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198-206
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC R-11A PRUDHOE BAY UNIT R-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 R-11A 50-029-20893-01-00 198-206-0 W SPT 8236 1982060 3200 1232 1234 1231 1231 595 593 595 596 REQVAR P Brian Bixby 4/10/2025 2 Year MITIA as per AIO 3.024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT R-11A Inspection Date: Tubing OA Packer Depth 554 3506 3448 3437IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250411043123 BBL Pumped:1.9 BBL Returned:1.9 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 99 99 99 999 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 11:13:14 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC R-11A PRUDHOE BAY UNIT R-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 R-11A 50-029-20893-01-00 198-206-0 G SPT 8236 1982060 3200 2375 2384 2378 2379 642 657 661 667 REQVAR P Austin McLeod 4/13/2023 Two Year to MAIP. AIO 3.024. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT R-11A Inspection Date: Tubing OA Packer Depth 1 3552 3504 3500IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230413190751 BBL Pumped:3.5 BBL Returned:3.5 Friday, May 12, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor �e( i 5Iftl'?JLj FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 26, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC R -11A PRUDHOE BAY UNIT R-1 ]A See: Inspector Reviewed By: P.I. Sup" 'BR - Comm Well Name PRUDHOE BAY UNIT R-1 IA API Well Number 50-029-20893-01-00 Inspector Name: Bob Noble Permit Number: 198-206-0 Inspection Date: 4/17/2021 " IDSA Num: mi[RCN210420100009 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IR -UA Type Inj w -TVD 8236 Tubing 1260 1261 - 1261 - 1261" PTD 1982060 IType Test I SPT Test psi 3200 IA 869 3550 - 3479 _ 3462 BBL Pumped: 12.3 - IBBL Returned: 2.3 - OA 852 849 _ 852 854 - Interval REQYAR p/F P Notes: 2 -year MIT -IA per AA AID 3.024 (1.0 x Max injection pressue of 3200 psi)' Monday, April 26, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 11, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. R -HA PRUDHOE BAY UNIT R -I IA Sre: Inspector Reviewed By: P.I. SuprvOZ— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-1 IA API Well Number 50-029-20893-01-00 Inspector Name: Guy Cook Insp Num: mitGDC190607174340 Permit Number: 198-206-0 Inspection Date: 6/5/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R -IIA -'Type Inj 1 0- 8236 Tubing ;10 Ise o6 - 3105 3Io� - YP BBL PumpBBL Returned: slzo IA 3600 - 3s48 - ss39 - -- --- - — p 3.2 OA ❑ ;.l 1206 - 1228. 1234 - PTD 1982060 T e Test sPT Test sl Interval REQVAR jP/F P Notes: Per AA 3.024 this well requires 24 month MIT -IA to maximum injection pressure. Thejob was completed with calibrated gauges and a triplex pump and bleed trailer. Thursday, July 11, 2019 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, May 27, 2019 2:39 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A, Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector R-11 (PTD #1982060) ready to be POI, will need AOGCC MIT -IA All, WAG Injector R-11 (PTD #1982060) was made Not Operable on 04/30/19 for lapsing on its 2 -year required AOGCC witnessed MIT -IA. The well is now ready for injection and will be reclassified as OPERABLE. Once thermally stable, an AOGCC witnessed MIT -IA will be scheduled. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, G Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Tuesday, Aork3O,2019 5:05 PM To:'chris.wallace@ala gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <A SGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@ om>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com , K, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeIIPadDFTN2@bp.com>, OPS Well Pad HUQ <AKOPSWeIIPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeIIPad LV@bp.com>; AK, OPS Wel MN <AKOPSWeIIPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeIIPadRJ@bp.com>; AK, OPS WELL PADS <AKO ELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeIIPadSW@bp.com>; AK, OPS WELL PAD W <AKOPS PADW@bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestArea bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt En AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.c >; Nottingham, Derek <Derek.Nottingham@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Comp 'ons Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integr Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Tuesday, April 30, 2019 5:05 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr, AKOpsProdEOCTL, Duong, Lea; Nottingham, Derek Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras 1 Subject: NOT OPERABLE: Injector R-11 (PTD #1982060) will lapse on AOGCC MIT -IA All, WAG Injector R-11 (PTD # 1982060) operates under AID 3.024 for continued WAG Injection with manageable OA repressurization. It is due for an AOGCC required 2 -year MIT -IA by the end April. The well is currently shut in and will not be online to complete the required testing before the due date. The well is now classified as NOT OPERABLE for tracking purposes. When the well is ready for injection and thermally stable, an AOGCC witnessed MIT -IA will be scheduled. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I DATE: Wednesday,May 03,2017 P.I.Supervisor ISS (11117 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. R-11A FROM: Matt Herrera PRUDHOE BAY UNIT R-11 A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-11 A API Well Number 50-029-20893-01-00 Inspector Name: Matt Herrera Permit Number: 198-206-0 Inspection Date: 4/28/2017 Insp Num: mitMFH170428162244 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R-IIA Type Inj W `TVD 8236 Tubing 1372 1386 - 1407 - 1400 PTD 1982060 Type Test SPT Test psi 2600 - IA 1614 2798 2787 - 2787 - BBL Pumped: 1 - BBL Returned: I - OA 953 929 - 940 - 942 , Interval REQVAR P/F P ✓ Notes: AIO 3.024.2 year Cycle IA test pressure 2600 psi per Operator v SCANNED AUG 2 4 2'01; Wednesday,May 03,2017 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, October 04, 2016 8:29 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad RJ;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Rupert, C. Ryan; Schultz, Kirsten L; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington,Aras J; Regg,James B (DOA) Subject: NOT OPERABLE:Injector R-11A (PTD#1982060) Sustained OA Casing Pressure Above Normal Operating Limit (formerly MOASP) �. SCANNED FEB 2 7 2017. All, Injector R-11A(PTD#1982060)was reclassified Under Evaluation on 09/07/16 due to sustained Outer Annulus pressure above Normal Operating Limit.An OA Repressurization Test conducted after a 7-hour open bleed yielded a build-up rate of 540 psi per day,which is not manageable by bleeds. Repressurization of the small void at the top of the cemented OA has recurred since the cemented annulus was created during a 2008 rig workover.The well operates under Administrative Approval AIO 3.024 for OA repressurization.The AA, approved 03/24/09, specifies a maximum OA pressure of 1000 psi.The OA has historically stabilized below this pressure, but is now stabilizing between 1000—1200 psi. Biennial OA gas sampling required by the AA indicates an external gas source. R-11A is a candidate for a revised (increased) OA NOL,and this option will likely be pursued. Once the BPXA internal process is completed, a revised AOGCC Administrative Approval will be sought prior to revising the NOL. The well is reclassified as Not Operable while the NOL revision is progressed. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegrityCoordinator@BP.com F.• II• K GWO SUPT Well Integrity Sent: Wedne •: e•tember 07, 2016 4:17 PM To: AK, OPS GC2 OSM; A', •° — Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West ""- •• Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad RJ; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; 0 Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; Rupert, C. Ryan; Hibbert, Micha- , uowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel,Troy; o on, Aras J; Regg, James 1 • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, September 07, 2016 4:17 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad RJ; Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Rupert, C. Ryan; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J; Regg, James B (DOA) Subject: UNDER EVALUATION:Injector R-11A (PTD #1982060) Sustained OA Casing Pressure Above MOASP Attachments: Injector R-11A (PTD#1982060) TIO Plot 2016-09-07.docx All, R-11A(PTD#1982060) is a water alternating gas (WAG) injector, currently on produced water injection.The well underwent a rig workover in 2008, during which the original outer annulus (OA) was cemented to surface, and the 13- 3/8" starting head removed.A 9-5/8" slip-lock wellhead was installed, and a 7" tie-back was run and cemented to surface, creating a new, cemented, 7" x 9-5/8" OA. The well operates under Administrative Approval A10 3.024 for OA repressurization.The AA, approved 03/24/09, specifies a maximum OA pressure of 1000 psi.The OA has historically stabilized below this pressure. Biennial OA gas sampling required by the AA indicates an external gas source. The well underwent an OA downsqueeze on 06/18/16. On 08/31/16, the well was brought online, and experienced OA repressurization.The OA was reported above MOASP on 09/06/16. Confirmed pressures were TBG/IA/OA= 1480/20/1160 psi.The well is reclassified as Under Evaluation. Plan Forward: 1. Downhole Diagnostics: OA Repressurization Test 2. Well Integrity Engineer: Evaluate for updated AA, and BP MoC, for increased OA MOASP 3. Well Integrity Engineer: Additional diagnostics as required �..-..,...-. A TIO plot is attached for reference. Please reply if in conflict with proposed plan. Thanks, scAN ED JAN 2 42017 Adrienne McVey Well Integrity Superintendent-GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C: (907)943-0296 H: 2376 Email: AKDCWellIntegrityCoordinator@BP.com 1 S • Injector R-11A(PTD#1982060) TIO Plot 09/07/16 Well R,I 2 O 766 tM 1W0• OA -1-OCICN 1.001 060716 061416 062116 62646 612516 0?188 871416 0726'16 06110216 000816 0816'16 081116 06X16 599ER Injection Plot WdlR9 E 410616110 2X0 1000 2 5150 ,.600 2W0 2600 —w6R 660 2202 as 6m I MO 2.060 1 164. ,000 100 06 hoc 200 rc 0602116 06'IF16 0612146 0611216 676516 011246 011916 OM% 610216 020216 081816 062/16 06:10/16 68486 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI.11 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well RI Re-enter Susp Well 0 Other:OA Cement Squeeze I1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-206 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20893-01-00 7. Property Designation(Lease Number): ADL 0028279 8. Well Name and Number: PBU R-11A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 'RECEIVED 11.Present Well Condition Summary: .p i� Total Depth: measured 14560 feet Plugs measured 13700 feet 1t �! �J,s true vertical 8737 feet Junk measured 14420 feet A U U 0 4 2016 Effective Depth: measured 13700 feet Packer measured 9717 feet 1"'l.� �j true vertical 8754 feet Packer true vertical 8243.94 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 2653 13-3/8"72#L-80 32-2685 32-2685 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11440-11470 feet 11850-11880 feet 13990-14050 feet 14350-14410 feet True vertical depth: 8778-8777 feet feet 8781-8782 feet 8749-8747 feet 8741-8740 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 30-9813 30-8322 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 2221 2221 12.Stimulation or cement squeeze summary: Intervals treated(measured): In OA:32'-52'. Treatment descriptions including volumes used and final pressure: SCANNED f ii 1\ �a , 2 0+ 32.4 Gallons SqueezeCrete Cement,500 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: "11428 0 2180 Subsequent to operation: Shut-In 0 1538 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 121 Exploratory 0 Development ❑ Service RI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG MGINJ 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: 316-028 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature itieWTPhone +1 907 564 4424 Date 8/4/16 Form 10-404 Revised 5/2015 VuT L lb l-7-/`6 ,4070,E RBDMS t.,`.' AUG 1 1 2016 Submit Original Only • • Q o 0 0 0 0 0 0 0 ,. CO I� v I� Ln 'Cr O N V LO P LO N- U ) 0 0 0 0 0 0 0 0 i C) M N- V co S co 6) CO N CO ct N ct m r V O r— co co I� CO LO IC) CO CO N LO CO O O CO Ln N CO O CO CO N- CO M N N CO CO CO CO CO 0 , 11 , 11 , 1 H CO CO O N N N N 6) V' 0 Co CO CO CO CO C33 CO CO CO CO r r N- CO O Lo CO O CO O aoO O 00 N N CT C3) ✓ p CUizof Q Q r N- CO N- - CN N N N CA CO O O CD I CO CO CO CO C) CO CA CO = n/ '— CA O • CD O O T CO CO O CO OD O aD Cr) = J CO J CO 44 _ 0 4t N *k �$ CO NN *k CO N r r C3) 0 COO COO _ U O CO LO N N N C3) CA 7 NI- .c L +' co IC) CC) CO CO CO O LO N- N Ln N O CO C CO CO 0) CO — N- O N- C) CN r CA CO V M O) W W W Q Q Q • U• LU W 0 LLJ LU O 0LL � � CCCQZ Z c W W W W W m H F — O DZDZ 0 0 Packers and SSV's Attachment PBU R-11A SW Name Type MD TVD Depscription R-11A PACKER 1960.36 1960.29 9-5/8" BOT External CSG PKR R-11A SSSV 2221.18 2221.11 4-1/2" MCX I-SSV R-11A TBG PACKER 9717.48 8243.94 4-1/2" Baker S-3 Perm Packer R-11A PACKER 9843.08 8347.18 7" Baker ZXP Top Packer • • C Y O - 0 Q L5 c a N _o U = Y p m CJ co as 0 ca u, o J m O Q n a) - c a) `no a) a) �1 u) > O > L 06 CO O • a V o > - al u) c) o >, U) 0 © v Q=c\M UO 7 a3 N a3 O L N O p, Q O O I I 'O _c — O (0 ) Ey -C 0(1) 3 � 0� aLo ) c) coO O CL II LI)) Q (aU) COJ c vOi O Z Q. Q 0 +� �' a) O '- o •- E E E I < > E o I I Q °' a) cn Q p Q O co = U) U) NN O oa) OCa)a.) o c L 0 r a)NmN N aTa 3 am c O aCI)) a)N CO ( 0 0oil c a) n D c� Q c a) 2U) U) wN ± c 0- oQ a)C0 • m -a 2 w - au) 'E " 0 EO >- N ° S aE O o a) mt c m i 0 a) E a) E E Ed zaa � Q o a) a) oUi L U OU 0 0 O O Ta Od N > Q aE >O `� L 0 COa CS) < < ` A Ci a. O � U Q 0 N 0 Oa °0a � Q E c Qa . E -c 0 EC) mQmao _ Qd o c ? O Ha' 0o_ I- Q eL 0o l- ii CD OCL '- II O C 0a O N a) *a) E N DQ ) as II c- w c U Ca o0 Q ma < da) Q 0-_0 v � 20Q2 2 c . .� Q+.r O �p � 2O i00 ) � Q � - OQ Q i a cn o .c O > ' 0 -0O 0 O. I . Q ¢ � ¢ cnOII (7) -0 - < U ( Q II QEl_ � — v -QvNc �_ - Ct E Ov ° p ) o� 0IIQ (a �Q = Q II ) II °O QcacQ �� 0 II o QUO Ea) 0>, � - � a a) � II OII II L II E o o > o> o > °o > a� N aai c > aE) a) > ] ~ > co a) 6 oU8 o0 wCU Qo • 4oa o Q ?I >o c0 � O Q N4=, 0 0 0 II J O II O 0 II O � mQ nNoo > > o o >a) C > CCO o > ? a > 0 >> � co � � > � � , � n > cn (n (/)� n U � Cr)) o � n3� � � a ci) 0 � � (DQ�QO > E ( > > o U) aU) ma U)>I I O F- �N (-1/1 E O I I I I -0 > ( > a I I NII a3 > 0TS0 _c 0oO � Oa0 .§ 11") a) Oa > Oao ° 5 OI I �co >> N L O >. _ Q _a) > - O >. < ) U - U - O > T.) >- 1=—Ca n _0 Uz F- U) II: o U) F-- 0 c U) F- -0 UF- -0 UI- QU) F- O U) w I- QO O O O O O O O CO > o r r r o O o r r 0 0 H N N N N N N N N N CO O 00CO 5 N N N N (N N U N N N N (0 CO CO Q r • • $ - o , O 0 _ 0 � � o \ ( e o © En co ± a) -e) 5 c / I / 0 p / > \ p p ƒ \ p 0 ƒ ƒ \ \ 0 I I b 0 % / " " \ E el i 7 / E $ 2 \ § / \ c m I . a N / 0 \ • I q N q $ / / ) a) a) G A . a) a) a) 6 / CS k S 2 ■ Cr 7 E S ) a) . / C § k ± C ) / \ / / 2 / a) $ � � E E E E n 0 o E o / / E 0_ < \ < @ \ / \ \ / \ / § / 5 \ % ) H 00 / 0 \ '<- O w Ni- E G § ¥ ..1, O § / ƒ \ / _ o_= s . = 6 e \ / 0 4 0 \ .2 0 o O ° 0 / _ U 6 3 / / / 0 k o / + 1 CO „ I 0 II O 2 II 0 • II I I I ƒ I \ § % II oIa I4- < I < I2 < m < Im 2E7 • % .2 O ¢ & O $ ƒ O ./O / - O « < > E I oI ' ® � • _ ¢ � •/ < Q < II \< � /< $ o $ a 7 T\- 7 % - m a- m > - e % - 2 e - o § ± 7 2 /c 0 X 2 0 co d /% b E • ii .75 -0° E E 2 " E 2 " E o �� E _ '� G \ �� E \ „ < ._ / a) CU▪ / § $ I- o 2 H 2 H \ / 0 2 H ) 2 / \ \ \ c d / \ $ \ ¥ d / \ •0 / d \ 0 •g E § / 7 -- �� 7127 = �� 7f �� < 0 �� 7 = „ 6f ° N / � $ / - / \ / / E$ \ / 77 \ > \ 2 \ \ m o m m \ / O m m $ CO m S m m 0 % 9 \ : a 2 . m e m m m e m 7 m ~ " 0 ¢ " 2 CD " g " ƒ % " $ $ " 0 ,. " \ R - % / 0 " / ƒ - / ° - ƒ / w / ® / E$ / § $ / k$ \ /$ / \ $ / R$ H —a 0 co co e e e CD CO / / \ / \ d CD'- / A / Cr / \ co \ ® o e e e 6 0 « TREE= CSN NOTES:H2S READINGS AVERAGE 125 ppm WELLHEAD= CNV WHEN ON ML WELL REQUIRES A SSSV WHEN ON ACTI�ITOR= BAKER C -11 A MI. WELL ANGLE>70°@ 10410' OKB.ELEV= 51.1' BF.ELEV= 21.68' I I, KOP= 3096' +y►� 19. 1929' H9-5/8"FES ES CEMENTER Max Angle= 99°@ 10685' +,,1 •4$.4 Datum Datum MD= 10446' 4,4,�� 0 Al 1951' —19-5/8"BKR ECP,CI=8.770" Datum TVD= 8800'SS �.0� •1 1• 9-5/8"BOWB4 CSG PATCH,47#, — 1994' ir,�1 ���4 2211' —�4-112"FES X NP,D=3.813" 11. 1 1 L-80 HYD 563,D=8.681' 1i 4. ►1ti�1 41 4 2590' —19-5/8"DV PKR • 7"CSG,26#,L-80 TCI XO TO L-80 BTC-M -I 2668' •' '1 • 13-3/8°CSG,72#,L-80,D=1234T —i 2689' .i ► O1 r 7 9687' —14-112"HES X NIP,D=3.813" i 1 II.••-.4 �I. 9708' 17"X 4-1/2"BKR S-3 PKR,D=3.875" Minimum ID =3.725" a@ 9790' y! - ► —1 4-1/2" HES XN NIPPLE ,4 • 9731' —14-1/2"HES X MP,ID=3.813" .4 •11 1i °4-1/2"TBG,12.6#,L-80 TCI, —1 •9803' �� ' 79790' —14-1/2"FES XN NP D=3.725" .0152 bpf,D=3.958" '� ►1 �� ` ► 9803' H4-1/2"WLEG,D=3.958" 7"CSG,26#,L-80 BTC-M,ID=6.276" —{ 9834' .' t1 HELVE)TT NOT LOGGED L9836' j—9-5/8"BKR ZXP LTP w ITE BACK SLV TOP OF 4-1/2'I.—.M --F 9837' &FLEX LOCK HGR,D=6.313" TOP OF 7"LNR H( 9911' 9860' —{7"X 4-1/2°XO,D=3.958' 9-5/8"CSG,47#,L-80,D=8.681" — 10155° PERFORATION SUMMARY REF LOG:SLB RES/GR on 12/14/98 ANGLE AT TOP PERF:92°@ 11440' MLLOUT WINDOW(R-11A) 10207'-10219' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2-7/8° 6 11440-11470 0 06/07/14 4` 13700' H4-1/2"BOT CBP(09/30/15) 2-7/8" 6 11850-11880 0 06/07/14 2-3/4" 6 13990-14050 C 12/21/98 141411014420' —ASH-FASDRLL 2-3/4" 6 14350-14410 C 12121/98 i/ PLUGS(12/22108) 414 ) 11411114, TOP OF WHPSTOCK —I 1020T • ••••••• • TOP OF CEMENT 10254' t ++ii •• •4 11111 •�♦••♦♦� � ���1111111 PBTD -I14418' ..� � •1111111111111 11111111111111 7"LNR,26#,L-80,.0371 bpf,D=6.184" —{ 10207' ;1�1�141,1,1,1, 4-1/2"LNR,12.6#,L-80, — 14560' 1ST.0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY COMvENTS PRUDHOE BAY UM' r 1983 JJ ORIGINAL COMPLETION 03/20/12 CDJ/JMD REMOVED ELMDTT(03/18/12) WELL: R 11A 01/22/98 LAZES SIDETRACKED 03/27/12 PJC ELM)NOT LOGGED PERMT No:'1982060 12/25/08 N4ES MO 09/11/14 RRW/JMC ADPERFS(06/07/14) AR No: 50-029-20893-01 06/17/09 AW/JMD DRLG DRAFT CORRECTIONS 10/02/15 CJS/.MAD SET CUP(09/30/15) SEC 32,T12N,R13E, 1121'FSL&1824'FWL 02/15/11 MB/JMD SSSV SAFETY NOTE 01/18/12 TM'/JVD Fi2S SAFETY NOTE BP Exploration(Alaska) OF TR C.9* 9* I%%,s THE STATE Alaska Oil and Gas N��►' �, °I\ Conservation Commission Nx _� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w,h Main: 907.279.1433 4'ALAS*P.' Fax: 907.276.7542 www.aogcc.alaska.gov Jessica Sayers Well Integrity Engineer BP Exploration(Alaska), Inc. wog .i 18 �"" P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-11A Permit to Drill Number: 198-206 Sundry Number: 316-028 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this ZZ day of January, 2016. RBDMS Lt- JAN [ 5 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION CON/MOONR JAN 14 2016 APPLICATION FOR SUNDRY APPROVALS 0.7"- rrI7' //6 20 AAC 25.280 ® /L1`O(O^ ` 1. Type of Request: Abandon I=1 Plug Perforations ❑ Fracture Stimulate CI Repair Well Q • OperationsJ•:, shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tabing El Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other MicroOA Squeeze p • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-206 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ CI Service Q• 6. API Number: 50-029-20893-01-00 99519-6612 Stratigraphic 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No Q PBU R-11A - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028279 PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14560 • 8737 , 13700 8754 13700 14420 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 2653 13-3/8"72#L-80 32-2685 32-2685 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 30-9813 Packers and SSSV Type. See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"MCX I-SSV 2221, 2221.15 12.Attachments: Proposal Summary p Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic El Development ❑ Service Q 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG Q GSTOR El SPLUG ❑ Commission Representative: GINJ El OpShutdown ❑ Abandoned El 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Sayers,Jessica be deviated from without prior written approval. Email Jessica.Sayers@bp.com Printed Name Er Sayers,Jessica Title Well Integrity Engineer Signature f^ ,�._ Phone +1 907 564 4281 Date \ 1` COMMISSION USE ONLY I� b Conditions of approval., ify Commission so tha representative may witness Sundry Number: Integrity 3`t&- 0 2_`1< Plug 9 y ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes El No ❑ Spacing Exception Required? Yes❑ No 0 Subsequent Form Required: /0 — 4 G Approved by: / ? ?il_e_vici_____ APPROVED BYTHE COMMISSIONER COMMISSION Date:/-2_2:-/‘.., vi-i- I/Z o`j . ORIGINAL RBDMS LI- JAN 2 5 2016 Submit Form and /Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. � • • a) Q o 0 0 0 0 0 0 C) cr- asr� co � c0o O o r� v � Ln � In 0 N V Ln V N- LC) N- U N o 0 0 0 0 CD CD 0 L 0) CO N- I` M '1:1' M 7 O) 00 N 00 - N m V CO O co N- co LC) r Ln CO r•-- O N N CO O LC) O 00 Ln CO O CO (p cc co co N N CO CO CO CO CO H co co O N (-NJ N N 0) c' O O CO CO CO CO 0 CO CO CO 00 C w LC) c‘jCO O L(') if) (c) (O o co LC) N CO N N O O V O O V 0 4-0 Q 03 M M M M a) co a) OM N '- 6) O) C �▪ J 1— CI o O Q O co O o CO 00 ' CO0 0? ' O = J J CO J CO N N J co N LC) N. U - M N - N i In (` N M O O CO CO r L() CO CO Q)O LC) t` N Ln N a0 C OO co 6) co r N O N- J N -- O CO 0) W W W QQ Q =oW000 •NUUW WW o o L IYCC CCa Z Z a W W W W W pp H I— I— � � Z_ Z_ U u) Z Z Z J J H • • a) N M m ti N a) in s O Ln co Co acri (O rn a) N- a co o N- N- N- N- o 00 CO co CO > I- 0- 0 - 0.0 I- N- aoa) s co Ln N- o- 0O O ao O 0 m o c w N N > O co CO CO 0 > Wcc 0 w Z cn w H I- -I a LW a g g 0 0 > 0 M O O W Y Y 2 O O O O _ _ J 0 0 W W L N- OD (f) s- J J J Q Q (n W a' C ,- - r 0 0 0 J W W Z V- .- Z Z < O 0 0 a Lu a t 2 0 0 0 a IW w Z o z H H Q J Q 0 < 2 2 2 0 (n co u) (n v) CU v- 4-; • a Q O F C J= 0 0 0 0 O mQ Ln a) Ln a) vooa) co o .- r) coaa) L m O 2 tY (n Y I 0 0 (n rY ` 22 2 0n nu nu G) a 0 0 c L1. LL (n U) m d d d d `a) Q Q 00 m a. 0 a) a) a a) H 8 0 0 0 O L J J Z O N N (N N Z LL 1 1 < LU m O O LLQ J 0 JJ LU N LL O CO CO 07 Z a :9 J :9 0 LW W LL W a < 0 J H J J J D a a < Qxia )3co 7_ u IL � a Lu a) E Ca z Q Q Q Q .- ,- � U- a co 0 LL N CC LL cC CC CC CC < < m m (Vi LL cocoa m • • x.0.4 Date: 12-27-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: R-11 SqueezeCrete MicroOA Squeeze Objective This program is intended to guide the execution of a fully cemented OA, low injectivity, surface casing squeeze repair treatment with SqueezeCrete. This well exhibits bubbling in the conductor when on production and returns fluid to the conductor when pressure tested. As such, it is suspected that the parent leak (leak present prior to fully cementing the OA from surface casing to conductor is the anomaly. SqueezeCrete will be used, followed by a WellLock top job to repair the leak. Well Detail Current Status: Not Operable Integrity Issues: Fully cemented OA; Well pressure not manageable when well is on-line Well Operation Detail Fluid Density: 14 ppg Equipment: See rig-up diagram Slurry: SqueezeCrete Relevant History: > 12/18/14: MIT-IA Passed to 4000 psi > 12/23/14: AOGCC MIT-IA Passed to 4000 psi > 03/26/15: PPPOT-T Passed to 5000 psi; PPPOT-IC Passed to 3500 psi 1 of 3 • S Procedure: 1 D Strap TOC in OA 2 D Place, Squeezecrete in OA, until clean, 1:1 SqueezeCrete returns are observed. Take returns to a grounded bucket. 3 D Rig up pneumatic pump, and resume pumping operation by squeezing SqueezeCrete into well. Pump until bump (2500 psi max) or until SqueezeCrete returns are observed in the conductor. 4 D Let well cure, POP under evaluation. 2 of 3 0 • TREE= cm ! SAFETY NOTES.IRS RCI EANCS AVERAGE 125 ppm CM, AELLIEAD= ACTUATOR- BAKER C R-1 1 A ,1 WHEN ON Mt WEU.REQUIRES A SSSV WHEN ON 1 IMIL WELL ANGLE,AV a 104W 0101 EA EV,-- SI ! ti* ItFV-- 71 MI I I.,. *4 41 KOP= 1 3098 4 o '40 1929' Ho-S/8'mEs ES cELEINER 1„), Max miss= 9Er©10685' #. 1 *4 4. t ft Daturn1A3= 1044S ao,• $4fr I issr 1 I s-ser BKR ECP 81).a ncrj IlituntIVD= B&W SS e ci e! Hi 9-518"BOWEN CS3 PATCH.4 . H 1994' r.,,-, N ..!".< I 22W H4-112'HES X NIP,ID=3.81r • • At L89HYD563 in=a sat- - —x4 f• ,. -- —1ne4F578-71:FIVT4C-Fil IP 4! * 7"CM 208,L-80 TQ XO TO L-80 BTC-81 H 2668' 4. ? ,• 4. ,y 4, ,1 . 13-3/8"MG 724,L-80 ID=12347 H 2689' e ,• t , I ro. 1 • sear 14447 ICSX44P ID=3 617 I ,4 * 4, 4 A.. V'ilr:. to:.;IP 9706" I---17-X4-1/2-BKR S-3 FKR ID=3 875- 1 1 Minimum ID=3225"@ 9790' . 1 !..4-112"HES XN NIPPLE 4. 4'. r9731- 1--14-1/7 HES X MP,13-3 8113"-1 ,0 0 *4 , 41 4 II 4112"TEIG,I2Itt 1-80 11:8 --I 9803' 4 I I 979r 1-14.10-MS XN re.,in= 725" .1 .0152 SC V 3.95r 4, ,• 4 1 1, 4 .• , it I 9803' 1+22'OLEG,it=71S4 1 t t 42 A. I HEE 1443 TT mzrr LOGGED I 1r csa,2e#,L4t0 eico4 63=6278" I 983C 1 ,* 01 Miff BKR 2XP LTP n tTE SACK SLV ITOPOF 4-10'U4R1 { 983T &FLEC LOCE I-83R.13=6 313" 9999' I 7"X 4 1/7 X0,ID-3 95F1 IMP OF r UR 1--1—ii911' j NI VI Stfr CSG 470 I 31)ID 3 631 H i01515. : k PERI ORATION SI AWRY 1411-108 518 Risiciti on 12/14/II8 I ANGLE AT TOP PEW sr 611440 MILLOUT MOON,(R-11A) 10207-1021T Nolo I to Productsmtli tor historical port data STIL SPF POENVAL 1 Opn/Sqa SHUT SOL 2-718' 6 11440-11470 0 06/07114 4.41•44 6..... 13700' 14 112'DOI cue(mums!1 2-7/8' 6 11850-11880 0 06/07/14 2-3.4" 8 13990 14050 C 12121198 -‘111* 14420' FISH-FASDRLL 2414" 6 14350-144W) C 12121/98 dr 44144 MUGS(12/2208) Nit !TOP OF ACIPSTOC( h 511F-207"[TOP OF cof"1 10284 A, NeWill'ir• ....,...-..''' •.••,,,••••••• 4411414 .-..3i014,1 4.4144 4 16TD —114418' I 4141114 • 441114+ #411111*** 4114141#41 .4404.44.44444$40,14 4.I/2-i tom,12 es,L-80, H 14560' 7"INFI.254.L.80, D371 WI D=6 184^ H 1020T BT J0152 bpf,D=3 968" DATE REV BY 000434TS - LATE REV BY CONANT'S FRILDHOE BAY ME "1911 J) ORIGINAL COMPLETION 03/20/12 CD.V.IMO REMOVED ELI/0 TT 107/19112) WELL.R-11A 01122/98 812E15 SIDETRACKED 03/27112 PK ELMD NOT LOGGED PERINI No'1982060 12125/08 NIES IWO 09111/14 RRAKAC ADFERES(06/07114} AR No: 50-029-20893-01 06117/09 AW/J843 DRI.G DRAFT OORRECTIONS 10102)15 CJS/M1 SET CEP(09130115) SEC 32,T1214 R13E,1121'FSL 8 1824 FVVL 07/15/11 oitioitA) .WiV 541-1 TY NOTE 01/18117 1748I.M)H2S SAFETY NOTE 8P Exploration(Alaska) 3 of 3 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI ON ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations H Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ® Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: DA-DAC/CJSt/0nI - yr,- 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-206 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20893-01-00 7. Property Designation(Lease Number): ADL 0028279 8. Well Name and Number: PBU R-11A 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: ECEIVED Total Depth: measured 14560 feet Plugs measured 13700 feet " true vertical 8737 feet Junk measured 14420 feet O C I 2 0 2015 Effective Depth: measured 13700 feet Packer measured 9717 feet G true vertical 8754 feet Packer true vertical 8243.94 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 2653 13-3/8"72#L-80 32-2685 32-2685 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11440-11470 feet 11850-11880 feet 13990-14050 feet 14350-14410 feet True vertical depth: 8778-8777 feet 8781-8782 feet 8749-8747 feet 8741-8740 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 30-9813 30-8322 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 2221 2221 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11440-11470,11850-11880. A_`N�� Treatment descriptions including volumes used and final pressure: �� {W` 30 Bbls DAD Acid,129 Bbls 1%KCL,122 Bbls 60/40 Methanol/Water,1485 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 6332 0 1829 Subsequent to operation: 12104 0 2241 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations Ed Exploratory 0 Development 0 Service I3 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-482 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 444.417 C-VV"" Phone +1 907 564 4424 Date 10/20/15 /,�/ DM Ut.► [ '11015 Form 10-404 Revised 5/2015 �T L U/ZZ/{5 q r7I L r� % Submit Original Only • • a) 12,0OOOOOOO I3 it) Zr: - - CrI 1.0 vu) N f- V 00) CC") N- -• OP M d• COQ) V CO N- CO 03V' N. CO ' CO CC) M f- O N O 0 C O M CC) N `— CD O M CO N- CO C") N (NI CO O CO CO 00 H CO Co O CNI00 CC") CN7MM � C Nt C") a- CO CO NC0to '0 Oc•-) NN0O) CD (%20) V p Q 2 4-0 < N- co s- e- N N N N 0) M O 0 _ Ce M CO O OO O co 0 O O c co 0 co N N J * J CO N N- 1 . d N 4 N0) c" = N � UOC`I Fs - � N 0) O) d L_ _ O C N Lc) N O COM G CO CO N- J N CA O M 0) W W W Q Q Q cO W W W U V 0 u_ rcce� ct lX Q Z Z w W W W W W m 0I— HZZ � 0 U Z Z Z • • I Packers and SSV's Attachment PBU R-11A SW Name Type MD TVD Depscription R-11A PACKER 1960.36 1960.29 9-5/8" BOT External CSG PKR R-11A TBG PACKER 9717.48 8243.94 4-1/2" Baker S-3 Perm Packer R-11A PACKER 9843.08 8347.18 7" Baker ZXP Top Packer • 41 _ 0 -8 E2 O O (1) (;) 0 0 = 0 �� g - cm- 0 U O m rYN v 0 r N m m o m _ ' ' N V D E ch Q 3 -- U U c §- J 8 l U o 0 m 3 - M co 32Y -5 m o � tn2 ,- Yz0 ami _ 5 ° o 0 (oULooN ' o o Em 0 Q. J Q M ' Q o U) a N m ' N ._.. _ o. � toaNv- a)a) ma2NO t CELo 4: 7:3 () mC W N U m ' c0 o m .. Q O Nd '� �- N ND -1 3 I- r- J Vm E — NI- _ _- E m N Y U v U O M O N .. - N _ ca- Q!L /N�� /�, .<-51LL V - 2 LI.) u' �j N Q� j ' -a)- a) Q � U U '(o Q m ,� � t0) _�iOJ 3 .2 CO U2 Na a) oo •c' LavUa a) C $ a) a)� o o oNoao , Y (L V _O >' 0 m � NM a) r3) ac moo ' (�p �+ m N2 � � C � � � Er' = i< E i < -.T) Ur � 3 � o . a, , 000 � 00 N Em a. o 23 --2 2 mD � I- E moa ) cn a 0 0 = 0- '1- 2 H rn ' m Lc) . P O m c Y m coy 1 m 0 N Q 130 710 r_ U a) LO ' I- U = c a) 2¢ a) 0 0 CO E b _ m � NJU 3 o2ZI-. mU) o m y 0 0 E U)0 C = 0 EOE -af. E 2 m ~ O m 0, r- .E, ! 0) 0 (h "= oda ' L -5a • n in � c' Dw d LO O 0- 0- (`o f° �-' Ui o a`) ' E = 0 (nC Q « .- � � 0IX re NE � EmHN NE 0"r- _ OU (0 ''' r � c- • tnc7 in j ea 0 ° Pfic.6 . 45 L 0 , °51w7.