoco Date: 9/15/2006 Time: 1.6:49:19 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference:. Well: G04; True North Site: PB G Pad Vertica l (TVD) Reference: 7:04 5/31 /1996 12:22.70.6 Well:. G-04 Section (VS) IZefereuce: Well (O.OON,O:OOE,300.OOAzi) Wellpath:' 'Pla n 3, G-04B Survey Calculation Method:. Minimum Curvature Dh: Oracle Survey MD Iucl Aziro SS TVD N/S E/W MapN MapE DI.S VS TFO ...:Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10460.00 65.59 319.42 8956.60 -3883.03 243.83 5965409.25 658573.63 28.00 -2152.68 40.44 MWD 10480.33 70.00 323.30 8964.29 -3868.33 232.09 5965423.70 658561.58 28.00 -2135.16 39.92 MWD 10482.45 70.59 323.30 8965.00 -3866.73 230.90 5965425.27 658560.36 28.00 -2133.33 0.00 G-04B 10500.00 75.51 323.30 8970.12 -3853.27 220.87 5965438.52 658550.05 28.00 -2117.91 360.00 MWD 10520.00 81.11 323.30 8974.17 -3837.58 209.17 5965453.96 658538.02 28.00 -2099.93 0.00 MWD 10540.00 86.71 323.30 8976.29 -3821.64 197.29 5965469.65 658525.81 28.00 -2081.68 0.00 MWD 10560.00 92.31 323.30 8976:46 -3805.61 185.34 5965485.42 658513.53 28.00 -2063.32 0.00 MWD 10569.62 95.00 323.30 8975.85 -3797.92 179.61 5965492.99 658507.63 28.00 -2054.50 0.00 MWD 10575.00 95.01 322.65 8975.38 -3793.63 176.38 5965497.20 658504.31 12.00 -2049.56 271.00 MWD 10600.00 95.05 319.64 8973.18 -3774.24 160.76 5965516.26 658488.29 12.00 -2026.34 270.94 MWD 10625.00 95.08 316.63 8970.98 -3755.70 144.14 5965534.44 658471.28 12.00 -2002.68 270.68 MWD 10644.62 95.09 314.27 8969.24 -3741.78 130.43 5965548.07 658457.29 12.00 -1983.85 270.41 MWD 10650.00 94.73 313.73 8968.77 -3738.05 126.57 5965551.72 658453.35 12.00 -1978.64 236.00 MWD 10675.00 93.05 311.24 8967.08 -3721.21 108.18 5965568.17 658434.61 12.00 -1954.29 235.95 MWD 10700.00 91.36 308.76 8966.12 -3705.15 89.05 5965583.82 658415.14 12.00 -1929.69 235.79 MWD 10719.62 90.03 306.81 8965.88 -3693.14 73.55 5965595.50 658399.39 12.00 -1910.26 235.69 MWD 10725.00 90.03 306.17 8965.87 -3689.93 69.22 5965598.61 658395.00 12.00 -1904.91 270.00 MWD 10750.00 90.03 303.17 8965.86 -3675.71 48.66 5965612.39 658374.14 12.00 -1880.00 270.00 MWD 10775.00 90.03 300.17 8965.84 -3662.59 27.38 5965625.06 658352.60 12.00 -1855.01 270.00 MWD 10800.00 90.03 297.17 8965.83 -3650.60 5.45 5965636.59 658330.42 12.00 -1830.02 270.00 MWD 10825.00 90.03 294.17 8965.82 -3639.77 -17.08 5965646.94 658307.67 12.00 -1805.09 269.99 MWD 10850.00 90.03 291.17 8965.80 -3630.14 -40.15 5965656.09 658284.40 12.00 -1780.30 269.99 MWD 10875.00 90.03 288.17 8965.79 -3621.72 -63.68 5965664.00 658260.70 12.00 -1755.71 269.99 MWD 10900.00 90.03 285.17 8965.78 -3614.55 -87.63 5965670.66 658236.60 12.00 -1731.39 269.99 MWD 10919.62 90.03 282.81 8965.76 -3609.81 -106.66 5965675.00 658217.48 12.00 -1712.53 269.99 MWD 10925.00 90.03 283.46 8965.76 -3608.59 -111.91 5965676.12 658212.21 12.00 -1707.38 90.00 MWD 10950.00 90.03 286.46 8965.75 -3602.13 -136.06 5965682.06 658187.93 12.00 -1683.24 90.00 MWD 10975.00 90.03 289.46 8965.74 -3594.43 -159.84 5965689.26 658164.00 12.00 -1658.79 90.00 MWD 11000.00 90.03 292.46 8965.72 -3585.48 -183.18 5965697.71 658140.47 12.00 -1634.10 90.00 MWD 11025.00 90.03 295.46 8965,71 -3575.33 -206.02 5965707.38 658117.42 12.00 -1609.25 90.01 MWD 11050.00 90.03 298.46 8965.70 -3564.00 -228.30 5965718.24 658094.91 12.00 -1584.28 90.01 MWD 11075.00 90.03 301.46 8965.68 -3551.51 -249.96 5965730.26 658073.00 12.00 -1559.29 90.01 MWD 11100.00 90.03 304.46 8965.67 -3537.91 -270.93 5965743.41 658051.74 12.00 -1534.32 90.01 MWD 11125.00 90.03 307.46 8965.66 -3523.24 -291.17 5965757.66 658031.20 12.00 -1509.46 90.01 MWD 11150.00 90.03 310.46 8965.65 -3507.52 -310.60 5965772.97 658011.44 12.00 -1484.77 90.01 MWD 11175.00 90.03 313.46 8965.64 -3490.80 -329.19 5965789.28 657992.51 12.00 -1460.31 90.01 MWD 11194.62 90.03 315.81 8965.63 -3477.02 -343.15 5965802.77 657978.26 12.00 -1441.34 90.02 MWD 11200.00 90.03 315.17 8965.62 -3473.18 -346.92 5965806.52 657974.41 12.00 -1436.15 270.00 MWD 11225.00 90.03 312.17 8965.61 -3455.92 -365.00 5965823.40 657955.97 12.00 -1411.86 270.00 MWD 11250.00 90.03 309.17 8965.60 -3439.63 -383.96 5965839.28 657936.67 12.00 -1387.29 270.00 MWD 11275.00 90.03 306.17 8965.59 -3424.36 -403.75 5965854.14 657916.57 12.00 -1362.52 270.00 MWD 11300.00 90.02 303.17 8965.58 -3410.14 -424.31 5965867.92 657895.72 12.00 -1337.61 270.00 MWD 11325.00 90.02 300.17 8965.57 -3397.01 -445.58 5965880.59 657874.17 12.00 -1312.62 269.99 MV1ID 11350.00 90.02 297.17 8965.56 -3385.02 -467.52 5965892.12 657851.99 12.00 -1287.63 269.99 MWD 11375.00 90.02 294.17 8965.55 -3374.19 -490.05 5965902.47 657829.24 12.00 -1262.70 269.99 MWD 11400.00 90.02 291.17 8965.54 -3364.56 -513.11 5965911.61 657805.98 12.00 -1237.91 269.99 MWD 11425.00 90.02 288.17 8965.53 -3356.15 -536.65 5965919.53 657782.27 12.00 -1213.32 269.99 MWD 11444.62 90.02 285.81 8965.52 -3350.42 -555.41 5965924.86 657763.39 12.00 -1194.21 269.99 MWD 11450.00 90.02 286.46 8965.52 -3348.92 -560.58 5965926.25 657758.19 12.00 -1188.98 90.00 MWD 11475.00 90.02 289.46 8965.51 -3341.21 -584.36 5965933.45 657734.26 12.00 -1164.53 90.00 MWD 11500.00 90.02 292.46 8965.50 -3332.27 -607.70 5965941.90 657710.73 12.00 -1139.85 90.00 MWD 11525.00 90.02 295.46 8965.49 -3322.12 -630.55 5965951.57 657687.68 12.00 -1114.99 90.00 MWD 11550.00 90.02 298.46 8965.48 -3310.78 -652.83 5965962.43 657665.17 12.00 -1090.03 90.00 MWD by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P n.r sNAU~s INTEQ Company: BP Amoco Date: 9/15/2006 Time: 16:49:19 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL• G-04, True .North Site: PB G Pad Vertical (TVD) Reference: 7:04 5/31/1996 12:22 70.6 WeIL G-04 Section (VS) Reference: Well (O.OON,O.OOE,300OOAzi) Wellpatn: Plan 3; G-04B Survey Calculation Method: Minimum Curvature Db: Oracle- Survey MD Intl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg tt ft ft ft ft degH OOft ft deg 11575. 00 90.02 301.46 8965.47 -3298.30 -674.48 5965974.45 657643.26 12.00 -1065.03 90.00 MWD 11600. 00 90.02 304.46 8965.46 -3284.70 -695.46 5965987.60 657622.00 12.00 -1040.06 90.01 MWD 11625. 00 90.02 307.46 8965.45 -3270.02 -715.69 5966001.85 657601.46 12.00 -1015.20 90.01 MWD 11650. 