-:12 N o w m Cn •a)5Cz � z c to - '524- mc) � 7 3 `a 00X ---- 0Z -'- 0 o 0 - E -0 °) o m � () -Ecl1 � UNNo -0 0- E � , 0L, 0 - w t 3 O E O v m Q a) 3 N 0 O "-' Eco co c to 0 U (O W ' - *k rn mp o 0 m ' ' m •- - NO0wa00 ( ' Y � L0 < _ .0 2 ce •S X - a 0-H 2 °) m 0, 0)= ate) E 2 , - 0 0 D H W � m- 0 c., 00 •S 0.2ri 3 E. UO .E _I as u_ nv) aO _amr. 1 u) I. I' mu U « cooc, 0FT) w I- Ur) u) to 0 G G o 0 I}- N N N N � O � o (- 5 N 0 CO m N ,:t Cr) N V O O Q TREE= aVV WELL1•EAD= CAN • NOTES:FRS READINGS AVERAGE 125 ppm *ACTtj4 D= BAKER C OKE.ELEV= 51.Y 11 A M ON Mt WELL REQUIRES A SSSV WHEN ON ML WELL ANGLE>70°@ 10410' BF.ELEV= 21.68' KOP= 3096' 1 a)( ' •�4• ) I 1929' x-119-5118"!MM. /?ER Max Angle= 99"@ 10685 •'' ►r•t im Datum MD= 10446' Al-� )1,0i4 - 1951' —19-5/8"BKR ECP,D=8.770" Datum TVD= 8800'SS 4' ►•f•'4 9-5/8"BOVVE N CSG PATC1-t 47#, H 1994' •*1 I I i •+ 2211' I--4-1/2"I XMP,D=3.813" • L-80 FiY •D 3.D=8.681" •4 '• • 25590' H9-5/8*DV PKR 7"CSG,26#,L-80 TCI XO TO L-80 BTC-M H 2668' • • ► • 13-318"CSG,72#,L-80,D=12.347" —{ 2689' • ►• 1 , �+ 9687' —14-112"FES X NP,D=3.813" •'►: �►i 9708' —I 7"X 4-1/2"BKR S-3 PIR,D=3.875" Minimum ID =3.725" @ 9790' ►• 4-112" HES XN NIPPLE • * • 9731' --H4-112"HES XNP,13=3.813" • 1 M • 4-1/2"TBG,12.6#,L-80 TCI, 9803' 1 , l+ 9790' —14-1/2"HES XN NF D=3.725" + .0152 bpf,D=3.958" I • �i ` ) 9803' —4-1/2"VVLEG,D=3.958" ♦+ ,+ F I—ELM)TT NOT LOGGED I 7"CSG,26#,L-80 BTC-tut ID=6.276" —{ 9834' , 9836' —9-5/8"BKR ZXP LTP w/TE BACK Sly TOP OF 4-1/2"LNR —I 9837' 8 FLEX LOCK HGR,0=6.313" TOP OF 7'LNR I— 9911' 9860' H7'X 4-112"XO,D=3.958' i 9-5/8"CSG,47#,L-80,D=8.681' H 10155' 1 PERFORATION SUMMARY REF LOG:SLB RES/GR on 12/14/98 ANGLE AT TOP PERF:92't 11440' Note:Refer to Production 06 for historical perf data MLLST W(R 11A) 10207'-10219' SIZE 1 SPFINTERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 1 11440-11470 0 06/07/14 13700' --f4-1/2'BOT CEP(09/30/15) 2-7/8" 6 11850-11880 0 06/07/14 2-3/4" 6 13990-14050 C 12/21/98 141114t14420' —ASH-FASDRLL 2-314" 6 14350-14410 C 12/21198 l/ NI, PLUGS(12/22/08) NIP TOP OF WHIPSTOCK H 1020T • .••••••• TOP OF CENENT 10254' •�•••••+••••• 1+++*+*+*++•44 [P&p FH 4,....• 14418' •• *••••+•++••+•+ •••••••••••••• 7"LNR,26#,L-80,.0371 bpf,D=6.184" H 1020T +i+i+�•�+a+i+i 4-1/2"LIdR 12.6#,L 80, —j 14560' BT.0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDH OE BAY MT r 1983 JJ ORIGINAL COMPLETION 03/20/12 CDJ/JM)REMOVED FiAIDTT(03/18/12) VVEJ. R-11A 01122198 WEE SIDETRACKED 03/27/12 PJC F3JvD NOT LOGGED PST No:9982060 12/25/08 N4ES 'IVO 09/11/141RW/JMC ADFERFS(06/07/14) API No: 50-029-20893-01 06/17/09 AW/1I)DRLG DRAFT CORRECTIONS 10/02/15 CJS/JMD SET CEP(09/33/15) SEC 32,T12N,R13E,1121'FSL&1824'FWL 02/15111 Mi3/JWD SSSV SAFETY NOTE 01/18/12 T VINLAID I-QS SAFETY NOTE BP Exploration(Alaska) OF Tye 4w--z.---4.11:446‘1:-:--7A �\ 11s� THE STATE Alaska Oil and Gas ti -s �.-7of A 1Conservation Commission LASkCA. tiftt#= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS'P Fax: 907.276.7542 www.aogcc alaska gov Cale Peru Petroleum Engineer 0 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-11A Sundry Number: 315-482 Dear Mr. Peru: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, aer Cathy . Foerster Chair "14- DATED this 3 day of August, 2015 Encl. i_ - LYS. .,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM__,JN APPLICATION FOR SUNDRY APPROVALS0 20 AAC 25.280 D .S III -. 115 �r-,,f- 1. Type of Request: Abandon 0 Plug Perforations @ • Fracture Stimulate 0 Pull Tubing 0 ,' ,e •, n 0 Suspend 0 Perforate 0 Other Stimulate VI • Alter Casing 0 Change ApprovedrProgram 0 Plug for Rednll 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other a C!u ��i n'L In 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class* 5. Permit to Drill Number: 198-206 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service RI 6 API Number: 50-029-20893-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Ed PBU R-11A • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028279 • PRUDHOE BAY,PRUDHOE OIL 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 14560 • 8737 • 14432 8739 None 14420 -I MD - Casing Length TVD — Burst Collapse Size p Structural Conductor 80 20"91 5#H-40 30-110 30-110 1490 470 Surface 2653 13-3/8"72#L-80 32-2685 32-2685 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 9821 7"26#L-80 30-9851 30-8354 7240 5410 Liner See Attachment See Attachment See Attachment , See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft). See Attachment See Attachment 4-1/2"12.6#L-80 L-80 26-9809 Packers and SSSV Type. See Attachment Packers and SSSV MD(ft)and TVD(ft) See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: ' BOP Sketch 0 Detailed Operations Program RI Exploratory 0 Stratigraphic 0 Development 0 Service I I 14.Estimated Date for Commencing Operations: 8/27/2015 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval. Date WINJ 0 GINJ 0 WAG ® • Abandoned 0 Commission Representative. Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Peru,Cale Email Cale Peru@bp.com Printed Name Peru,Cale Title Petroleum Engineer Signature11#// Phone 907.564.4522 Date 8/6/2015 COMMISSION USE ONLY Conditions of approval.Notify Commission so that a representative may witness Sundry Number: 315_ -(4" Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 ' - - Other: Spacing Exception Required? Yes 0 No W Subsequent Form Required' /0— 0 4— / APPROVED BYTHE Approved by: T (/._ COMMISSIONER COMMISSION Date:B_f3 _Ls-- 1_6(2/////5- RBDMSAC AUG 1 4 2015 ORIGINAL / s44z ,r ,l Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: R-11A 'Well Type: WAG Injection Well API Number: 50-029-20893-01 Well Activity Conventional 4 Classification: Activity Description: Set CIBP.Acidize. Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, 75 bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory requirements? _ Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Cale Peru Contact numbers: (907)564-4522 (832)316-5774 Well Intervention Engineer: Michael Hibbert Contact numbers: (9071 564-4351 (907)903-5990 Lead Engineer: Dan Robertson Contact numbers: (907) 564-5546 (9071 529-5818 Date Created: July 21,2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate In] Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 6/12/2015 0 22000 MCF/d 2,400 Current Status: Operable Shut In Inclination>70°at Depth (ft) 10,410' MD Recent H2S (date,ppm) NA 0 ppm Maximum Deviation (Angle and 99° 10,685' MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 37° 10,250' MD Reservoir pressure(date, 3/14/2012 3,225 psi Minimum ID and Depth 3.725"@ 9790'XN psig) - Reservoir Temp,F 180°F Shut-in Wellhead Pressure 1,750 psi Known mech.integrity none known problems(specifics) Coil.Add perfs. Drift: BHA: CTC 2.2"x2.96', PDS Memory 2 7/8"x9.84',XO 2"x0.4',JSN 3.3"x0.5'. OAL= 14.7'Max OD=3.3" Drift to 13,000'with no issues Perfs: Guns 2 1/8"x 2.96' MHA&2.88"x 30' PJ HMX. Added perfs from 11440 to 11470' & 11850 to 11880', Rig down CTU. No issues reported. Last downhole operation(date, 26/May/2014: SL drift, RIH W/2-7/8"x 11' DUMMY GUN,T.E.L. 2.50"S- operation) 6/7/2014 BLR. LOCATE TT AT 9,783' SLM +20' CORRECTION TO 9,803' MD. DRIFT TO DEVIATION AT 10,431' MD (-70 degrees)...POOH Latest drift to TD: 11/17/2000 iProf. PU BAKER BHA. 1.90 NO GO CONNECTOR, CV, DISCONNECT,XO. OA LENGTH=3.61'. PULL TEST TO 12000, PT TO 3500 PSI. 10:15 PU PDS TOOLS(GR/CCL/P/T) OA LENGTH= 15.20' Make passes to 14,365'. Most recent TD tag(date,depth, 6/7/2014 13000' MD Drift: BHA: CTC 2.2"x2.96', PDS Memory 2 7/8"x9.84',XO , toolstring OD) 2"x0.4',JSN 3.3"x0.5'. OAL= 14.7' Max OD=3.3" Surface Kit Fit-for-Service? YES If No,Why? Online in June 2015 Comments,well history, Attached map illustrates the comments below. background information, etc: The purpose of this job is to set a CIBP to isolate the toe perfs(shot in 1998)from the heel perfs(shot South of the fault in 2014)to make more efficient use of MI.The row of producers South of the fault have not seen MI from the North previously. The toe perfs have had 5 MI cycles and the area appears to have reached MI maturity. R-11Ai is in the middle of an MI cycle now and R-29A had a brief buzz during this cycle(-80 bopd and 2MM extra gas however that buzz appears to be ending). No response has been seen in the producers to the South which may be because the heel perfs were not stimulated or broken down and the toe perfs are thermally fractured. This job will include setting a CIBP,acidizing the heel perfs then putting the well on MI. • Well Intervention Details Suspected Well Problem: Conformance Specific Intervention or Well Objectives: 1 Establish heel only injection South of the fault. 2 3 Key risks,critical issues: Mitigation plan: 1 MI injector,higher tbg pressures,higher pumping Coil unit will bullhead 1.5x tbg volume of 1%KCL to pressures. displace MI prior to running in hole. 2 3 Summary Service Line Activity Step# 1 C Drift/depth control run/caliper. Set CIBP. Injectivity test. Spot acid. Injectivity test. 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1) Bullhead 200 bbl of 1% KCL down production tbg. Rate 5 bpm. Initially don't exceed 3000 psi,as MI is displaced lower pump pressure, ideally stay below 1800 psi. reason:knock down Ml pressure before entering the well and displace Ml so later infectivity tests are meaningful. 2)Drift to 14,400' (20'above fish)with 40 arm Caliper/GR/CCL/3.70"JSN (same OD as 4.5"CIBP). Caliper liner only,tag depth to 9800'. 1 C reason:SL will be out multiple times for MCX set/pulls. Cheaper to have them caliper tbg another time. Modeling suggests coil can reach 14,400'without locking up. b)POOH,flag pipe at 13,600'. 3) MU 4.5"CIBP. Stop at flag, correct depth. Set CIBP at 13,700' (+/-30ft).Tie in log attached. note:coil has made it to 14,365'in the year 2000 but with a smaller ID iProf tool string. Modeling suggests we can make it to depth without locking up. CIBP setting depth reason:leave room for future add perfs. 4) POOH a)paint flag at 11,420'. b)perform injectivity test down backside. 1,3,5 bpm record pressure when it stabilizes. 5) RIH with nozzle. Use flag or tag CIBP for depth control. Spot Dad acid across perfs(12 bbl)across each of the two interval(24 bbl's total).Additives sheet attached. Let soak 30 mins Over flush with 50 bbl of 1% KCL down backside. POOH. Injectivity test on way out. 1,2,5 bpm record pressure when it stabilizes. Don't exceed 3000 psi. Success:WHP less than 1500 psi at 3 bpm. If this is not achieved perform another injectivity test down backside. 2,6,8 bpm record pressure when it stabilizes. Don't exceed 3500 psi. Then see if WHP is less than 1500 psi at 3 bpm. 6) RD Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: 10 BWPD: Expected Production Rates: FTP(psi): 2500 Choke setting: Post job POP instructions: Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE= / SAFETY NOTES:H2S READINGS AVERAGE 12S ppm 1M1LHFAD CIW R-11 A W ML WELL L ANGI.L>7QREQUIRES A SSSV WHEN ON ACTUATOR= BAKER C Oka ELEV= 51 1' BF.ELEV= 21.68 KOP= 3096' ( ,4j'! 'I•,�I 1929' H -SIB HES ES CB.QJTB2 Msx Angle= 99-Q 10685' 144 4! 14 pptun MD_ ,_ .. 10446' ,�• , 1951' 9-98.8KR ECP,O=8 770' �DatunTVD= 8800'SS 1,:4! 4 Iii:! • 9-5/8-BOWEN CSG PATCH,474, ^i 1994' 4'4! I ■ I•. 1 2211• H"H4-1/2"HES X MP D- 3 813' 1 • L80H1'D563,D=8.681- �•,.! 4; N., —{ 2590—--E5I8'[ii as r CSG.260.1-80 TO XO TOL-80 BTC-441-1 2668' 4 1 • ,4 M .i I ;133/8•CSG,7244,L-80,ID.12.347' 1-4 2689' �4• I I {._.9-6 A7�HH4-117 HES X NP,D=3.813'1 •i I ♦. I Minimum 1D=3.725"a 9790' 1 ii'=' N sloe' rx4-1/2-0102 S-3 RR,D=3.875• • 4-112" HES XN NIPPLE 4• r--a► { 9731' 841 HES xMPD=3.813• 4 I M 14-12'TBG,12.60,L-80 T'CI, --1 9803' I I P I 9790' H4-1/7'(ES XN MP,D=3.725' I (.0152bpf,D=3.958' ii• I ii • p 1 9803' H4.1/7 MEG,D=3.958' I :! I I NH-MDTTNOTLOGGED I r CSG,264,L-80 BTC-IA,D=8278' 9834' L. 9836' f--9-SI8'BKRZXPLTPwFIE BACK SLV Ci [TOP OF 4-1/2-LW/H 9437 8 FLEX LOCK HDR D-6.313' TOP OF r LNR 9®11' 9860' H7'X 4-1/2'XO,D=3.958' a 9-5/8'CSG,474,L-80,O=8.681' -{ 10155 f , PEREORA TION SUMMARY REF LOG.SLB RES/GR on 12/14/98 ANGLE AT TOP F .9T Q 11440' Note:Refer to Production OB for historical pact data A.!-LOUT WINDOW(R-114) 10207-10219' SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 2-7/8' 6 11440-11470 0 0607/14 ` 2-7/8' 6 11850 11880 0 06/07/14 ` 2-314' 6 13990-14050 0 12/21/98 14420' -ASH-FASORLL i 2-314' 6 14350-14410 0 12/21/98 ` PLUGS(12/22/08) [TOP OF V*FSTOO( [--4 10207 ••• [TOP OF CEMENT H 10254' 1 / •~ •••• ❖ • •••114.4 1--- 14118- • •• ••••••••••••• II r 1NR,284,L-80, 0371 bpi,D=8.184- 10207 ••4.44.4••••1 4-12'LNI.12.64.L-80, H 14580• ' ET.0152 bpi,D=3.958- DATE REV BY COMWB'ITS DATE REV BY OOMWEI4TS PRWMOE BAY UNIT IP 1583 i JJ ORIGNMLCOMpeET10! 03/20/12 CfY940 REMOVED M)TI(03/18/12) WELL R-11A 01/22198 !203 SIDETRACKED 03/27/12 PJC ELM NOT LOGGED P6ik(T No.1982060 12(25/08 NIES RYVO 09/11/14 RRIMJMD ADMIRES(06107114) AR Pb. 50.029-20893-01 06/17/09 AW/JMDDFLG DRAFT COFRECITONS SEC 32,T/2N,R13E,1121'FSL81824'FWL 02/15/11 1.18/900 SSSV SAFETY NOTE 01/18/12 TMWJMO I12S SAFETY NOTE OP Ecploratlon(Alaska) Injector Minilog El Techlog Prosect PBU WWF R Well. -1 1 1 A H Author Laura J.Larson Scab 1 5000 V R Date 5/18/2015 *1....6w ts I$ x 828221 f7 SPW Omar 1,111.1202 000000 ,:.wY+ USA bowmen dew%KS y 4$77/1757 Compton Da* 1118-12.21 009000 .a Prudhoe 1•y rowOKM+1104$ tarok**44,00734 Suet. Coordnw.System N1027MT LAM,*70748702 OpuMor 1/P%A -"car-, SPXA 0- Z Z 0 $EST.GR a 0 API 2..02 PE Notes 3, cm Rote 01Penetration Tvou MO N . X' IEST.ROP (FEET) (f1tT) ► (ndfx.TVQ55 BEST COMP _ 1:5004 1:5000 °L 3 4 - --- _ X' moo /t �0 OH 1.41.1 204 tSO,: 1 SttA 1/615! i4 Com' 06155 ' pp. 1700 -• G......,.®..��.-- $7s„is 1-10700----- t L, -t75S 4� -t74S ! } r "5 '1,-11000 3r I . 1_ h4$ . . SAD •ISSN —._ , 8730 . 6» Z.,r 4 -12000 .". 8735 A ti1735 J , I _____ 1740 1 TSMC -.4_.` _ _ —... TSAD .� `12500 a --1 8725 -, r 8725 1730 tt ti.._ �. -8725 113000 G , CI t 1171S -N, __" t 8710 '-13100 .t ,'. It} 11701 Set CIBP, r13,700' i I. . r 8700 i t -14000 j 1695 1 t y.. 8890 1 1 .18500 i _— F I * * e Company BP Exploration (Alaska) Itic. view, R-1 1 A IMPulse Field: Prudhoe Bay Final Print Rig Nabors 2ES State: Alaska Recorded McKie Resistivity Data ...., , Setikwil)erger Measured Depth Log neon Scales 1:. • and 1240 -...xtaP"lout, o ' , 14560 ft ! eg.t Ke 51 15ft .... *3 , 5 Cit_ 1390ft ill fn G- C,4 0 3 _ 2___ ''r 7 Lu °4' -7.• 75 17. , . .,.. 1 "r4S Lt L'41: 4-erfrarielit.datum Mear•Sea Levet Elea, Q ft. Z cr. Z rt co 1-t e4 measored from FRB 51 15 ft.above Peon fiatum Depth reference Detect Dt 17; le --,. 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NN N N N N N N N N N N N N N N NN m E 8888 88 2822 88� 2 288 E 4 m8288882 $2 2 2 g 2 a i .e 2 WVoNNmmSSmmmH8S8NNNFAEImSa` il O E 4� �� 0 . -" y 6 -amooN o 6m�m maamo0o1 ._Rs E °�J 8 ` 000oo000000000000 00 0000Ug9 oFm EM3 A i g LLd2�&gnS$� �§$S$§RR�B$S2�§2 `153 Y m uo n t iE e N E N NN vim meoicoieoi voieoieiei a 66ei mmm m vim eieeii n mmvi w \9 ra��4�ms m " II6. w ry . 014 � la.> ; II q m m g m 2 m" DATA ENTRY AREA:MUST ENTER DEPTHS,FLUID DENSITIES AND SURFACE TBG COLLAPSE REFERENCE DATA User Input Tbg Size Class Pressure Derated Depth of Fluid Tubing Conditions IA Conditions Interface Etc. Fluid Fluid 2 7/8"\6.5# L or N-80 11165 (Needs Entry) Density Pressure Density Pressure 80%= 8932 Depth-(TVD Ft) (#/gal) (Psi) (#/gal) (Psi) 3 1/2"\9.3# L or N-80 10533 0 Enter Tbg= 3000 Enter IA= 0 80%= 8426 3000 6.8 1059 6.8 1059 4 1/2"\12.6# L or N-80 6750 6750 8800 8.5 2560 8.56 2578 80%= 5400 7588 brst r 0 5 1/2"\17# Lor N-80 6280 ✓ 0 80%= 5024 r 0 7"\26# Lor N-80 5410 r 0 80%= 4328 r 0 ✓ 0 FLUID GRADIENT REFERENCE DATA r 0 TYPE DENSITY GRADIENT ✓ 0 (#/GAL) (PSI/FT) r 0 15°CRUDE 8.05 0.4182 DATA ENTRY AREA:ENTER FLUID INTERFACE DEPTHS AND FLUID 0 28°CRUDE 7.40 0.3841 DENSITIES FOR ALL INTERFACES. ENTER SURFACE PRESSURES. 0 30°CRUDE 7.31 0.3793 DENSITIES REFER TO FLUID AT THAT POINT AND ABOVE. ENTRY POINTS 0 40°CRUDE 6.88 0.3572 ARE DESIGNATED BY RED LETTERING. 0 DIESEL 6.80 0.3531 0 100%METH 6.64 0.3446 0 50/50 M/W 7.49 0.3888 60/40 M/W 7.32 0.3800 Pressure I Pkr=6620 Pkr=3638 FRESH WATER 8.34 0.4329 Max Differential at Packer= -2982 SEA WATER 8.56 0.4443 PROD WATER 8.51 0.4417 Brine Water 9.60 0.4985 Differential Pressure across Tbg Brine Water 10.00 0.5193 Brine Water 10.60 0.5505 Prod Gas @ 2000 1.14 0.0592 ICalc Differential Pressure Calculated Threshold Prod Gas @ 1000 0.49 0.0254 Your Choice= 2 0.1039 -4000 -2000 0 2000 4000 6000 8000 10000 I ' r--' EXAMPLE CASE 'Too of Well. 1000 IDiesel I II �� 2000 IA TVDuid Interface @ 2000' 3000 I. i *- . ; 4000 ( , Gas t I I 1�'' Brine 10.6#/gal ------", \ 6000 is ! 7000 •I I '' TTbg VDFluid Interface @ 8000' 8000 I +- ijiiliai I -Diff Pressure j::::::::::::. 9000 \��^ - -T126# - • 51/2.\178 Packer Depth @ 8200'TVD. Ei3fEpE:: 10000 - •41/2"\126# 1 Crude 1 - •31/2"V9.3# .2 7/8"/6.58 1':ii::: ::1 • • , 63 % , I. \ v t �f l if _i A 111'1 \) -, ,f . i ,, \ _ ! -----iiit• -........ ia - ! l 1. i ' COQCO '411 N 4 N t/ 1 ^ .,, - N t a N / i 4.\\/,' iiii -..i„,......' ? 'Ill f „r_ f: Nr 11 cL Lr / '‘jal to `off 0 die / e 5e I O � / Jo 6 o ra J I / gra �1 , i j \ C\ 4 a£ l0 m c � O�Q m E a S �o co c m m ! II u i / M l 1 �` 0 &OP i 2 § 12 © S S ® m o § Q b VI X In , § § § § ©q tn SeV q ® c § Q . . . ntS L. 2 E § § § 2 q _ o § $ $ 3 o C.) § U. 0 IL R § } S ao o § .. U Q . - Ln E w ) ( _ o o a o § q@ 13 o . - M { � - \ CU % § 2 ; : ; : ; ; :al —to 2 22 2 2 \ E { \ / \ - \ - \ L \ / u 4 © $ ? % \ i ƒ 44 G lo O § ; \ ) J a 2 « § o 0 a E G0 ! E m \ ] , \ \ O \ \ \ \ \ ) \ \ \ O ` c o k k \ a ( \ en +n 7 'D ° vt \ it k < < u. § >, k < 0 TIS= C3W S Y NOTES:H2S READINGS AVERAGE 125 ppm VVELLI-EAD= (MVV R-1 1 A ANL ON WELL B L ANG L>REQUIRES1041SSSV WHEN ON ACTUATOR= BAKER C OKB.ELEV= 51.1' BE ELEV= 21.68' , KOP= 3096' I 1`14 1�•`' I 1929• -19-5/8"I IM ES CEMENTER Max Angle= 99°@ 10685' 1". (I1 Datum MD= 10446' 4, 1'�1�- 1951' -9-5/8"BKR ECP,D=8.770" Datum TVD= 8800'SS A:41 111• i3O# 1114 9-5/8"BOWEN CSG PATCH,47#, - 1994' 14�� +� 2211' H4-1/2"HES XNIS,D=3.813" L-80 HYD 563,ID=8.681" 1i#� 11 .± -.. 1'1- —I 2590' H9-5/8"DV FKR 7"CSG,26#,L-80 TCI XO TO L-80 BTC-M -1 2668' 6• '1 +1 11 13-3/8"CSG,72#,L-80,ID=12.347" -I 2689' '' 1 • ., ' ' 9687' -{41/2"HI' ES X N ,D=3.813" A 1 Minimum ID = 3.725" @ 9790' .i''= =�•1 9708' -{7"x 4-1/2"BFCFRS 3 F D=3.875" • 4-1/2" HES XN NIPPLE !� ;' 9731' H4-1/2"HESXNP,D=3.813" 04 I I 04 I 4-112"TBG,12.6#,L-80 TCX, H 9803' 1 9790' -1 4-1/2"HES XN MF D=3.725" .0152 bpf,D=3.958" '4i ►1 • +• N. 1 9803' --14-1/2"WLEG,D=3.958" • . I. P H ELMD TT NOT LOGGED 7"CSG,26#,L-80 BTC-M D=6.276' H 9834' \ * \ 9836' -9-5/8"BKR ZXP LW w/TE BACK SLV TCW OF 4-1/2"LNR -1 9837' 8 FLEX LOCK HGR,D=6.313" TOP OF 7"LNR 9911' 9860' 17"X 4-112"XO,n=3.958" 9-5/8"CSG,47#,L-80,D=8.681" -1 10155' k PERFORATION SUMMARY REF LOG:SLB RES/GR on 12/14/98 ANGLE AT TOP PERE.92°@ 11440' Note:Refer to Production DB for historical perf data Mt LOUT VNNDOW(R-IIA) 10207 -10219' SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 11440- 11470 0 06/07/14 4444/ 2-7/8" 6 11850- 11880 0 06/07/14 2-3/4" 6 13990- 14050 0 12/21/98 ;, 441141 14420' -FISH-FASDRLL 2-3/4" 6 14350- 14410 0 12121/98 N PLUGS(12/22108) TOP OF WHIPSTOCK 10207' lk 44 TOP OFCHNBNT - 10254' 1 `.••••• 1111111 •i•• 1111111 1111111111111 P611) H 14418' • *111111//11111 X1111111111114 7"LNR,26#,L-80,.0371 bpf,D=6.184" 10207' i1i1.1,1A1�1�1, 4-1/2"LNR,12.6#,L-80, H 14560' IBT.0152 bpf,D=3.958" DATE REV BY COIMrENTS DATE REV BY CONVENTS FRIDHOE BAY UNIT r 1983 JJ ORIGINAL COMPLETION 03/20/12 CDJ/JND REMOVED ELM?TT(03/18/12) WELL: R-11A 01/22/98 N2ES SIDETRACKED 03/27/12 PJC ELM)NOT LOGGED FERMI No:'1982060 12/25/08 N4ES RWO 09/11/14 RRW/JM3 ADPE2FS(06/07/14) AR No: 50-029-20893-01 06/17/09 AW/JPA) DRLG DRAFT CORRECTIONS SEC 32,T12N,R13E, 1121'FSL&1824'FW- 02/15/11 MB/JM) SSSV SAFEIY NOTE 01/18/12 T AI/JM) Ii2S SAFETY NOTE BP Exploration(Alaska) x 0 0 0 0 0 0 0 0 Cr�O I- N 1 ca � COCO7V LS v LC) 0 N V LO U 00 O O O O O O i 6) co f— N V (o V co V Cr) CO CO N "Cl" N m 'Cr CO CO N- 00 N CO LC) N- "Zr V N- O CY) CO C7) 0 LC) CO L() CO CA CO CO CO CO N CO CO CO 00 CO > 1 I I i I I 1 1 r N- N O N O 0) O CO CO COCOCOCA COCOCO N 00 CO CD cz)C N O N- 00 C� L[) i Packers and SSV's Attachment ADL0028279 SW Name Type MD TVD Depscription R-11A PACKER 1959 1958.93 9-5/8" Baker ECL Packer R-11A PACKER 9714 8241.08 4-1/2" Baker S-3 Perm Packer R-11A PACKER 9842 8346.29 7" Baker ZXP Top Packer l d N f6 m N- N CO 10 L O LO CO CO Q y I-- co V co ❑ I- N N- ❑ CO 00 CO CO H • Q 0 N- CO CO .c CO LO a °O o Oo 0 • co dt � N- N- r- ❑ CO CO CO I- 0 m w > Y Y- ap 0 0 0 0 W Q < w W N- CO In r J w J J a a ❑ v V' U a U O U J J J D J Q) Z w Z w 2 0 0 0 0 J 0 w Q H < - Q = 0 u.„ a > m 2Q = � = z N z ❑ 0 E U U U w Q F. w z 0 w ( ( 22 2 0 c~n0 ) < 0 Cn ai n3 N Q 00 a N = O Q r o C 1.9 0 J Qd" 00C) ++ CN Q Y U O cJ) 2 2 2 O c) 1- can 0) can 0 a 0 U .2 • LL LL w' m d d w w m < < d d a 0 a, m o_ 0 Lu H ~ 0 0 vvrnrn o CD o o Q 0") rn > > w J J Z c 0 0 Z w 0 0 < w w 0 N N V- a w W W LU N N U 0CCNN a CD 0 U W LLI wLLI Q co a Q m m I I cn cn a CI) E m z < < < < Cl) w a U) N w MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,January 08,2015 Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC R-11A FROM: Bob Noble PRUDHOE BAY UNIT R-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm •Well Name PRUDHOE BAY UNIT R-1 IA API Well Number 50-029-20893-01-00 Inspector Name: Bob Noble Permit Number: 198-206-0 Inspection Date: 12/23/2014 Insp Num: mitRCN141223143251 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R-11A Type Inj w 'TVD 8236 - Tubing 601 . 596 600 . 601 • PTD 1982060 'Type Test SPT Test psi 2059 IA 141 4010 - 3958 = 3941 - Interval1REQvAR P/F P OA j— 18 28 35 38 Notes: Test to max inj pressure Max inj pressure is 3300 psi i isc:R.) 3,02 SCANNEDF-h ii . ,> Thursday,January 08,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] ' Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Mildred Daretha(~..owell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Dareth~'-'___...~ th~i~an~owell Date:..~/~) Is~ ~ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '---7 )e-4, 1 I ZA ( 1 DATE: Wednesday, January 23, 2013 P.I. Supervisor ( ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R-11 A FROM: Chuck Scheve PRUDHOE BAY UNIT R -I l A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry S.:le- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-11 A API Well Number 50-029-20893-01-00 Inspector Name: Chuck Scheve Permit Number: 198-206-0 Inspection Date: 1/20/2013 Insp Num: mitcS130122072419 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min W 1 R-11 A Type Inj I w JTVD I 8236 ' ' IA 600 T 3980 - ] 396O r 3960 1 I 1 PTD 1 1982060 / Type Test SPT Test psi i 3600 ' OA 893 835 - 1 860 876 . i —H 1 1 1 I 1 Interval ' REQVAR - P/F 1 P ' Tubing 95 ° I 95 ° 1 95 ° 95 ° ' I , I _ Notes: Two year MIT per AA:AIO 3.024. , -.. SCANNED APR 11 2C13 Wednesday, January 23, 2013 Page 1 of 1 R -11A (PTD #1982060) Sustained OA pressure that does not exceed MOASP Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 01, 2011 10:36 AM To: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA) Subject: FW: R -11A (PTD #1982060) Sustained OA pressure that does not exceed MOASP Attachments: R- 11A.pdf; R -11A TIO and Injection Plots.doc; R_11_OA_GAS_022809.dot; R -11 2011 -02 -08 OA Gas Sample.xls Further to the earlier message, there was a new gas sample included with the latest MIT info. There are slight variations in the analysis, but based on the BTU the samples are essentially the same. There is a slight amount of CO2 in the new sample, however I don't believe it is significant. Tom From: Maunder, Thomas E (DOA) Sent: Tuesday, March 01, 2011 9:10 AM To: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA) Subject: FW: R -11A (PTD #1982060) Sustained OA pressure that does not exceed MOASP Gents, I have been reviewing MITs and files for recently completed MITs. You might find this information of interest. The message and attachments are in the appropriate well file, but this information may need to be included elsewhere. Where elsewhere is I am not sure. Tom From: NSU, ADW Well Integrity Engineer [ mailto: NSUADWWelllntegrityEngineer @BP.com] Sent: Saturday, February 28, 2009 4:17 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; GPB, Area Mgr West (GC2 /WRD); GPB, GC2 011; GPB, GC2 Wellpad Lead; GPB, Well Pad RJQ Subject: R -11A (PTD #1982060) Sustained OA pressure that does not exceed MOASP Jim, 0 R -11A (PTD #1982060) is a WAG injector that was worked over in December 2008 to repair a surface casing leak. The repair included cementing the OA (7" x 9 -5/8" annulus) to surface. Over a week after the well was put on water injection, the OA was found to have sustained OA pressure that does not exceed MOASP. The OA has been bled several times since 02/02/09 to find the same results. The OA pressure increases approximately 200 psi /hr until reaching approximately 800 psi where it stabilizes. It is evident on the TIO plot that OA pressure is consistently higher than the IA pressure; eliminating the prospect of IAxOA communication. In addition, the well passed an AOGCC witnessed MITIA post - initial injection on 01/21/09. Gas sample results of the OA indicate the gas is dissimilar to formation gas as it does not have any CO2 and has a low heavy end content (C2 -C6). Our plan for this well is to apply for AA for continued WAG injection. We will send you a digital copy as soon as we mail the request to your office. A TIO plot, injection plot, gas sample analysis and wellbore schematic have been included for reference. «R- 11A.pdf» «R -11A TIO and Injection Plots.doc» «R_11_OA_GAS_022809.dot» Please call with any questions or concerns. 3/1/2011 DATE SAMPLE SAMPLE ANALYSIS ANALYSIS SW NAME SAMPLE SAMPLE_NUM DESC POINT ANALYSIS NAME RESULT UNITS ANALYSISRESULT TEXT ANNULAR OUTER BTU GRSDRY BTU @14.696 R -11A 08- Feb -11 PC53877 GAS ANNULUS IDEAL 1069.6 PSIA ANNULAR OUTER BTU GRSDRY BTU @14.65 R -11A 08- Feb -11 PC53877 GAS ANNULUS REAL 1068.7 PSIA ANNULAR OUTER BTU GRSSAT BTU @14.73 R -11A 08- Feb -11 PC53877 GAS ANNULUS IDEAL 1053.4 PSIA • ANNULAR OUTER BTU @14.696P R -11A 08- Feb -11 PC53877 GAS ANNULUS BTU NET 965.1 SIA ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS C6P -MOL% 0.018 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS CO2 -MOL% 0.017 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS ETHANE -MOL% 5.223 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS I- BUTANE -MOL% 0.157 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS I- PENTANE -MOL% 0.007 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS LINE PRES 500 PSIG ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS METHANE -MOL% 92.006 MOL% . ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS MOL WEIGHT 17.451 ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS N- BUTANE -MOL% 0.103 MOL% ANNULAR OUTER N- PENTANE- R -11A 08- Feb -11 PC53877 GAS ANNULUS MOL% 0.004 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS NITROGEN -MOL% 0.959 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS 02 CONTAM MOL% <0.001 ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS PROPANE -MOL% 1.506 MOL% ANNULAR OUTER R -11A 08- Feb -11 PC53877 GAS ANNULUS SPG REAL 0.6037 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg ryye j DATE: Wednesday, February 09, 2011 P.I. Supervisor 1�£� / 2 1 1 q , 1 ( SUBJECT: Mechanical Integrity Tests L BP EXPLORATION (ALASKA) INC R-11 A FROM: Chuck Scheve PRUDHOE BAY UNIT R -1 IA Petroleum Inspector Src: Inspector Reviewed By: p P.T. Supry Age-- --- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT R -11A API Well Number: 50- 029 - 20893 -01 -00 Inspector Name: Chuck Scheve Insp Num: mitCS110207125516 Permit Number: 198 -206 -0 Inspection Date: 2/5/2011 — Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 'Well 1 R -11A ' Type Inj. W ' TVD 8236 • IA 40 4000 - 3980 3980 P. T.D 1982060 TypeTest S Test psi 2059 ' OA — 960 860 940 950 Interval R p/F P ' Tubing 450 450 450 450 Notes: 5, [)p5 S. ANNEX) APR 1 3 fall 1 Wednesday, February 09, 2011 Page 1 of 1 July 10, 2009 `~.;~~'~~$~~~~ .iU~. ~ ~~'' ~.~~~~ Mr. Tom Maunder ~/~ Q r~ Alaska Oil and Gas Conservation Commission ~-O 333 West 7th Avenue ~ ~ 11 ~ Anchorage, Alaska 99501 ~-. Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad 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 altemate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. 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) R-pad Date Revised 7/10/2009 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 500292~3540000 1781000 1.25 NA i.25 NA 6.8 5111l2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-OS 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6l22/2009 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-186 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 162 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 125 1VA 11.05 5/14/2009 R-31 A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11 /2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, ~~ ~~~. ~~ ~ >,~~'~~ Enclosed please find a spreadsheet with a list of wells from R-Pad 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, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this ietter 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, Anna Dube, at 659-5102. Sincerely, ~~~'~~~~ ,~ G ~ . r : `l ~1~ ; ~ Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~ Date R-pad ~ 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11 A 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/1 S/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 025 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 225 NA 2.25 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18l2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 i 931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 • • i � 1 I . [j 1 i ( SARAH PAIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE. SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AIO 3.024 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Z G t Anchorage, AK 99519 -6612 WOOED MAR (1 2, RE: PBU R -11 A (PTD 198 -206) Request for Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order (AIO) 3.000, the Alaska Oil and Gas Conser- vation Commission (Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water alternating gas (WAG) injection in the subject well. The Commission was notified by BPXA of outer annulus (OA) repressurization while in- jecting in PBU R -11A. The well was recently worked over to repair a surface casing leak by cementing the OA back to surface.. Diagnostic mechanical integrity testing confirms the well exhibits competent tubing and production casing. Analysis of the gas sampled from the well's OA indicates the source is a shallow gas zone, not gas injected for en- hanced oil recovery, and not Ivishak reservoir gas. BPXA has elected to perform no ad- ditional corrective action at this time on PBU R -11A. The Commission believes that the well's condition does not compromise overall well in- tegrity so as to threaten the environment or human safety, if the well's operation is subject to the certain constraints. BPXA' s legitimate attempt to repair the surface casing leak is in part the basis for the Commission's administrative approval to continue WAG injec- tion in PBU R -11A, conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall limit the well's outer annulus pressure to 1000 psi; MO 3.024 • • March 24, 2009 Page 2 of 2 4. BPXA shall perform an MIT of the tubing - casing annulus every 2 years to the maximum anticipated injection pressure; 5. Every 2 years, BPXA shall sample and analyze gas from the OA; 6. BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer an- nulus pressure, increased repressure rate, or increased bleed frequency; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is January 21, 2009. DONE at Anchorage, Alaska and dated March 24, 2009. # () L i ■1.." Daniel T. Seamount, Jr. Cathy ' . Foerster 7 an • Chair Co issioner ommissianer, OIL �V ? cc: BPXA Well Integrity Coordinator, PRB -20 ' ° - P.O. Box 196612 Anchorage, AK 99519-6612 Y r - the pc RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was nailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration" In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. .0 \4 MAR 1 1 ?009 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Alaska OiI & Gas Cans. CommissitilY Post Office Box 196612 Anchora Anchorage, Alaska 99519 -6612 March 10, 2009 Mr. Daniel Seamount, Chairman Alaska OiI and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well R -11A (PTD #1982060) Request for Administrative Approval: Continued WAG Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued WAG injection operations into Prudhoe Bay well R -11A with a sustained OA casing pressure that does not exceed the maximum operating annulus surface pressure. Well R -11A has a sustained outer annulus pressure, which stabilizes at approximately 800 psi. An outer annulus gas sample indicates a shallow gas zone, not similar to the Ivishak reservoir, is responsible for the sustained pressure. This is further evidenced because the inner annulus pressure is stable at a pressure well below the outer annulus pressure. Because the outer annulus was cemented to surface during a recent rig work over, the outer annulus both bleeds off and repressures rapidly. A pressure test of the inner annulus passed to 4000 psi, indicating competent tubing and production casing. Based upon sound engineering practice, two barriers have been established and the well can be safely operated. In addition, the observed annulus operating pressure does not exceed 45% of the casing's rated burst pressure. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well R -11A is safe to operate as stated above and requests administrative approval for continued WAG injection operations. If you require any additional information, please contact me at 564 -5637 or Anna Dube / Andrea Hughes at 659 -5102. Sincerely / R. Steven Rossberg BPXA, Wells Manager • • Attachments: Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Bixby /Olsen Dube /Hughes West Area Manager Don Brown Harry Engel Janice Vosika Pru ne Bay Oil Pool well R -11 m • Technical Justification for Administrative Approval Request March 10, 2009 Well History and Status Prudhoe Bay well R -11A (PTD #1982060) has sustained outer annulus pressure that stabilizes at approximately 800 psi. An OA gas sample indicates the gas source is not injected or Ivishak reservoir gas. An MIT -IA to 4,000 psi passed on 01/21/09, confirming competent tubing and production casing. Recent Well Events: 12/25/08: RWO completed - run tie -back to surface, cement OA & OOA to surface 01/21/09: AOGCC Witnessed MIT -IA Passed to 4000 psi 02/27/09: OA gas contains no CO2 and very little C2 -C6, confirming shallow gas zone Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 4000 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 4 -year MIT -IA to 1.2 times maximum anticipated injection pressure. 4. The well's will be shut -in and the AOGCC notified if there is any change in the wells mechanical condition. • R-11 A TIO Plot 4,000 • • 3,000 • • • • Tbg 2,000 OA 00A -4— 000A -II- On r 1,000 t i / 14 0 141 1 ° 03/18/08 nailaa 05/19/08 08/19/08 07/20/08 08/20/08 09/20/08 10/21)08 11/21/08 12/22/08 01/22/09 02)22/09 • • R-11A Injection Plot 1,d00 -10,000 1,300 - 9,000 1,200 1,100 - - 8,000 1,000 y - 7,000 900 � mg —WHIP 800 - 6,000 v — SW — PW 700 • - 5,000 - MI — GI 600 • o — Other - 4,000 111 On 509 - 400 - - 3,000 300 - 2,000 00 0 - '- 1 , 90 0 1 00 • 03,18/08 04/18/08 05/19/00 06/19/08 07/20/08 08/20/06 09/20/08 10/21/08 11/21/08 12/22/08 01/22/09 02/22/09 TREE = 4 - 1/16" 5M CNN SAFF1 Y TES: * ** TO° @ 10410' & 90° ACTUATOR WELLHEAD = 13 -5/8" 5M McVOY SSH R-11 A 10 ACTUATOR = BAK : KB. ELEV = 51.15' BF. ELEV = 21.68' DRLG DRAFT 1 KOP = 3096' � tt Max Angle = 99 @ 10685' � `�" 1929' H9 -5/8" FES CEMENTER I Datum MD = 10446' i ` ( 2211' H4 -1/2" HES X NIP, ID = 3.813" I Datum TV D = 8800' SS r 59 20' j DV PKR I9 -5/8" CSG PATCH, 47 #, L -80, ID = 8.681" H 1994' 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I-i 2689' X 17" CSG, 26 #, L -80, TCII, ID = 6.276" H 2668' Minimum ID = 3.725" @ 9827' I r I 9687' I- 14 -1/2" HES X NIP, ID = 3.813" I 4-1/2" HES XN NIPPLE S $� ` ( 9708' 1--17" X 4 -1/2" BAKER S -3, PKR, ID = 3.875" I 1 I 9731' H4-1/2" HES X NIP, ID = 3.813" 1 14-1/2" TBG, 12.6 #, L -80, ID = 3.958" H 9803' I I 9790' H4 -1/2" HES XN NIP, ID = 3.725" I 9803' 4 -112" WLEG I7" CSG, 26 #, L -80, BTC-M, ID = 6.276" H 9834 I ( �� I 9836' J TIE BACK SLEEVE BAKER 9 -5/8" ZXP TOP OF 4 -1/2" LNR H 9837' LT- PKR, BAKER FLEX -LOCK HGR ID = 6.313" THROUGH PKR AND HGR 9860' H7" X 4-1/2" XO I I TOP OF 7" LNR H 9911' I II II I9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10155' I • PERFORATION SUMMARY REF LOG: N/A ANGLE AT TOP PERF: 92 @ 13990' MILLOUT WINDOW FROM Note: Refer to Production DB for historical perf data 10207' - 10219' SIZE SPF INTERVAL Opn /Sqz DATE 2 -3/4" 6 13990 - 14050 0 12/21/98 2 -3/4" 6 14350 - 14410 0 12/21/98 TOP OF WHIPSTOCK 10207' PBTD 14418' r TOP OF CEMENT H 10254' 'eov1.1.A' 111t1N/ �•s�.� HM1111 , ssss. N11N // s•sss. �111N11 ••sss. 11111111 �ss 111 1111 • • • ■1 1 1 1 1 1 1 1 1 1 1 1 1 1 • 1 ■1 1 1 1 1 1 1 1 1 1 1 1 1 / 1 4 -1/2" LNR, 12.6#, L -80, 14560' 17" LNR 26 #, L -80, .0371 bpf, ID = 6.184" 10207' �, 1ST .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1983 JJ ORIGINAL COMPLETION WELL: R 11A 01/22/98 SIDETRACKS PERMIT No: 1982060 12/25/08 N4ES �RWO 4 API No: 50 -029- 20893 -01 SEC 32, T12N, R13E BP Exploration (Alaska) R-1 lA (PTD #1982060) Sust:d OA pressure that does not exceed ~SP Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, February 28, 2009 4:17 PM ~ ~ ~} ~~l 0~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~ 1 t Cc: Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad RJQ Subject: R-11A (PTD #1982060) Sustained OA pressure that does not exceed MOASP Attachments: R-11A.pdf; R-11A TIO and Injection Plots.doc; R_11_OA_GAS_022809.dot Jim, R-11A (PTD #1982060) is a WAG injector that was worked over in December 2008 to repair a surface casing leak. The repair included cementin t (7" x 9-5/8" annulus) to surface. Over a week after the well was put on water injection, e A was found to have sustained OA pressure that does not exceed MOASP. The OA has been bled several times since 02/02/09 to find the same results. The OA pressure increases approximately 200 psi/hr until reaching approximately 800~si where it stabilizes. It is evident on the TIO plot that OA pressure is consistently higher than the IA pressure~imma mg t e prospect of IAxOA communication. In addition, the well passed an AOGCC witnessed MITIA post-initial injection on 01/21/09. Gas sample results of the OA indicate the gas is dissimilar to formation gas as it does not have any C02 and has a low heavy end content (C2-C6). Our plan for this well is to apply for AA for continued WAG injection. We will send you a digital copy as soon as we mail the request to your office. A TIO plot, injection plot, gas sample analysis and wellbore schematic have been included for reference. «R-11A.pdf» «R-11A TIO and Injection Plots.doc» «R_11_OA_GAS_022809.dot» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/23/2009 TREE = 4-1/16" 5M CMI WELLHEAD = 13-5/8" 5M McVOY SSH ACTUATOR = BAKER KB. ELEV = 51.15' BF. ELEV.- 21.68' KOP = 3096' Max Angle = 99 @ 10685' Datum MD = 10446' Datum TVD = 8800' SS S~ NOTES: *** 70° @ 10410' & 90° @ 105',f9' *** R-11 A ~~L~ ~~AFT 9-5/8" CSG PATCH, 47#, L-80, ID = 8.681" ~ 1994' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2689' 7" CSG, 26#, L-80, TCII, ID = 6.276" 2668' Minimum ID = 3.725" @ 9827' 4-1 /2" HES XN NIPPLE I4-1/2" TBG, 12.6#, L-80, ID = 3.958" ~ 9803' 7" CSG, 26#, L-80, BTGM, ID = 6.276" 9834' TOP OF 4-112" LNR 9837' TOP OF 7" LNR ~~ 9911, 9-5/8" CSG, 47#, L-80, ID = 8.681" 10155 PERFORATION SUMMARY REF LOG: N/A ANGLE AT TOP PERF: 92 @ 13990' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 6 13990 - 14050 O 12/21/98 2-3/4" 6 14350 - 14410 O 12/21/98 TOP OF WHIPSTOCK 10207' TOP OF CEMENT ~ 10254' 7" LNR, 26#, L-80, .0371 bpf, ID = 6.184" 1929' 19-5/8" HES CEMENTER 2211' 4-1/2" HES X NIP, ID = 3.813" 2590' ~9-5/8" DV PKR g6g7' ~ 4-1 /2" HES X NIP, ID = 3.813" 9708' 7" X 4-1/2" BAKER S-3, PKR, ID = 3.875" 9731' 4-1/2" HES X NIP, ID = 3.813" g7g0' 4-1/2" HES XN NIP, ID = 3.725" 9803' 4-1/2" WLEG 9836' TIE BACK SLEEVE BAKER 9-5/8" ZXP LT- PKR, BAKER FLEX-LOCK HGR, ID = 6.313" THROUGH PKR AND HGR 9860' ~-'~ 7" X 4-1 /2" XO MILLOUT WINDOW FROM I 10207' - 10219' PBTD ~~ 14418' 4-1/2" LNR, 12.6#, L-80, IBT .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 1983 JJ ORIGINAL COMPLETION 01/22/98 SIDETRACKED 12/25/08 N4ES RWO PRUDHOE BAY UNIT WELL: R-11A PERMff No: 1982060 API No: 50-029-20893-01 SEC 32, T12N, R13E BP Exploration (Alaska) PBU R-11A PTD 198-206 2/28/2009 4,000 '-i fII III 2 000 t ,000 l 2/2 1,400 1,300 1,200 1,100 1,000 900 euo a `zj 700 600 500 auo 300 200 100 12/ TIO Plot _ ~,_ _ _ te r; ~---r tr-a r r~~ r r ~ a r ~ ffri-r-r-r-r: a; e ~ r-r r r-r~-~~--r=~~-r r-ff a-r-ra r O1 /03/09 Ol /l0/09 Ol /t 7/09 01/24/09 01/31/09 02/07/09 02/14/09 02/27/09 Injection Plot ~,ooo 6,500 6,000 5,500 5,000 4,500 4,000 3,500 ~ 3,000 c+ 2,500 2,000 1.500 1,000 500 _.•.... lbp • ~ IA OA OOA OOOA - On • WHIP -._. SW PW MI GI __....._._ Other On s ~ GPB LABORATORYANALYTICAL REPORT 907-659-5654 Bmail: GPBLab(C(,Up.COm Sample ID PC27376 Collection Date 02/27/09 Facility R-PAD Location OUTER ANNULUS Analysis Name Analysis Unit Combination Result LINE PRES PSIG 810 METHANE-MOL% MOL% 92.619 " ETHANE-MOL% MOL% 4.935 ' PROPANE-MOL% MOL% 1.190 I-BUTANE-MOL% MOL% 0.250 N-BUTANE-MOL% MOL% 0.098 I-PENTANE-MOL% MOL% 0.008 N-PENTANE-MOL% MOL% 0.004 C6P-MOL% MOL% 0.029 C02-MOL% MOL% 0.000 NITROGEN-MOL% MOL% 0.867 MOL WEIGHT 17.356 BTU GRSDRY IDEAL BTU@14.696PSIA 1066.4 BTU GRSDRY REAL BTU@14.65 PSIA 1065.5 BTU GRSSAT IDEAL BTU@14.73 PSIA 1050.3 BTU NET BTU@14.696PSIA 961.9 SPG REAL 0.6004 02 CONTAM MOL% 0.000 DISTRIBUTION Reported by: at 2:58 PM on 03/23/09 MEMORANDUM • To: Jim Regg ~ ~~ !/?~~z-~; j P.1. Supervisor ' l FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 28, 2009 StfBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R-1 ]A PRUDHOE BAY UNIT R-I I A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J:6,~-- Comm Well Name: PRUDHOE BAY UNIT R-11A API Welt Number: 50-029-20893-O1-00 Inspector Name: Chuck Scheve Insp Num: mitCS090122083452 Permit Number: 198-20G-0 Inspection Date: 1i21i2oo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _ - 1 _ ---.-. _ __ tialA YP ~ __ _ .._ Well T e In', w TVD sz9s = . IA - 300 __... _ _ 4000 ~ 3960 3960 ___ __ P.T. t9szobo TYPeTest sPT Test psi... zo~as y pp slo ~bo ato sto ...._ _ Interval wlucovR p~ P ,: Tubing Iloo ', Iloo ttoo Itoo _ Notes• Pretest pressures observed and found stable. 1~Pt C- (`, PI J. ~ ~t~: Wednesday, .lanuary 28, 2009 Pagc I of I ry~ \~~qa STATE OF ALASKA A~ OIL AND GAS CONSERVATION CO~SION ~C~~~~ j~® REP RT OF SUNDRY WELL OPE TION G V ~~ 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulat~~~S~(a l~it~~Op~gfll1 ® Alter Casing - ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ horage ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 198-208 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20893-01-00 - 7. KB Elevation (ft): 51.15' - 9. Well Name and Number: R-11 A - 8. Property Designation: 10. Field / Poot(s): ADL 028279 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 14560' feet true vertical 8737' - feet Plugs (measured) None Effective depth: measured 14418' feet Junk (measured) None true vertical 8740' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2689' 13-318" 2689' 2689' 4930 2670 Intermediate 10155' 9-5/8" 10155' 8606' 6870 4760 Production Liner 296' 7" 9911' - 10207' 8403' - 8650' 7240 5410 Liner 4722' 4-1/2" 9837' - 14559' 8342' - 8737' 8430 7500 Scab Liner 9834' 7" 40' 7240 5410 834' Surface - 8 3 Surface - 9 g r r'~~ii +~~`~~+ rry[ e~ tt/ ~ry r~~''' Perforation Depth MD (ft): 13990' - 14410' Perforation Depth TVD (ft): 8749' - 8740' 4-1/2", 12.6# L-80 9803' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-112" Baker 'S-3' packer ~~ 9708' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing. Cut and pull 9-518" casing from 1997'. Run 9-5/8" (47#, L-80, HYD-563) tieback to surface. Cement w/ 165 bbls Class'G' w/ Gas-Blok (926 cu ft 1799 sx). 9-5/8" Top Job with 6 Bbls ArcticSetl (34 cu ft / 29 sx), Run T' (26#, L-80, BTC / TCIq Scab Liner to 9834' cement with 286 Bbls Class 'G" (1606 cu ft / 1348 sx). Clean out and run new tubing. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: _ ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations rk: 16. Well Status after wo ® Well Schematic Diagram ~ ( ^ Oil ^ Gas IaI WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Aras Worthington, 564-4102 308-378 Printed Name Sondra Stewman Title Drilling Technologist ~.- Prepared By Name/Number: i nature ,Ph a 5743 Date~~• ~~~ Sondra Stewman 564-x750 Form 10-404 Revised 04/2006 ~" ~ ~ s1 ~ ~~ (~ ~ ~ Submit Original Only TREE _ I4-1/2" TBG, 12.6#, L-80, ID = 3.958" ~-~ 9803, 7" CSG, 26#, L-80, BTGM, ID = 6.276" 9834' TOP OF4-1/2"LNR 9837' WELLHEAD = 13-5/8" 5M McVOY SSH ACTUATOR = BAKER KB. ELEV = 51.15' BF. ELEV = 21.68' KOP = 3096' Max Angle= 99 @ 10685' Datum MD = 10446' Datum TV D = 8800' SS S~ NOTES: *** 70° @ 10410' 8~ 90° @ R-11 A 105 "** 9-5l8" CSG PATCH, 47#, L-8Q ID = 8.681" ~ 1994' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2689' 7" CSG, 26#, L-80, TCII, ID = 6.276" 2668' Minimum ID = 3.725" @ 9827' 4-1 /2" HES XN NIPPLE 1929' I-~9-5/8" HES CEMENTER 2211' 4-1/2" HES X NIP, ID = 3.813" 2590' 9-5/8" DV PKR 9687' --~ 4-1 /2" HES X NIP, ID = 3.813" 9708' 7" X 4-1/2" BAKER S-3, PKR, ID = 3.875" 9731' 4-1/2" HES X NIP, ID = 3.813" 9790' 4-1/2" HES XN NIP, ID = 3.725" 9803' 4-1/2" WLEG 9836' TIE BACK SLEEV E BAKER 9-5/8" ZXP LT- PKR, BAKER FLIX-LOCK HGR, ID = 6.313" THROUGH PKR A ND HGR 9860' I-17" X 4-1/2" XO TOP OF 7" LNR ~-1 9911, 9-5/8" CSG, 47#, L-80, ID = 8.681 " 10155' PERFORATION SUMMARY REF LOG: N/A ANGLE AT TOP PERF: 92 @ 13990' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 6 13990 - 14050 O 12/21 /98 2-3/4" 6 14350 - 14410 O 12/21/98 4-1/16" 5M CNV TOP OF WHIPSTOCK 1020T TOP OF CEMENT ~ 10254' 7" LNR, 26#, L-80, .0371 bpf, ID = 6.184" I-I 1 MILLOUT WINDOW FROM 10207' - 10219' 4-1/2" LNR, 12.6#, L-80, IBT .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 1983 JJ ORIGINAL COMPLETION 01/22/98 SIDETRACKED 12/25/08 N4ES RWO PBTDI~ 14418' I 14560' I PRUDHOE BAY UNff WELL: R-11A PERMfr No: 1982060 API No: 50-029-20893-01 SEC 32, T12N, R13E BP Exploration (Alaska) i Well History Well Date Summary R-11A 10/15/2008 T/V0= 120/120/0+ Temp = S/I. (RWO prep) MIT-T *PASSED* to 3000 osi, Punped 2.7 bbls of 34* methanol to achieve test pressure. TBG lost 40 psi / 1st 15 min & 10 psi / 2nd 15 min. Lost a total of 50 psi during the 30 minute test. Bled back - 2 bbls to 1000/140/O.~yf lff-IA *PASSED* to 3000 osi. Pumped 7.4 bbls of 34* methanol to achieve test pressure. Lost 80 psi / 1st 15 min & 20 psi / 2nd 15 min. Lost a total of 100 psi during the 30 minute test. Bled back - 7 bbls to final WHP = 100/100/0+. Annulus casing valves are open to gauges. SSV is closed. Verify valve positions w ith F/O at permit closure. R-11A 10/16/2008 Bled pressures post pressure tests Final WHPs 100/100/0 R-11A 10/21/2008 *** WELL S!I ON ARRIVAL.*** (pre_rwo) PULLED 4 1/2" PX PLUG BODY AND PRONG FROM 9807' MD. DRIFTED TO DEVIATION AT 10,407' SLM W/ 3.70" CENT, 3' -STEM, 3.65" CENT. *** WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS.*** R-11A 10/24/2008 T/VO=SSV/140/0. Temp=Sl. Monitor WHP (eval spray in cellar liner). Cellar has 4x10 cellar board buried in gravel. Cellar gravel is frozen and heater w as ordered to thaw cellar. Well has 30" insulated conductor. SV, WV, SSV=Gosed. MV=Open. IA & OA=OTG. NOVP. R-11A 10/26/2008 T/V0=SSV/140/0. Temp=Sl. PI-eo for cellar liner: remove gravel to --3 - 4' deep (pre RWO). Dug out 3 pieces cellar board, leveled gravel @ 53" from top. SV,WV,SSV=C. MV=O. IA,OA=OTG. NOVP. R-11A 10/28/2008 ***WELL SHUT IN ON ARRNAL. INITVaL T/VO: 250/150/0 PSI.*** SET TWO HALLIBURTON FAS-DRILL PLUGS AT 9930' & 10020' DEPTH CORRECTED TO PDS JEWELRY LOG DATED 11-28-00. LRS MIT TUBING TO 3000 PSI AFTER SETTING FIRST PLUG MIT PASSED. WILL RESUME JOB IN MORNING. DSO NOTIFIED WELL SHUT-IN AND SECURE, INFORMED OF VALVE PLACEMENT. ***JOB INCOMPLETE*** R-11A 10/28/2008 T/V0=10/130/0. Temp=Sl. Assist FB w/MIT-T 3000 psi**PASS** maintain open bleed ;vac flutes. Coductor has no fluid w ith gravel - 18"from top of conductor. Install tree containment, hold open bleed on OA. Have vac truck on location to remove fluid from flutes. During MIT-T no fluid w as detected in conductor. Final WHPs=0/130/0. E line & IRS still in control of w ell on departure. R 11A 10/28/2008 T/V0=10/130/0 temp=Sl Assist E-line w ith MIT TBG to 3000 psi PASSED (RWO prep) TBG pressured up to 3000 psi w ith 4.2 bbls diesel. TBG lost 240 psi in first 15 minutes and 40 psi in second 15 minutes. For a total of 280 psi in 30 minutes. Bled pressure down. FWHPs=0/120/0 AT DEPARTURE VALVES in following positions -and operator notified of positions and result of job. Wing closed, Sw ab open, SSV open, Master open, IA open, OA open, Well SI- Eline on w ell at departure R-11A 10/29/2008 '** WELL SHUT-IN ON ARRNAL*** INITIAL T/VO = 0/150/0. CUT 4.5" TUBING WfTH 3.65" POWERCUTTER IN MIDDLE OF FIRST FULL .,,JOINT ABOVE PACKER AT 9752', TIED INTO PDS JEWELRY LOG DATED 18-NOVEMBER 2000. TIE IN LOG IS ABOUT 10' DEEPER THAN TUBING TALLY. WELL SHUT IN ON DEPARTURE, SSV CLOSED, SWAB CLOSED, VALVES OPEN TO GAUGES, DSO NOTIFIED. FINAL T/VO = 0/0/0 PSI. ***JOB COMPLETE*** R-11A 11/12/2008 T/V0=440/0/0 Glrc. Out (RWO Prep) Pumped 5 bbl neat meth spear & started punping X-Slick 1 %KCL dow n TBG, taking returns up IA to w ell #12. ***Continued on 11-13-08 WSR* R-11A 11/13/2008 ***Continued from 11-13-08 WSR*** Grc Out (RWO Prep) Pumped 226 bbls X-Slick 1 % KCL & 860 bbls 1 %KCL dow n TBG, taking returns up Va, dow n hard line to w ell #12. Pumped 157 bbls DSL dow n Va, taking returns up TBG.U-tube for 2 hrs 15 min. Pump 5 bbls dow n hardline to freeze protect. Bleed WHPs to 0 psi. Annuls valves open to gauges. Tags hung. FWHPs=O/0/0 Print Date: 1/15/2009 Page 1 oft Well Date Summary R-11A 11/13/2008 T/Va/OA=O/0/0 Temp=cold PPPOT-T (PASS) PPPOT- IC (FAIL) (Pre RWO) PPPOT-T Pressure bled through slotted bleed screw verified 0 psi. Removed 1" NPT plug, removed internal check, installed 1" Alemite. Cycle all LDS "Standard" all moved and were in good condtion. RU HP BT onto THA flushed void until clean returns achieved. Pressured void to 5000 psi for 30 min, 4900/ 15 mins, 4900/ 30 mins. Bleed THA void to 0 psi, RD test equipment, re-installed Alemite cap. PPPOT-IC Pressure bled through slotted bleed screw verified 0 psi. Removed 1" NPT plug, removed internal check, installed 1" Alemite. Cycle all LDS "Standards" all moved and were in good condition. RU HP BT onto IC flushed void until clean returns achieved, attempted to pressure to 3500 psi, would not build pressure above 1000 psi. RU elephant gun onto packing port, injecting plastic into packing port until air free ribbon of plastic achieved, pressured to 6200 psi, on packing port. (2nd test) Pressured to 3500 psi for 30 minutes, 3000/ 15 minutes, 2900/ 30 minutes. Bled off test pressure to 0 psi, RD all test equipment, re-installed Alemite cap *** INTERNAL CHECKS REMOVm *** R-11A 11/21/2008 T/V0=0/0/0. Set 4" CNV H BPV. Pre Nabors 4ES. R 11A 12/2/2008 T/V0=0/0/0; Killed 4-1 16" CNV "H" BPS/ #144 thru tree for 4ES Decorrpletion; 1-2' ext. used, tagged @ 102"; ***Conplete*** (Best/Fraker) R 11A 12/3/2008 T/V0=0/0/0; Filled 4-1/16" CNV "H" TWC #258 thru stack for 4ES Decompletion; RK6=20.75'; 1-2' + 2- 5' + Centralizer used, tagged @ 84"; ***Complete*** (Best/Fraker) R 11A 12/30/2008 T/VO=Vac/0/350; Pull 4-1/16" CNV "H" BPS/ #279 thru tree Wst 4ES; 1-2' ext. used, tagged @ 96'; ***Complete*** (Best/Fraker) R-11A 12/30/2008 ***WELL S/I ON ARRIVAL*** (post rwo) RAN 3.60" BE1L GUIDE & 2" JDC TO 5,600' SLM, NOT ABLE TO WORK DEEPER (LOOKS LIKE PUSHING SOMETHING DOWNHOLE) DRIFTED W/ 3.80" G-RING & 4.5" BRUSH DOWN TO 9,701' SLM ~RETRIEVm ORANGE COLORm CHUNKS OF RUBBER IN BRUSHI PULLED B&R FROM 9.736' SLM IN THE PROCESS OF RUNNING IN W/ 3.80' GAUGE RING ***CONT. WSR ON 12/31/08*** R-11A 12/30/2008 ***WELL S/I ON ARRVAL*** RAN 3.60" BELL GUIDE & 2" JDC TO 5,600' SLM (DUE TO TOOLS FALLING SLOWLY) DRIFTED W/ 3.80" G-RING & 4.5" BLB DOWN TO 9,701' SLM(RETRIEVm ORANGEISH COLORED CHUNCKS OF RUBBER) FULLED B&R FROM 9,736' SLM IN THE PROCESS OF RUNNING IN W/2.25" P-BAILER ***CONT. WSR ON 12/31/08*** R-11A 12/31/2008 ***CONT WSR FROM 12/31/08*** (post rwo) DRIFTED W/ 3.80" G-RING TO 4.5" RHC aC~ 9.742'_ SLM. _ MAKE SEVERAL RUNS W 3.5" PUMP BAILER W/ 3.62" FINGER BASKET BAILING PEJCES OF RUBBER FROM PKR OFF~P OF RHC (al 9742' SLM CURRENTLY ON SAFETY STAND DOWN ***CONT. WSR ON 01/01/09*** R-11A 1/1/2009 ***CONT. WSR FROM 12/31/08*** (post rwo) RAN 3.5" P-BAILER W/ 3.62" FINGER BASKET TO 9,747' SLM (BAILER EMPTY) MADE SEVERAL RUNS W/ 2.5" P-BAILER W/ 2.5" FINGER BASKET TO 9,747' SLM RETRIEVING PIECES OF RUBBER EACH RUN. DRIFT TUBING WfTH 3.250" CENT AND 2.25" DRIVE DOWN BAILER UNABLE TO PASS 10413' SLM DUE TO DEV VaTION ***WELL LEFT S/I AND NORMALLED. SSV, MV=OFEN. SV, WV=S/I. CSG VLVS OTGS*** Print Date; 1/15/2009 Page 2 of 2 • BP EXPLORATION Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours ~~ Task Code NPT 112/2/2008 107:30 - 14:00 I 6.50 I MOB I P 14:00 - 16:00 2.00 RIGU P 16:00 - 18:00 2.00 RIGU P 18:00 - 18:30 0.50 DHB P 18:30 - 19:30 1.00 DHB P 19:30 - 20:00 0.50 DHB P 20:00 - 11:30 15.50 PULL P 11:30 - 00:00 I 12.501 PULL I P 12/3/2008 100:00 - 01:00 I 1.001 WHSUR 01:00 - 02:30 I 1.501 WHSUR 02:30 - 05:00 2.50 BOPSU 05:00 - 06:00 1.00 BOPSU 06:00 - 10:30 4.50 BOPSU 10:30 - 11:30 I 1.001 WHSUR 11:30 - 13:30 I 2.001 PULL 13:30 - 18:00 ~ 4.50 ~ PULL 18:00 - 19:00 1.00 PULL 19:00 - 20:00 1.00 PULL 20:00 - 00:00 4.00 PULL 12/4/2008 00:00 - 02:30 2.50 PULL P 02:30 - 04:00 ~ 1.50 ~ WHSUR P Start: 11 /30/2008 Rig Release: 12/25/2008 Rig Number: Page 1 of 16 Spud Date: 12/2/1998 End: 12/23/2008 Phase Description of Operations PRE Moved sub carrier, rig pits, pipe shed and camp from M-Pad to R-Pad. Moved rig shop and spotted well over R-11A. Bermed rig and pit module. Spotted tiger tank. PRE Raised and scoped derrick. Accepted rig ~ 16:00 hrs 1 PRE RU fluid lines to pits, tree and tiger tank. Took on hot seawater. DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. DECOMP bricator. Test same to 500. psi. Pull BPV. UD BPV & DECOMP Finish R/U lines to tree & Tiger Tank. Test lines to 3500 psi, OK. DECOMP Open well. SITP = 0 psi, SIAP = 0 psi. Circulate well w/ 120 seawater& displace out freeze protect fluids. Pumped 5.7 BPM C~ 900 psi. total fluid pumped = 706 bbls. No gas or losses. OAP = 0 psi. DECOMP Monitor well. Pressures dropped to 0 psi when pump was shut down. TP = 0 psi. IAP = 0 psi. Well Dead. DECOMP P/U Tee Bar & install TWC. Pressure test TWC from below wl_ 1000 si for 10 min. Test from above to 4000 si for 10 min. Charted testing. DECOMP Bleed hanger void. N/D tree & adapter flange. Inspect hanger threads.. threads badly galled. Will use spear to pull hanger.. DECOMP N/U BOPE. DECOMP M/U test jts. Fill BOP stack. Prep to test BOP. DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Tested BOPE to 250 psi low / 4000 psi high per BP policy and AOGCC regulations. Tested annular to 250 psi / 3500 psi. Tested VBR with 3-1/2" and 4-1/2" test joints. Tested annular with 3-1/2" test joint. Test witnessed by Toolpusher and WSL. BOPE test witness waived by J. Crisp, AOGCC at 06:00 hrs 12/3/2008. RD test equipment. DECOMP RU DSM lubricator and tested to 500 psi. Pulled TWC and LD DECOMP MU landing joint and tubing spear. RIH and engaged grapple. BOLDS. Pulled tubing hanger free with 115k Ib PU. Continued pulling tubing hanger to rig floor. Disengaged and LD spear and landing joint. LD tubing hanger. DECOMP Held PJSM. Monitored well; fluid levels static and no gas bubbling. „eOH and LD 4-1/2" NSCT completion. Installed thread protectors on pins. 93 jts LD at 16:00 hrs. DECOMP Crew Change. Service rig. Check PVT alarms. Inspect derrick. DECOMP Break out jt # 94. Power tongs egging tubing. Change out to wrap around slips. Waited 45 min for slips to brought out from Csg Shop. Installed & test new slips, OK. DECOMP Con't to POOH & UD 4 1/2" 12.6#, L-80, NSCT completion. Out of hole w/ 186 jts. DECOMP Con't to POOH & UD 4 1/2" 12.6#, L-80, NSCT completion. Recovered total of 243 jts + 1 - 20.31' cut off jt. Cut was out of .See Photos. DECOMP R/D completion handling tools. R/U tools to P/U BHA. P/U running tool. Install Wear Bushing RILDs. VD running tool. Printed: 1/5/2009 11:17:26 AM • BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: R-11 A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date ', From - To Hours Task ;Code NPT Phase II Description of Operations 12/4/2008 04:00 - 05:00 1.00 PULL P DECOMP Clear & clean rig floor. 05:00 - 06:00 1.00 FISH P DECOMP P/U & M/U BHA #1 to mill acker as follows: Mill shoe, 2 jts wWash Pipe, W/O Boot Basket, XO, 2 Boot Baskets, XO, Bumper Sub, Jars, XO, 9 - 6 1/4" DCs, XO, XO. 06:00 - 09:30 3.50 FISH P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued MU packer mill BHA #1. 09:30 - 16:00 6.50 FISH P DECOMP RIH with packer mill BHA #1, PU 3-1/2" DP. RIH w/ 301 full jts Tagged up on packer 3' in it # 302. 9800'. DPM. 16:00 - 18:00 2.00 FISH P DECOMP UD Jt # 302. P/U 24' DP pup & kelly. Begin milling packer 9' in on kelly. Milled from 9800 to 9801'. 18:00 - 18:30 0.50 FISH P DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. 18:30 - 22:30 4.00 FISH P DECOMP Con't to mill packer from 9801' to 9803.5'.-Packer move down hole 2'. Tailpipe on liner recepticle. Verify w/ by stacking 15K on liner Recept. P/U Wt = 160K, S/O Wt = 130K. Rot Wt = 144K. Pump 5 BPM ~ 900 psi. Free Torq = 3K Ft-Ibs. Rot Torq = 3K - 9K. 60-80 RPMs. WOB 3K - 15K. 22:30 - 00:00 1.50 FISH P DECOMP Mix & pump 40 bbl Hi-Vis sweep. 5.5 BPM ~ 995 psi. 12/5/2008 00:00 - 02:00 2.00 FISH P DECOMP Con't to circulate 40 bbl Hi-Vis sweep around. Pump 5.5 BPM ~ 995 psi. Pumped total of 675 bbls. No Gas circulated to surface. Recovered Smoo on shaker screens w/ occasional millin s. No losses noted Burin circulation. Set Back & blow down kelly. 02:00 - 06:00 4.00 FISH P DECOMP UD DP pup 1 single. POOH & stand back 100 stands of 3 1/2" DP. 06:00 - 09:00 3.00 FISH P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued POH with packer mill BHA #1, standing back 3-1/2" DP. LD packer mill BHA #1. 09:00 - 10:00 1.00 FISH P DECOMP Cleared junk baskets and cleaned rig floor. Recovered about 5 gal scale, metal shavings, and heavy hydrocarbon liquids. 10:00 - 12:00 2.00 FISH P DECOMP Held PJSM. PU and MU spear BHA #2: cut lip guide, Bowen SHLD spear, wash pipe ext, boot basket, bumper jar, oil jar, 9 x DC, jar intensifier, POS. 12:00 - 16:00 4.00 FISH P DECOMP RIH with spear BHA #2 on 100 stnds 3-1/2" DP. PU 2 singles, 24' DP pup, and kelly. 16:00 - 16:30 0.50 FISH P DECOMP Established parameters: PU/SO/Rot 160k/130k/142k; 3 bpm, 415 psi; 21 rpm, 150 a, 3000 Ib-ft. Tagged fish at 9741'. SO 15k Ib, then PU total of 185k Ib, indicating fish engaged 16:30 - 18:00 1.50 FISH P DECOMP LD 24' DP pup and 2 singles. POH with spear BHA #2 and packer fish, standing back 3-1/2" DP. 18:00 - 19:00 1.00 FISH P DECOMP Crew change, New crew w/ 2 new hands to Rig 4es. Service rig. Inspect derrick. Check PVT alarms. 19:00 - 22:30 3.50 FISH P DECOMP Con't to POOH w/ fish. Had drag of up to 35K. Stand back 99 stands of 3 1/2" DP. 22:30 - 00:00 1.50 FISH P DECOMP UD 2 single. Stand back 3 stands of 6 1/4" DCs. Break out & UD BHA. 12/6/2008 00:00 - 00:30 0.50 FISH P DECOMP Finish breakino out BHA. No recovery. Lost fish in hole 00:30 - 01:30 1.00 FISH P DECOMP Empty WP Boot Basket. Had -2 gals of Smoo w/ several pieces of packer junk. Notified town engineer. Plan to run S ear extension w/ double ra le. Reviewed Totco log. Had 34K overpull w/ 22 stands left to pull & 28K overpull w/ 10 stands to pull. Broke out Wash Pipe & inspected spear, spear was in release position & pin sheared. 01:30 - 02:30 1.00 FISH P DECOMP Wait on fishing tools. Clear & clean rig floor. Printed: 1/5/2009 11:17:26 AM • BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date 'From - To Hours Task Code'.. NPT Phase Description of Operations ~_ _ _ - 12/6/2008 102:30 - 04:00 1.50 ~ FISH P DECOMP P/U & M/U BHA # 3 to fish cut off 't & acker ass .Same as 04:00 - 06:00 2.00 FISH P 06:00 - 08:30 2.50 FISH P 08:30 - 10:00 1.50 FISH P 14:30 - 16:30 2.00 FISH I P 16:30 - 18:00 1.50 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 00:00 5.50 CASE P 20:00 - 00:00 4.00 CASE P 12/7/2008 00:00 - 01:00 1.00 CASE P 01:00 - 01:30 0.50 CASE P 01:30 - 04:00 I 2.501 CASE I P 04:00 - 05:00 1.00 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 09:00 3.00 CASE P 09:00 - 13:00 4.00 CASE P 13:00 - 16:30 3.50 CASE P 16:30 - 18:00 1.50 CASE P 18:00 - 18:30 0.50 CASE P 18:30 - 20:00 1.50 EVAL P 20:00 - 22:30 2.50 EVAL P 22:30 - 23:30 1.00 EVAL P 23:30 - 00:00 0.50 EVAL P 12/8/2008 00:00 - 00:30 0.50 CASE P Spear Assy #2 except running a double grapple &~Wash Pipe Extension. TL = 329.46'. DECOMP RIH w/ BHA #3 on stands of 3 1/2" DP.to fish packer & tailpipe assy. DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued RIH with spear BHA #3 (2nd spear run) on 3-1/2" DP. DECOMP Tagged fish at 9752' DPM. MU kelly. Established parameters: PU/SO 158k/131 k. Engaged fish and PU 20k over string weight. DECOMP POH with BHA #3, standing back 3-1/2" DP. Recovered fish. DECOMP LD spear BHA #3 and fish. Recovered 96.48', entire milled packer and tailpipe assy. DECOMP Cleared and cleaned rig floor. DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. TIEB1 P U BHA #4 as follows: Polish Mill, XO, XO, Csg Scraper, XO, Bumper Sub, XO, 9 -DCs, XO, XO, Pump Out Sub. TL = 309.79'. TIE61 RIH w/ BHA #4 on 99 stands of 3 1/2" DP & scope casing. TIE61 P/U 9 singles & taa uo C~ 9835' L/D 2 jts. P/U 24' DP pup & kelly. Break circulation. Scraoed casino to 9819'. TIEB1 Re-tag ~ 9836'. Polish & dress liner recepticle. TOL ~ 9830' DPM. Bottom of mill ~ 9836'. Recepticle spec shows 7.6' length. P/U Wt = 158K, S/O Wt = 130K, Rot Wt = 145K. 60-95 RPMs Pumped 4.5 BPM ~ 860 psi. WOB = 3-4K. Free Torq = 3500 Ft-Ibs, Rot Torq = 3500 - 4500 ft-Ibs. TIEB1 P/U out of liner & reverse well clean. Pump 40 bbl Hi-Vis sweep. 