00 90.02 310.46 8965.45 -3254.30 -735.13 5966017.16 657581.70 12.00 -990.51 90.01 MWD 11675. 00 90.02 313.46 8965.44 -3237.59 -753.72 5966033.47 657562.77 12.00 -966.06 90.01 MWD 11700. 00 90.02 316.46 8965.43 -3219.93 -771.40 5966050.76 657544.71 12.00 -941.91 90.01 MWD 11725. 00 90.02 319.46 8965.42 -3201.36 -788.14 5966068.96 657527.59 12.00 -918.13 90.01 MWD 11750. 00 90.02 322.46 8965.41 -3181.94 -803.89 5966088.04 657511.44 12.00 -894.78 90.01 MWD 11775 .00 90.02 325.46 8965.40 -3161.73 -818.60 5966107.94 657496.31 12.00 -871.94 90.01 MWD 11794 .62 90.02 327.81 8965.40 -3145.35 -829.38 5966124.09 657485.18 12.00 -854.41 90.01 MWD 11800. 00 90.08 328.46 8965.39 -3140.78 -832.22 5966128.60 657482.24 12.00 -849.66 84.50 MWD 11825. 00 90.37 331.44 8965.30 -3119.14 -844.74 5966149.97 657469.27 12.00 -828.00 84.50 MWD 11850. 00 90.65 334.43 8965.08 -3096.88 -856.11 5966171.98 657457.43 12.00 -807.02 84.51 MWD 11875 .00 90.94 337.42 8964.73 -3074.06 -866.31 5966194.58 657446.76 12.00 -786.78 84.54 MWD 11894 .62 91.16 339.76 8964.37 -3055.80 -873.47 5966212.68 657439.22 12.00 -771.45 84.58 MWD 11900 .00 91.17 339.11 8964.26 -3050.76 -875.36 5966217.68 657437.22 12.00 -767.30 271.00 MWD 11925 .00 91.22 336.11 8963.74 -3027.65 -884.88 5966240.58 657427.22 12.00 -747.50 270.99 MWD 11950 .00 91.27 333.11 8963.20 -3005.08 -895.59 5966262.93 657416.03 12.00 -726.93 270.92 MWD 11975 .00 91.31 330.11 8962.64 -2983.09 -907.47 5966284.65 657403.69 12.00 -705.65 270.86 MWD 12000 .00 91.35 327.11 8962.06 -2961.76 -920.49 5966305.71 657390.23 12.00 -683.71 270.79 MWD 12025 .00 91.38 324.11 8961.46 -2941.13 -934.60 5966326.03 657375.68 12.00 -661.18 270.72 MWD 12050 .00 91.42 321.11 8960.85 -2921.28 -949.78 5966345.56 657360.10 12.00 -638.11 270.65 MWD 12075 .00 91.45 318.11 8960.22 -2902.24 -965.97 5966364.24 657343.51 12.00 -614.57 270.58 MWD 12100 .00 91.47 315.11 8959.59 -2884.08 -983.13 5966382.04 657325.96 12.00 -590.62 270.50 MWD 12125 .00 91.49 312.11 8958.94 -2866.85 -1001.23 5966398.89 657307.51 12.00 -566.34 270.43 MWD 12150 .00 91.51 309.11 8958.29 -2850.58 -1020.20 5966414.75 657288.20 12.00 -541.77 270.35 MWD 12175 .00 91.52 306.11 8957.63 -2835.33 -1039.99 5966429.57 657268.09 12.00 -517.01 270.27 MWD 12200 .00 91.53 303.11 8956.97 -2821.14 -1060.56 5966443.33 657247.23 12.00 -492.10 270.19 MWD 12225 .00 91.53 300.11 8956.30 -2808.05 -1081.84 5966455.97 657225.68 12.00 -467.12 270.11 MWD 12250 .00 91.53 297.10 8955.63 -2796.08 -1103.78 5966467.47 657203.50 12.00 -442.14 270.03 MWD 12275 .00 91.52 294.10 8954.97 -2785.28 -1126.32 5966477.79 657180.74 12.00 -417.22 269.95 MWD 12300 .00 91.52 291.10 8954.30 -2775.68 -1149.38 5966486.90 657157.48 12.00 -392.45 269.87 3.5" • • a. ~~aa `: F ~a t . ~~.E ~~~ ~- a "W s i ) E '-f i ~.,~ ~ !r}: i t-. fit/ t , ~FI, 4 [ Tr , i r { ,1~~ I l1 " } 1 ~ f / I ~1i / }. ~i ~ it ~ ~ , /) ~ ~~~~ Ear r f.~~ rf,i ~; ~ ~~~~ ~1Ff I ~. ~` ~ I C' ~ I i t{ ~f t~ ~I ~, ~ , ~ if , *~ ,~ mot' r ~ r 1 I ~~ ~~ ~i~~ C~ l i~, ~ _~lt ~i.t ~ ~ EIi~ i ~ i O ~ I~ ! t' // $ W ~ i j / / N i' ~ )..~ 3 F ~ 1 ~ i~~ ////~ / 1 ~ [ . \ ~ t~ 1 / j y ~ k$ r. ~~ ~ ~c ,$,: ~ ;il i , :;, ~ ~;, ~)~: ~ -~ `~' l0!l+l00l1 (*)41~oN/(~)41no5 F ~ ~ `~ ~ It y - I-- ! .. d~d~Y~~d ~ F/ ~~- r r111'i ~.~ gfBN o ~a ~ a~ e~8 a °' ~ ~~ ass ~~~~~ Q ~ a _ ° 3 8 ~ g etmyr e a p~;m > M W sf a8 8 ~~ ~~ ~ a Nss 3?-g'; ~ ~ 3~ k~ ~ ' ~ ~ 3~~~ ~ t ^asasa ~:a~~~ € assess ~~"s ~ 3$aia° ~~ gJg yye~a a 4 g X888 ~ "E Q Aar€--~~„_- ~~I,! [u!n~os] ~idaa `o ~ :' 8 dg 1 a ~, ~> • • rem are i ~_ ~ G-04B of bag BAG 7 1 /16" 5000 psi. cross middle of blind/shears middle of Blind/Shears TOTs 2 3/8" combi ram/slips ~ 1/16" 500opsi Mud Cross I I Mud Cross 7 1/16" 5000psi variable bore pipe 3 1/2"-2 3/8" TOTs 2 3/8" combi ram/slips 7 1/16" 5000psi Flow Tee • ss-sir2s2 304 ~,~ x,-. Terri Hubble BP Exploration AK Inc. PO Box 196612 M6 7-5 Anchorage, AK 9957.9 PAY TO THE ORDER OF IIIVVV / 1. /1 J~ "Mastercard Check" First Na#iona ank Alaska Anchorage, AK /99/501- MEMO:.. ~ -J`1~~ • DATE ~ ~~ ~~ r$ d 1L~1 U~-~U~- ~:L2520OD60~:99L46227L556~~' 0304 • • TRANSMITTAL LE'T'TER CI-I~CKLIST WELL NA~YIE ~~~~_~ ~~~ PTD# ZQ_ _.~~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS i TEXT FOR APPROVAL LETTER WHAT ; (OPTIONS) APPLIES ~ ~ MULTI LATERAL i The permit is for a new wellbore segment of existing f ~ ~ well j (If last two digits in ~ ~ ~ ~ Permit No. API No. 50- i API number are ; - - I between 60-69) i Production should continue to be reported as a function of the original API number stated above. I PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs j 'acquired for the pilot hole must be clearly differentiated in both ~ well name ( PH) and API number ~ I j (~0- -) from records, data and logs j ~ I acquired for well I ~ SPAC[NG EXCEPTION I I I ~ The permit is approved subject to full compliance with 20 AAC 125.05. Approval to perforate and produce /infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the ~ ~ liability of any protest to the spacing exception that may occur. ~ ;DRY DITCH j All dry ditch sample sets submitted to the Commission must be in ;' I SAMPLE I no greater than 30' sample intervals from below the permafrost or j from where samples are first caught and 10' sample intervals j through target zones. ! Non-Conventional ~ Please note the following special condition of this permit: i ~ production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Companv Name) has designed and I implemented a water well testing program to provide baseline data ~ on water quality and quantity. (Company Name) must contact the j I ~ Commission to obtain advance approval of such water well testing ~ Rev: 025/06 C:~jody\transmittal checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150. _ _ _ _ Well Name: PRUI)_H_OE BAY UNIT G-046 _ ___ .program DEV __ _ _ Well bore seg ' J PTD#:2061400 Company BP EXPLORATION (ALASKA) INC __ _ ___ . __ __ _ Initial Class(fype DEV (1-CIIL_ GeoArea 890_ _ _ Unit 1165Q___ ___ On/Off Shore On Annular Disposal Administration 1 Permit-fee attached. Yes !2 Lease number appropriate _ Yes '3 Unique well name and number - -Yes 4 Well located in a_defined pool Yes '5 Well located proper distance from-drilling