6 BPM ~ 1590 psi. Pump total of 680 bbls. Blow down & Set back kelly. TIEB1 R/U & dum 700# of 20-40 sand d & chase w/ 54 bbls. Allow sand to fall. TIE61 Allow sand to settle. Hold weekly safety meeting with night rig crew. TIEB1 Held crew change and performed pre-tour checks of PVT equipment and derrick. RIH and tagged sand at 9834' with polish mill. Reverse circulated 4 bpm, 660 psi. SO and no- o'd olish mill t ' D Reversed until clean, had about 2 gal sand in returns. TIEB1 Held PJSM. S&C drill line. Replaced dead man. TIEB1 li h mill BHA #4 standing back 3-1/2" DP. TIEB1 Stand back 3 stands of 6 1/4" DCs. Break out & L/D BHA. Inspect Polish mill. Good indication of liner top impression on mill. TIEBi Crew change. Service rig. Inspect derrick. Check PVT alarms. TIEBi Hold PJSM w/ 3rd party loggers. R/U to run USIT. TIEB1 Run USIT from 3000' to surface. Located To of cement ~ 2030'. Confirmed cut depth w/ town engineer ~ +/- 1980'. (1st collar above cement top ~ 2003') TIEB1 Hold PJSM w/ 3rd party loggers. R/D logging equip. TIEBi Clear & clean rig floor. Load RBP in shed. TIE61 Finish cleaning up floor. Load RBP into pipe shed & warm up same. Printed: 1/5/2009 11:17:26 AM BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: R-11 A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task I' Code': NPT Phase Description of Operations 12/8/2008 00:30 - 01:30 1.00 CASE P TIEB1 RIH on 3 stands of 6 1/4" DCs. 01:30 - 03:00 1.50 CASE P TIE61 RIH w/ RBP on 19 stands of 3 1/2" DP. Had to L/D 2 jts of DP w/ swelled boxes. Space out RBP. Casing collars ~ 2084' & 2123'. 03:00 - 04:00 1.00 CASE P TIE61 Set RBP w/ 20K S/O wt. Over pull to 10K. P/U & verify plug is set. Center of element ~ 2091'. Top of fishing neck ~ 2086'. P/U Wt & S/O wt = 56K. Close annular. Pressure test plug to 1000 si for 10 min 04:00 - 05:00 1.00 CASE P TIE61 Pull 1 stand & R/U to dump sand. Dump 2200# of 20-40 sand d w DP. Chase w/ 1 DP volume. 05:00 - 06:00 1.00 CASE P TIE61 Wait & Allow sand to fall. RIH to tag sand top. 06:00 - 06:45 0.75 CASE P TIEB1 Held crew change and performed pre-tour checks of PVT system and derrick. RIH and tagged sand at 2036'. _ 06:45 - 08:30 1.75 CASE P TIEB1 POH with RBP settin tool, standing back 3-1/2" DP. LD RBP setting tool. 08:30 - 10:00 1.50 BOPSU P TIEBi Cleared floor, pulled wear ring, set test plug. RU BOPS test equipment. 10:00 - 15:00 5.00 BOPSU P TIEB1 Tested BOPE to 250 psi low / 4000 psi high per BP policy and AOGCC regulations. Tested annular to 250 psi / 3500 psi. Tested VBR and annular with 3-1/2" test joint. BOPE test witnessed by WSL and Toolpusher. BOPE test witness waived by J. Crisp, AOGCC at 08:15 hrs, 12/8/2008. 15:00 - 16:00 1.00 BOPSU P TIEB1 RD BOPE test equipment. Pulled test plug. Installed wear bushing. 16:00 - 17:00 1.00 CASE P TIEBi PU and MU casing cutter BHA #5_ 8-1/4" MS cutter, XO, stabilizer, XO, 9 x DC, 2 x XO. 17:00 - 18:00 1.00 CASE P TIE61 RIH w/ BHA #5 to cut 9 5/8" casing. 18:00 - 18:30 0.50 CASE P TIEB1 Crew Change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 CASE P TIE61 Finish RIH w/ BHA #5 on 18 stands of 3 1/2" DP. 19:00 - 19:30 0.50 CASE P TIEB1 Locate collars & space out cutter to cut 9 5/8" casing. Found Cotlars ~ 1970' & 2010'. Plan to cut casino ~ 1987'. 19:30 - 21:00 1.50 CASE P TIEB1 P/U kelly, R/U test equip. & pressure test lower Kelly Valve. LP 250 psi. HP 4000 psi, Tested OK. Charted same. R/D test equip. 21:00 - 23:00 2.00 CASE P TIEB1 Hold PJSM & review cutting & circulating procedure. Assign personnel to specific tasks & stations to monitor returns & watch cellar. Spot in equip & check all lines for integrity & be sure no lines are frozen. 23:00 - 00:00 1.00 CASE P TIEB1 Space out kelly 27.5' in & cut 9 5/8" casing ~ 1987'. Indication of cut after 8 min. Con't to rotate, rotary stalled, pipe appears to be in com ression.-Free rotary & continue to rotate to insure cut for total of 30 min. P/U & pulled tight. Cut strings are mis-ali ned. Pull 110K over (170K) & cutter came free. P/U & S/O Wts = 59K. Pumped 3 BPM & increased to 46PM ~ 470 psi, Free Torque = 1800 ft-Ibs. Max Torq = 10K Ft-Ibs. 65 RPMS.Saw pressure drop when cut. no real losses noted. 12/9/2008 00:00 - 05:00 5.00 CASE P TIEB1 Blow down & set back kelly. P/U 24' DP pup & install circulating head. Establish circulation thru cut & out OA. Pumped 1 BPM C~ 120 psi. Displace out Arctic PAC out OA & into open too tank. Pump 50 bbls of 140 degree Diesel & spot w/ 15 bbls of 9.8 ppg Brine in OA. Pumped 2 BPM ~ 950 psi. S/D & allow to soak for 30+ min. Displace diesel w/ 120 bbls of 120 degree Printed: 1/5/2009 11:17:26 AM • BP EXPLORATION Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date 'From - To Hours Task ', Code,~i~ NPT 12/9/2008 100:00 - 05:00 5.00 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 12:00 6.00 CASE P 12:00 - 12:30 0.50 CASE P 12:30 - 15:00 2.50 CASE P 15:00 - 20:00 5.00 CASE P 20:00 - 20:30 0.50 CASE P 20:30 - 00:00 3.50 CASE P 12/10/2008 00:00 - 02:00 2.00 CASE P 02:00 - 04:00 I 2.001 CASE I P Start: 11 /30/2008 Rig Release: 12/25/2008 Rig Number: Phase TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 Page 5 of 16 Spud Date: 12/2/1998 End: 12/23/2008 Description of Operations 9.8 ppg Brine. Pumped 3 BPM ~ 600 psi. S/D & allow to soak for 30+ min. Displace OA w/ 365 bbls of 120 degree 9.8ppg Brine. Pump 5 BPM C~ 1750 psi, Had to slow to 4.5 BPM ~ 1700 psi. Displace 9.8 ppg Brine w/ 135 bbls of seawater until return fluid was 8.5 ppg. During circulation had communication to. nnductor Rio .Very small amount of returns to cellar. Had Vac truck sucking up any returns to cellar. R/D circulating equip. UD 24' DP pup. POOH w/ BHA #5. Held crew change and performed pre-tour checks of PVT equipment and derrick. POH with casing cutter BHA #5. LD cutter ass'y. Casing cutter intact. Several Metal Muncher buttons missing from cutter knife bodies. Cutter knife bodies not broken. PUMU 9-5/8" Itco spear. Engaged 9-5/8" casing with spear. Cameron wellhead tech. BOLDS. Unlanded 9-5/8" casing with 110K pick up weight. Pulled hanger and packoff to floor Disengaged spear and layed down same. TIE61 POH laying 9-5/8" casing down 1 x 1 through pipe shed. Pipe condition is good. Considerable amount of arctic pack adhered to pipe. Cleaning off arctic pack as pipe is pulled. Pipe hanging up on every joint and having to work pipe through tight spot. Collars are hanging up in stack. Re-center BOP stack. TIE61 Crew change. -Late change out due to weather, Phase II in effect. service rig. Inspect derrick. Check PVT alarms. TIEB1 Circulate well to remove Arctic Pac. Con't to break out & UD single Jts of 9 5/8" casing. connections breaking ~ 8-10K ft-Ibs of torque. Gusting winds making & string of Arctic Pac off jts making UD go slowly. Pulled & UD 37 jts. TIEB1 Con't to POOH & UD 9 5/8" casing. Wiping Arctic Pac "skin" off every jt. Occasionally having to hammer connections to break free. Gusting winds slowing operation. Recovered total of 48 jts + 1 cut off jt, 17.18'. Overall condition of casina was ood. Cut I . 2 s lit , 1-9" & the other 12". Bottom was ve ra ed & belled out to 11. ". See photos. TIEB1 R/D casing tools & false Bowl. Clear & clean rig floor. R/U to P/U BHA. 04:00 - 06:00 2.00 FISH P T IEB1 P/U & M/U BHA #6 to dress 9 5/8" casin stub as follows: Dress off Shoe, W/P Ext, Dressing Mill, W/P Boot Basket, XO, Scraper, XO, Bumper Sub, XO, 9 - 6 1/4" DCs, XO. TL = 304.94'. 06:00 - 06:30 0.50 FISH P T IEB1 Crew change pre-tour meeting. Service rig -grease crown, blocks and drawworks, check PVT's, daily derrick inspection and environmental walkaround. 06:30 - 10:30 4.00 FISH P T IE61 RIH w/BHA #6 on 3-1/2" 15.5# drill pipe from derrick. Stopped every 5 stands and CBU. No arctic pack in returns. Lost 50-Bbls. while RIH and B 10:30 - 12:30 2.00 FISH P T IEB1 Ta to of 9-5/8" casin t a 1 '. Kelly up, break circulation and establish milling parameters: PUW = 60K, SOW = 60K, 65 RPM at -2500-8500 ft/Ibs. torque and circulating at 3-4 BPM. Losses = 24-bph. Slight flowback from conductor pipe into cell. vacuuming out cellar with trash pump. Ordered out vac truck with 290-Bbls. 120E seawater for Printed: 1/5/2009 11:17:26 AM BP EXPLORATION Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date. From - To ~ Hours I Task Code NPT 12/10/2008 10:30 - 12:30 2.00 FISH P 12:30 - 14:00 1.501 FISH P 14:00 - 14:30 ~ 0.50 ~ FISH ~ P 14:30 - 17:00 2.50 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 19:30 1.00 FISH P 19:30 - 00:00 I 4.501 FISH I P 12/11/2008 00:00 - 01:30 1.50 FISH P 01:30 - 03:00 1.50 FISH P 03:00 - 04:30 I 1.501 FISH I P 04:30 - 06:00 1.50 FISH P 06:00 - 08:00 2.00 FISH P 08:00 - 09:00 1.00 FISH P 09:00 - 11:30 2.50 FISH P 11:30 - 12:30 1.00 FISH P 12:30 - 14:00 1.50 FISH P Start: 11 /30/2008 Rig Release: 12/25/2008 Rig Number: Page 6 of 16 ~ Spud Date: 12/2/1998 End: 12/23/2008 Phase Description of Operations TIEB1 TIE61 TIEB1 TIEB1 TIEB1 TIE61 TIEBi TIE61 TIE61 TIEB1 TIEB1 TI EB 1 TIEB1 pits. Milled 2.5' and could not get washover shoe over stub. Discussed with RWO engineer and agreed to POH and look at milling assembly. Set back and blow down kelly. POH standing 3-1/2" 15.5#/ft. "E" grade DP in derrick. Inspect dress-off shoe and wear pattern indicated that mill shoes was slicing casing stub in stead of swallowing it, No wear visible on pilot mill or dress-off mill. Casing scraper is in good condition. Lay BHA down. PUMU BHA #7: 4-1/2" bull nose, 8-1/4" swage, XO, 8-1/4" Multi-String Cutter 8-1/2" stabilizer, XO, 9 - 6-1/4" collars and XO = 292.38'. RIH w/ BHA #7 on 18 stands of 3 1/2" DP. Crew change. Srvice rig. Inspect derrick. Check PVT alarms. P/U 24' DP pup & kelly. Enter top of cut ~ 1988'. took 8K to go thru stub w/ stabilizer. Break circulation w/ 2.5 BPM ~ 200 psi. Locate collar ~ 2010'. P/U 14' to make cut ~ 14AFi'. Cut casing ~ 1996'. Pump 2.5 BPM & rotate ~ 60 RPMs After 3 min increase rrate to 3.5 BPM ~ 350 psi. After 3 min, had good indication of cut, drop in pump pressure to 220 psi & Loss of torq. Con't to rotate additional 10 min. P/U & S/O Wt = 60K. Rot Wt = 60K. Free torq = 1000 ft-Ibs. Rot Torq = 2500 Ft-Ibs. P/U, then S/O to string took wt. to insure good cut. Mix & pump 40 bbl Safe-Surf-O sweep. Spot sweep w1 15 bbls. Pump 1 BPM ~ 30 psi. Losses ave. 3 bbls/5 min. Increase rate to 1.5 BPM Q 70 psi. Ave losses 4 bbl/5 min. Sweep hole w/ seawater 6 BPM @ 890 psi. Got back a few chunks of Arctic Pac. Pump total of 638 bbls. Lost 197 bbls. Blow down & set back kelly. POOH & stand back 18 stands of 3 1/2" DP. Set back 3 stands of 6 1/4" DCs. Break out & UD BHA # 7. Recoverd fish fish was stuck on stabilizer. (egged). Fish was 7.6' long Had good clean re-cut end. Old cut end was egged & had 2 splits (~3"-8") on opposite sides w/ rragged cut. (see Photos). Clean rig floor. I,U & M/U BHA #8 to dress csa stub. (same as BHA #6) TL = 304.94 RIH w/ BHA #8 on 18 stands of 3 1/2" DP. Tag top of 9-5/8" casing stub at 1997'. Kelly up and establish parameters: 60K P/U wt., 58K S/O wt., RPM = 65, Atte_ mpt to after several attempts and with varied parameters. Unable to get over stub. TIEB1 Break out and la down BHA #8. Clear and clean rig floor. TIEB1 PJSM -reviewed making up BHA. PUMU BHA #8 as follows: 11-3/4" x 10.75" washover shoe, 11-3/4" washpipe ext., 10 x 8-9/16" dressing mill, 11-3/4" washover boot basket, double pin sub, XO, 6-1/4" LBS, XO, 9 - 6-1/4" drill collars and XO = 300.90' TIE61 RIH w/BHA #9 on 3-1/2" 15.5#, Grade "E" DP from derrick. RiH w/18 stands and kelly up. TIEB1 Establish milling parameters: 64K P/U wt., 62K S/O wt., RPM = 65, ROt wt. = 62K. Break circulation at 2.0-bpm. Tag 9-5/8" Printed: 1/5/2009 11:17:26 AM BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code I NPT Phase I Description of Operations 12/11/2008 12:30 - 14:00 1.50 FISH P TIEB1 casing stub at 1996'. Commence milling to dress off stub. Dressed off -0.6' of stub. Pulled washover shoe off stub and rotated back over stub with no resistance. Pulled off stub and then slid over stub without rotating with no resistance and tagged at same place. New top of casing stub is 1997'.. 14:00 - 16:00 2.00 FISH P TIEB1 POH w/BHA #9 and lay down same. Break out washover shoe and washpipe ext. from dress off assy. Inspect dress off milt and pilot mill for correct wear pattern indicating successfull dress-off. 16:00 - 18:00 2.00 FISH P TIE61 PUMU BHA #10 as follows: Overshot, XO, XO, Bumper Sub, XO, 9 - 6 1/4" DCs, XO. TL = 291.97'. 18:00 - 19:00 1.00 FISH P TIEB1 RIH w/ BHA #10 on 18 stands of 3 1/2" DP. P/U 10' 3 1/2" DP Pup. 19:00 - 20:00 1.00 FISH P TIEB1 Hold 1 hr Safety Stand Down. Review latest incident on Rig 2 ES. Discuss hand safety. "Control of Work", communication, supervision, verification of competency, know hazards, & focus on safety compliance. 20:00 - 21:00 1.00 FISH P TIE61 P/U kelly. Break circulation & engage casing stub (no problems). P/U & verify engagement. Pull test overshot & casin to 200 . S/O & attem t to test casin overshot ack off to 2000 si for 10 min. No Test. Pressure bleed of -900 psi in 10 min. Charted test. Rotate & disengage overshot from casing stub. P/U, Blow down Kefly & UD 10' pup. P/U & S/O Wt = 60K. 21:00 - 22:00 1.00 FISH P TIEB1 POOH & stand back 18 stands of 3 1/2" DP. 22:00 - 23:30 1.50 FISH P TIEB1 Break out & UD BHA #10. 23:30 - 00:00 0.50 FISH P TIEB1 Clear & clean rig floor. 12/12/2008 00:00 - 00:30 0.50 FISH P TIE61 Crew Change. Service rig. Check PVT alarms. Inspect derrick. 00:30 - 01:30 1.00 FISH P TIEBi Hold Safety stand down w/ evening tour. Review recent incident on Rig 2ES. Discuss hand safety, "Control of Work, Communication, Supervision, competency verification & known hazards. 01:30 - 02:30 1.00 FISH P TIEB1 P/U & M/U 13 3/8" RTTS to test casin shoe &RBP. RIH on 3 stands of 6 1/4" DCs. 02:30 - 03:30 1.00 FISH P TIEB1 RIH w/ RTTS on 18 stands of 3 1/2" DP. 03:30 - 04:00 0.50 FISH P TIEB1 P/U 1 DP single & space out RTTS. Center of element ~ 1990'. Bottom of Pkr '. Set RTTS w/ 20K down weight. P/U & S/O Wt = 55K. 04:00 - 05:00 1.00 FISH P TIE61 R/U lines & test equip. Pressure test Casing shoe &RBP to 1000 psi for 30 min. Tested Good. Charted test. Unset & equalized RTTS. 05`00 - 07:00 2.00 FISH P TIEB1 POOH w/ RTTS & stand back 18 stands of 3 1/2" DP. 07:00 - 08:30 1.50 WHSUR P TIE61 PJSM -Reviewed plan forward to identify hazards and initiated confined space entry and hot work permits. Adjust BOP stack to center 13-3/8" surface casin in 20" conductor. Install 4 steel wedges equidistant around circumference of 13-3/8" surface casing to centralize it in the 20" conductor. Shovel out gravel and debris and clean lined cellar. 08:30 - 09:30 1.00 BOPSU P TIE61 PJSM -Reviewed nipple down BOP procedure. Nipple down BOP and set back on slum . 09:30 - 12:00 2.50 WHSUR P TIE61 Nipple down tubing spool and remove from cellar area. Assist Cameron wellhead tech. to rig up Wachs casing cutter. Cut 13-3/8" casing 5" above top of 20" conductor. Removed casing Printed: 1/5/2009 11:17:26 AM • BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: R-11A Common W ell Name: R-11A Spud Date: 12/2/1998 Event Nam e: WORKOVER Start : 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALAS KA DRI LLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours ~ Task Code ~ NPT I Phase Description of Operations - _ _ ___- 12/12/2008 09:30 - 12:00 2.50 WHSUR P TIE61 - head from cellar area. 12:00 - 13:00 1.00 CASE P TIEB1 Crew change and pre-tour meeting. Check PVT's, derrick inspection, service rig and enviro walkaround. 13:00 - 15:30 2.50 CASE P TIEB1 Rig up 9-5/8" casing handling tools on rig floor. 15:30 - 16:00 0.50 CASE P TIEB1 PJSM -Review running casing procedure with all crew. 16:00 - 21:00 5.00 CASE P TIEB1 RIH w/9-5/8" Bowen casing patch assV. 9-5/8" Baker ECP ancL Halco 9-5/8" ES Cementer. Made up BTC-M connections to the mark and Baker-Lok'd all connections below ES Cementer. Continued RIH w/9-5/8" 47# L-80 H dril 563 casing torque turning connections to 15,200 ft.-Ibs. RIH w/ 35 jts. 21:00 - 21:30 0.50 CASE P TIE61 Crew change. Service rig. Inspect derrick. Check PVT alarms. 21:30 - 23:00 1.50 CASE P TIEB1 Con't to RIG w/ 9 5/8" 47#, L-80, HYD-563 BTC casing. torque Turn all connections to 15200 ft-Ibs. Use Jet Lube Seal Guard thread compound on all connections. Ran total of 49 jts. + 1 - 9.8' Pup. Applied one free floating centralizer per joint, includin t 't. 23:00 - 23:30 0.50 CASE P TIE61 Slowl RIH ~ to to of casin stub ~ 1997'. Rotate Pipe 1/2 turn & slide over stub. Swallow 3' & bottom out w/ casing patch overshot. S/O 25K, P/U 25K overpull, S/O 50K, then P/U & pull test casing tie-back to 250K. S/O to string wt ~ 95K. S/O & P/U Wts = 95K. Holding 95K string weight static during cement 'ob. 23:30 - 00:00 0.50 CASE P TIE61 R/D Torque Turn equip. Begin clearing floor. 12/13/2008 00:00 - 00:30 0.50 CASE P TIEB1 R/D false bowl & remaing casing tools. Clear & clean rig floor. 00:30 - 01:30 1.00 CASE P TIEB1 Load cementing plug & R/U cementing head, R/U circulating & test lines. Level up 9 5/8" casing in side of 13 3/8" casing. 01:30 - 03:00 1.50 CASE P TIE61 Pressure up & test casing for 10 min., increase ressure in 200# increments to 1800 si to full set ECP. Held each t for _ 5 min. Continue to ressure to to 2000 psi & test casing for 30 min. Bleed off pressure & re-aressure ~ 3 BPM to 2900 si & ES Cementer sheared out & opened. 03:00 - 04:30 1.50 CASE P TIEBi Circulate well & pump 1 casing volume. Take returns into cellar. R/U cementers & spot in Vac trucks for cellar returns & mix water for cement job. Have 85 degree returns. 04:30 - 06:00 1.50 CASE P TIE61 Prep to cement. W/O crew change. 06:00 - 08:30 2.50 CASE P TIEB1 W/O Schlumberger crew change. 08:30 - 09:00 0.50 CASE P TIEB1 PJSM -All Nabors, CH2MHill, Baker, Halliburton and Schlumberger personnel. Reviewed cementing procedure and hazards associated with task. Assigned personnel to specific tasks and discussed hazards of individual tasks. Reviewed CoW standard and expectations regarding any scope changes. Made 24-hrs. notification to AOGCC -Chuck Sheve of impending BOPE test. 09:00 - 11:00 2.00 CEMT P TIE61 All personnel assumed assigned positions. Blew air through seawater source line to cementer. Pump 5-Bbls. seawater through cementing line to rig floor. PR lines: Low pressure stall at 800-psi. Check lines for leaks - no leaks. High pressure test to 4500-psi. Check lines for leaks - no leaks and good pressure test. Batch up cement to 15.8-ppg. Start um in 1st sta a of 4 - I 15.8-ppg Class "G" cement with gas-blok and 1/4 Ib./bbl. celloflake at 2-6 bpm at 200-285 psi. Switched to 2nd stage of 15.8-ppg Class "G" cement with gas-blok and pumped 125-Bbls. away at 2-6 bpm at 200-300 Printed: 1/5/2009 11:17:26 AM BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11 A Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To Hours ~ Task Code NPT 12/13/2008 109:00 - 11:00 2.00 ~ CEMT I P 11:00 - 18:00 7.00 CEMT P 18:00 - 18:30 0.50 CEMT P 18:30 - 22:00 3.50 CEMT P 22:00 - 23:00 1.00 CEMT P 23:00 - 00:00 I 1.001 CEMT I P Start: 11 /30/2008 Rig Release: 12/25/2008 Rig Number: Spud Date: 12/2/1998 End: 12/23/2008 Phase ', Description of Operations TIEB1 TIE61 TIE61 TIEB1 TIEB1 TIE61 12/14/2008 100:00 - 02:00 I 2.001 CEMT I P I ITIEBI 02:00 - 03:00 I 1.001 CEMT I P I ITIEBI 03:00 - 04:30 1.50 CEMT P TIE61 04:30 - 05:30 1.00 WHSUR P TIEB1 05:30 - 06:00 I 0.501 WHSUR P TIE61 06:00 - 06:30 I 0.501 WHSUR I P I ITIE61 06:30 - 12:00 I 5.501 WHSUR I P I ITIEBI 12:00 - 14:30 2.50 BOPSU P TIEB1 14:30 - 18:00 3.50 BOPSU P TIEB1 18:00 - 18:30 0.50 BOPSU P TIEB1 18:30 - 19:30 1.00 BOPSU P TIEBi 19:30 - 22:00 2.50 BOPSU P TIEB1 22:00-00:00 I 2.OOIBOPSUFiP I ITIEBI 12/15/2008 100:00-01:00 I 1.OOIBOPSURP I ITIE61 01:00 - 02:00 I 1.001 BOPSURP I ITIEBI psi. Shut down pumping and dispatched wiper plug. Wiper plug away and displaced cement to 9-5/8" annulus at 2-7 bpm. At 104-bbls. displacement away had NEAT cement returns to- surface. Continued displacement at 2-7 bpm at 300-900 psi. Bumped plug at 144.5-Bbls. displacement. Pressured up to -1800-psi and closed ES cementer. Increased pressure to 2300-psi and held for two minutes. Bled off pressure and observed no flow back into 9-5/8" casino. Took returns to well cellar during entire job. Cement in place at 10:40-hrs. Washed out well cellar with fresh water and vac'd out. Waiting on cement to reach 500-psi UCA. Lab test indicates that cement will reach 500-psi UCA at 80 degrees F at 11 hrs. - 46 minutes after cement is in place. RDMO Schlumberger cementers and CH2MHill vac trucks. Cement settled out of sight in the 13-3/8" x 9-5/8" annulus. Atop iob is planned.. Crew Change. Service rig. Check PVT alarms. Inspect derrick. Wait on cement. Rig cementing equip for top job. Spot in vac truck. Hold PJSM w/ all hands & review top job procedure. Assign tasks & make final check on equip. Perform top job cementing operation. Mixed & pumped 6 bbls of Arctic-Set 1 D-816 topped in w/ 6 bbls & had -3 bbls of returns. Had good thick cement to surface. Pulled stinger & cement reamined topped off to surface.,S/D & cleaned cellar. Annulus remained full. Wait on cement. Annulus remaining full. R/D cementing equip. clean rig & perform maintenance. Hold Weekly safety meeting. Discussed recent incidents & safety bullitins. Discuss personnel responsibility & crew safety performance goals. Wait on cement. SWS e-mailed UCA for top job 480 psi. ~ 03:50. Remove 9 5/8" casing X-overs. Cut jt. length = 18.53'. R/U & prep to cut 9 5/8" casing. Pre-tour meeting and crew change. Reviewed cutting casing procedure. Daily derrick inspection, check PVT's, service rig and enviro walkaround. Complete casing cutting operations. Rig down Wachs casing cutter and tools. Install Cameron S-3 9-5/8" x 11" 5M "Slip-Lock" wellhead and make up to specified torques. Nipple up BOPE. Replace Hydril 13-5/8" "GX" annular preventer element. Crew change. Service rig. Inspect derrick. Check PVT alarms. Finish annular element replacement. Tighten up annular cap. Install choke & kill lines. service mud cross. N/U flow nipple & riser. R/U test equip to test ROPE. Break in new annular element by cycling on test jt. Attempting to test ROPE. Test plug leaking. Attempt to RIH & tighten LDS. No Good. Wait on new test plug. Pull existing test plug. Load, drift & tally Printed: 1/5/2009 11:17:26 AM • BP EXPLORATION Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Dat~ From - To Hours j Task i Code NPT ~__ I 12/15/2008 01:00 - 02:00 1.00 BOPSU P 02:00 - 02:30 0.50 BOPSU P 02:30 - 10:00 7.50 BOPSU P 10:00 - 11:00 1.00 CEMT P 11:00 - 11:45 ~ 0.75 ~ CEMT ~ P 11:45 - 12:30 0.75 CEMT P 12:30 - 14:30 2.00 CEMT P 14:30 - 18:30 4.00 CEMT P 18:30 - 00:00 5.50 CEMT N 12/16/2008 00:00 - 02:00 2.00 CEMT N 02:00 - 03:30 1.50 CEMT N 03:30 - 04:30 I 1.001 CEMT I P 04:30 - 06:30 I 2.001 CEMT I P 06:30 - 08:30 I 2.001 CEMT I P 08:30 - 09:00 ~ 0.50 ~ CEMT ~ P 09:00 - 09:30 0.50 CEMT P 09:30 - 11:30 2.00 CEMT P 11:30 - 12:30 1.00 CEMT P 12:30 - 15:30 3.00 CEMT P Start: 11 /30/2008 Rig Release: 12/25/2008 Rig Number: Page 10 of 16 ~ Spud Date: 12/2/1998 End: 12/23/2008 Phase... i Description of Operations TIEB1 TIEB1 TIE61 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TI EB 1 TIEB1 TIE61 TIE61 TIEB1 TIEBi TIEB1 TIEB1 TIE61 TIEB1 TIE61 7" casing. P/U & install new test plug. Con't weekly BOPE testing as per BP/AOGCC requirements. LP 250 psi, HP 4000 psi. Chuck Scheve w/ AOGCC witnessing test. Testing w/ 2 7/8" & 3 1/2" test jts. 1 failure -drillpipe dart failed and repaired and passed retest. Rigged down test equipment. Rip up to RIH with shoe track cleanout BHA. PJSM -reviewed Making UP BHA procedure with crew. PUMU BHA #11 to cleanout shoe track as follows: 8-1/2" bit, 2 x 7" boot basket, XO, 6-1/4" oil jar, XO, 9 x 6-1/4" drill collars, XO and 3-1/2" pump out sub = 299.51' RIH w/BHA #11 on 3-1/2" 15.5#, Grade "E" drillpipe from derrick. Taaged TOC at 1912'. Kelly up and break circulation at 2.0-bpm at 10-psi. Halted rig operations due to access to wellpad by HSE support personnel not available. Spine Road blocked both ways from R Pad/Spine Road intersection. Continue circulating. Establish drilling parameters: P/U wt. = 57K, S/O wt. = 57K, RPM = 74, Torque = 60-180 amps, BPM = 3.5. Wash and ream down to 1934' and tag wiper plug. Drilling on wiper plup._ Drill out wiper plug & ES cementer. Con't to drill & clean out liner to 1956'. called PHASE II conditions ~ -1630hrs & went to PHASE III conditions C~ 1830 hrs. Cease operations. Set slips. Blew down & set back kelly. ait on weather. PHASE III . Evening Tour did not make change out. Wait on weather,-- PHASE III. Operations shut down. Went to PHASE II ~ -0200 hrs. Ordered crew change. Plan to restart operations after crew change. Change out crews. Pre-Tour Safety meeting. Crew change. Service rig. Inspect derrick. Check PVT alarms. Resume operations. Con't to drill & clean out cement from 1956'. P/U Wt , S/O Wt & Rot wts = 57K. 60 RPMs, 4 BPM ~ 150 psi. Torq = 1250 ft-Ibs. Depth ~ 0500 hrs = 1966'. Break through cement at 2038' and dry drill to 2043'. recovered cement, arctic pack, metal debris and small amount of sand across shaker screens. Pump 40-bbl. Hi-Vis sweep at 2.5-bpm to 5.5-bpm at 150-psi. Recovered arctic pack, cement, rubber and metal cuttings across shaker screen. Set back and blow down kelly. PJSM -reviewed pulling 3-1/2" DP and standing in derrick. Prepared floor to POH. POH standing 3-1/2" DP in derrick. Break out and lay down 8-1/2" bit and 2 x 7" boot baskets from BHA #11. Cleaned out boot baskets and recovered approx. 2.5 gallons of cement, metal debris and sand. Make up boot baskets, 9-5/8" scraper and RCJB to BHA #12 as follows:?-7/8" RCJB with 8-1/2" head, 2 x 7" boot baskets, 9-5/8" scraper, XO, 6-1/4" oil jar, XO, 9 x 6-1/4" drill collars, XO and 3-1/2" pump out sub = 311.95'. Service rig, pre-tour meeting and crew change. RIH w/BHA #12 on 3-1/2" 15.5#, Grade "E" drill pipe from Printed: 1/5/2009 11:17:26 AM i ~ BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABORS 4ES Rig Number: Date From - To ~ Hours ~ Task Code NPT ' Phase Description of Operations 12/16/2008 12:30 - 15:30 3.00 CEMT P TIEB1 derrick. Tag TOS at 2043'. Pick up 20'. 15:30 - 17:00 1.50 CEMT P TIE61 Mix and pump 40-bbl. Safe-Surf-O pill surface to surface to aid in removal of arctic pack. 17:00 - 18:00 1.00 CEMT P TIEB1 Drop ball and pump in place. Hoover off top of sand to 2,054_'. 18:00 - 19:30 1.50 CEMT P TIEB1 POH w/BHA #12. 19:30 - 20:30 1.00 CEMT P TIEB1 Break out RCJB assy. and inspect junk basket contents. Recovered several pieces of pot metal and cement in the boot baskets. There was no recovery in the RCJB_ 20:30 - 21:00 0.50 CEMT P TIEB1 Clear and clean rig floor. 21:00 - 21:30 0.50 CEMT P TIEB1 Service rig, pre-tour meeting and crew change. 21:30 - 22:30 1.00 CEMT P TIEB1 M/U Halco Retrieving on 9 X 6-1/4" drill collars. 22:30 - 23:30 1.00 CEMT P TIEB1 RIH w/Halco Retrievin tool on 3-1/2" 15.5#, Grade "E" drill pipe from derrick. Tag TOS at 2054". 23:30 - 00:00 0.50 CEMT P TIEB1 M/U reverse circulating assembly on single of 3-1/2" drill pipe and P/U. 12/17/2008 00:00 - 00:30 0.50 CEMT TIEB1 Reverse sand off of RBP to 2,087' 4 bpm at 420 psi. Latch and release RBP. Released without any roblems. 00:30 - 01:00 0.50 CEMT TIEB1 Circulate bottoms up with 4 bpm at 300 psi. 01:00 - 01:30 0.50 CEMT TIE61 R/D circulating assembly and blow down lines. Monitor well. 01:30 - 03:00 1.50 CEMT TIEB1 POOH with Halco RBP, standing back 3-1/2" drill pipe in derrick. 03:00 - 04:00 1.00 CEMT TIEB1 La down 6-1/4" drill collars. Break out and lay down Halco RBP. 04:00 - 04:30 0.50 WHSUR TIE61 Pull wear bushing. 04:30 - 08:00 3.50 CASE TIEB1 Rig up handling equipment for running 7" casing. Pre-tour meeting and crew change. Senvice rig, daily derrick inspection, check PVT's and enviro walkaround. 08:00 - 08:30 0.50 CASE TIEB1 PJSM-Review running 7" casing procedure and running order. 08:30 - 00:00 15.50 CASE TIEB1 Make u Baker 7" seal stem assembl and 7" Halco float collar. Filled float collar joint and verified float holding and weep hole weeping. Baker-Lok'd connection at bottom of float collar. RIH w/7" 26#, L-80 BTC-M casing 1 x 1 from pipe shed. Made up first 5 BTC-M connections and averaged out torque to be 8,400 ft.-Ibs. Run free floating centralizer on every other'oint. 71 jts. RIH at 15:30-hrs. 171 jts. RIH at 23:00 hrs. 12/18/2008 00:00 - 06:00 6.00 CASE P TIEB1 RIH w/7" 26#, L-80 TC II casing 1 x 1 from pipe shed. Torque Turn connections, average make up torque is 10,100 ft.-Ibs. Run free floating centralizer on every other joint. Fill casing every 5 joints. 