unit-boundary- Yes 'i6 Well located proper distance from. other wells- Yes ~!7 Sufficient acreage available in-drilling unit. Yes - ~18 If deviated, iswellbore plat included Yes 9 Operator only affected party - Yes 10 Operator has_appCOpriate-band in force Yes '~11 Permit can be issued without conservation order Yes ~I12 Permit can be issued without administrative approval - Yes - - Appr Date 13 I Can permit be approved before 15-day-wait Yes - - RPC 101312006 ',14 Well located within area and strata authorized by Injection Order # (put-10# in comments)_(For- NA ' !15 All wells-within 1/4-mile area of review identified (For service well only) NA- ~16 Pre-produced injector. duration of pre production less than_3 months (For service welt only) - NA - - 17 Nonconuen, ga_s conforms to AS31.05.030Q.1.A),(j.2 A-D) NA- - - 18 _. _ _ - -- Conductor strmg_provided _- -- _ __ __ __ NA Engineering !19 Surface casing protects all-known USDWs NA - - 20 CMT_vol-adequate to circulate on conductor & surf csg - - NA - 21 CMT vol. adequate_to tie-fn long string to surf csg NA- - 22 CMT will cover all known .productive honzons - Yes Adequate excess. ',23 Casing designs adequate for C, T, B &-permafrost- - _ _ _ _ Yes _ - ',24 Adequate tankage or reserve pit Yes . - CTDU. ~'I25 If a-re-drill, has-a-1.0-403 for abantlon_ment been approved _ - - Yes _ . - - - -' 26 Adequate wellbore separation proposed Yes_ 27 I If diveder required, does it meet regulations NA_ Sidetrack. - '28 Drtlling fluid program schematic & equip list adequate Yes - Max MW 8.6 ppg Appr Date 29 BOPEs, do they meet regulation . - - Yes WGA 1013!2006 30 BOPE_press rating appropriate; test t_o-(put prig in comments)_ Yes Test to 3500. psi. MSP 2320 psi, 31 Choke manifold complies wlAPI RP-53 (May 84) _ _ Yes - 32 Work will occur without operation shutdown _ - - Yes - I33 Is presence_of H2S gas probable. No Max H2$25 ppm on-pad.. i34 Mechanical condition of wells within AOR verified (For service well only) NA_ . - !,,35 Permit can be rssued wlo-hydrogen sulfide measures No_ Geology 36 Data-presented on potential overpressure zones NA_ 37 Seismic_analysis of shallow gas_zones NA _ - -- Appr Date ~~,38 Seabed condition survey-(if off-shore) NA- --- RPC 1013/2006 i~i39 Contact name/phone for weekly_progress reports [exploratory only] - NA . Geologic Date: Engineering Pub Date Date Commissioner: Com si r Commissioner: ~. ~a ~ a6 - ~ -- --- • • • Well I-iistory File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 08/11/24 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/04/01 1391543 01 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las HAS BEEN 02~Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1,20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 9935.0000: Starting Depth STOP.FT 12302.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: G-04B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 21.993"N 148 deg 43' 0.718"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: O1 Apr 2007 API API NUMBER: 500292022502 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 70.57 DMF DF EKB .F 0 EDF .F 70.57 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~o ~ -/415 ~1 ~~ ~ (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (6) Tools ran in the string included Casing Collar Locator, Electical Disconnnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), Directional and Gamma Sub, Hydraulic Orienting with a Near Bit Inclination Sensor an Ultra Slim Resistivity Sub. (7) Data presented here is final and has been depth shifted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 02 Apr 2007 per Mike McTeague with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from G-04 through a milled window in a 4.5" inch liner. Top of window 10112 feet MD (8715 feet TVDSS) Bottom of window 10120 feet MD (8720 feet TVDSS) (9) Tied to G-04 at 10065.56 feet MD (8686.30 feet TVDSS). (10) MWD Runs 1 through 3 were used to set the Bridge Plug, Whipstock and Mill the window. No logging data is presented for these runs. (11) Resistivity data presented from 10120 ft. MD (8720 ft. TVDSS) to 10683 ft. MD (8968 ft. TVDSS) is MAD data. The interval was hours after being drilled. MNEMONICS: ohm.m GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, TVDSS -> True Vertical Depth (Subsea) TVDSS -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 9956.48, 9956.48, ! 0 9963.79, 9963.27, ! -0.522461 9975.81, 9975.81, ! 0 9987.83, 9987.83, ! 0 9994.62, 9994.62, ! 0 10119.5, 10115.3, ! -4.17969 10164.9, 10160.8, ! -4.17969 10233.9, 10230.8, ! -3.13477 10239.7, 10236.5, ! -3.13477 10247, 1 0243.8, ! -3.13477 10265.8, 10265.8, ! 0 10284.1, 10281.5, ! -2.6123 10288.8, 10286.7, ! -2.08984 10297.1, 10294, ! -3.13477 10301.3, 10299.7, ! -1.56738 10317.2, 10315.6, ! -1.56738 10335.4, 10332.8, ! -2.6123 10366.3, 10363.7, ! -2.6123 10397.1, 10391.9, ! -5.22461 10427.9, 10428.4, ! 0.522461 10451.4, 10444.1, ! -7.31445 10459.3, 10454, ! -5.22461 10472.9, 10469.2, ! -3.65723 10482.3, 10479.6, ! -2.6123 10485.9, 10482.8, ! -.3.13477 10498.5, 10495.8, ! -2.6123 10506.8, 10500.5, ! -6.26953 10528.8, 10523, ! -5.74707 10543.6, 10540.4, ! -3.13477 10568.6, 10565.5, ! -3.13477 10601, 10595.8, ! -5.22461 10613, 10607.8, ! -5.22461 10638.1, 10632.4, ! -5.74707 10679.6, 10674.4, ! -5.22559 10704.7, 10700, ! -4.70215 10719.8, 10712.5, ! -7.31445 10743.8, 10738.1, ! -5.74707 10772.1, 10765.8, ! -6.26953 10817.2, 10812.5, ! -4.70215 10822.9, 10818.7, ! -4.17969 10850.1, 10845.4, ! -4.70215 10876.7, 10871.5, ! -5.22461 10898.1, 10893.4, ! -4.70312 10906, 10901.8, ! -4.17969 10929.5, 10923.7, ! -5.74707 10953.5, 10947.8, ! -5.74707 10964, 10957.7, ! -6.26953 10977, 10971.8, ! -5.22461 10980.2, 10977.6, ! -2.6123 10986.4, 10981.7, ! -4.70215 11003.7, 10998.5, ! -5.22461 11013.1, 11008.9, ! -4.17969 11040.1, 11036.4, ! -3.6582 11047.4, 11043.2, ! -4.17969 11061.5, 11057.8, ! -3.65723 11070.9, 11066.2, ! -4.70215 11096, 11091.8, ! -4.17969 11113.2, 11111.1, ! -2.08984 11130.5, 11122.1, ! -8.35938 11168.6, 11162.9, ! -5.74707 11181.7, 11174.9, ! -6.79199 11213.5, 11206.2, ! -7.31445 11227.7, 11222.4, ! -5.22461 11233.4, 11227.7, ! -5.74707 11244.9, 