06:00 - 08:30 2.50 CASE P TIEB1 Pick u and makeu 7" BTC x TCII BxP XO. Picked up and made up 6' and 10' 7" 26#, L-80 BTC pups. Spaced out and tagged top of 7" liner tie-back receptacle at 9830'. Slacked off and tagged top of liner tie-back receptacle with seal stem No-Go. Rigged up headpin and circulating line. Pressured up casin to 300- si. Pulled seal stem u until ressure bled off - -- - ___ to ex ose 4 x 1" orts in seal stem. Made up Schlumberger cement head with wiper Halco 7" plugs loaded. Hooked up lines and started circulating at 3.0-bpm to warm up hole. Finished rigging up for cement job. 08:30 - 09:00 0.50 CASE P TIE61 PJSM -All rig crew and included Baker, MI, Schlumberger cement crew and CH2MHill vac truck drivers. Reviewed and identified hazards of job.. Assigned tasks to individuals and reviewed hazards in those positions. Printed: 1/5/2009 11:17:26 AM BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11 A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To '~, Hours Task '.Code NPT Phase Description of Operations 12/18/2008 09:00 - 11:00 - - 2.00 CEMT N - SFAL T __ IEB1 (Schlumber ger batch up 75-Bbl. 15.8-ppg Class "G" cement w/Gas-Block. Finished hatching cement at 10:00-hrs. Pumped 5-Bbls. seawater to warm and prime up lines. Pressure tested lines. Low pressure stall - 2500-psi, high pressure - 4500-psi. Bled off. Opened up to pump cement. Started pumping 80-bbls. lead cement at 3.0-bpm and at 3.0-bbls. away, hammer union on cment head started leaking. Shut down and tightened up hammer union connection. Resumed pumping and connection still leaking. Shut down and disconnected cement head to investigate reason for leak. Found O-Ring seal in hammer union connection blown out. Schlumberger did not have backup O-Ring on wellpad. Talked about options with Schlumberger and rig leadership. Called and spoke to RWO engineering lead and presented situation and options. Decision made to dispose of 80-bbls. batched 15.8-ppg Class "G" cement with Gas-Block antl to circulate out 3.0-bbls. cement in 7" casin .New 80-bbl. cement lead ordered out. 11:00 - 15:00 4.00 CEMT N SFAL TIE61 Circulate out cement in pipe long way taking returns to rig pits. Diverted returns to open top tan at 580-bbls. pumped to catch 15:00 - 16:00 1.00 CEMT N SFAL TIEB1 16:00 - 23:00 7.00 CEMT N TIE61 23:00 - 23:30 I 0.501 CEMT I N I ITIEBI 23:30 - 00:00 I 0.501 CEMT I N I I TIEB1 12/19/2008 100:00 - 03:30 I 3.501 CEMT I P I I TIEB1 Install Halliburton 7" BTC adaptor and cement head. Wait on cement to be blended at Schlumberger and delivered to rig. Rig up Schlumberger and stage trucks on location. PJSM -All rig crew and including Baker, MI, Schlumberger cement crew and CH2MHill vac truck drivers. Reviewed and identified hazards of job. Assigned tasks to individuals and reviewed hazards in those positions. Break circulation with 75 degree seawater at 3 bpm with 140 psi. Pump 5 bbls of water, pressure test lines to 4,800 psi, batch and pump 75 bbls of 15.8 ppg, class G cement with Gas-Blok at 5 bpm with 330 psi. Pump 211 bbls of 15.8 pp class G cement at 5 bpm with 250 psi. rop plugs, observed flag as plugs came out of head„Displace with seawater at 6 bpm with 150 psi, caught cement at 190 bbls of seawater pumped. Diverted returns to open top tank at 320 bbls of seawater pumped. Cement returns to tank at 347 bbls of displacement pumped. Slowed rate to 1.5 bpm at 4,450 psi at 355 bbls of displacement pumped. Bump plug to 4,700 psi at 382 bbls pumped. CIP at 03:00 hours. 35 bbls of cement back to surface._ 03:30 - 04:00 I 0.501 CEMT I P I ITIEBI 04:00 - 06:00 2.00 CASE P TIEB1 06:00 - 06:30 0.50 WHSUR P TIEB1 06:30 - 08:00 1.50 WHSUR P TIEB1 08:00 - 13:30 I 5.501 WHSUR I P I I TIE61 off into recepticle and bleed off R/D cementing lines, flush and drain BOP stack. Crew change, inspect and service rig. Split and lift BOP stack, set Cameron S6-3-N-L_10'+ x 7" slips and run in lock down screws. Rigged up Wach's cutter and cut 7" casing. set BOP stack back and dress 7" stump. N/U Cameron Type S3-YB 11" 5M tubing spool with 7"x 10" YB in bottom. Pump plastic packing to energize Y seal. Test void to 4,320 psi for 30 minutes as per Cameron Wellhead procedure. N/U BOPE Test breaks to 250 psi low and 4 000 Printed: 1/5/2009 11:17:26 AM BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABORS 4ES Rig Number: Date i From - To Hours ~, Task I'I Code NPT '• Phase Description of Operations 12/19/2008 13:30 - 16:00 2.50 DRILL P TIEB1 MU BHA #14: 6-1/2" Bit, (2) 4-3/4" boot baskets, XO, Bumber jars, Oil Jar, (9) Drill Collars, pump out sub. Total Length 314.44' 16:00 - 18:00 2.00 DRILL P TIE61 TIH w/ BHA #14. 69 stands in prior to crew change 18:00 - 19:00 1.00 DRILL P TIEB1 Crew Change, inspect and service rig. 19:00 - 20:00 1.00 DRILL P TIEB1 Continue to TIH w/ BHA #14. Tag TOC ~ 9663.23'. 20:00 - 21:00 1.00 DRILL P TIEB1 Pressure test 7" scab liner cement'ob to 4000 si for 30 minutes. Good test. 21:00 - 00:00 3.00 DRILL P TIEB1 Pick up Kelly. Establish milling parameters: PU: 160k, SO: 116k, Rot: 60 rpm and 135k, 220 amps/ 4700 fUlbs torque, 5.5 bpm ~ 500 psi, WOB 5-10k 12/20/2008 00:00 - 02:00 2.00 DRILL P TIEB1 Continue to mill out cement shoe track. Found CemenVsand No-Go. PUH re are to circulate. 02:00 - 04:00 2.00 DRILL P TIEB1 Circulate and condition wellbore. 25 bbls hi vis sweep. Saw good returns. 5-1/2 bpm at 1,500 psi. 04:00 - 06:00 2.00 DRILL P TIEB1 Lay Down Kelly, Trip out of Hole with BHA #14, standing back 3-1/2" drill pipe. 06:00 - 07:00 1.00 DRILL P TIE61 Crew change, service rig, inspect derrick, set alarms. 07:00 - 09:30 2.50 DRILL P TIE61 POOH with clean out BHA #14, standing back 3-1/2" drill pipe in derrick. 09:30 - 10:30 1.00 DRILL P TIEB1 Break out and UD clean out BHA. 10:30 - 11:00 0.50 DRILL P TIEB1 Clear rig floor. 11:00 - 11:30 0.50 BOPSU P TIE61 M/U running tool and pull wear bushing. 11:30 - 15:00 3.50 BOPSU N TIEB1 Install Cameron test plug, leaking by test plug, pull test plug and install second test plug. Pressure up to 200 psi and started leaking by test plug. Pull test plug and replace seal. Rerun test lu .Test lu holdin . 15:00 - 18:00 3.00 BOPSU N TIEB1 Test, BOPE. Test 2-7/8'x 5" VBR's, hydril, blinds, manual choke va ve, manual kill valve, HCR choke valve, HCR choke valve, choke manifold valves, floor valve, and dart valve to 250 psi low and 4,000 psi high. Hold each test for 5 minutes on the chart. test witnessed by the Nabors Toolpusher and BP WSL. AOGCC witness of test was waived by Lou Grimaldi. Perform drawdown test on Koomey. No failures. 18:00 - 19:00 1.00 BOPSU N TIEB1 Crew Change, service rig, inspect derrick, set alarms. 19:00 - 20:00 1.00 BOPSU N TIE61 Test upper and lower kelly valves to 250 psi and 4,000 psi for 5 minutes each. Good tests. 20:00 - 21:00 1.00 BOPSU N TIEB1 I to I nd install Wear Bu hin .. 21:00 - 00:00 3.00 BOPSU N TIEB1 M BHA #15 3-5/8"funk mill, XO, 146 Jts of 2-7/8" HT Pac drill pipe, XO, XO, 7" Casing Scraper, XO, Circulating Sub. Total BHA lenght = 4,637.31' 12/21/2008 00:00 - 02:00 2.00 DRILL TIEB1 Continue to M/U BHA #15, 3-5/8"junk mill, XO, 146 Jts of 2-7/8" HT Pac drill pipe, XO, XO, 7" Casing Scraper, XO, Circulating Sub. Total BHA lenght = 4,637.31' 02:00 - 05:00 3.00 DRILL TIE61 Circulate DP volume with 3 bpm at 720 psi while changing handling equipment from 2-7/8" to 3-1/2". 05:00 - 06:00 1.00 DRILL TIE61 RIH with BHA #15 on 3-1/2" drill pipe from derrick. Tag sand at 9 853' 06:00 - 07:00 1.00 DRILL TIE61 Establish parameters. Up weight 139K, Down weight 102K, Rotating weight 124K. 3-1/2 bpm at 1,600 psi. Free rotating torque is 3,200 ft/Ibs at 60 rpm. Set torque limit to 5,000 fUlbs. Wash from 9,953' to 9,907'. Starting to get rocking torque. Printed: 1/5/2009 11:17:26 AM • • BP EXPLORATION Page 14 of 16 Operations Summary Report. Legal Well Name: R-11A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 12/21/2008 07:00 - 09:00 2.00 DRILL TIEB1 Circulate a 20 bbl hi-vis sweep around at 5 bpm with 2,600 psi. Sweep brought up sand and cement cuttings. Add one drum of EP tube. 09:00 - 10:30 1.50 DRILL TIEB1 Mill from 9,907' to 9 915'. 2 -5k weight on mill, 60 rpm with 3,200 to 4,700 ft/Ibs of torque. 3 bpm with 1,450 psi. Unable to make progress from 9,915'. Torque dropped to 3,200 ft/Ibs, Very weight between 2 to 10K and pump from 1 bpm to 5 bpm. Unable to make ro ress. Discuss options with Baker and Well engineer. Discission made to POOH. 10:30 - 11:30 1.00 DRILL TIEB1 Monitor well. Drop ball and open circulation sub. Sub sheared at 1,900 psi. 11:30 - 13:30 2.00 DRILL TIEB1 POOH with BHA #15 standing back 3-1/2" drill pipe in derrick. 13:30 - 16:00 2.50 DRILL TIEB1 Change out handling equipment. POOH with BHA #14, standing back 2-7/8" drill pipe in derrick. 16:00 - 18:00 2.00 DRILL TIE61 Handle BHA #14, 3-5/8" Bladed junk mill was marked up on the sides and the bottom was wore up 2 inches on the outer mill tapering down to full lenght in the center. Discussed options with Well Engineer and Baker fishing. Decision made to run another junk mil. 18:00 - 19:00 1.00 DRILL TIEB1 Crew Change out. Service and inspect rig. 19:00 - 21:30 2.50 DRILL TIEB1 M/U BHA #16, 3-5/8"junk mill, XO, 146 Jts of 2-7/8" HT Pac drill pipe, XO, XO, 7" Casing Scraper, XO, Circulating Sub. Total BHA lenght = 4,637.96' 21:30 - 22:30 1.00 DRILL TIEB1 Sunday Safety meeting. PJSM for slip and cut drill line. 23:30 - 00:00 0.50 DRILL TIEB1 Slip and cut drilling line 12/22/2008 00:00 - 01:00 1.00 DRILL TIEB1 Cont cut and slip drilling line 01:00 - 01:30 0.50 DRILL TIE61 PJSM, running drill pipe 01:30 - 03:30 2.00 DRILL TIE61 RIH w/ BHA #16 from 4637' to 9915' MD. Establish parameters. 03:30 - 06:00 2.50 DRILL TIE61 Establish parameters, P/U weight 130K, S/O weight 105K, Rot weight 115K, 3,200 fUlbs rotary torque at 50 rpm. Set rotary torque limit to 5,000 ft/Ibs maximum. Mill from 9,915' to 9,996'. WOM 5K 06:00 - 06:30 0.50 DRILL TIE61 Crew change, inspect derrick and set alarms. 06:30 - 07:00 0.50 DRILL TIEB1 RIH to 10 305 ushin lu down, 30 to 35K overpull. 07:00 - 09:00 2.00 DRILL TIEB1 Circulate 40 bbl high vis sweep around at 4 bpm with 1,700 psi while working pipe. brought back sand and formation cu inn 09:00 - 11:30 2.50 DRILL TIEB1 RIH f/ 10,305'to 11,797' ushin lu s down. Fluid starting to run over tool joint when slacking off. 11:30 - 12:30 1.00 DRILL TIE61 Pump drill pipe volume at 4 bpm with 1,700 psi pump pressure. 12:30 - 14:00 1.50 DRILL TIEB1 RIH f/ 11,797' to 13,721' ushin plugs down. Getting 30 to 35K overpull when picking up string. Call Well Engineer and discuss options. Dicide to displace well to clean seawater at this time. 14:00 - 15:30 1.50 DRILL TIEB1 Circulate 30 bbl high vis sweep around at 4-1/2 bpm with 2,400 psi pump pressure. While cleaning a pit and organizing seawater trucks. Sweep brought back formation cuttings with some crude and gas breaking out. 15:30 - 16:30 1.00 DRILL TIEB1 Set back Kelly and pu 1 joint of drill pipe and M/U circulating head. 16:30 - 18:30 2.00 DRILL TIEB1 Circulate and Condition wellbore with clean seawate . 70 spm C~ 2600 psi 18:30 - 19:00 0.50 DRILL TIEB1 Crew change, inspect derrick and set alarms. Printed: 1/5/2009 11:17:26 AM a BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To i Hours Task Code NPT Phase ~ Description of Operations 12/22/2008 19:00 - 21:30 2.50 DRILL TIEB1 TIH from 13572' to 14350' MD. Set down 10k. PU kelly and establish parameters: PU 160k, SO 110k, ROT 115k, 60 rpms w/ 240 Amps ~ 5,000 Ibs/ft. WOB ~ 5 -6k. Wash in from 14350 to 14420' MD. Set down 15k and spin for 3 unable to make anymore hole. 10' past the perforations and still takin returns estimated to be losin - 3 b .decide to CBU and POOH LDDP. 21:30 - 00:00 2.50 DRILL TIEB1 CBU 1.5 wellbore volumes. 71 spm @ 2700 psi. 12/23/2008 00:00 - 06:00 6.00 DRILL TIEB1 POOH UD 3-1/2" DP from 14420' to 8500' MD. Maintain continious holefill. Losing 2 - 3 bph. 06:00 - 06:30 0.50 DRILL TIE61 Crew change, inspect derrick, service rig and set alarms. 06:30 - 09:30 3.00 DRILL TIEB1 POOH UD 3-1/2" DP from 8500' to 4,637'MD. Maintain continious holefill with seawater. 09:30 - 17:30 8.00 DRILL TIEB1 Change out handling equipment from 3-1/2" to 2-7/8". POOH UD 7" scraper and 146 jts 2-7/8" PAC HT DP from 4,637'. LD 3-5/8"junk mill. Maintain continious holefill with seawater. Hea solids coating drill pipe. 17:30 - 18:00 0.50 DRILL TIE61 Cleared rig floor. 18:00 - 00:00 6.00 BUNCO RUNCMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Cleared and cleaned rig floor. Had large quantity of hydrocarbon solids slough off drill string during LD. Pull up floor coverings and clean. Clean floors 12/24/2008 00:00 - 04:30 4.50 BUNCO RUNCMP Cleaning rig floor. Had large quantity of hydrocarbon solids slough off drill string during LD. Pull up floor coverings and clean. replace floor coverings. Clean walkways coming off of rig floor. 04:30 - 05:00 0.50 BUNCO RUNCMP Pull Wear bushing. UD running tool. 05:00 - 06:00 1.00 BUNCO RUNCMP R/U floor and handling equipment to run 4-1/2" completion. 06:00 - 17:30 11.50 BUNCO RUNCMP Held crew change and performed pre-tour checks of PVT system and derrick. RIH with 4-1/2" 12.6# L-80 TC-II tubina and accessories. Bakerloc'd all connections from packer down. Used Jet Lube Seal Guard thread compound and torque-turned all connections. 192 of 229 jts RIH at 16:00 hrs. Ran 229 joints. 17:30 - 18:30 1.00 BUNCO RUNCMP M/U Cameron SA-SRL, 11"tubing hanger. Land tubing string. Up weight 110K, Down weight 94K. RILDS, lock down torque 500 Wlbs 18:30 - 20:00 1.50 BUNCO RUNCMP Reverse in 140 bbls of inhibited fluid down IA taking returns out the tubing. 3 bpm at 250 psi/ 20:00 - 22:30 2.50 BUNCO RUNCMP R/U Little Red pump truck and test lines to 4,500 psi. Reverse in 70 bbls of diesel freeze protect down the IA taking returns out the tubing. 2 bpm at 180 psi. U-tube diesel between tubing and IA. 22:30 - 00:00 1.50 BUNCO RUNCMP Dro rod and ball. Pressure u and set acker, Test tubin to 4 000 si for 30 minutes on the chart. Good test. 12/25/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Bleed tubin ressure to 1,500 si, pressure up on the IA to 4,000 psi for 30 minutes on the chart. Good test. Bleed pressures to 0 psi.._ 02:00 - 03:00 1.00 BUNCO RUNCMP T-bar i~type H TWC with Cameron wellhead tech. Test the TWC from above to 3,500 si for 10 minutes on the chart. Good test. 03:00 - 06:00 3.00 BUNCO RUNCMP Secure well and rig. Suspend well operations for Holiday break. 06:00 - 15:00 9.00 BUNCO RUNCMP Continued suspension of rig operations for Christmas holiday. Printed: 1/5/2009 11:17:26 AM BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: R-11A Common Well Name: R-11A Spud Date: 12/2/1998 Event Name: WORKOVER Start: 11/30/2008 End: 12/23/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2008 Rig Name: NABOBS 4ES Rig Number: I I I From - To Date 'Hours Task ~, NPT Code Phase.. Description of Operations 12/25/2008 06:00 - 15:00 9.00 BUNCO RUNCMP Obtained approvals and inspection for move to M-07. Notified AOGCC at 09:05 hrs of M-07 BOPE test. 15:00 - 20:00 5.00 BOPSU P RUNCMP Held pre-tour safety meeting and performed checks of PVT system and derrick. ND and stand back BOPE. Barriers for nippling down were rod and ball on seat with kill weight fluid and tested TWC. 20:00 - 22:00 2.00 BOPSU P RUNCMP N/U adaptor flange and tree. Pad operator checked orientation on tree. 22:00 - 23:00 1.00 BOPSU P RUNCMP Test hanger void to 5,000 psi for 30 minutes, test tree to 5,000 psi for 15 minutes with diesel. Good tests. 23:00 - 00:00 1.00 BOPSU P RUNCMP Secure well and cellar. Rig released at 24:00 hours. Printed: 1/5/2009 11:17:26 AM 12/18/08 5chlumberger~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wnll I..l. Y N0.5011 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 11-34 12071901 USIT ~-I - uaat; 10/17!08 oL I.OIOf 1 VU 1 V-219 12103700 USIT - 11/21/08 1 1 D-12 12113022 INJECTION PROFILE 12/05/08 1 1 R-11A 12096929 USIT _ ~ 12/07/08 1 1 01-34 12116292 CORRELATION/GR LOG _ CO - / ~}- ~ a 12/06/08 1 1 F-19 AWJI-00011 MEM LDL (_ 12/08/08 1 1 18-29B AWJI-00010 MEM LDL ~ ~ 12/05/08 1 1 09-41 12017504 PRODUCTION PROFILE J01 ._-C3 12/04/08 1 1 18-14B 12005233 MCNL - - 09/21/08 1 1 18-066 12083417 MCNL - 10/28/08 1 1 18-14C 12066551 MCNL ~ 10/06/08 1 1 05-10C 11649990 MCNL 10/04/08 1 1 V-219 12103700 CH EDIT (USIT) 11/21/08 1 ~-- ~ °~~ Wl T -t ~s - ~ c PI F~St= ACKNAWI Fnnc o~ r•e1oT ev elr_~ u~~n e.~n 11 GT11r1.1 Lin Auk w~eav ~. w. • ~w BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered; • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth Received by: • • ALA-SRi.A OIIe A1~TD ~`zA-S COI~TSERQATIOIiT COl~l-'IISSIOI~T David Reem Engineering Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 ~, ~~-, k y. SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-11A ~b Sundry Number: 308-378 ~ ~ ~' Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~~ Daniel T. Seamount, Jr. Chair <J DATED this~~- day of October, 2008 Encl. STATE OF ALASKA - ALAS~IL AND GAS CONSERVATION COMMIS Q C T ~ ~ ~0~8 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension~ChCfB~6 ®Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ~ Pull Tubing ^ Perforate New Pool ^ Waiver ' ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 198-206 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20883-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: R-11A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028279 51.15' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft):) Plugs (measured): I Junk (measured): I 14560' 8737' 14418' 8740' 9807' None r . __-.~ ~.:__ un nin R~~rc+ r:nllanca Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13990' -14410' 8749' - 8740' 4-1/2", 12.6# L-80 9839' E Packers and SSSV Type: 9-5/8" x 4-1l2" Baker'S-3' packer Packers and SSSV MD (ft): 9783' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Pro ram 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: December 1, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. 1 hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthirwton, 564-4102 Printed Na avid em Title Engineering Team Leader r~epared sY rr: Signature ~. Phone 564-5743 Date !o Zo Terrie Hubble 564-4628 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test `~Mechanicat Integrity Test ^ Location Clearance Other. 1 ~ ~ ~ ~ ~ 1 ~~~ ~ °~S~ Subsequent Form Required: y'~ Form 10-403 APPROVED BY ~ ~-I1~. Submit In Duplicate I.JIa.1~r..t ~e ~g 1 ~ ~'_~ ~~. QC~ ~ ~ X006 • • R-11 A Expense Rig Workover Scope of Work: Pull 4-~/2" completion, cut and pull 9 5/a" casing, remove wellhead, run 9 5/8" casing and cement to surface, install new wellhead, run 7" liner from tieback to surface•and cement, run 4-'/z" L-80 premium thread "stacker-packer" completion. MASP: 2400 psi Well Type: Injector Estimated Start Date: December 1, 2008 Production Engineer: Don Brown Intervention Engineer: Aras Worthington Pre-Rig Work Request: S 1 Pull PX lu @ 9807' md. Drift for Fasdrill lu to 10,200' md. E 2 Set Fasdrill plug in 4 '/z" liner @ 10,000' md. CMIT Tx IA to 3000 psi (to verify plug integrity/barrier). Set 2"d Fasdrill (after successful CMIT of 1~' plug) in 4'/z" liner @ 9900' MD. E 3 Jet cut the tbg @ 9742' and (reference tbg tally of 12/20/1998) in the middle of the first full 'oint above the roduction acker. F 4 Circulate well with seawater. FP w/diesel throu h the cut. Bleed WHPs to 0 si. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured with a Fasdrill lu at this time. V 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . D 8 Line the Cellar around the wellhead with im ermeable, s ra -sealed Herculite. Proposed Procedure 1. MIRU. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. ND tree. NU BOPE with 3-~/z" x 6" VBR pipe rams. Pressure test to 4000 psi. 3. Pull and LD 4-~/z" tubing string to the cut. Mill and retrieve packer and tbg tail. 4. Set RBP @ 9800' MD. 5. Run USIT log to determine top of cement in 9 5/e" x 13-3/8" annulus. 6. Set retrievable bridge plug 100' below the top of cement. 7. Cut and pull 9-6/a' casing from above the top of cement. Note: Pipe rams will not be changed to 9- 5/e" as the well has two tested barriers (Two RBPs) to the reservoir. 8. ND BOPs, Cut 13 3/8" casing just below casing spool, remove casing spool. 9. Run and fully cement new 9 5/8" casing to surface. 10. Install new wellhead on 9 5/8" casing. 11. NU and test BOPs to 4000 psi. 12. Pressure test new casing and drill out shoetrack. • • 13. Clean out to retrievable bridge plug(s) and retrieve same. 14. Run new 7" liner from 7" tieback to surface and fully cement same. Note: Pipe rams will not be changed to 7" as the well will has two tested barriers (Two Fasdrill plugs) to the reservoir. 15. Run 4-~/2" L-80 stacker packer completion with Baker S-3 packer. Position packer at 9700' MD. 16. Displace the IA to packer fluid and set the packer. 17. Test tubing and IA to 4000 psi. Freeze protect to 2200' MD. 18. Set BPV. ND BOPE. NU and test tree. RDMO. WELLHEAD = 13-5/8" 5M McVOY SSH ACTUATOR = BAKER KB. ELEV = ~ 51.15' BF. ELEV = 21.68. KOP = ~ 3096' Max Angle = 99 @ 10685' Datum MD = 10446' Datum TVD = 8800' SS R _ ~ ~ ~ S NOTES: '`** 70° @ 10410' & 90° @ 2016' 4-1 /2" HES X NIP, ID = 3.813" 2590' 9-5/8" DV PKR r~ ~J 13-3/8" CSG, 72#, L-80, ID = 12.347" ~--~ 2689' Minimum ID = 3.725" @ 9827' 4-1 /2" HES XN NIPPLE 4-1/2" TBG, 12.6#, L-80, 9839' .0152 bpf, ID = 3.958" TOP OF 4-1 /2" LNR 9837' 9839' 4-1/2" WLEG 9849' ELMD TT LOGGED 11/18/00 9860' 7" X 4-1 /2" XO TOP OF 7" LNR ~ 9911' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10155 PERFORATION SUMMARY REF LOG: N/A ANGLE AT TOP PERF: 92 @ 13990' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 6 13990 - 14050 C 12/21 /98 2-3/4" 6 14350 - 14410 C 12/21/98 TOP OF CEMENT ~~ 10254' 7" LNR, 26#, L-80, .0371 bpf, ID = 6.184" ~~ 10207' 9772' ~ 4-1/2" HES X NIP, ID = 3.813" 9783' 9-5/8" X 4-1/2" BAKER S-3, PKR, ID = 3.875" 9807' 4-1/2" HES X NIP, ID = 3.813" 9807' 4-1/2"? PX PLUG (12/26/07) 9827' 4-1/2" HES XN NIP, ID = 3.725" 9836' TIE BACK SLEEV E BAKER 9-5/8" ZXP LT- PKR, BAKER FLIX-LOCK HGR, ID = 6.313" THROUGH PKR AND HGR MILLOUT WINDOW FROM 10207' - 10219' 10207' I-iTOP OF WHIPSTOCK PBTD ~-~ 14418' 4-1/2" LNR, 12.6#, L-80, ~ 14560' IBT .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 1983 JJ ORIGINAL COMPLETION 01/22198 SIDETRACKED 02/27/02 RN/TP CORRECTIONS 09/22/06 RDW/PA WA V ER SFTY NOTE DELETED 12/26/07 DTRITLH PX PLUG SET PRUDHOE BAY UNff WELL: R-11A PERMff No: 1982060 API No: 50-029-20893-01 SEC 32, T12N, R13E BP Exploration (Alaska) TREE= 41 /16" 5M CM/ WELLHEAD= 13-5/8" 5MMcVOY SSH CTUATOR = ~ BAKER KB. ELEV = 51.15' BF. ELEV = 21.68' KOP = 3096' Max Angle = 99 ~ 10685' Datum MD = t 0446' Datum TV D = 8800' SS R ~1 A Proposed 1 ~,f NarES: """ 70° ~ 10410' 8 90° ~ 41 /2" HES X NIP, ID = 3.813" 'nerd to Surface 2590' ~ 9-5/8" DV PKR 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2689' Minimum ID = 3.725" ~ 9827' 4-1/2" HES XN NIPPLE ~ 7" CSG, 26#, L-80, ID = 6.276" ~ 41 /r' TBG, 12.6#, L-80, 9839' .0152 bpf, ID = 3.958" TOP OF 41 /2" LNR - TOP OF 7" LNR I~ 9911' 9-5/8" CSG, 47#, L-80, ID = 8.681 " I-I 10155' PERFORATION SUMMARY REF LOG: N/A ANGLE AT TOP PERF: 92 ~ 13990' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL OpNSgz DATE 2-3/4" 6 13990 -14050 C 12/21 /98 2-3/4" 6 14350 - 14410 C 12/21 /98 I TOP OF CEMENT I T' LNR, 26#, L-80, .0371 bpf, ID = 6.184" I-i 10207' 41 /2" HES X NIP, ID = 3.813" -9800' 7" X 41 /r' BAKER S-3, PKR, ID = 3.875" ~~ 41 /2" HES X NIP, ID = 3.813" 41 /2" HES XN NIP, ID = 3.725" I 9836' TIE BA CK S LEEV E BA KER 9-5/8" ZXP LT- PKR, BAKER FLEX-LOCK HGR, ID = 6.313" THROUGH PKR AND HGR 9839' 41 /2" WLEG 9849' ELMD TT LOGGED 11 /18/00 9860' 7" X 41 /2" XO MILLOUT WINDOW FROM 10207' - 10219' TOP OF WHIPSTOCK ~~ I~ 14418' 41/2" LNR, 12.6#, L-80, IBT .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 1983 JJ ORIGINAL COMPLETION 01/22/98 SIDETRACK 02/27/02 RN/TP CORRECTIONS 09/22/06 RDW/PA WAIVER SFTY NOTE DELETED 12/26/07 DTR/TLH PX PLUG SET PRUDHOE BAY UNfT WELL: R-11A PERMff No: 1982060 API No: 50-029-20893-01 SEC 32, T12N, R13E BP Exploration (Alaska) U 3.~1~s~~1`3~11i®A~ ~® s~s7~®A~ r''RAI11K ~1. MURKOU6/SK1, GOt1ERA/OR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 275-7542 ~9~11VL~~L6~/~11 ~®BY AD1~~II~iISTIZATIVE APPR®~'AL YO. AI® 3.00 ti~"~,1~~e~ JA~i ~ ~ ~D~fi GIs. Anna Dube, Well Integrity Coordinator ~ n BP Exploration (Alaska) Inc. ~~ 4' Attn: We11 Integrity Engineer, PRB-2~ P.O. Box 196612 ~~ anchorage, AK 99~ 19-6612 RE: Cancellation of Administrative Approval AIO 03.00 (w'e11 PBL; R-1 lAl Dear :tits. Dube: Pursuant to BPXA's request dated October 10, 2006 AOGCC hereby cancels Administra- tive Approval AIO 03.00, which allows water injection in well PBL' R-1 I A. This well exhibited a surface casing leak, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the ad- ministrative approval. Since then, BPXA has determined that PBL~' R-1 1 A's condition has deteriorated to the point that safe operation is no longer supported. The well will remain shut in for evalua- tion of repair options. Consequently, Administrative :approval AIO 03.00 no longer ap- plies to operation of this well. Instead, injection in well PBU R-11A will be governed by provisions of the underlying Area Injection Order ~o. 3. DOSE at anchorage, Alaska and dated ®ctober 16, 2006. The Alaska Oil and Gas Conservation Commission i ~f~ ~~`~~, J/ohn~I. '~~orman ~~~ Cathy F erster ~' ~ C~iairman Com issioner ~; • f I I ~ ~ i ~i ~ ~ ; ' _' ~ . , ~ t J J ~ ~ mo u ~ ~ - ~,~ - d '~®,~ ~ ~ - 1 ..,~i ~-e..> ~. ~. ~~TT~~++ ALA~5t~81~ OIL ~1~T~Dr ~+~4so-~7T i 1 /( FRANK H. MURKOWSKI, GOVERNOR ,' r 333 W. 7'" AVENUE, SUITE t00 ' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 3.005 Mr. Steve Rossberg, Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 RE: PBU R-11 A (PTD 198-206) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order 003.000, the Alaska Oil and Gas Con- servation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to inject water in the sub- ject well. The Commission hereby denies BPXA's request for administrative approval to inject gas in the subject well. PBU R-11 A exhibits surface casing to conductor casing communication with gas leakage to the atmosphere. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU R-1 lA. The Commission further finds that, based upon reported re- sults of BPXA's diagnostic procedures, PBU R-11A exhibits t~vo competent barriers to release of well pressure. Accordingly, the Commission believes that well operation in water injection service will not threaten the environment or human safety. However, the Commission believes that PBU R-11A's condition does not conform to the relatively more stringent standards of well integrity necessary to ensure safe gas injection. AOGCC's administrative approval to inject water in PBU R-11A is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform an annual ivIIT - IA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall limit the well's IA pressure to 1000 psi; L_ J vir. Steve Rossberg January 27, 2006 Page 2 of 2 C 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 6. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PNI on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated January 27, 2006. ~ ' ~ ~'~ Cathy P. Foe ster Daniel T. Seamount, Jr. Commissioner Commissioner ,mss. ~ ,0~~ ~-~s~-. r C Y~y~T~~a~ `~ ~5% Y~. ~`~. g~ ~. v ` i ~' I ' ~ Ss l j9~ i. 7 ~ :. =1 1 Well R-ll (PTD #1982060) Classified as TrW - Cancel waiver . All, The waiver for well R-11 has been cancelled. The waiver process relating to wells with surface casing leaks has been reviewed and the finding is that GPB will no longer waiver these types of wells. «--\ \ þ~- Lead Operator: Will you please ensure any waiver related signage is removed from the wellhouse. Please call with any questions. Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 P~.6.J¡>'I ;¡.iI::~ . nr,r; (, t, Znrç \J'-'~~1j~~...J ~Jt{¡' /t ;¿j . u,dJ; lofl 9/25/200610:51 AM RE: R-IIA p,[)"'- ¡'ìß.-. e Hello all. R--I CA Attached is a waiver for &-:tf: 5ß~ 7/Isl()~ Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom ¿. «R-11A SC Waiver 05-02-06 001.pdf» From: Wilson, Ronald D (VECO) Sent: Monday, July 03,20067:11 PM To: NSU, ADW Well Integrity Engineer Subject: R-11 I:-Il A Hi Joe. ..~. has been put on the S drive and the hardcopies distributed. Ron lA SC Waiver 05-02-06 Content-Description: R-IIA SC Waiver 05-02-06 001.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 7/13/20062:38 PM e e Notice of Waivered Well WELL: R-11A WELL TYPE: Water Inlector DATE: 05-02-06 Pressures: Injecting 81 Tubing 1060 psi 600 psi Inner Annulus 850 psi o psi Outer Annulus o psi 20 psi D~ \ C\c¿.Þ 4-- Injection Data: 09/12105: 14,417 BWD @ 771 psi REASON FOR NOTICE: Surface Casing leak COMMUNICATION INDICATED BY: · SC leak occurs at 50 psi with Nitrogen - 04108104. TUBING INTEGRITY DEMONSTRATED BY: · MIT-IA Passed to 4000 psi - 01/02106. PRODUCTION CASING INTEGRITY DEMONSTRATED BY: o MIT-IA Passed to 4000 psi - 01/02106. IMPORTANT CONSIDERATIONS I COMMENTS: · 2 Levels of protection are competent tubing and production casing which have been tested to at least 1.2 times the maximum injection pressure. · AOGcc issued Administrative Approval (AIO 3.005) for continued water injection. · Note conductor bllbbling was observed at 50 psi OAP. o OAP limit of 40 psi was assigned to accommodate minor thermal Induced pressure changes. · This waiver supercedes the current waiver dated - 08126/04. PLAN OF ACTION: Any deviation from this waiver must be pre-approved by the Wells Group and the Operations Manager. · Water Injection Only - No Mllnjection allowed. o Monitor well head pressures and log dally. · Ensure no LEL in wellhouse Of continuous liquid leak to cellar. o Submit a monthly report of injection rate and wellhead pressures to the AOGcc. · Perform the following waiver compliance testing: · Annually conduct an MIT-IA to 1.2x the maximum well pressure. · Stop Injection and notify the AOGcC upon indication of compromised Integrity. Operating Umits Max lAP = 1000 psi Max OAP = 40 psi .&1Qwk /1/ ~~. ( Wel~era ions Supervisor 06 /)5/~ Date s¡j~~1o I Date ~"'~ a Manager ~/~~6 Date {\ fLL" ~/ Wells Manager r ~l ~.!'~ 4Il1/ð~ Date Distribution: DS I Pad Operator DS I Pad Engineer WOE I"(J:: \J t: I vt: D " STATE OF ALASKA) ALA ..~ OIL AND GAS CONSERVATION COM(\,. -,SION JAN 2 6 2006 REPORT OF SUNDRY WELL OPERATIONSAfaska Oil & Gas Cons. Comm;sSio.1 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other ~ñöho~eSundry Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 WaiverD Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Ir' Exploratory Ir 198-2060 3. Address: P.O. Box 196612 Stratigraphic Ir Service Ir:ï 6. API Number: Anchorage, AK 99519-6612 50-029-20893-01-00 7. KB Elevation (ft): 9. Well Name and Number: 51 .15 KB 8. Property Designation: ADL-028279 11. Present Well Condition Summary: Total Depth measured 14560 true vertical 8736.72 Effective Depth measured 14418 true vertical 8739.52 , Casing Conductor Surface Production Liner Liner Length 80 2660 10127 4724 296 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 4-1/2"12.6# L-80 7" 26# L -80 . . '. Perforation depth: Measured depth: 13990 - 14050 True Vertical depth: 8748.58 - 8746.88 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) ~2. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations R-11A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 30 - 110 29 - 2689 28 - 10155 9836 - 14560 9911 - 10207 TVD 30 - ,11 0 29 - 2688.91 28 - 8606.06 8341.34 - 8736.72 8403.23 - 8649.81 Collapse 470 2670 4760 7500 5410 Burst 1490 5380 6870 8440 7240 14350 - 14410 8740.79 - 8739.65 4-1/2" 12.6# 26 - 9839 L-80 9-5/8" DV Packer 4-1/2" Baker 8-3 Perm Packer 4-1/2" Baker ZXP Packer 2590 9783 9839 .' M ~ M ..