11238.1, ! -6.79199 11288.1, 11281.8, ! -6.26953 11338.2, 11333, ! -5.22461 11371.7, 11367.5, ! -4.17969 11399.4, 11390.5, ! -8.88184 11406.7, 11398.3, ! -8.35938 11414, 11404.6, ! -9.40527 11424.5, 11414.5, ! -9.92676 11455.8, 11448, ! -7.83691 11491.3, 11484, ! -7.31543 11502.3, 11492.4, ! -9.92676 11515.9, 11510.1, ! -5.74707 11531.6, 11524.8, ! -6.79199 11539.4, 11531.6, ! -7.83691 11542, 11535.2, ! -6.79199 11556.6, 11547.8, ! -8.88184 11599, 11591.1, ! -7.83789 11675.4, 11660.8, ! -14.6289 11706.8, 11701, ! -5.74707 11725.6, 11718.3, ! -7.31445 11763, 11751.5, ! -11.4941 11785.5, 11774, ! -11.4941 11798.5, 11792.3, ! -6.26953 11827.8, 11822, ! -5.74707 • 11832.5, 11829.4, ! -3.13477 11838.8, 11834.1, ! -4.70215 11846.1, 11843.5, ! -2.6123 11850.3, 11850.3, ! 0 11858.6, 11857.1, ! -1.56738 11869.1, 11867, ! -2.08984 11876.4, 11872.7, ! -3.6582 11879, 11876.9, ! -2.08984 11885.3, 11882.1, ! -3.13477 11890.5, 11887.4, ! -3.13477 11934.6, 11931.4, ! -3.13477 11962.2, 11960.2, ! -2.08984 11999.3, 11995.7, ! -3.65723 12038.5, 12034.3, ! -4.17969 12092.3, 12086.1, ! -6.27051 12110.5, 12102.1, ! -8.35938 12114.7, 12106.8, ! -7.83691 12134.5, 12126.7, ! -7.83691 12143.4, 12133.5, ! -9.92676 12152.8, 12142.4, ! -10.4492 12170.6, 12159.6, ! -10.9727 12179.5, 12166.9, ! -12.54 12191, 12 178.4, ! -12.5391 12199.3, 12188.9, ! -10.4492 12214.5, 12204, ! -10.4492 12220.2, 12209.2, ! -10.9717 EOZ END END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 192 records... 8 bytes 138 bytes *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN G-04B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN G-04B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifting ~ ~ to a PDC (Primary Depth Control) recorded by Schlumberger GR CNL dated 06-Apr-20 per Mike McTeague with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 132 Tape File Start Depth = 9935.000000 Tape File End Depth = 12302.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 145 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 • 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN G-04B.xtf LCC 150 CN BP Exploration (Alaska) WN G-04B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM --- ---- ODEP GR GR ---- GRAX ------------------ 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE _ -0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 • Total Data Records: 263 Tape File Start Depth = 9935.000000 Tape File End Depth = 12301.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 276 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/04/01 1391543 01 **** REEL TRAILER **** MWD 08/11/24 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9935.0000 26.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9935.5000 26.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 22.9613 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 21.0714 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 48.0029 30.1909 30.2587 27.6624 29.8811 25.9460 10300.0000 46.9082 54.9601 9.9269 8.3150 7.9014 6.9975 10400.0000 29.9262 85.2262 13.7143 18.1541 18.2711 20.1802 10500.0000 81.8275 99.6670 15.0068 15.6429 15.0432 14.4664 10600.0000 68.6182 128.9222 15.6682 14.9904 15.4332 14.4492 10700.0000 65.5605 112.1998 13.2672 14.1582 13.3748 12.5696 10800.0000 64.0609 138.1352 12.6170 12.9088 13.6260 13.5250 10900.0000 42.0015 213.1755 15.6481 17.7601 17.4644 16.2701 11000.0000 43.0782 169.4340 13.3300 14.9878 14.8016 14.4735 11100.0000 52.3546 170.4546 15.9540 18.4062 18.3540 17.4198 11200.0000 41.1788 183.5318 13.1633 12.8847 12.9640 12.4000 11300.0000 28.5811 147.3727 16.0389 17.9699 19.2640 19.0094 11400.0000 64.9416 53.5583 14.8885 17.2850 17.3070 16.9969 11500.0000 78.7471 133.2046 12.6893 13.3725 14.9690 16.6423 11600.0000 31.6833 284.1287 12.1177 11.4040 11.8128 11.3840 11700.0000 95.3213 42.9813 13.4609 12.4721 12.3395 11.6113 11800.0000 90.5964 68.0157 14.7764 16.1314 16.7110 16.4960 11900.0000 45.7412 183.615E 12.6403 12.1260 12000.0000 38.8338 1207.8215 13.1506 12.3210 12100.0000 55.8873 430.6600 10.1431 12.5104 12200.0000 42.0520 371.9570 8.0341 7.3754 12300.0000 -999.2500 -999.2500 -999.2500 -999.2500 12302.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9935.000000 Tape File End Depth = 12302.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 13.1138 12.7387 8.0434 8.8326 -999.2500 -999.2500 12.9773 13.7080 9.0125 8.5260 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9935.0000 26.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9935.2500 26.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 22.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 17.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 19.9000 58.4000 23.6910 13.6540 12.9200 12.7560 10300.0000 23.7000 57.5000 10.8010 9.0160 8.4700 8.2360 10400.0000 28.7000 86.8000 13.7510 18.0890 19.9790 22.4820 10500.0000 110.6000 97.5000 14.0290 12.6100 12.7020 11.6240 10600.0000 138.1000 75.9000 15.1270 14.6990 14.9690 14.1500 10700.0000 68.8000 112.6000 13.2240 14.2400 13.7660 13.4150 10800.0000 59.5000 115.8000 12.4510 12.7540 13.4880 13.5250 10900.0000 43.2000 157.1000 16.5090 18.5490 18.1700 16.9570 11000.0000 38.5000 176.3000 13.0880 14.8070 14.8190 14.4540 11100.0000 53.6000 165.7000 15.8620 18.0280 17.9240 16.7180 11200.0000 39.0000 184.9000 13.2830 13.5400 13.2260 12.5350 11300.0000 26.7000 1708.3999 16.0980 18.4680 18.8700 18.4910 11400.0000 31.7000 208.9000 15.2700 17.3440 16.5350 15.6850 11500.0000 88.4000 172.2000 13.4620 13.7600 15.4620 16.8550 11600.0000 30.2000 126.9000 12.2450 11.6540 12.3350 12.1260 11700.0000 77.7000 89.7000 13.5710 12.1790 11.9820 11.1510 11800.0000 74.4000 84.3000 14.4640 15.7360 • 16.1570 15.9070 11900.0000 43.9000 188.2000 12.3350 11.7470 12000.0000 38.5000 1966.0000 12.7020 11.7470 12100.0000 65.0000 266.1000 9.0330 9.6530 12200.0000 49.2000 256.9000 9.2960 10.1070 12300.0000 -999.2500 221.4000 -999.2500 -999.2500 12301.7500 -999.2500 119.6000 -999.2500 -999.2500 Tape File Start Depth = 9935.000000 Tape File End Depth = 12301.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 12.9190 12.6170 8.4660 8.3560 -999.2500 -999.2500 12.8520 13.4150 8.2740 9.1000 -999.2500 -999.2500 • Tape Subfile 4 is type: LIS