~ 120GB SCANNED ~,1 H\\'i¡ (!, RBDMS 8Ft ,IAN 2 6 2006 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 7201 0 Tubing pressure 875 15. Well Class after proposed work: Exploratory r Development r 16. Well Status after proposed work: Oil r' Gasr WAG r GINJ:, Service P' WINJ w' WDSPL r 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: 304-241 Contact Rob Mielke Printed Name Rob Mielke Title Well Integrity Engineer Date 1/17/2006 Signature Phone 659-5102 Form 10-404 Revised 0412004 0 R \ G \ N A L Submit Original Only MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ('Ké"Í'í11, ,(4!OG;> P.I. Supervisor l /, DATE: Wednesday, January 04, 2006 FROM: Jeff Jones Petrol cum InspectOJ" SUBJECT: Mechanical Integrity Tests BP EXPLORA TrON (ALASKA) INC R-llA PRUDHOE BAY UNIT R-Il A Src: Inspector , / ðfJ(¡; \ a q; Reviewed B;", . P .I. Sup rv ~113e:...-. Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT R-IIA Insp Num: mitJ.J060I04082141 ReI Insp Num API Well Number 50-029-20893-01-00 ]Permit Number: 198-206-0 Inspector Name: Jeff Jones Inspection Date: 1/2/2006 Packer Pretest Initial Well R-IlA Inj. TVD 8298 IA 95 4000 P.T. ] 982060 TypeTest SPT Test psi 2074.5 OA 0 20 . . .--....-.-...--.--.-..,-".---- "-~.... - '. .._~"..""""'-,-"..,,,....._."_.....¡....._,,-- 15 Min. 30 Min. 45 Min. 60 Min. 3850 3780 20 20 ... Jº-~.~ry.~I.._~~~9~0~. p IF................_........._.......~.....______________........__...._......_._......!.~.~!.~_~.._._.._~-=-~~ 750 730 750 --,....-. ,~.._. ". "...,-,.-.. ,,~ ., ~....,. -. '_~'"--"~'._~.....'.."".~.,,,,.''' Notes 8.6 BBLS methanol pumped. 1 well house inspected; no exceptions noted. Sf;ANNED JAN 11 200.6 Wedncsday, January 04. 2006 Page 1 of 1 ) TREE = 4-1/16" 5M CIW W8..LHEAD = 13-5/8" 5M IV\:::VOY SSH ACTUATOR = BAKER KB. ELEV = 51.15' BF. ELE\Ì = 21.68' KOP = . 3096' Max Angle = 99@) 10685' Datum MD = 10446' Datum TVD = 8800' SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1--1 2689' Minimum ID = 3.725" @ 9827' 4-1/2" H ES XN NIPPLE r-J R-11 A 1 t 1 =-1 ~ = I Z r z 4-1/2" TBG, 12.6#, L-BO, -1 .0152 bpf, 10 = 3.958" I TOP OF 4-1/2" LNR 1-1 I~ 9839' 9837' I TOP OF 7" LNR 1-1 9911' 9-5/8"CSG,47#,L-80, 10=8.681" 1-1 10155' PERFORATION SUMrv\A.RY REF LOG: N'A ANGLEA T TOP PERF: 92 @ 13990' Note: Refer to Ffoductbn œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 6 13990 - 14050 0 12/21/98 2-3/4" 6 14350 - 14410 0 12/21/98 I TOP OF CErvENT 1--1 10254' 1 17" LNR, 26#, L-80, .0371 bpf, 10 = 6.184" J-1 10207' 1 OA TE RBI BY COM'v1ENTS 1983 JJ ORIGINAL COM PLETION 01(22/98 SIDETRACKED 02f27/02 RN'TP CORRECTONS 08f29/04 ELYLllLPWAIVER SAFErY NOTE OA TE REV BY ~ . I .4 ~ ~ COMrvENTS ) SAÆTY NOTES: 70° @ 10410' & 90° @ 10559' *** SURFACECSG LEAK = MAX lAP = 2000 PSI, MAX OAP = 100 PSI (08/26/04 WAIVER) NOTE: PW I ONLY / NO MIINJ ECllON ALLOW ED *** 2016' 1-14-1/2" HES X NIP, 10= 3.813" I 2590' 1-1 9-5/8" DV PKR 9772' 1---1 4-1/2" HES X NIP, 10 = 3.813" I 9783' 1-19-5/8" X4-1/2" BAKERS-3, PKR, 10 =3.875" 9807' 9827' 1-1 4-1/2" HES X NIP, 10= 3.813" I 1-1 4-1/2" HES XN NP, 10= 3.725" I 9836' 1- TE BACK SLEEVE BA KER 9-5/8" ZXP L T- A<R, BAKER FLEX-LOCK HGR, 10 = 6.313" THROUGH A<RAND HGR 9839' 9849' 1-1 4-1/2" WLEG 1 1-1 ELMOTT LOGGBJ 11/18/00 1-1 7" X 4-1/2" XO I 9860' MlLLOUT WINDOW FROM 10207' - 10219' 1 10207' I-tTOPOFWHIPSTOCK 1 4-1/2" LNR, 12.6#, L-80, -¡ 14560' 1 IBT .0152 bpf, 10 = 3.958" PRUDHOE SA Y UNIT WELL: R-11A PffiMrr No: 1982060 A A No: 50-029-20893-01 SEC 32, T12N, R13E BP Exploration (Alas ka) ~ - ( ( BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage. Alaska 99519-6612 0, ,\' " ,b"P I ~ -r:, ' I ~' ,,~ ~, " June 18, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Rr-C E ~1"r¡"'"'' . I- ~ \\ .:" \:., Ib- I~ ,,,,",, ~ ~,.. JUN 2 3 2004 ,Alaske Oil [L '.."., ~. Subject: R-11A (PTO 1982060) Application for Sundry Approval to Continue Injection with Surface Casing Leak Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well R-11A (PTD 1982060). The purpose of this request is to continue WAG injection into R-11A with a surface casing leak. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. ;;¡~& Anna Dube Well Integrity Coordinator Attachments Application for Sundry form 10-403 Description Summary of Proposal Wellbore Schematic ORlhlMAL r {VJ~;~?z~!:~ ~ STATE OF ALASKA' r~~\t: ~C:, ~ \~.t ~t'~ ~,.,.) r ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 ~ 2004 -\ APPLICATION FOR SUNDRY APPROVAl. ,) ." 20 AAC 25.280fd~)~:¡((ì (,,H¡ " ' } - . ,. J ,. 1. Type of Request: Abandon 0 Alter Casing D Change, Approved Program 0 2. Operator Name: Suspend 0 RepairWell D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Exploratory D BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 51.15 KB 8. Property Designation: ADL-0028279 11. Total Depth MD (ft): ITotal Depth TVD (ft): 14560 8736.7 Casing Length Conductor 80 Liner 4724 Li ner 300 Production 10123 Surface 2656 Perforation Depth MD (ft): 13990 - 14050 14350 - 14410 Packers and SSSV Type: 4.1/2" Baker S.3 Perm Packer 4-1/2" Baker ZXP Packer 9-5/8" DV Packer 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 20" 91.5# H-40 4.1/2" 12.6# L.80 7" 26# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Perforation Depth TVD (ft): 8748.6 - 8746.9 8740.8 - 8739.7 4.5 " PerforateD WaiverŒ} Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 198-2060 30.0 8341.3 8399.9 28.0 29.0 12.6 # Packers and SSSV MD (ft): StratigraphicD Service Œ] 9. Well Name and Number: R-11A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): I Effective Depth TVD (ft): 14432 8688.1 S~ MD ND top bottom top 30 - 110 9836 - 14560 9907 - 10207 28 - 10151 29 - 2685 Tubing Size: BOP Sketch 0 13. Well Class after proposed work: Exploratory 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasD WAG ŒI GINJD July 2, 2004 Printed Name An~ Dube () /J Signature", C-V/\.;A..A..Á C..J... - ""- .I~ fIA.o ~ Conditions of approval: Notify Commission so that a representative may witness Commission Use Only Contact 6. API Number 50-029-20893-01-00 Plugs (md): Junk (md): None None Burst Collapse bottom 110.0 8736.7 8649.8 8602.7 2684.9 Tubing Grade: L-80 1490 8430 7240 6870 4930 Tubing MD (ft): 26 470 7500 5410 4760 2670 9839 9783 9836 2586 DevelopmentD Service ŒI Plugged 0 Abandoned 0 WINJD WDSPLD Prepared by Garry Catron 564-4657. Joe Anders I Anna Dube Title Phone Well Integrity Coordinator 659-5102 6/18/04 I Sundry Number: .30 l/.. ;2.. t./ I 0 L . ()yl tv, , tio Clearance, t L¡)a.{ 1;>' . ¡p P , . . MeP. hanc, i8, I' Int;g~lr~~B \toy ~ '1 , li¡i~ s i-/ 2-6{/¡"/~Z-OO"'f/' °' p¡. Test, :t&.'-.. ~~.[ , iL) P J-v if ca.- ( ~ ' - to{ I lA-1êA...;, rRLO ~y >. I \ ~/ t) t/\- eii ~l BY ORDERM~~ION Date: . ~EOOM ;'aQ.100~ORIGINAL ,^,_BFtL Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE ~. R-11 A Description Summary of Proposal 06/18/04 Problem: Injector with Surface Casing Leak Well History and Status Well R-11A (PTD 1982060) is a WAG injector with a surface casing leak. Summary of recent events: > 07/08/03: AOGCC MITIA Passed to 2500 psi. > 04/08/04: MITOA wi N2 FAILED. Leak to conductor wi N2 at 50 psi. > 04/23/04: AOGCC MITIA Passed to 4300 psi. / This sundry request is to allow for continued injection. The following supports the request: - A MITIA Passed to 4300 psi on 04/23/04, demonstrating competent tubing and production casing. - Pressures, temperature and injection rate are monitored and recorded daily. Proposed Action Plan 1. Allow well to continue WAG injection. 2. Record wellhead pressures, temperature, and injection rate daily. 3. Submit a monthly report of daily pressures, temperatures, and injection rates. 4. Perform an MITIA once every 2 years. 5. Notify the AOGCC of any indication of leaks or sustained fluids leaking from around the well. TREE = 4-1/16" 5MCIW W8..LHEAD = 13-518" 5M M:VOY SSH ACTl.1A. TOR = BAKffi KB. a.EV = 51.15' BF. a.EV = 21.68' KOP = 3096' Max Ange = 99 @ 10685' Datum MD = 10446' Datum TVD = 8800' SS 113-3/8" CSG. 72#, L-80,ID = 12.347" H 2689' ~ Minimum ID = 3.725" @ 9827' 4-1/2" HES XN NIPPLE I 4-1/2" TBG,12.6#, L-BO, H 9839' .0152 bpf, ID = 3.958" I' 1 TOP OF 4-1(2" LNR H 9837' I TOPOF7" LNR 1--1 9911' I 19-518" CSG, 47#. L-BO. ID = 8.681" 14 10155' 1 ÆRFORA TON SUMvlARY RB= LOG: N/A A NGLE AT TOP PERF: 92 @ 13990' Note: Refer to Production DB for historical perf data SIZE SFf. NTffiVAL Opn/Sqz DA TE 2-3/4" 6 13990 - 14050 0 12/21/98 2-3/4" 6 14350-14410 0 12/21/98 1 TOP OF CEtvENT 1-1 10254' I 17" LNR, 26#, L-80, .0371 bpf, ID = 6.184" I~ 10207' I OA.TE 1983 01/22/98 11/22/00 01/18101 02/27/02 REV BY COMtvENTS JJ ORlGINð.L COMA-EllON SIDElRAO<ID SIS-SL T CONVERTED TO CANV AS SIS-M) FINð.L RN/TP CORRECTIONS DATE REV BY R-11A ~ ~ ( SAÆTYNOTES: 70° @ 10410' AND 90° @ 10559' 1 2016' H4-1/2" HES XNIP,ID= 3.813" J =--I 2590' H 9-518" DV PKR I - - I :g . ~ ~ r \ ,/ , .L - ~ 9772' 9783' H 4-1/2" HES X NIP,ID = 3.813" I H 9-518" X 4-1/2" BAKffi 5-3 PKR, 10= 3.875" I H 4-1/2"HESXNIP,ID=3.813" 1 H 4-1/2" HES XN NP, ID = 3.725" I 9827' 9836' I- TE BACK SLEEVE BAKER 9-5/8" ZXP L T- A<R, BAKER FLEX-LOCK HGR, ID = 6.313" lHROUGH A<RAND HGR 9839' H 4-1/2" WLEG I 9849' H ELMD TT LOGGID 11/18100 I 9860' H 7" X 4-112" XO I MLLOUT WINDOW FROM 10207' - 10219' I 10207' HTOP OF WHPSTOCK I I A3TDH 14418' I ~ 14-1/2" LNR, 12.6#, L-80. H 14560' IBT .0152 bpf, ID = 3.958" I co MtvENfS PRUDI-K)E BA Y !...NIT WELL: R-11A PffiMT t\b: 198-2060 API t\b: 50-029-20893-01 see 32, T12N, R13E BP Exploration (Alaska) MEMORANDUM Jim Regg y,q ?/1IDtt P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: Lou Grimaldi DATE: Wednesday, April 28, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R-lIA TO: Petroleum Inspector PRUDHOE BAY UNIT R-I IA Src: Inspector Reviewed By: P.I. Suprv _1£ ~ '5lr:;I()4 Comm NON-CONFIDENTIAL API Well Number: 50-029-20893-0 I -00 Insp No: mitLG040423205630 Inspection Date: 4/23/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: R-lIA Type Inj. P TVD 9783 IA 230 4300 4230 4210 PoT. 1982060 TypeTest SPT Test psi 2445.75 OA 0 10 10 to Interval Other (describe in notes) P/F P Tubing 750 750 750 750 Notes: High pressure test for Sundry evaluation. Wednesday, April 28, 2004 Page 1 of I ~ ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / R Pad 04/08/04 Joe Anders ~mq4 I C(6 - J () ç, Email to: Winton_Aubert@admin.state.ak.us; Bob]leckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us 0 F Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = SaltWater Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU R-11A 04-08-04.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg / P.I. Superviso~ DATE: July 8, 2003 BPX Proudhoe Bay Field R Pad FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL Prudhoe Bay Field Packer Depth Pretest Initial 15 Min. 30 Min. I WellI R-11A I Typelnj. I S I T.V.D. 18297 I Tubingl 950 I ~o I ~o I ~0 I lntervall 4 I P.T.D.I 1982060 ITypetestI P ITestpsil 2000 I CasingI 600 I 25101 24601 24501 P/F I -P I Notes: OA pressure 0. 4.2 BBL's pumped. I WellI R-32A I Typelnj.[ G I T.V.D. I 8624 I Tubing 12700 12700 127_o_o4 2700 I,nterva, I 4I P.T.D.I 19soo9o ITypetestl P ITestpsil 2o00 I CasingI 180 I 25oo I~s~l 246ol P/F I P I Notes: Pretest OA psi. 0 240 psi. during test. 5.9 BBL pumped ~? I We,,I ,-~, I T~,~,.i.I ~ I T.V.~. 1~03 t Tu~,.~l ~0 I~0 I~0'1 ~0 I,,,~,1, P.T.D.I 1931530 ITypetestl P ITestpsil 2000 I Casingl 540 I 2500 I 2480 I 2480 I P/F I P Notes: POA pretest 220 psi. 540 psi. during test. 2.3 BBL pumped. Welll I Typ~ Inj. I I T.V.D. I I Tubing I I I I I'ntervall P.T.D. I I Type testl I Test psiI I Casing I I I I I P/F I Notes: I WellI Type Inj. P.T:D.I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 3 Attachments: Number of Failures: 0 Total Time during tests' 3 hr. CC: MIT report form 5/12/00 L.G. 2003-0708_MIT_PBU,R-34ic.xls 7/17/2003 ,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state. ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / R-PAD 07/08/03 Pat Lattner John Crisp WellI R-1 lA P.T.D.11982060 Notes: WellI R-32A P.T.D.11980090 Notes: WellI R-34 P.T.D.I1931530 Notes: WellI P.T.D.I Notes: WellI Notes: Packer Depths (ft.) J Pretest Initial 15 Min. 30 Min. I 9., 3'1 Type test Test psiI 20741 / Casingl 6001 25101 2460l 2450l P/FI ~. T,,~,,j. I~ I M~,~I ~,.~.'1 ~.~,'1 Tubingl 2700l 27001 27001 27001 Inte~a~ 4I Type test I P I Test P~l 2~561 I c~i.~l ~801 250012470124601P/FI P ~ i T'""'"¢t ~ IM~'~I ~'"~'1~'~0~'1Tu~'""I ~01 ~01 ~01 ~01 'nt~al4l Typetes~ P I Testpsil 21511 I Casin~l 5401 25001248012480lP/FI PI Type Inj. Type Inj. Test Details: 4-year MITIA's TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-0708_MIT_PBU-R-34.xls 'Emailing: MIT KRU 2nd qtr MITs for diagnostics.,"' Subject: Emailing: MIT KRU 2nd qtr MITs for diagnostics.xls Date: Sun, 6 Jul 2003 07:28:47 -0800 From: "NSK Problem Well Supv" <rtl 617@conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, tom_maunder~admin.state.ak.us, jim_regg~admin.state.ak.us CC: "nl 617" <nl 617@conocophillips.com> Attached are results from a few MIT's completed for diagnostic reasons during the month of June that have not previously been submitted for your review. 3F-03 (PTD 1852270) - well was SI during for LDS replacement during regular scheduled 4 year MIT's 1R-08 (PTD 1850730) - MITIA post braiden head work 3C-05 (PTD 1851540) - MITIA for diagnostics Please call if you have any questions Thanks MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043The message is ready to be sent with the following file or link attachments: MIT KRU 2nd qtr MITs for diagnostics.xls Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. (See attached file: MIT KRU 2nd qtr MITs for diagnostics.xls) ~_~MIT KRU 2nd qtr MITs for diagnostics.xls Name: MIT KRU 2nd qtr MITs for diagnostics.xls : Type: EXCEL File (application/msexcel) .Encoding: base64 I of I 7/11/2003 1:55 PI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ SCHM OO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 51 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4159' FNL, 3456' FEL, Sec. 32, T12N, R13E, UM (asp's 635465, 5977605) R-1 lA At top of productive interval 9. Permit number / approval number 1858' FNL, 1550' FEL, Sec. 06, T11 N, R13E, UM (asp's 632155, 5974567) 198-206 At effective depth 10. APl number 4654' FNL, 4344' FEL, Sec. 31, T12N, R13E, UM (asp's 629309, 5977000) 50-029-20893-01 At total depth 11. Field / Pool 4536' FNL, 4421' FEL, Sec. 31, T12N, R13E, UM (asp's 629229, 5977117) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 14560 feet Plugs (measured) true vertical 8737 feet Effective depth: measured 14418 feet Junk (measured) true vertical 8740 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 72 cf Concrete 140' 140' Surface 2659' 13-3/8" 3720 cf Permarost II 2689' 2689' Intermediate 10125' 9-5/8" 1412 cf Class 'G', 130 cf 10155' 8606' PF 'C' Liner 296' 7" 408 cf Class 'G' 9911' - 10207' 8403'- 8650' Sidetrack Liner 4722' 4-1/2" 730 cf Class 'G' 9837' - 14559' 8342' - 8737' Perforation depth: measured Open Perfs 13990'-14050', 14350'-14410' RECEIVED true vertical Open Perfs 874g'-8747', 8741'-8740' NOV 0 6 20O2 Tubing (size, grade, ~nd measured depth) 4-1/2", 12.6#, L-80, TBG @ g83g' MD. Nasle 011 & Gas ns. ( 0mml i ' :Packers & SSSV (type & measured depth) 9-5/8" DV PKR @ 2590'. 9-5/8" x 4-1/2" Baker S-3 PKR @ 9783'. ArlchOragf~ TB Sleeve BKR 9-5/8" ZXP LT PKR, BKR Flex-Lock HGR @ 9836'. HES X Nipple @ 2016'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 09/03/2002 2788 3194 Subsequent to operation 09/18/2002 11178 2906 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE R-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/30/2002 ANNCOMM 09/15/2002 SCMOO-B-GONE--SBG: SCMOO-B-GONE 09/16/2002 SCMOO-B-GONE--SBG: SCMOO-B-GONE 10/15/2002 TESTEVENT IN] PRESS, PSI: 2,417 TYPE: IVlI VOL: 7,482 EVENT SUMMARY 08/30/02 T/I/O = 3000/0/0 TEMP = 130 DEGREES. MONITOR (DSO CALLED IN FLUID INCONDUCTOR PIPE~. 09/15/O2 PUMPED DOUBLE SCHMOO-B-GONE TREATMENT. 240 BBLS SBG. LET SOAK FOR THREE HOURS. THEN ANOTHER 240 BBLS SBG. SOAKED FOR THREE HOURS AGAIN. 09/16/O2 PUMPED 590 BBLS 1% KCL WATER FOR OVERFLUSH ON SCHMOO-B-GONE TREATMENT. PUMPED 40 BBLS 50/50 METHANOL DOWN TUBING TO FREEZE PROTECT. <<< LEFT WELL SHUT IN >>>. 10/15/02 TESTEVENT INJECTION PRESSURE, PSI: 2,417, TYPE: MI Vol: 7,482 Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) 5 NEAT METHANOL 40 50/50 METHANOL WATER 480 SCHMOO-B-GONE 590 1% KCL WATER 1115 TOTAL Page I TREE: 4-1/1 ~' 5M CIVV ~/FI LHEAD: 13-5/8" 5M McVOY SSH ACTUATOR = BAKB~ ___ KB. ELEV: 51.15' BF. ELEV = 21.68' KOP = 3096' M__.ax_~A_n.~._~ .................~.99~ _~_ . ?_. .0.. 6_ _85_~ Datum MD = 10446' Datum TVD = 8800' SS I13-3/8" CSG, 72#, L-80, ID = 12.347" H IMinimum ID = 3.725" @ 9827' 4-1/2" HES XN NIPPLE 4-11'Z' TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" R-11A aJ ~ i 2016' 2590' 2689' 9772' 9783' 9807' 9827] 9839' 9836 TOPOF 4-1/2" LNR H 9837' SAFETY NOTES : 70° @ 10410' AND90° @ 10559' I TOPOF7" LNR H 9911' H4-1/Z' HES XNIP, ID= 3.813" I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 10155' H 9-5/8 " DV PKRI H 4 .1/2,,HESXNiP, iD=3.813,, i H 9-5/8" X 4-1/2" BAKER S-3 PKR,,D:3.875"I H 4 _1/2,,HESXNiP, iD=3.813,, i 4-1/2" HES XN NP, ID = 3.725" ITE BACK SLEEVE BAKER 9-5/8" ZXP LT- PKR, BAKER FLEX-LOCK HGR, ID = 6.313" 'tHROUGH PKRAND HGR 9839' H 4-1/2" WLEG [ I 984 ' H ELMDTT LOGGED 11/18/00 ] 9860' H 7" X 4-1/2" XO I PERFORATION S UIVIVIARY RI~ LOG: N/A ANGLEAT TOPPERF: 92 @ 13990' Note: Refer to Production DB for historical per[ data SIZE SPF NTERVAL Opn/Sqz DATE 2-3/4" 6 13990- 14050 O 12/21198 2-3/4" 6 14350- 14410 O 12/21/98 I TOP OF CEIVENT H 10254' t MLLOUT WINDOW FROM 10207' - 10219' 10207' HTOP OF WI-IPSTOCK I 17" LNR, 26~, L-80, .0371 bpf, ID= 6.184" H 10207' · 14-1/2"LIx~, 12.6~, L-80, ~-~ 14560' IIBT.0152 bpf, ID= 3.958" DATE REV BY COMIVENTS DATE REV BY OOMIVENTS 1983 JJ ORIGINAL COMPLETION 01/22/98 SIDETRACKED 11/22/00 SIS-SLT CONVERTED TO CANVAS 01/18/01 SIS-IVD FINAL 02/27/021 RN/-fP CORRECTIONS PRUDHOE BAY uNrr WELL: R-11A PERIVIT No: 198-2060 AP/No: 50-029-20893-01 SEC 32, T12N, R13E BP Exploration (Alaska) '19'8.206.0 Roll #1: Start: PRUDHOE BAY UNIT R-11A Stop Roll #2: Start 50- 029-20893-01 BP EXPLORATION (ALASKA) INC Stop MD 14560 TVD 08737 Completion Date: 12/21/98 Completed Status: WAGIN Current: Name CBL IMP-RES/GR-MD SRVY RPT 9020 9037 Interval Sent Received T/C/D FINAL 9866-10330 CH 5 1/4/99 1/5/99 FINAL 10200-14513 OH 2/25/99 3/3/99 T SCHLUM 10196.05-14504.26 OH 3/26/99 3/30/99 1 SCHLUM IMP-GR/RES-MD OH 2/25/99 3/3/99 2-7 SCHLUM IMPULSE OH 3/3/99 Thursday, January 25, 2001 Page 1 of 1 STATE OF ALASKA .__~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Siatus of Well Classification of Service Well ' ~ [] Oil [] Gas [-~Suspended I--]Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-206 3. Address 8. APl Number ~ · '' ~- ,~ !, .~: ~,~:..'., P.O. Box 196612, Anchorage, Alaska 99519-6612~ 50-029-20893-01 .~i%'i;:?;: .,'~ 4. Location of well at surface ~' ~- i 9. Unit or Lease Name 1121' NSL, 1824' EWL, SEC. 32, T12N, R13E, UM ~ -'i ~ ' ' ~FtiI~It Prudhoe Bay Unit At top of productive interval :::. ; 10. Well Number 1858' SNL, 1550' WEL, SEC. 06, T11N, R13E, UM ' "2~ .- R-11Ai At total depth -' / 11 Field and Pool 746' NSL, 4420' WEL, SEC. 31, T12N, R13E, UMw!' -~ ' ~'- .7 · ..... ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Design~ti0n and Serial No. Pool KBE = 51.15'I ADL 028279 12. Date Spudded I 13. Date I.D. Reached I 14. Date Comp., Susp., or Aband.l15. Water depth, if offshore I16. No. of Completions 12/2/98 12/14/98 12/21/98 N/A MSLI One 17. T~tal Depth (MD+TVD)118. Plug Back Depth (MD+-I-VD)I19. Directional Survey 120. Depth where SSSV set t21. Thickness of Permafrost 14560 8737 FTI 14432 8739 FTI [] Yes [] NoI (Nipple) 2016' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIP, GR, RES, DEN, NEU, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SE'II-lNG DEPTH HOLE ~ SiZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20"X 30" Insulated Conductor Surface 110' 36" .8 cu yds concrete 13-3/8" 72# L-80 Surface 2689' 17-1/2" :?720 cu ft Permafrost II 9-5/8" 47# L-80 Surface 10155' 12-1/4" 1412 cu ft Class 'G', 130.cu ft PF 'C' 7" 26# L-80 9911' 10207' 8-1/2" 408 cu ft Class 'G' 4-1/2" 12.6# L-80 9837' 14559' 6" 730 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9839' 9783' MD TVD MD TVD 13990' - 14050' 8749' - 8747' 14350' - 14410' 8741' - 8740' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel !![! /~ ! 27. PRODUCTION TEST ORl6 lu/4 Date First Production Method of Operation (Flowing, gas lift, etc.) March 1, 1999 Water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-DeL GAS-MCF WATER-BBL CHOKE S~ZE IGAS-O,L RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 10209' 8651' Shublik 10256' 8689' Shublik 'B' 10328' 8739' Shublik 'C' 10350' 8753' Top of Sadlerochit 10388' 8772' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~'~~ ~ (~'~) Terrie Hubble v - -' Title Technical Assistant III Date R-11Al 98-206 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM ,5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM ¢)1.' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB R Pad Well R-1 iA Page 1 Rig Nabors 2ES Date 15 January 99 Date/Time 26 Nov 98 06:00-09:00 09:00-14:00 14:00-18:00 18:00-23:00 23:00-23:30 23:30-02:00 27 Nov 98 02:00-04:30 04:30-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-09:00 09:00-10:00 10:00-10:30 10:30-20:00 20:00-21:00 21:00-22:00 22:00-22:30 22:30-01:30 28 Nov 98 01:30-06:00 06:00-07:30 07:30-08:30 08:30-09:30 09:30-14:00 14:00-15:00 15:00-16:30 16:30-19:00 19:00-22:30 22:30-01:30 29 Nov 98 01:30-06:00 06:00-07:00 07:00-08:30 08:30-09:00 09:00-11:00 11:00-12:00 12:00-13:00 13:00-17:00 17:00-19:30 19:30-21:00 21:00-03:00 30 Nov 98 03:00-03:30 03:30-06:00 06:00-10:00 10:00-11:45 11:45-12:00 12:00-13:00 13:00-16:00 16:00-17:30 17:30-18:00 18:00-19:30 19:30-21:30 21:30-22:00 22:00-00:00 01 Dec 98 00:00-01:00 Duration 3 hr 5 hr 4 hr 5hr 1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1 hr 1 hr 1/2 hr 9-1/2 hr 1 hr 1 hr 1/2 hr 3hr 4-1/2 hr 1-1/2 hr lhr lhr 4-1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 3-1/2 hr 3 hr 4-1/2 hr lhr 1-1/2 hr 1/2 hr 2 hr lhr lhr 4 hr 2-1/2 hr 1-1/2 hr 6hr 1/2 hr 2-1/2 hr 4hr 1-3/4 hr 1/4 hr lhr 3 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2 hr 1/2 hr 2 hr 1 hr Activity Rig moved 100.00 % Rigged up Drillfloor / Derrick Fill pits with Seawater Circulated at 9816.9 ft Installed Hanger plug Removed Adapter spool Rigged up BOP stack Tested BOP stack Tested BOP stack Retrieved BOP test plug assembly Retrieved Hanger plug Retrieved Tubing hanger Rigged up Tubing handling equipment Repaired Drillstring handling equipment Laid down 9815.0 ft of Tubing Held safety meeting Tested Blind ram Serviced Block line Made up BHA no. 1 R.I.H. to 6301.9 ft Singled in drill pipe to 9823.9 ft Fished at 9823.9 ft Circulated at 9823.9 ft Pulled out of hole to 326.8 ft Laid down fish Made up BHA no. 2 R.I.H. to 9836.9 ft Milled Permanent packer at 9836.9 ft Circulated at 9836.9 ft Pulled out of hole to 2301.8 ft Pulled out of hole to 321.8 ft Pulled BHA Made up BHA no. 3 R.I.H. to 7726.9 ft Serviced Block line R.I.H. to 8294.9 ft Pulled out of hole to 1.8 ft Laid down fish Made up BHA no. 4 R.I.H. to 10214.9 ft Tested Casing - Via annulus Circulated at 10214.9 ft Pulled out of hole to 291.9 ft Pulled BHA Held safety meeting Made up BHA no. 5 R.I.H. to 10101.9 ft Logged hole with LWD: DIR/DD from 10101.9 ft to 10211.9 ft Drilled cement to 10237.9 ft Circulated at 10260.9 ft Pulled out of hole to 6001.8 ft Serviced Block line Pulled out of hole to 371.8 ft Pulled BHA Progress Report Facility PB R Pad Well R- 1 lA Rig Nabors 2ES Page 2 Date 15 January 99 Date/Time 02 Dec 98 03 Dec 98 04 Dec 98 05 Dec 98 06 Dec 98 07 Dec 98 01:00-03:30 03:30-06:00 06:00-08:00 08:00-09:00 09:00-17:00 17:00-18:30 18:30-23:00 23:00-00:30 00:30-02:30 02:30-06:00 06:00-14:30 14:30-17:00 17:00-21:00 21:00-21:45 21:45-22:15 22:15-01:30 01:30-02:30 02:30-03:30 03:30-06:00 06:00-09:00 09:00-10:30 10:30-16:30 16:30-17:00 17:00-21:00 21:00-23:00 23:00-00:00 00:00-00:15 00:15-04:00 04:00-06:00 06:00-06:00 06:00-15:30 15:30-16:00 16:00-06:00 06:00-12:00 12:00-12:30 12:30-13:30 13:30-16:00 16:00-17:00 17:00-18:00 18:00-19:30 19:30-20:30 20:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-10:00 10:00-11:00 Duration 2-1/2 hr 2-1/2 hr 2hr lhr 8hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 2 hr 3-1/2 hr 8-1/2 hr 2-1/2 hr 4hr 3/4 hr 1/2 hr 3-1/4 hr 1 hr lhr 2-1/2 hr 3 hr 1-1/2 hr 6hr 1/2 hr 4hr 2 hr lhr 1/4 hr 3-3/4 hr 2 hr 24 hr 9-1/2 hr 1/2 hr 14hr 6 hr 1/2 hr lhr 2-1/2 hr lhr lhr 1-1/2 hr 1 hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr lhr Activity Made up BHA no. 6 R.I.H. to 3901.8 ft R.I.H. to 10231.9 ft Set tool face Milled Other sub-surface equipment at 10208.9 ft Circulated at 10232.9 ft Pulled out of hole to 251.9 ft Pulled BHA Made up BHA no. 7 R.I.H. to 10223.9 ft Drilled to 10351.9 ft Circulated at 10351.9 ft Pulled out of hole to 1.8 ft Pulled BHA Made up BHA no. 8 R.I.H. to 7561.8 ft Serviced Block line R.I.H. to 10323.9 ft Drilled to 10426.9 ft Drilled to 10571.9 ft Circulated at 10571.9 ft Pulled out of hole to 751.9 ft Pulled BHA Tested BOP stack Made up BHA no. 9 Singled in drill pipe to 2001.8 ft Held safety meeting Singled in drill pipe to 4651.9 ft R.I.H. to 10351.9 ft Drilled to 11691.9 ft Drilled to 12161.9 ft Repaired Bell nipple Drilled to 12601.9 ft Drilled to 12671.9 ft Held safety meeting Drilled to 12796.9 ft Circulated at 12796.9 ft Flow check Drilled to 12836.9 ft Circulated at 12796.9 ft Pulled out of hole to 11501.9 ft Circulated at 11401.9 ft Held safety meeting Pulled out of hole to 10101.9 ft Serviced Block line R.I.H. to 12191.9 ft Circulated at 12191.9 ft Flow check Circulated at %s Flow check Pulled out of hole to 10194.9 ft Circulated at 10194.9 ft Flow check Circulated at 10194.9 ft Progress Report Facility PB R Pad Well R-11A Rig Nabors 2ES Page 3 Date 15 January 99 Date/Time 08 Dec 98 09 Dec 98 10 Dec 98 11:00-12:00 12:00-12:30 12:30-15:00 15:00-17:00 17:00-18:30 18:30-21:00 21:00-23:30 23:30-02:00 02:00-04:30 04:30-06:00 06:00-08:00 08:00-11:30 11:30-12:00 12:00-12:30 12:30-14:30 14:30-15:30 15:30-17:00 17:00-18:00 18:00-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-04:00 04:00-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-09:30 09:30-12:00 12:00-12:30 12:30-13:30 13:30-14:30 14:30-15:00 15:00-17:00 17:00-17:30 17:30-18:30 18:30-19:30 19:30-20:00 20:00-20:30 20:30-21:30 21:30-00:00 00:00-00:30 00:30-01:00 01:00-02:30 02:30-04:00 04:00-04:30 04:30-06:00 06:00-08:00 08:00-09:30 09:30-12:00 12:00-12:30 12:30-13:00 13:00-14:30 Duration 1 hr 1/2 hr 2-1/2 hr 2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 2 hr 3-1/2 hr 1/2 hr 1/2 hr 2 hr 1 hr 1-1/2 hr 1 hr 4 hr lhr 1 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr lhr lhr 1 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr lhr 1/2 hr 2hr 1/2 hr lhr lhr 1/2 hr 1/2 hr lhr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr Activity Pulled out of hole to 8001.9 ft Held safety meeting Pulled out of hole to 5001.8 ft Pulled out of hole to 51.8 ft Pulled BHA Made up BHA no. 10 R.I.H. to 10233.9 ft Worked toolstring at 10233.9 ft Pulled out of hole to 4001.8 ft Pulled out of hole to 1.8 ft Made up BHA no. 11 R.I.H. to 10233.9 ft Circulated at 10233.9 ft Held safety meeting R.I.H. to 12594.9 ft Circulated at 12594.9 ft Pulled out of hole to 10203.9 ft Washed to 10236.9 ft Pulled out of hole to 181.8 ft Pulled BHA Serviced Block line Held safety meeting R.I.H. to 10236.9 ft Reamed to 10236.9 ft Singled in drill pipe to 10401.9 ft Reamed to 10570.9 ft R.I.H. to 12207.9 ft Reamed to 12231.9 ft Laid down 400.0 ft of 5in OD drill pipe Reamed to 12566.9 ft Held safety meeting Pumped out of hole to 12401.9 ft Circulated at 12401.9 ft Pumped out of hole to 12201.9 ft Circulated at 12201.9 ft Circulated at 12201.9 ft Circulated at 12201.9 ft Batch mixed slurry - 50.000 bbl Mixed and pumped slurry - 50.000 bbl Displaced slurry - 160.000 bbl Pulled out of hole to 9831.9 ft Circulated at 9831.9 ft Held safety meeting R.I.H. to 12171.9 ft Circulated at 12171.9 ft Circulated at 12171.9 ft Mixed and pumped slurry - 50.000 bbl Displaced slurry - 160.000 bbl Pulled out of hole to 9801.9 ft Circulated at 9801.9 ft Pulled out of hole to 4801.8 ft Held safety meeting Serviced Kelly Pulled out of hole to 1.8 ft Progress Report Facility PB R Pad Well R-11A Rig Nabors 2ES Page 4 Date 15 January 99 Date/Time 14:30-15:30 15:30-18:30 18:30-19:30 19:30-21:30 21:30-00:00 11 Dec 98 00:00-00:30 00:30-01:00 01:00-01:30 01:30-04:30 04:30-06:00 06:00-08:00 08:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-20:30 20:30-23:00 23:00-00:00 12 Dec 98 00:00-00:30 00:30-01:00 01:00-03:00 03:00-04:30 04:30-06:00 06:00-08:30 08:30-12:00 12:00-12:30 12:30-13:00 13:00-00:00 13 Dec 98 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-15:00 15:00-15:30 15:30-16:00 16:00-00:00 14 Dec 98 00:00-00:30 00:30-06:00 06:00-09:30 09:30-12:00 12:00-12:30 12:30-14:30 14:30-16:00 16:00-17:00 17:00-18:00 18:00-19:30 19:30-00:00 15 Dec 98 00:00-00:30 00:30-02:30 02:30-06:00 06:00-07:30 07:30-09:30 09:30-11:00 11:00-12:00 Duration lhr 3hr 1 hr 2hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr 1-1/2 hr 2 hr 4hr 1/2 hr lhr 1/2 hr 6-1/2 hr 2-1/2 hr lhr 1/2 hr 1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 3-1/2 hr 1/2 hr 1/2 hr llhr 1/2 hr 5-1/2 hr 6hr 1/2 hr 2-1/2 hr 1/2hr 1/2 hr 8hr 1/2 hr 5-1/2 hr 3-1/2 hr 2-1/2 hr 1/2 hr 2 hr 1-1/2 hr 1 hr lhr 1-1/2 hr 4-1/2 hr 1/2 hr 2 hr 3-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 1 hr Activity Rigged up High pressure lines Tested BOP stack Rigged down High pressure lines R.I.H. to 4801.8 ft R.I.H. to 10461.9 ft Held safety meeting Reamed to 10501.9 ft R.I.H. to 12078.9 ft Reamed to 12318.9 ft Circulated at 12318.9 ft Circulated at 12318.9 ft Reamed to 12571.9 ft Held safety meeting Circulated at 12571.9 ft Pulled out of hole to 12023.9 ft Reamed to 12836.9 ft Circulated at 12836.9 ft Pulled out of hole to 11301.9 ft Held safety meeting Serviced Block line Pulled out of hole to 4801.8 ft Pulled out of hole to 1.8 ft Made up BHA no. 14 R.I.H. to 5001.8 ft R.I.H. to 10201.9 ft Held safety meeting R.I.H. to 12836.9 ft Drilled to 13070.9 ft Held safety meeting Drilled to 13301.9 ft Drilled to 13531.9 ft (cont...) Held safety meeting Drilled to 13690.9 ft Pulled out of hole to 12501.9 ft R.I.H. to 13690.9 ft Drilled to 14038.9 ft Held safety meeting Drilled to 14401.8 ft Drilled to 14561.9 ft (cont...) Circulated at 14561.9 ft Held safety meeting Pulled out of hole to 10161.9 ft Serviced Block line R.I.H. to 11571.9 fi Circulated at 11571.9 fi R.I.H. to 14561.9 ft Circulated at 14561.9 fi Held safety meeting Circulated at 14561.9 ft Pulled out of hole to 8001.9 ft Pulled out of hole to 5001.8 ft (cont...) Pulled out of hole to 401.9 ft Pulled BHA Rigged up Casing handling equipment Progress Report Facility PB R Pad Well R- 1 IA Page 5 Rig Nabors 2ES Date 15 January 99 Date/Time 16 Dec 98 17 Dec 98 18 Dec 98 19 Dec 98 12:00-12:30 12:30-18:30 18:30-19:00 19:00-20:00 20:00-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-05:00 05:00-06:00 06:00-10:30 10:30-11:30 11:30-12:30 12:30-13:00 13:00-18:30 18:30-22:30 22:30-00:00 00:00-00:30 00:30-03:30 03:30-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-09:00 09:00-11:00 11:00-13:00 13:00-13:30 13:30-15:00 15:00-20:00 20:00-20:30 20:30-21:00 21:00-21:30 21:30-00:00 00:00-00:30 00:30-02:30 02:30-04:30 04:30-06:00 06:00-07:00 07:00-12:00 12:00-12:30 12:30-16:00 16:00-22:30 22:30-00:00 00:00-00:30 00:30-01:30 01:30-02:30 02:30-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-10:30 10:30-11:00 Duration 1/2 hr 6hr 1/2 hr lhr 3hr lhr 1/2 hr 1/2 hr 4hr 1 hr 4-1/2 hr lhr lhr 1/2 hr 5-1/2 hr 4 hr 1-1/2 hr 1/2 hr 3 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2hr 2 hr 1/2 hr 1-1/2 hr 5 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2 hr 2 hr 1-1/2 hr 1 hr 5 hr 1/2 hr 3-1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 1 hr lhr 1 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr Activity Held safety meeting Ran Liner to 4701.9 ft (4-1/2in OD) Installed Liner hanger Circulated at 4701.9 ft Ran HWDP on landing string to 10201.9 ft Circulated at 10201.9 ft Held safety meeting Circulated at 10201.9 ft Ran Liner on landing string to 14561.9 ft Circulated at 14561.9 ft Circulated at 14561.9 ft (cont...) Mixed and pumped slurry - 130.000 bbl Displaced slurry - 215.000 bbl Set Liner hanger at 9837.9 ft with 4000.0 psi Circulated at 9837.9 ft Pulled Drillpipe in stands to 1.8 fl Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Worked toolstring at 10331.9 ft Conducted electric cable operations Rigged down Logging/braided cable equipment Retrieved Wear bushing Installed BOP test plug assembly Tested BOP stack Held safety meeting Installed Wear bushing Rigged up Drillstring handling equipment R.I.H. to 4601.9 ft Serviced Block line Rigged up Drillstring handling equipment Made up BHA no. 15 R.I.H. to 9837.9 ft Held safety meeting R.I.H. to 13845.9 ft Washed to 14046.9 fl Circulated at 14001.9 ft Circulated at 14001.9 ft (cont...) Reamed to 14301.9 ft Held safety meeting Reamed to 14413.9 ft Circulated at 14413.9 fl Pulled out of hole to 12001.9 fl Held safety meeting Pulled out of hole to 9755.9 ft Tested Liner Pulled out of hole to 6001.8 ft Laid down 2865.0 fl of 3-1/2in OD drill pipe Rigged up Drillstring handling equipment Pulled out of hole to 1.8 fl Pulled BHA Rigged up Slickline unit Conducted slickline operations on Braided cable equipment - Tool run Rigged down Slickline unit Facility PB R Pad Progress Report Well R-1 lA Page 6 Rig Nabors 2ES Date 15 January 99 Date/Time 20 Dec 98 21 Dec 98 11:00-12:00 12:00-12:30 12:30-16:30 16:30-20:30 20:30-21:00 21:00-23:00 23:00-00:00 00:00-00:30 00:30-01:30 01:30-02:30 02:30-05:00 05:00-05:30 05:30-06:00 06:00-09:30 09:30-11:30 11:30-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-23:30 23:30-00:00 00:00-00:30 00:30-03:30 03:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-07:00 07:00-08:30 08:30-10:00 10:00-13:00 13:00-15:00 Duration lhr 1/2 hr 4 hr 4 hr 1/2 hr 2 hr 1 hr 1/2 hr 1 hr lhr 2-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 2hr 1/2 hr 1/2 hr 1 hr 1/2 hr 9-1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr lhr 1/2 hr 1/2 hr lhr 1-1/2 hr 1-1/2 hr 3 hr 2 hr Activity Rigged up Drillstring handling equipment Held safety meeting Installed TCP Ran Drillpipe in stands to 14419.9 ft Perforated Reverse circulated at 9701.9 ft Pulled out of hole to 12001.9 ft Held safety meeting Pulled out of hole to 8501.9 ft Serviced Block line Laid down 3500.0 ft of Drillpipe Retrieved TCP Rigged up Drillstring handling equipment Laid down 4450.0 ft of 2-3/8in OD drill pipe Retrieved TCP Retrieved Wear bushing Held safety meeting Rigged up Completion string handling equipment Installed Packer & tailpipe assembly Ran Tubing to 9840.9 ft (4-1/2in OD) Installed Tubing hanger Held safety meeting Reverse circulated at 9801.9 ft Freeze protect well - 150.000 bbl of Diesel Stung into Tie back packer Set packer at 9784.9 ft with 4000.0 psi Tested Tubing - Via string Tested Casing Tested Tubing Rigged down BOP stack Rigged up Surface tree Rigged down High pressure lines ANADRI LL SCHLUMBERGER Survey report ~lient ................... : BP~."xploration (Al~aska)~I~rc. Field .................... : Pr~hoe Bay q~ 14-Dec-98 09:27:28 -- Field Print -- Well ..................... : R-11Ai Spud date ................ : 26-Nov-98 API number ............... : 50-029-20893-01 Last survey date ......... : 14-Dec-98 Page 1 of 6TM Engineer ................. : Nutter Total accepted surveys...: 138 MD of first survey ....... : 10196.05 ft MD of last survey ........ : 14504.26 ft|u~'~<'~y-~~Of~ Rig: .................... : Nabors 2ES ............... : Nabors 2ES State: .................. : Alaska ..... Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Magnetic dip ............. : 80.72 degrees Depth reference .......... : GL above permanent ....... : ,.__ 19.90 ft KB above permanent ....... : 51.15 ft DF above permanent ....... : 49.75 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ 0.00 ft 0.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1997 Magnetic date ............ : 30-Dec-1997 Magnetic field strength..: 1146.39 HCNT Magnetic dec (+E/W-) ..... : 28.19 degrees MWD sur'_v~y Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1146.39 HCNT Reference Dip ............ : 80.70 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of-Dip ......... : (+/-) 0.30 degrees Platform reference pointr Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 328.91 degrees Corrections . -- Magnetic dec (+E/W-) ..... : 27.73 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W.) .... : 27.73 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 ANADRILL SCHLUMBERGER Su~ey Report Seq Measured Incl Azimuth Co~rse # depth angle angle length ~ {ft) (deg) !deg). (ft~ __ --1 10196.05 32.42 227,3_i_ 0.00 2 1021-9.64 34.72 227,1 2~3.60 3 10249.93 39.04 228,4 30.30 4 10280.58 44.12 228,9 30.70 5 10298.01 46.74 229,3 17.40 6 10312.98 48.70 229,6 15.00 7 10345.10 53.41 230,2 32.10 8 10378.77 61.35 230,9 33.70 9 10410.34 70.63 233,0 31.50 10 10440.87 78.05 239,2 30.60 11 10471.86 79.31 249,3 31.00 12 10503.64 79.03 259,0 31.70 13 10520.87 79.83 263,5 17.30 14 10527.07 81.29 264,6 6.20 15 10559.15 87.91 271,3 32.10 16 10623.33 93.46 274,9 64.10 17 10653.44 96.08 276,7 30.10 18 10685.23 99.05 277,4 31.80 19 10717.33 98.12 279,1 32.10 20 10749.26 95.51 282,4 32.00 21 10781.06 92.37 282,2 31.80 22 10813.26 91.03 282,0 32.20 23 10844.18. 90.99 281,5 30.90 24 10876.40 91.03 281,4- 32.20 25 10908.40 91.20 281,8 32.00 26 10940.44 91.27 281,5 32.00 27 10972.75 91.34 281,3 32.30 28 11004.92 91.34 281,-L. 32.20 29 11036.91 91.54 280,7 32.00 30 11069.16 90.86 282,4 32.30 · TVD depth (ft) 8640.62 8660.28 8684.51 8707.47 8719.68 8729.77 8749.94 8768.10 8780.90 8789.16 8795.26 8801.23 8804.41 8805.42 8808.45 8807.68 8805.18 8800.99 8796.20 8792.40 !4~Dec-98 09:27~28 Page Vertical Displ. section +N/S-. (ft) (ft) -78~. 56 -2889.52 -- L788.21 -2898.39 -791.74 -2910.61. -795.38 -2924.08 -797.49 -2932.19 Displ Total +E/W- displ (ft) (ft) ~3270.62~ 4364.20 -3280.19 4f77.25 ~3293 · 65 4395.43 ~3308.93 4415.79 ~3318 · 30 4428.19 At Azim (deg] 228.54 228.54 228.53 228.53 228.53 2 of 6 DLS (deg/ 100f) 0.0~ 9.76 14.45 16.60 15.15 -799.31 ~2939.41 -3326.73 4439.29 228.54 13.15 -803.21 ~2955.48 ~3345.82 4464.24 228.54 14.74 -807.33 ~2973.50 -3367.73 4492.58 228.56 23.63 -810.79 ~2991.20 -3390.37 4521.27 228.58 30.08 -812.21 ~3007.58 -3414.81 4550.44 228.63 31.11 -809.38 ~3020.77 -3442.16 4579.68 228.73 32.20 -801.20 -3029.26 ~3472.07 4607.78 228.90 30.07 -794.74 ~3031.85 ~3488.87 4622.16 229.01 25.98 -792.14 -3032.48 -3494.96 4627.16 229.05 29.34 -776.64 ~3033.61 ~3526.86 4652.04 229.30 29.27 -740.64 -3030.15 -3590.82 4698.49 229.84 10.32 -722.64 ~3027.12 ~3620.66 4719.39 230.10 10.55 ~703.17 ~3023.25 -3651.94 4740.96 230.38 9.59 ~683.05 -3018.70 ~3683.35 4762.31 230.66 5.98 -661.86 ~3012.77 ~3714.56 4782.75 230.96 13.09 8790.21 ~640.07 -3006.01 -3745.55 4802.63 231.25 8789.26 -618.04 ~2999.26 ~3777.02 4823.02 231.55 8788.71 -597.03 ~2992.97 -3807.2~-- 4842.85 231.83 -- 8788.15 ~575.27 ~2986.58 -3838.83 4863.77 232.12 8787.52 ~553.57 ~2980.15 -3870.17 4884.62 232.40 8786.83 -531.86 -2973.69 -3901,50 4905.56 232.69 8786.10 -510.05 -2967.31 ~3933.16 4926.93 232.97 8785.35 ~488.39 ~2961.05 ~3964.7-3 4948.43 233.25 8784.54 ~466.99 -2955.00 ~3996.15 4970.03 233.52 8783.87 -445.11 ~2948.54 ~4027.78 4991.69 233.79 9.89 4.21 1.62 0.33 1.36 0.96 0.66 0.62 1.40 5.67 Srvy tool type TIP MWD M MWD M MWD M MWD M MWD M MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qua 1 type 6-axis 6~'-axis 6-axis 6-axJ_s 6-a x i s 6-axis 6-a×i s 6-axi s 6-axis 6-axis 6-axis 6-axis 6-a xJ. s 6-axi s 6-axis 6-axis 6-axJ. s 6-axJ. s 6-axis 6-axis 6-axis 6-axis 6-axis [(C)!998 Anadril! IDEAL ID5 0C 01R] ANADRILL SCHLUMBERGER Sukizey Report Seq 31 32 33 34 35 Measured Incl Azimuth Co~rse depth angle angle length {ft) (deg) (deg), (ft). 11094~.81 89.69 284,1 ~ 25.60 1112~. 82 88.70 286,3 3F. 00 11159.02 88.90 289,2 32.20 11191.35 88.87 292,7 32.30 11222.71 90.14 295,4 31.40 36 11260.53 91.95 298,1 37.80 37 11292.47 92.92 301,1 32.00 38 11323.39 91.99 303,8 30.90 39 11355.39 91.89 303,1 32.00 40 11387.16 92.13 304,5 31.80 41 11419.30 92.26 303,9 32.10 42 11448.22 92.37 302,8 28.90 43 11480.53 91.47 304,8 32.30 44 11513.36 89.49 303,9 32.90 45 11543.31 89,35 302,5 29.90 46 11575.38 89.52 302,3 32.10 47 11605.81 89.66 304,0 30.40 48 11637.88 89.66 305,5 32.10 49 11666.55 89.52 305,7 28.70 50 11698.74 89.31 305,4 32.10 51 11729.22 89.14 304,6 30.50 52 11761.34 88.94 303,9 32.10 53 11792.60 88.80 305,8__. 31.30 54 11824.84 88.63 305,4-- 32.20 55 11857.27 88.53 306,2 32.50 56 11889.21 89.38 305,8 31.90 57 11921.29 89.59 306,5 32.10 58 11953.31 89.38 305,-~. 32.00 59 11985.36 88.94 304,7 32.10 60 12013.32 88.66 303,6 27.90 TVD depth (ft) 8783.74 8784.19 8784.87 8785.50 8785.77 8785.08 8783.72 8782.39 8781.31 8780.20 8778.97 8777.80 8776.72 8776.44 8776.75 8777.06 8777.28 8777.47 8777.67 8778.00 8778.42 8778.95 8779.57 8780.29 8781.10 8781.68 8781.97 8782.26 8782.73 8783.31 14-Dec-98 09:27:58 Page 3 of 6 · . Vertical Displ section +N/S- (ft} (ft) -427,22 -2942.67 -404.10 -2934.28 -379.86 -2924.47 -354.40 -2912.92 -328.64 -2900.13 Displ T-otal At DLS +E/W- displ Azim (deg/ (ft~ . (ft) (deg~ i00f) ._ -4052.70~ 5008.36 234.02 8 -4083.58 5028.48 234.30 7.54 -4114 . 23 5047.72 234 . 59 9.03 -4144 . 39 5065.68 234 . 90 10.83 -4173.06 5081.85 235.20 9.50 -296.65 -2883.12 -268.78 -2867.33 -241.14 -2850.77 -212.27 -2833.14 -183.49 -2815.46 -4206.80 5099.96 235.58 8.60 -4234.60 5114.04 235.90 9.84 -4260.65 5126.40 236.21 9.23 -4287.33 5138.86 236.54 2.21 -4313.74 5151.23 236.87 4.46 -154.35 -2797.43 -128.30 -2781.56 -99.07 -2763.60 -69.15 -2745.04 -42.21 -.2728.67 -4340.27 5163.68 237.20 1.91 -4364.39 5175.42 237.49 3.82 -4391.21 5188.47 237.82 6.79 -4418.37 5201.66 238.15 6.61 -4443.39 5214.34 238.45 4.71 -13.49 -2711.47 13.89 -2694.84 43.18 -2676.55 69.53 -2659.84 99.00 -2641.18 -4470.49 5228.51 238.76 0.82 -4495.94 5241.73 239.06 5.61 -4522.32 5255.02 239.38 4.67 -4545.65 5266.66 239.67 0.85 -4571.77 5279.86 239.98 1.14 126.88 -2623.6~ 156.05 -2605.62 184.62 -2587.74 214.19 -2569.00 244.07 ~2550.00 -4596.75 5292.81 240.28 2.68 -4623.28 5306.97 240.59 2.27 -4648.96-- 5320.64 240.90 6.09 -- -4675.13 5334.48 241.21 1.35 -4701.48 5348.50 241.53 2.48 273.45 ~2531.25 303.03 ~2512.34 332.53 -2493.48 361.93 -2474.96 387.26 -2459.3~ -4727.29 5362.32 241.83 2.94 -4753.22 5376.33 242.14 1.98 -4779,'~8 5390.46 242.45 1.99 ~4805.29 5405.20 242.75 3.69 -4828.37 5418.61 243.01 4.07 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axJ. s 6-axis 6-axis 6-axis 6-axis 6-axJ. s 6-axis 6 -axis 6-axis 6-axis 6-axis 6-axJ_s 6-axJ. s 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1998 Anadril! IDEAL ID5_0C_01R] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle ~ (ft) (deg) (deg), ' -61 12048.53 88.0~ 304,8~ 62 120-g0.36 89.35 304,4 63 12110.25 89.49 305,3 64 12141.87 88.94 304,6 65 12169.37 88.66 305,0 Course length (ft~ 35.20 31.90 29.80 31.70 27.50 66 12199.01 88.46 305,1 67 12230.81 90.31 306,5 68 12263.65 92.23 310,4 69 12294.81 92.81 311,3 70 12326.72 93.40 314,1 29.60 31.80 32.80 31.20 31.90 71 12357.96 92.92 316,7 72 12396.05 92.13 319,6 73 12427.82 92.06 322,8 74 12460.01 91.65 325,7 75 12491.39 91.44 328,6 31.30 38.10 31.70 32.20 31.40 76 12523.77 90.72 329,9 77 12555.71 90.31 332,9 78 12587.57 90.65 334,0 79 12619.65 90.58 334,1 80 12651.36 90.21 332,7 32.40 31.90 31.90 32.00 31.80 81 12683.00 89.66 332,6 82 12714.90 89.21 333,8 83 12767.83 88.70 336.A_ 84 12804.79 88.22 336,6- 85 12837.69 87.74 336,6 31.60 31.90 52.90 37.00 32.90 86 12869.91 87.49 336,8 87 12901.86 89.18 335,7 88 12933.36 92,92 334r8 89 12965.12 96.77 334,1 90 12996.60 98.22 333,1 32.20 32.00 31.50 31.70 31.50 TVD depth (ft) 8784/31 8785.03 8785.33 8785.76 8786.34 8787.08 8787.43 8786.70 8785.33 8783.60 8781.87 8780.19 8779.03 8777.99 8777.14 8776.53 8776.25 8775.98 8775.64 8775.42 8775.45 8775.77 8776.73 8777.73 8778.89 8780.23 8781.16 8780.58 8777.90 8773.79 !4~Dec-98 09:27728 Vertical section (ft) ~ 4__,..!9.22 448~28 475.49 504.46 529.55 556.61 585.86 616.58 646.21 676.79 Displ +N/S- (ft) Displ +~./W- (ft~ ~'. -2439. -2421. -2404. ~2386. -2370. -2353. -2334. -2314. ~2294. -2272. 53 ~4857.4~ 42 -4883.72 39 -4908.18 23 -4934.16 54 -4956.73 55 -4980.96 95 -5006.75 56 -5032.42 17 -5056.00 57 -5079.41 707 744 775 808 839 871 903 935 967 999 1030 1062 1114 1151 1184 1216 1247 1279 1310 1341 .18 .57 .96 .03 .40 .79 .66 .46 .33 .03 .56 .37 .95 .61 .19 .07 .79 .09 .52 ,64 -2250. -2221. -2197. -2171. ~2144. -2116. -2088. -2060. -2031. -2003. -1.975. -1946. -1898. -1864. -1834. -1805. ~1775. -1747. -1718. -1690. 32 -5101.35 97 -5126.74 29 -5146.59 17 -5165.39 81-5182.41 97 -5198.98 96 -5214.24 43 -5228.50 66 -5242.50 22 -5256.74 16 -5271.26 68 -5285.64 72 80 -5322.66 62 -5335.72 07 -5348,44 80 -5361.32 2O -5374.--51 71. ~5388.13 73 -5402.01 Page 4 of 6 Total At DLS Srvy displ Azim (deg/ tool (ft~ (d~g) i00f) type 5435.65 243.33 3..7_9 MWD ~451.06 243.63 4.17 MWD 5465.46 243.90 3.06 MWD 5480.88 244.19 2.81 MWD 5494.42 244.44 1.78 MWD 5509.00 244.71 0.76 5524.45 245.00 7.30 5539.18 245.30 13.25 5552.15 245.59 3.43 5564.62 245.90 8.96 5575.64 246.20 8.43 5587.54 246.57 7.88 5596.02 246.88 10.09 5603.14 247.20 9.09 5608.71 247.52 9.26 5613.46 247.84 4.59 5617.13 248.17 9.49 5619.84 248.49 3.61 5622.41 248.82 0.38 5625.50 249.14 4.55 5629.16 249.46 1.77 5632.73 249.78 4.02 5637.29 250.32 5.01 5639.87 250.69 1.41 5642.31 251.03 1.46 5644.83 251.35 0.99 5647.76 251.67 6.30 5651.37 251.99 12.21 5655.60 252.31 12.34 5660.42 252.62 5.58 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qua 1 type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axJ_s 6-axis 6-axis 6-axis 6-axJ_s 6-axis 6-axJ_s 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axJ. s 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(C)!998 Anadril! IDEAL ID5 0C 01R] ANADRILL SCHLUMBERGER ~urvey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg~ --- 91 130128.14 95.1~ 332~.. 92 1~J~61.05 91.99 331,0 93 13092.47 90.14 329,2 94 13124.59 90.14 329,8 95 13156.24 89.90 329,4 Course length (ft). 31.50 -32.90 31.50 32.10 31.60 96 13187.74 89.90 329,5 97 13219.83 90.62 326,8 98 13252.49 91.37 327,2 99 13284.13 91.20 327,7 100 13315.90 91.13 327,0 31.50 32.10 32.70 31.60 31.80 101 13347.01 91.34 326,7 102 13378.87 91.03 326,5 103 13410.83 90.86 326,7 104 13442.44 90.72 326,1 105 13474.16 91.10 325,9 31.10 31.90 31.90 31.60 31.80 106 13505.83 92.61 327,1 107 13538.08 92.20 326,8 108 13569.88 92.71 326,7 109 13601.93 92.64 326,8 110 13634.14 92.19 326,6 31.60 32.30 31.80 32.00 32.20 111 13665.13 91.44 327,1 112 13695.13 91.23 326,7 113 13727.48 91.10 3~.6~.~ 114 13758.94 90.34 327'73 115 13791.17 89.83 327,4 31.00 30.00 32.40 31.40 32.30 116 13821.88 89.6.6 327,4 117 13853.77 90.58 327,0 118 13885.59 92.47 3~,0 119 13917.32 92.26 327,5 120 13949.78 91.85 327,0. 30.70 31.90 31.80 31.70 32.50 TVD depth (ft) 8770.12 8768.06 8767.48 8767.40 8767.39 8767.44 8767.30 8766.73 8766.02 8765.37 8764.70 8764.04 8763.52 8763.08 8762.58 8761.55 8760.20 8758.84 8757.34 8755.99 8755.00 8754.31 8753.65 8753.25 8753.20 i4-Dec~98 09:2%:28 Vertical Displ section +N/S- (ft) (ft) 1372.86 ~1662. 1405.65 ~1634. 1437.14 -1606. 1469.24 -1579. 1500.83 -1551. 1532.33 ~1524. 1564.43 -1497. 1597.10 ~1470. 1628.68 ~1443. 1660.47 ~1416. Dispt +E/W- (ft~ 95 -5~16.~8 07 -5432.00 77 -5447.70 11 -5463.99 86 -5479.98 1691.54 -1390. 1723.41 -1363. 1755.28 -1337. 1786.84 ~1311. 1818.60 ~-1284. Page 1850.15 -1258. 1882.40 ~1231. 1914.15 -1204. 1946.09 -1178. 1978.24 -1151. - Total At displ Azim (ft) {deg} 5665.92 252.93 5672.46 253.26 5679.71 253.57 5687.60 253.88 5695.47 254.19 2009.21 ~1125. 2039.18 ~1100. 2071.55 ~1073. 2102.92 ~1046. 2135.21 ~1019. 73 -5495.99 5703.57 254.49 47 -5512.93 5712.69 254.80 05 -5530.73 5722.77 255.12 42 -5547.73 5732.43 255.42 65 -5564.88 5742.37 255.72 8753.34 2165.90 -993. 8753.27 2197.79 -966. 8752.43 2229.55 -940. 8751.12 2261.21 -913. 8749.95 2293.68 -886. 62 -5581.89 5752.50 256.01 99 -5599.44 5763.18 256.31 36 -5617.00 5774.01 256.61 04 -5634.49 5785.00 256.90 68 -5652.27 5796.42 257.20 35 -5669.70 5807.66 257.49 30 -5687.30 5819.06 257.78 73 -5704.72 5830.54 258.08 00 -5722.24 5842.24 258.37 11 -5739.91 5854.19 258.66 17 -5756.85 5865.78 258.94 04 -5773.23 5877.10 259.21 00 -579t.~6 5889.63 259..50 70 -5808~1 5901.77 259.78 50 -5825.63 5914.17 260.07 64 -5842.17 5926.07 260.35 82 -5859.45 5938.68 260.63 17 -587~.76 5951.49 260.91 53 -5893.90 5964.27 261.19 21. -5911.43 5977.53 261.47 5 of 6 DLS (deg/ 100f) 10.36 8.19 1.87 1.48 0.32 8.71 2.60 1.67 2.21 1.18 1.16 0.82 1.95 1.35 6.10 1.57 1.63 0.38 1.53 2.91 1.51 0.74 3.51 1.61 0.55 3.14 5.94 1.71 1.99 s rvy tool type MWD MWD MWD MWD MWD lV~D MWD MWD IVg~D MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M%~ D IV~D MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-a×is 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)!998 Anadril! IDEAL ID5 0C 01R] ~ ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) _ 121 i~3982.61 91.~2 327z3 122 140T3.27 91.65 327[6 123 14045.29 91.47 328.1 124 14075.30 91.23 327.0 125 14107.39 91.20 327.1 126 14139.36 91.34 327.7 127 14171.56 91.13 327.0 128 14203.83 91.30 326.9 129 14234.42 91.17 326.8 130 14266.53 90.89 326.9 131 14298.34 90.96 326.7 132 14328.76 91.13 326.4 133 14360.34 91.17 325.9 134 14392.36 91.06 327.3 135 14423.49 90.89 326.8 136 14454.95 91.23 326.9 137 14487.04 91.20 326.6 138 14504.26 91.13 326.8 Course length (ft) 32.80 30.70 32.00 30.00 32.10 TVD depth (ft) 8748.88 8747.92 8747.05 8746.34 8745.66 14-Dec-98 09:27:28 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) S2326.44 -858.67 -5929__~25 23~7.12 -832.81 -5945.76 2389.10 -805.72 -5962.78 2419.09 -780.41 -5978.88 2451.16 -753.48 -5996.33 Page 6 of 6 Total At DLS displ Azim (deg/ (ft) (deg) ~O0f) 5991.10 261.76 40,94 6003.80 262.03 1.31 6016.97 262.30 1.66 6029.59 262,56 3.75 6043.49 262,84 0.33 32.00 8744.95 2483.14 -726.53 -6013.57 6057.30 32.20 8744.26 2515.32 -699.43 -6030.93 6071.36 32.20 8743.57 2547.50 -672.44 -6048.49 6085.76 30.60 8742.92 2578.07 -646.83 -6065.22 6099.61 32.10 8742.34 2610.14 -619.96 -6082.77 6114.28 Srvy tool type MWD MWD MWD MWD MWD 31.80 30.50 31.50 32.10 31.10 263.11 1.92 MWD 263.38 2.27 MWD 263 . 66 0.61 MWD 263.91 0.54 MWD 264 . 18 0 · 93 MWD 8741.82 2641.92 -593.35 -6100.18 6128.97 264.44 0.67 8741.27 2672.39 -567.91 -6116.99 6143.30 264.70 1.13 8740.64 2703.84 -541.75 -6134.53 6158.41 264.95 1.59 8740.01 2735.91 -514.96 -6152.20 6173.71 265.22 4.37 8739.48 2766.99 -488.87 -6169.11 6188.45 265,47 1.70 MWD MWD MWD MWD I,fWD 31.50 8738.90 2798.46 -462.50 -6186.33 6203.60 32.00 8738.22 2830.43 -435.74 -6203.88 6219.16 17.30 8737.87 2847.72 -421.29 -6213.37 6227.64 2 65 . 72 1 . 13 MWD 265.98 0.94 MWD 266.12 1.22 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [{c)1998 Anadrill IDEAL ID5 0C 01R] 2/25/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99,503 AI-fN: Sherrie NO 12374 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape R-11A ~ ~O"'&.O 99085 IMPULSE/GR/RES 981214 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 995'19-6612 Date Delivered: (:Iii & (';as (lo~s. (;ol~'idssion Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK A'I-I'N: Sherrie(~ ~¢) ~i - p, Received by"x.~4 1/4/99 GeoQuest 3940 Arctic Bird Anchorage, AK 99,503 AI'I'N: Sherrie NO. 12200 Company Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Color Well Job # Log Description Date Print Blueline Sepia LIS Tape D-27 98491 CNTD 980308 1 1 R-15 LAI C_.. INJECTION PROFILE 981216 1 1 R-1 lA CEMENT BOND LOG 981217 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd .- Anchorage, AK 99503 ~ ATTN: Sherrie ~ Receive~. '~~ BP EXPLORATION ARCO Alaska, Inc To: Blair Wondzell Dec 17th 1998 From: Philippa Stevenson, SSD MB 8/34 Subject: R-11ai EHST Regarding well R11Ai, the subject of a drilling permit 98-206 approved on10/16/98. A horizontal sidetrack has been drilled from the existing Rll well ( as permitted) and it is our intention to return the well to water injection once the completion has been run. Evaluation of the cement bond log for Rll in the 7" casing shows there to be 296' of good cement bond above the top of the sag river. The side-track was kicked off at the top of the sag and a 4-1/2" liner run and cemented with the hanger in the 9-5/8" casing above the top of the existing 7" liner. A CBT was run to evaluate this cement job and only reached 10330' showing 78ft of good bond below the top of the Sag River. Please advise whether this is acceptable for a water/gas injection well. It is possible that CBT log could be run deeper in the 4-1/2" after the completion has been run if deemed necessary. Please find attached a summary of the evaluation carried out by Schlumberger and a completion diagram. Prepared by:"l°~Pq_ o~~ Approved by: ~---~,'~.~ Nabors 2ES Ops. Drlg. Engr. St, Drlg. Engr BP Exploration (Alaska) Inc. Prudhoe Bay Well R-1 1al 12/16/98 Evaluatin_~ CBT Loq 12/16/98 Sidetrack ~ The cement bond quality (zone isolation) between the 7" liner and the 4 W' liner over the measured depth 991 lft-10207ft,shows 46ft of excellent bond, The cement bond quality (zone isolation) in the 4 ~" liner over the measured depth 10207ft-10330ft shows 78ft of excellent bond. Total excellent bonded interval in 4 ~" above 10330ff is thus 124ft. The tool could not descend deeper that 10330ft so bond quality below this point is not known. This interpretation is based on the VDL(5ft) and amplitude/attenuation signal analysis(2.4ff and 3.4ff). .Ori_qinal wellbore(CBL 12/07/83) The cement bond quality (zone isolation) behind the 7" liner above the top of the Ivishak @ 10343 fl MD is excellent to the base of the 9-5/8" easing set @ 10158 ft. The Sag River formation is from 10207 to 10239 ff and is perforated from 10204 to 10238 ff. This is based on strong formation arrivals and weak pipe arrivals measured by the variable density log (VDL). Across the 7" liner lap with the 9-5/8" casing, the cement bond is excellent from the 10158 ft to 9908 ft. Based on the VDL formation signal and Iow amplitude from the first casing arrival from the 7" liner. Above the 7" liner lap, the CBL was not set up to measure the cement quality behind the 9-5/8" casing, DeWayne Schnorr/Graham Stuart 7 998 1,,2/17/98 12:54 FAX 907 564 51.93 BP EXPLORATION -> At)GCC [~003 ........................ R:~ Ai EHS'I'(P ' - t~" " TREE: 7-1/16"-SM-UcEvoy ~1 roposed Sta N^soRs 2ES WELLHEAD: 13-5/8" j KB. ELEV -- 51' 5M McEvoy SSH~, ' NOTE; THIS WELL WILL CONTAIN AN X NIPPLE AT 2000' NOT AN ~ ~ I ~--7' x 4-1/2" CROSSOVER RECENT BP SSSV MANAGEMENT -- ~ IMPLEMENTATION PLAN _.. ~ ~ ~ --6.8PPG DIESEL FREEZE FOG -~ ~ ~ ~. PROTECTION AT +/- 2200' MD L-80, BTRS @ 2685' . 4-1/2", 12.6#/ft, L-80 NSOT TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT I "X 4-1/2" PRODUCTION ~ = I-------PACKER @ +/-9780' ~~ ]~ I 0-5/8' X 4-1/2" L~NER , t~ ~t~l~ 4 1/2", 12.6#/ft, L-80 IBT LINER ,, WHIPSTOCK SET ON CEMENT ~_ i 6 TD @ 14560' WINDOW 10207'- 10219' ___.__ 4 1/2" X NIPPLE, @@ 10472/10465'-"-'- ~1~[~ 3.813" ID (OTIS) 4 1/2" XN NIPPLE, @ 10470'~''~'' 3.725" ID (OTIS)J 4 1/2" WLEG (ELMD) , . PBTD @ 10855 ---.--.--- TD @ 10900' ~ ~ 7", 29#, L-80 ~J4S ii !, i~1 iiiii ii i iiii i jill i iii DATE REV. BY COMMENTS ...... PRUDHOE BAY UNIT 9-29-98 pas ., Proposed ,,StatuS, , WELL: R-11Al . ............. APl NO: S0-025-20893_-01 ....... BP Explorafi'0n (Alaska) 'v' D ~.Coma~io~ MEMORANDUM TO: David Johnston, State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 17, 1998 THRU' Blair Wondzell,~~0"~ FILE NO: P. I. Supervisor /96 aimklqfe.doc FROM: Chuck Scheve, ~ __,~ SUBJECT: Petroleum Inspector BOPE Test Nabors 2ES PBU R-11Ai PTD # 98-206 Thursday, December 17, 1998: I traveled to BPXs R-11Ai well and witnessed the weekly BOPE test on rig 2ES. As the attached AOGCC BOPE Test Report shows there was one failure. The inside BOP (dart valve) failed to pressure test. This valve was repaired and retested after I departeed location. The testing went very well with good test procedures being employed by the Nabors crew. The rig was clean and all equipment seemed to be in good working order. The location was clean and all extra equipment was properly stored. Summary: I witnessed the weekly BOPE test on Nabors Rig 2ES drilling BPXs R-11Ai well. NABORS 2ES, 12117/98, Test Time 3.5 Hours, One Failure Attachment: aimklqfe.xls X Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASK OIL AND GAS CONSERVATION coMM -SSlON BOPE Test Report OPERATION: Drlg: X Workover: DATE: 12/17/98 Drlg Contractor: NABORS Rig No. 2ES PTD # 98-206 Rig Ph.# 659-4836 Operator: SSD Rep.' Sheridan Whip Well Name: R-llAi Rig Rep.: Kieth Spools Casing Size: Set @ Location: Sec. 32 T. 12N R. 13E Meridian Test: Initial Weekly X Other Um. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test 1 250 250 250 250 2 Press. P/F /3500 P /5000 P /5000 P /5000 P 250/5000 P 250/5000 P 250/5000 P N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 500/5,000 P 500/5,000 F CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 14 250/5,000 32 250/5,000 1 Functioned Functioned P/F P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 {~,2200 3,000 P 1,500 P 0 minutes 25 sec. minutes 45 sec. YES Remote: YES Psig. Number of Failures: '/ ,Test Time: 3.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days.~lofify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. 1. Supervisor at 279-1433 REMARKS: Dart Valve failed to pressure test. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector F1-021L (Rev. 12.194) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: aimkk:lfe Chuck Scheve TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: ~907) 276-7542 October 16, 1998 James E. Smith Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit R-11At~ BP Exploration (Alaska) Inc. Permit No: 98-206 Sur Loc: 1121'NSL. 1824'EWL. Sec. 32, T12N. R13E. UM Btmhole Loc. 643'NSL, 4478~,VEL, Sec. 31, T12N, R13E. UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv laxv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the i~ection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission max' witness the tests. Notice max' be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Gmne. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA · ALASKA -~,~-AND GAS CONSERVATION COb,-...,~SSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas []Single Zone ~ Multiple Zone 2. Name of Operator !5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 51' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028279 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1121' NSL, 1824' EWL, SEC. 32, T12N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3535' NSL, 1456' WEL, SEC. 06, T11N, R13E, UM R-11Ai At total depth 9. Approximate spud date Amount $200,000.00 643' NSL, 4478' WEL, SEC. 31, T12N, R13E, UM 10/26/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028257, 403'I No Close Approach 2560 14520' MD / 8720' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10200' MD Maximum Hole Angle 98.4 o Maximum surface 2520 psig, At total depth (TVD) 8800' / 3400 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT 4470' 10050' 8363' 14520' 8720' 523 sx Class 'G' OCT 19. To be completed for Redrill, Re-entry, and Deepen Operations. .¢-_. Present well condition summary '~ ~: Total depth: measured 10904 feet Plugs(measured) ~i~!10J~&GasC0i~.~Dli~l~~ i~-~ L true vertical 9152 feet ,~lCti0rag~ Effective depth: measured 10737 feet Junk (measured) Fill at 10737' MD (09/88) true vertical 9107 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2655' 13-3/8" 3720 cu ft Permafrost II 2689' 2689' Intermediate 10121' 9-5/8" 1412 cuft Class 'G', 130 cuft PF 'C' 10155' 8606' Production Liner 993' 7" 408 cuft Class 'G' 9911' - 10904' 8403' - 9152' Perforation depth: measured 10204' - 10240' (Sag River) 10344' - 10375', 10390' - 10450', 10480' - 10500' (Ivishak) Sqzd: 10500' - 10520' true vertical subsea 8593' - 8623' (Sag River) 8712' - 8846' (three Ivishak intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Philipj;~,Stevenson, 564-5738 Chris Brown, 564-5582 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th,,e~oreg4::)ing)C/true~ ,¢1~d correct to the best of my knowledge Signed ~' '"'/ "~'/////' James E. Smith,S, ~.~/~.~ Title Senior Drilling Engineer Date ~ ""'~'" '"' ~ - f') Commission Use Only Permit Number I APl Number Approval Date I See cover letter c~ ~ _ ~ 0 (oI 50-029-20893-01 ,,/E)~//~,-vO~', for other requirements Conditions of Approval: Samples Required []Yes [~'No Mud Log Required []Yes [-~No Hydrogen Sulfide Measures I~Yes [] No Directional Survey Required [~Yes [] No Required Working Pressure for DOPE []2K; []3K; []4K; ,I~L5K; [] 10K; [] 15K Other: by order of Approved By ,.~,'u~li'lS.l SICJf!.~d ~Y Commissioner the commission Date//~ ~'~ --,~ Submit In Triplicate uavid ~/ Form 10-401 Rev. 12-01-85 ]Well Name: IR-11Ai HST Sidetrack Summary ]Type of Well: l WAG Injector Surface Location: 1120' FSL, 3456' FEL, S32, T12N, R13E, UM Target Location: 3535' FSL, 1456' FEL, S06, T11N, R13E, UM Bottom Hole Location: 643' FSL, 4478' FEL, S31, T12N, R13E, UM I AFE Number: 14P1149 ] I Estimated Start Date: I 10/26/98 I I Rig: I Nabors 2ES I Operating days to complete: IuD: 114520, I I TVD: 18720 ss I I KB Elev. I Extended Horizontal Sidetrack I I Well Design: 125 151' Objective: IThis well is to be drilled as a horizontal sidetrack. The new sidetrack will provide injection conformance in Zone 4 and replace the injector M12i. The well has an undulating profile through Zone 4. Formation Markers Formation Tops TSag Kick Off Point 10194' 10200' TVD (ss) 8588' 8595' TSHU 10237' 8625' TSAD 10359' 8710' TD 14520 8720' HOT NR 8965' Directional ImOP: 11°,2°°' MD Maximum Hole Angle: Rig Move Close Approaches: Drilling Close Approaches: 98.1 ° through target 5 & 6 R-25 will be 34' from R-11Ai and will be shut in during'the rig move. None Casing/Tubing . rogram Hole Size Tubular Wt/Ft Grade Conn' Length Top Btm O.D. MD/TVDss MD/TVDss 6" 4-1/2" 12.6g LB0 IBT 4470' 10050'/8363' 14520'/8720' Production Tubing NA ] 4-1/2" 12.6# LB0 IBT 10000' surf/surf 10000'/8320' Mud Program Milling Interval: 6% Quickdiln Density, ppg Funnel Vis, secI LSRVI pH I APl FL, cc 8.7-8.8+ 50 - 65 45,000 - 65000 8.5 - 9.0 NC Hazards/Concerns [ Maintain viscosity at 50 - 65 to insure adequate removal of metal cuttings. Ensure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Production (6" hole) Section: 6% Quickdriln (viscosified SW) Density, ppg I Funnel Vis, secI LSRV [ pH I APl FL, cc 8.7- 8,8+ I 50- 65 I 45,000- 65000 8.5- 9.0 NC Hazards/Concerns Potential high torque could require lubricant use. If so, employ Lubetex. Be alert for lost circulation, differential sticking due to overbalanced MW (approx 600 psi differ- ential.) Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8+ ppg. The well profile crosses 4 faults so be prepared with LCM. Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments 4-1/2" N/A 523 / 15.7 / 1.19 Class G: 50% excess; TOC 10050' MD, 8363' TVD SS Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Open Hole Logs: 6" Hole Cased Hole Logs: Logging Program MWD Dir/GR/Res/Den Neu No open hole logs unless MWD resistivity unavailable or unusable Cement Evaluation log Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Bottom hole pressure is expected to be 3400psi @ 8800' TVDSS. Maximum expected surface pressure is 2520 psi (assuming gas column of 0.1psi/ft) Hazards The main production target for this well is Zone 4. A 25' throw, EW fault will be instersected midway through the target polygon. Three other smaller faults (10-15') throw will also be intersected. However recent wells drilled in this area have not experienced severe losses, even whilst drilling through major faults. The faults near R pad tend to be cemented up with pyrite. Therefore, although lost circulation is not expected to be a problem, preparations should be made to pump LCM if necessary. No potential close approaches have been identified while drilling this well. Risk of differential sticking is low based on offset wells, but should it occur, will be mitigated by the use of the Quikdriln drilling fluid which is solids free and does not form a filter cake. Sag River At R11 the Sag River is in pressure communication with the sands below and should be around 3320 psi. Although differential sticking is still a concern it has not occurred on recent sag wells with lower pres- sures. The pad data sheet indicates that only one well (R-36i) has experienced major lost circulation in this production interval, most other drilling wells experiencing only minor losses. Ivishak Differential sticking has occurred frequently on older wells in the Ivishak at +/-9183' TVD. Once the sticking occurs it is very strong and has created difficulty in freeing up the drillstring. On R-35A, the sticking was successfully alleviated by pumping a 20bbl pill of Liquid Casing, OM Seal, and Barafibre and reducing pump rate to 5bpm (to reduce ECD). Note however that these wells were drilled using LSND mud; since this well will employ solids free Quikdriln, this should mitigate the risk of sticking. High torque has been reported on several older wells in the production hole, hence some open hole lu- brication may be required. The pad data sheet incorporates wells from R, F and J pad as the bottom hole location of these wells are all in the same area. Wells from all three pads have experienced problems with bridges, tight hole, differential sticking, and packing off while in the production interval. This has caused numerous incidents of stuck logs, casing, and drillstring. This is a high potential stuck pipe area - be alert while drilling this interval and employ frequent reaming if any sign of unstable hole is seen. Note however, that recent R-pad wells have not experienced any trouble from sticking and it is expected that this well will be drilled without a significant sticking problem. Disposal All cuttings should be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion fluids and other Class 1I wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. Operations Summary Pre- Rig Work NOTE: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the wellhead manufacturer to initiate repairs and inform the Operations Drilling Engineer. 1. Test 9-5/8" packoff and tubing hanger packoff to 5,000psi. If annulus has not been recently (_<1 month) tested, pressure test to 4,000psi. , R/U 1.75" coiled tubing unit. RIH to PBTD at 10859' and spot a balanced cement plug from TD to 10080'. Attempt to squeeze 5bbls of cement to perforations before RIH to 10240' and circulate out excess cement with contaminant to obtain the required TOC. Highest acceptable TOC is 10240' in order to leave room to set whipstock at required depth for kick-off. Circulate the well bottoms up to clean seawater prior to POOH. RD coiled tubing. Let the plug set up, then tag with slickline. Note: A positive pressure test on the cement plug should not be attempted to avoid the potential of breaking down the cement in the squeezed perforations above the top of cement. Will request weight test requirement only from AOGCC. ,, R/U Wireline and RIH with chemical cutter to cut tubing at 9822', lft below collar in 5-1/2" pup joint above K-anchor. 1. Circulate seawater through cut in tubing until clean returns are obtained. Freeze protect tubing and annulus to 2,200ft with diesel. Bleed pressures on tubing/annulus. Zero psi on all annuli required. 2. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Rig Work: , Check with PE's on pre-rig work status. MIRU. Circulate the well to clean seawater. Pull BPV and ensure well stands full of fluid. Set/test TWCV. N/D tree, N/U and test BOP rams to 5000 psi, an- nular to 3500 psi. Pull TWCV. 2. Pull existing 5-1/2" completion. 3. RIH with overshot fishing assembly and engage K-anchor. Retrieve K-anchor with 18 turns to the right and POOH. (no PBR run) 4. RIH with milling assembly and mill up the SAB-3 packer. Retrieve the packer and the remainder of the existing 5-1/2" completion. , RIH with 7" RTTS and scraper on drillpipe spaced out to scrape 7"liner to 10,225' (to scrape across EZSV setting depth) with RTTS set at 10,050'. Set RTTS at 10,050' and test the 9-5/8" casing and 7" x 9-5/8" liner lap to 4000psi. 6. R/U wireline unit. Set EZSV at _+ 10220' (placed for window kick off at 10200'-10212'). R/D electric line unit. RIH with bottom trip whipstock and set on EZSV. Shear off and mill window in 7". POOH. 4 7. RIH with 6" drilling assembly with 4 phase resistivity LWD and tag TD of new hole. Displace well to drilling fluid, and drill section to TD of 14520' as per directional plan. 8. M/U and run ,-,4500' of 4-1/2" L80 IBT liner to 14520', cement liner in place and set liner hanger at + 10050'. Run cement evaluation log. , R/U and run 4-1/2" L80 completion with 7"x4-1/2" production packer set at _+ 10000' and standard WOA tailpipe. Circulate freeze protection to _+2,200'MD. Land completion and set packer. Tail pipe shoud be stung into 4-1/2" liner top. 10. Set and test BPV, ND BOP, NU tree. RDMO. TREE: 7-1/16"-SM-McEVOY R I 1 KB. ELEV=55.10' WELLHEAD: 13-5/8" - 5M - McEVOY - SSH -- BF. ELEV = 21.40' ACTUATOR: OTIS [ O SSSVLANDINGNIPPLEI 9 5/8" DV PACKER (CAMCO)( 4.562" ID) 1999 I2590' I ~ O0 GAS LIFT MANDRELS ( OTIS 5 1/2" W/PA Latch) 13-3/8" 72#/ff L-80 BTRS N-° MD(BKB) TVDss I 2689' I ~ i~ 6 3004 2947 5 5724 5158 I i 4 : 7938 6783 [ KOP: 2800' r~] 39321 7867 MAX ANGLE: 46 deg 2 9734 8202 I 9803 8257 5-1/2" 17# L-80 IJ4S/TC4S TUBING TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT ~ ~ S-1/2" X NIPPLE I I I (OTIS) (4.455" ID) 9843 ~-.j [. --~"-- BAKER K-22 ANCHOR 9847 .~-- 9-5/8" PERM PACKER I · (BAKER 'SAB-3') (4.75" ID) 9848 "~ 5-1/2" "X" NIPPLE I I (OTIS) (4.562" ID) 9874 5-1/2" "XN" NIPPLE TIEBACK RECEPTACLE 9-5/8" 47# L-80 BTRS I 10155 PERFORATION SUMMARY REF: LOG: BHCS SlZl~~ SPF INTERVAL OPEN 'SQZ'D I 10204-10240 OPEN 10344-10375 OPEN ~ I 10390-10450 OPEN 7" MARKER JOINT 10382 10480-10500 OPEN 1 0500-1 0520 SQZ'D ~ TOP 7" OTIS "WD" PKR I 10461 -- --~ (OtiS) (3.813" id) 10469 I I 4-1/2 .... XN" NIPPLE I I (OTIS) (3.725" ID) 10474 ~, , 4-1/2" WLEG 10476 (ELMD) 7" 26# L-80 I 10904 I ~ · IJ4S DATE REV. BY COMMENTS PRUDHOE BAY UNIT 1/30/83 Initial Completion WELL: R-11 f32-06-11-13~ 9-19-90 DFF POST 1990 RWO APl NO: 50-029-20893 ~dated Plug SEC 6: TN 11N: RGE 13E 12-20-94 HUGHES L ,nrc BP Exploration (Alaska) GAS LIFT MANDRELS OTIS 5 1/2" W/PA Latch) N-° MD(BKB) TVDss 6 3004 2947 5 5724 5158 4 7938 6783 3 9321 7867 2 9734 8202 1 9803 8257 NABORS 2ES TREE: 7-1/16"-5M-McEvoy R.. 1AiEHST(Proposod Stat, is)KB. ELEV 51 WELLHEAD: 13-5/8" = ' 5M McEvoy SSH _ ,, "~ ~ ' ~ .... BF. ELEV = 21.4' NOTE: THIS WELL WILL CONTAIN AN X NIPPLE AT 2000' NOTAN SSSV IN COMPLIANCE WITH BELOW TUBING HANGER RECENT BP SSSV MANAGEMENT ~ IMPLEMENTATION PLAN 6.8PPG DIESEL FREEZE FOC ~ ~:;~?~ '. :, ¢~:.~;~;;:~:::~¢~.~:. ~: PROTECTION AT +/- 2200' MD ......... 8.5PPG SEAWATER :~:: i~ :;z z: ~ ~:: ~ ~:.~ .:~.~ ~ ~ ~ ..........:... ..... :::::::::::::::::::::::::::::: 4-1/2", 12.6¢/~, L-80 TUBING ID: 3.958" ..... ..... .... . .. .... ....... :.: .............. :. ..... .... · . .. ............... :. :...::..:..:: .: ...... 4 1/2", 12.6¢/ff, L-80 TAILPIPE ~:::':.~ ¢~;?~:.:* ~ 4 1/2" WLEG STABBED INTO WOA CO N FI G U RATIO N ~ N L I N E R T O P HANGER/PACKER ~ 10,050' ?~.?::~:';::'~ ~:~?~:~& 4 1/2", 12.6¢/~, L-80 IBT LINER WHIPSTOCK SET ON CEMENT--~ ';'~:;:~;:;~:~:::;'~;~;~(;';:~*~':::~:"::~ 6" TD ~ 14520' RETAINER~ 10220' __ (FOR WINDOW 10200'- 10212') CEMENT RETAINER ~ -10,225' TOO (pre rig - 10240') 3.813" ID (OTIS) 4 1/2" XN NIPPLE, ~ 10470'~ 4 ~/2" Wk~ ~ ~0472~ (~) PBTD ~ 10855 TD ~ 10900' i k 7", 29¢, L-80 IJ4S DATE REV. BY COMMENTS PRUDHOE BAY UNIT 9-29-98 PAS Proposed Status WELL: R-11Al APl NO: 50-029-20893-01 BP Exploration (Alaska) Anadril ] Schlumberger Alaska Oistrict 5940 A/eric Blvd Anchorage, AK 99503 (907] 273 - 1700 Fax 273 -8537 DIRECTIONAL WELL PLA~I for SHARED SERVICES DRILLING ~4ell ......... : R-1IA (P3A] Field ........ : Pruhdhoe Bay Computation..: Minimum Cur~aSure Unihs ........ : FEET Surface Lat..: 70.34670242 Surface Long.: 148.90033448 Legal Surface ...... ; 1120 F~L 3456 Tie-in survey: 3510 FSL ~456 'Tazx3et 1 ..... : 3534 FSL 2510 Ta~c3et 2 ..... : 3849 FSL 2934 Target 3 ..... : 4099 FSL 3259 Ta~et 4 ..... : ~923 FSL 3826 Ts_~c3et 5 ..... : 5273 FSL ~055 ~}{L .......... : 643 FSL 4478 LOCATIONS - ALASKA Zone: ~ Description X-Coord Y-Coord FEL ~32 TI2N RT3E LD4 635464.91 59776~5,09 FEL S06 TllM R/3E tim 6322%7.31 5974657.L6 FEL S06 Tl lN RL3E UM 631192.74 5974662,62 FEL ~06 TllN RL3E ~4 630762.15 S974969,8~ FEL S06 TllN R13E UIK 630432.71 5975213.93 FEL S06 T1TN RI3E ~4 629847.94 5976~$.43 FEL SO6 TL1N R13E ~4 62~611,67 5976374.19 FEL S31 TL2N R13E U~ 629175,03 59770L6.35 Prepared ..... : 23 Sep 1998 vert sect az.: 320.43 KB elevatioo.: 49.30 ft Ma§he,it Dcln: ,27,769 Scake Factor.: 0,99992085 Convergence,,: +1.03561893 I x;.? ,j- STATION ,'3 EDE~I' I PICOT I ON TI E- IN ~ Kce/um~ ia/too S~LIK M]~AeURED rNCLN DIRECT/ON DEPTH ANGLE AZ IMUTH 10194.20 32.42 10200.00 32,35 ~0237.22 36.93 10150.00 38.63 VERTICAL-DEPTF~S SECTION TVD SUB-SEA DEPART 8637.30 85~8.00 227.30 8638.77 8589.47 -143.93 227.25 8645.67 $594.37 -144.10 235.88 %674.30 8625.00 -143,59 236.42 8584.40 8635,10 -i42.67 Cni~O C 10300.00 45.70 1035~.~0 53.24 10359,08 54.64 246.74 8721,47 8672,17 -155,46 253.22 8753.96 8704.66 -122,65 254,25 8759.30 8710.00 -119.75 C00RDIAIATES-FROM ALASKA Zone 4 TOOL DL/ WELL~]~AD X Y FACE L0O 2889,52 S 32?0.62 W 632247.31 5974657.16 L601 <TIE 2891.63 S 3272.90 ~ 632245.06 5974655.01 5~R 1.2~ 290~.68 S 3289,49 ~ 632228.71 597.4641.63 ~908.92 S 3296.07 W 632229.22 5974637.51 ~IR 2924.19 S 3325.86 W 632[92.70 597~621.51 3~R 18,00 2937.06 S 3361.55 W 63~157,26 5974607.99 3~R 18,09 29'39,12 S 33~8.59 W 632150.25 5974605.$1 308 18.00 Z P (Anadrill (c)98 RllAP3A 3,2C 4:28 23 Sep 1998 Pa~e 2 STATION MF2%SURED INCLN DIRECTION VERTICAL-DEPTHS [ D~I FI CATION DEPTH ANGLE AZINUTH TVD S[IB -SF2% SECTION COORf~IIAkTE$-~ROM ALASKA Zone 4 DEPART WELL}lEAD X Y TSAD 10359,0~ 5{.64 254.25 8759.30 6710.00 10~00.00 61.07 258,51 8781.07 8731.77 10450.00 69,08 263.05 8802.13 8752.83 10700.00 77.19 267.12 8S~6.63 8767.33 10550.00 85.36 270.94 ~824.21 8774.91 TOOL DL/ FACE 180 -%19.75 293~.12 S 336~.59 W 632150.25 5974605,81 30R 18.00 -104,.55 2947.22 S 3402.25 W 632116.75 597~597.10 28R 18.00 -81.62 2954.42 S 5446,96 W ~32072.18 5994589.09 26R 18.~0 -54.41 2958.~8 S 3494.5~ W 652024.64 5974584.18 27R 18.00 -23.59 2959.29 S 3543.95 ~ 631975.30 5974582.~7 25R 18,00 END 18/100 CURVE CURVE 18/100 10577.71 89.90 273.O1 8825.35 8776.05 11156.00 89,90 2~3.01 8826.32 8777.02 11200.00 91,64 280.73 8825.72 6776,42 11250.00 93.5S 289.53 8823.44 8774,14 11300.00 95.43 298.37 8819,50 8770.20 -5.24 2959.34 S 3571,61 ~ 6319~7.63 59?4582.92 H~ 18.00 386.02 2926.01 S 4145,11 ~ 631369,72 5974602.80 77R 0,00 417.87 2922.76 S 4192.75 W 635326.00 5974607,27 77R 18.00 458.59 2909.73 S 4240.92 W 631277.61 5974619,42 78R 18.00 503.16 2889,53 S 4286.43 ~ 631231.~4 5974638.80 78R 18.00 END 18/100 CURVE TARGET 1 CURVE 10.75/100 TARGET 2 li346,02 97.03 506.54 8814.58 8765.20 11346.02 97,O3 306.54 8814.50 $765.20 11879.03 97,03 306.54 8749.30 8700,Q0 11879.03 97.03 306.54 8749.30 8700.00 11900.00 94.78 306.68 6747.14 8697.8~ 546.64 2865.00 S 4325,00 ~ 632192.74 59?4662.62 HS 18,0~ 546.64 2865.00 S 4325.00 W 635192.74 5954662,62 ~]S 18.00 1060.19 2550.00 S 4750.00 W 630762.15 5974969,87 177R 0.00 1060.19 2550.00 9 4750.00 W 6307~-15 5974969.~7 Z77R 0.00 1080.44 2537.$~ S 4766.74 W 630745.19 5974982.00 177R 10.7S 90 INCLINATION END 10.75/100 CURVE lo/tOO 119~4.51 90.00 306,97 8745,29 8~95.99 1123,65 2510.92 12000.00 84,05 307,32 8748.13 8698.87 1177.56 2~77.47 12090,91 ?4,29 307.93 8765.23 8715,93 1264.52 242.3.03 12137.69 74.29 307.93 8777.9G 8728,60 1308.~8 2395,35 12200.00 80.52 307.95 8791.48 8742.~8 1367.82 2357,99 4802,33 W 630709-13 5975008.00 177R 10.75 4846.48 W 630664.38 5975040.64 177R 10.35 4917.12 W 630~92.78 5975093.75 }IS 10.75 4952.64 W 630556,77 5975120.82 ~S 0.Q0 5000.58 Z 630508.16 5977~57..30 H$ lO.OO TARGET 3 END 10/L00 CURVE CURVE 10./100 90 I~CLIhlkTION 1229~.78 90.00 307,93 8799,30 8750.00 145~.93 2300.00 12300,00 90.14 308.43 8799,29 8749.99 1465.04 2296.77 12400.00 92,72 318.10 8796.79 8747,49 1564.10 2228.35 ]2494.99 95,11 327.31 8790.38 6741,00 1658.68 2153,05 13191.40 95.1[ 327.31 8728.29 8678,99 2349.33 1569.26 13200.00 94.25 327.26 8727.59 8678.29 2355,84 1562.05 ~3242.56 90.00 32?,03 8726,02 8676.72 2398.06 1526.~3 13300.00 84,26 326.71 8728~69 8679.59 2455~05 1478.31 5075.00 5079.11 5151.8I 5209.18 5583.79 5588.42 5611.4~ S642.83 630432.71 5975213,93 630428.55 S975217.09 630354.62 5975284.18 630295,91 5975358~ 629910.$4 5975935 30 629906.08 5975942 43 629882.37 5975977 72 629650,17 5976025.~6 75R 10.00 75R 10.00 75R 10.00 H$ 10,00 1771 0.O0 1771 10.00 1771 10.00 I?~L 10.O0 (knadrill (c}98 RI~AP3A 3.2C q:28 P[4 P) R-11A (P3AI 23 Sep 1998 Pa~e 3 STAT[ON MEASUI~D INCLN IDENTIFICATIO~ DEPTH ~GLd~ TARGET 4 13303.98 83.87 SND 10/IOQ CUR%~ 15346.5l 79.62 CURVE 10/100 13542.ll 79.62 1360D.0fl 85.40 90 INCLINATION 13646.08 90_00 L370Q.O0 95,38 END 10/10~ CURVE 1372~,28 98.11 Ti~R(~R'T 5 11727.25 98.[1 CURUE 11.50/[00 1418~.23 TAP. GET 6 14188.23 98.11 ENO 11.50/100 CORVE 4-1/2" ~ PT 14200.00 96.76 14300,00 85,3L L4400.00 73,85 1~79.72 64.73 14519.79 64.73 TD ~OT 0OWC 14519.79 64.73 PROPOSBD ~]ELIo PROFILE ~[I~C~ION VE~TICAL-DSPTHS AZIMUTH TV~ SU~-SEA 8729.32 8680°00 8770.64 8721.34 87~8.19 8728.89 8780.0~ 8730.74 326.69 326.44 326,44 326,76 327,05 SECFION COORDINATES-FROM AOASKA Zone 4 DEPART WELL}fE.~D X Y 2466.98 [475.00 S $645.00 W . 6~9S47.94 5976028.~3 2500.83 1439.88 S 5668.19 ~ 62~824,12 5976063.12 2692.16 1279.57 S 5774.56 W 629714.68 5976221,46 2749,2[ [221.66 S 5806.[4 W 62~682.44 5966268.~0 ~794.94 1193,10 S 5631.26 ;~ 629656.63 59~6306.90 327.37' 8777,50 8728~20 2848_42 1147.83 S 5860.42 327.53 8774,30 8725.00 2675,29 1125.08 S 5875,00 325.53 ~774.30 8725.~0 2~75,29 1125.~0 S 5875,00 327.~3 R~09.30 8660.00 3328.14 74~.00 S 6120.00 52~.53 8~09.30 S66~,00 3328.~4 ?40.00 S 6120.0~ TOOL DL/ FACE 100 177L iD. O0 HS lO .OD 3g 0.00 3~ 10. OO 3~ lO.O0 629626.66 5976351,62 3R 10.00 62961Z.67 5976374.19 ~B 10.80 629611.67 S9~6374.19 KS lO.O0 629359.77 5976754.67 175L 0,00 629559.77 59~6754.67 [75L O,~O 327.40 8707.78 8658.48 3339~72 730.16 S 6126.28 316.36 S705.98 8656.68 3438.90 646.56 S 6180.8k 325.28 6724,Q3 8674.73 3536,65 565.32 S 6235.96 324.33 8752.20 8702.90 5610.93 504.44 S 6278.87 32(.33 8769.30 8720.00 3647.DS 475.00 S 6300.00 629353.32 5976764.39 629297.29 5976846.98 629240.69 5976927.2t 629196.68 629~75.03 5977016.35 2755 1[.50 175L 175L 1[.50 HS 11.50 324,33 8769.30 8720.00 90L4.30 8965.00 9060,30 3647.08 476.0~ $ 6~00,00 W 629175.02 5977016.35 0.00 ~3 Z (knadril[ (c]98 P. 11AP3A 3.2C 4:28 PM P) I> ~07-561-F ~Y ANADRILL DPC · PAGE 06 !, SHARED SERVICES DRILLING ~ ITVD Scale,: :l inch ~ ~200 feet )o - I " lOe, Scs]e_' ~ ~nch = ~200 feet Anadri ] ] Schlumberger , ,. Narken Iden(ifjcabJon t~D BKB SECTN INCLN ~0~ J " A) TIE-IN SURVEY 10194 8639 -144 32,42 B) KOP/CURVE 18/t00 10200 864~ ~144 3~.35 6) END 18/100 CURVE 10578 B825 -5 8~.~0 0-~ ~ ...... , ..... D) CURVE 18/J00 11156 8826 386 89,g0 E} ENO 18/~00 CURVE 1~3~6 8814 5~7 97.03 F) TARGET ] 11~46 881~ 54? 97,03 ~ 6) CURVE ~0,75/~00 11879 8749 1060 ~7.03 0 ~ ....... HI TARGET 2 11879 8749 1060 97.03 ~ I) 90 INCLINATION ~ 1945 8745 ~ 1E4 90.00 J) END ~0.7~/100 CURVE 12091 8765 ~265 7a,29 0 ......... K] CURVE ~0/100 12138 8778 1308 74.29 L) TARGET 3 12295 8799 la60 90.00 ~ ~) END 10/100 CURVE ~2495 8790 1659 95, ~ N] CURVE 10/]00 ~3~9t 8728 23a7 95.~J ~ " "" O] 90 INCLINATION ~3243 8726 2398 90,00 P) TARGET 4 !330~ 8729 2~59 8~.87 ~) END ~/~00 CURVE ~3347 8735 2501 79,62 ) ........ RI CURVE 10/100 135~2 8771 2692 79.62 S) 90 INCLINATION 13646 8780 2795 90.00 T} END 10/~00 CURVE ~3727 8774 2875 98,~ U] TARGET 5 13727 8774 2875 98,11 ) ~ ' - VI CURVE ~1,50/100 ~4188 8709 3328 98, ~] N) TARGET 6 14188 8709 3328 98.~ j X) END ~.50/I00 CURVE ~4480 8752 36~1 64.73 )~ ....... Y] 4-1/2" LNR PT ~4520 8769 3647 64.73 [ '-- Z] TD 14520 8769 3647 64,73 1 /:t,. : ¢, ~.,~:-.(~ ~ /: $;" .-. "';:'~ :. ~ ..... , .... ~ ~ , . 2 .~ '~.~; ~ ' ~ ~.. :. ........ - ~L~t i "" ~ /, ~ ~ I : .... ' ., "?C ~ i ~. . . -.,. .......... .... ~. u u7,~.. ~) ! ............... , ........ I ~200 -600 0 600 1200 ~800 2400 3000 3600 4200 4800 5400 E00O 6600 7200 'SF:iARJEB SERVICES DR:IL'LING " _ iii i i i i ii ii ii /fnad~ ~ ] ] Sch ]u~t~erger R-i A (P3A) VERTICAL SECTION VIE~ Section at' 320.43 TVD Scale.' ~ inch = 500 feet Dep Scale.' 1 inch = 500 feet Opawn ' 23 Sep ~9fl8 700O 875(] ~arker ZdenLifiua~ion NO BKB SECIN ~NCLN A) TZE-IN S~VEY ~0194 8639 -)44 52.42 B) KOPICURVE 18/[O0 JOEO0 8644 -~44 32.35 C) ENO ~8/~00 CURVE ~0578 8625 -5 89.90 O0 29 O0 O0 87 $2 O0 ! E) END 'tS/lO0 r:.lJFIVE t~346 88t4 547 97.( FI '[&FIC£T ! tt346 88t4 547 §?.( ............. ~1 cu.vE~o/~o~) ~_~ ~a ~o~ ~,~ L) IARBET 3 12295 879g ~46D 90.( O) 90 INCLINATION ~3~43 8726 2398 90.~ P) TARGET 4 13304 8729 2459 83.1 .......... .) cu~v~ ~o/~0o ~;~ ~7~ ~g~ 7~,~ ~) END ~O/tO0 CURVE t37~7 B774 2875 ~8. UJ TARGET 5 ~3727 8774 2875 gB. V~ CO~VE ~i,50/~Oa ~4t88 8709 ~328 9B, ~) T~6ET 6 MtB8 8709 3928 98. X) END 1'1.50/t00 CURVE 14480 8752 36il 64 ' ............... Y) 4-t/2' LNR PT ~4520 8769 3647 64 Z) rD t4520 8769 3647 6~.' - '-" ' ..... ,, '-I -~ - ~~- ' j ~ ~ ~~~ ~ NO PC ~ $ ~ ~ ~ I~ULn~ E 0 E ..... , ..... '~T- ~¢~ ...... ~T~ - ~ff .................. , ...... _ ...... -500 -250 0 250 500 750 ~OOO '!250 1500 ~7~ 2000 2250 2500 2750 , 3000 3250 3~0 3750 4000 ........... .Sect ion ,Depant,u..r,e .......................... ._q co -..j ]> Z 09/15/1998 10: q~ 90 ,'7-561-r~W~ . ,' ANADRILL DPC PA~E 08 . .~ ,, SHARED' SERVICES 'DRILLING R-] A (P3A) PLAN VIEW -- CLOSURE ' 63~B fee[ at Azimuth 265.69 DECLINATION.' +27.769 SCALE ' ~ inch ~ 500 fee[ BRAWN ' 23 Sep 1998 ,i i , AnadrJ 11 Sch./u~ber#er Marker Identification A) TIE-IN SURVEY B) KOP/CURVE 18/100 C) END 18/100 CURVE D) CURVE E) END 18/100 CURVE F) TARGET 6) CURVE 10.75/100 H) TARGET 2 90 INCLINATION J) END 10.75/100 CURVE K) CURVE t0/100 L) TARGET 3 M) END 10/100 CURVE N) CURVE '10/I00 O) go INCLIN/~TION P) TARGET 4 MO N/S E/W 10194 2890 ~ 327~ w 10200 2892 3273~ 10578 ~958~ 3572 11346 2865 S 4325 11879 2550 S 4750 11879 2550 S 4750 12091 2423 S 4917 12138 2395 S 4953 ~2295 2300 S 5075 12495 2t53 S 5209 ~3t91 1569 S 5584 13243 ~5~6 S 5611 13304 1475 S 5645 ' "' ~ ....... ~o~ ..... I ~o-~ -:~ ¥~ ( R) ~U~VE~ ]3~42 ]2)0 S )775 W J j 90 INCLlqAT~0N 13146 t~]3 S ~831 W l _, ~NO ~o/~o cu.v~ ~3:~ ~ s ~ ~ V) CURVE ~ 50/100 14'.BB 7qO S ~120 W / TARGET ~ t4~B8 7~0 S ~620 W j X) E~D t~.~]/~00 CURVE ]4'80 5]4 S i~79 W ~ Y) 4-1/~" I ~R PT ,.lJ~2A 4?q K ~0 W . / .. " ........ ..... ; ~ .... ..~ ......... . ...... . ........ . "' , ~' .......... C ~ I/.,~ .~ .': '" ..L. "",:'~, -" ~Rrge ~(Poin:) :,. :" :":" ': ' " "'" '"; ~1 " ...... ' -' "~:" :'" -'" - '- .... " :' ·" '": .. ~ ~ '.; .:..,.. ~ ,,~ ... . 6500 ~250 6000 5750 5500 5250 5000 4750 4500 4250 4000 3750 3500 3250 3000 <- WEST NOTES 1. DATE OF SURVEY,SEP. :2g, lgg3o 2. REFERENCE ;FIELD BOOK WOA 9217 (PGS. 5 THEU 8): ~ ~ ..:. -.- 3. ALASKA SI'ATE pJ..AN[:.COORDINAIES ~ AS-STAKE WELLS · EXISTING ~EIIS 5. HORIZONTN.~ PO~Tli~i ~BASED,~",.:..- R PAD MONOMENTS R-l"/dqO.:R~2. · :. .:~ . · ,: -~:'.. .~ . , · SURVEYOR'S CERTIFICATE I HEREBY CERTIFY-THAT ! PROPERLY RE~TERED AND UC~SED . TO PRACTICE LAND SURVEYING IN'. -L ,-~ .... . --. ~i~'ONS-~ANO OTHER DETAILS ARE . .'___,... ..... CORRECT AS OF SEP? 29. 1993. - . ExPLoRATION::: 10/2/g3 ORIGINAL AS-BUILT ISSUE.' DATE REVISIONS O. EV. DRAWN"I CHECi~ R PAD CONDUCTOR AS-BUILT :: .. WELLS .32. 3.3. 34, 35, ., rial.,: JI~A'II~ . Ii~11~1~.: A,r'~g~Ai,: .J ~T.~I ~,N~m - ' I~ ~ I ~ !~ ~~E J ~'=~0' I J RP~A8 I Alaska hared ervices rilling WELL NAME R-11Ai DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT ~'] Permit Documentation Prepared: ODE: ~ t'~O0 c.,- S~ ~.~Date:lO(~!q~ Permit ~pplldat?n~Re~wed: SDE/ES: U~ ~~ Date;/tg/~A7 mermit~bli, ca~i,4n Su~p~fijted: TA: ~' ][/~_/L&A..~0~_~ __ Date: I~.~ ["] PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: D ate: ]l'~l SUNDRY NOTICE D Sundry Documentation Prepared: ODE: Date: D Sundry Application Reviewed: SDE/ES' Date: D Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: . hare.d _ .z erv!ces ~S~a rill'rig WELL NAME R-11Ai DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET 'la The attached work cannot commence without obtaining the required signatures in the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT [~] Permit Documentation Prepared: ['~ Permit ApphcationRev~wed: . SDE~S :-0~ ff~ Date/~A~ ~ eemt~pblicafi& Sub~tted: SUNDRY NOTICE Sundry Documentation Prepared: ODE: Date: [Z] Sundry Application Reviewed: SDE/ES: Date: E] Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW PRE-RIG WORK Reason for Sundry (Check all that apply) Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate APPROVAL TO PROCEED / Approved AOGCC Permit/Sundry Received TA: Date: II Approval to Commence Operations SDE/ES: Date: I Well Name: R-11Ai I HST Sidetrack Summary Type of Well: I WAG Injector [ Surface Location: 1120' FSL, 3456' FEL, S32, T12N, R13E, UM Target Location: 3535' FSL, 1456' FEL, S06, T11N, R13E, UM Bottom Hole Location: 643' FSL, 4478' FEL, S31, T12N, R13E, UM [AFE Number: 14Pl149 [Rig: [Nabors 2ES I Operating days to complete: I [TVD: [8720 ss [KB Elev. [Extended Horizontal Sidetrack l. Estimated Start Date: I 10/26/98 [' MD: [ 14520' I Well Design: [25 151' Objective: This well is to be drilled as a horizontal sidetrack. The new sidetrack will provide injection conformance in Zone 4 and replace the injector M12i. The well has an undulating profile through Zone 4. Formation Markers Formation Tops TSag Kick Off Point 10194' 10200' TVD (ss) 8588' 8595' TSHU 10237' 8625' TSAD 10359' 8710' TD 14520 8720' HOT NR 8965' Directional Rig Move Close Approaches: Drilling Close Approaches: [KOP: 110,200' MD [ Maximum Hole Angle: 98.1 o through target 5 & 6 R-25 will be 34' from R-11Ai and will be shut in during the rig move. None Casing/Tubing ,rogram Hole Size Tubular WUFt Grade - Conn' Length Top Btm O.D. MDfrVDss MDfrVDss 6" 4-1/2" 12.6# LB0 IBT 4470' 10050'/8363' 14520'/8720' Production Tubing NA [ 4-1/2" 12.6# LB0 IBT 100130' surf/surf 10000'/8320' Mud Program Milling Interval: 6% Quickdiln Density, ppg [ Funnel Vis, sec [ LSRV pH API FL, cc 8.7-8.8+ [ 50 - 65[ 45,000 - 65000 8.5 - 9.0 NC Hazards/Concerns Maintain viscosity at 50 - 65 to insure adequate removal of metal cuttings. Ensure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Production (6" hole) Section: 6% Quickdriln (viscosified SW) Density, ppg I Funnel Vis, secI LSRV [ pH API FL, cc 8.7 - 8.8+ I 50 - 65 45,000 - 65000 8.5 - 9.0 NC Hazards/Concerns ] Potential high torque could require lubricant use. If so, employ Lubetex. Be alert for I lost circulation, differential sticking due to overbalanced MW (approx 600 psi differ- ential.) Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8+ ppg. The well profile crosses 4 faults so be prepared with LCM. Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments 4-1/2" N/A 523 / 15.7 / 1.19 Class G: 50% excess; TOC 10050' MD, 8363' TVD SS Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Open Hole Logs: 6" Hole Cased Hole Logs: Logging Program MWD Dir/GR/Res/Den Neu No open hole logs unless MWD resistivity unavailable or unusable Cement Evaluation log Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Bottom hole pressure is expected to be 3400psi @ 8800' TVDSS. Maximum expected surface pressure is 2520 psi (assuming gas column of 0. lpsi/ft) Hazards The main production target for this well is Zone 4. A 25' throw, EW fault will be instersected midway through the target polygon. Three other smaller faults (10-15') throw will also be intersected. However recent wells drilled in this area have not experienced severe losses, even whilst drilling through major faults. The faults near R pad tend to be cemented up with pyrite. Therefore, although lost circulation is not expected to be a problem, preparations should be made to pump LCM if necessary. No potential close approaches have been identified while drilling this well. Risk of differential sticking is low based on offset wells, but should it occur, will be mitigated by the use of the Quikdriln drilling fluid which is- solids free and does not form a filter cake. Sag River At R 11 the Sag River is in pressure communication with the sands below and should be around 3320 psi. Although differential sticking is still a concern it has not occurred on recent sag wells with lower pres- sures. The pad data sheet indicates that only one well (R-36i) has experienced major lost circulation in this production interval, most other drilling wells experiencing only minor losses. Ivishak Differential sticking has occurred frequently on older wells in the Ivishak at +/-9183' TVD. Once the sticking occurs it is very strong and has created difficulty in freeing up the drillstring. On R-35A, the sticking was successfully alleviated by pumping a 20bbl pill of Liquid Casing, OM Seal, and Barafibre and reducing pump rate to 5bpm (to reduce ECD). Note however that these wells were drilled using LSND mud; since this well will employ solids free Quikdriln, this should mitigate the risk of sticking. High torque has been reported on several older wells in the production hole, hence some open hole lu- brication may be required. The pad data sheet incorporates wells from R, F and J pad as the bottom hole location of these wells are all in the same area. Wells from all three pads have experienced problems with bridges, tight hole, differential sticking, and packing off while in the production interval. This has caused numerous incidents of stuck logs, casing, and drillstring. This is a high potential stuck pipe area - be alert while drilling this interval and employ frequent reaming if any sign of unstable hole is seen. Note however, that recent R-pad wells have not experienced any trouble from sticking and it is expected that this well will be drilled without a significant sticking problem. Disposal All cuttings should be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. Operations Summary Pre- Rig Work NOTE: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the wellhead manufacturer to initiate repairs and inform the Operations Drilling Engineer. 1. Test 9-5/8" packoff and tubing hanger packoff to 5,000psi. If annulus has not been recently (_<1 month) tested, pressure test to 4,000psi. , R/U 1.75" coiled tubing unit. RIH to PBTD at 10859' and spot a balanced cement plug from TD to ,-, 10080'. Attempt to squeeze 5bbls of cement to perforations before RIH to 10240' and circulate out excess cement with contaminant to obtain the required TOC. Highest acceptable TOC is 10240' in order to leave room to set whipstock at required depth for kick-off. Circulate the well bottoms up to clean seawater prior to POOH. RD coiled tubing. Let the plug set up, then tag with slickline. Note: A positive pressure test on the cement plug should not be attempted to avoid the potential of breaking down the cement in the squeezed perforations above the top of cement. Will request weight test requirement only from AOGCC. FI/U Wireline and RIH with chemical cutter to cut tubing at 9822', lft below collar in 5-1/2" pup joint above K-anchor. 1. Circulate seawater through cut in tubing until clean returns are obtained. Freeze protect tubing and annulus to 2,200ft with diesel. Bleed pressures on tubing/annulus. Zero psi on all annuli required. 2. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. .Rig Work: , Check with PE's on pre-rig work status. MIRU. Circulate the well to clean seawater. Pull BPV and ensure well stands full of fluid. Set/test TWCV. N/D tree, N/U and test BOP rams to 5000 psi, an- nular to 3500 psi. Pull TWCV. 2. Pull existing 5-1/2" completion. o . , o RIH with overshot fishing assembly and engage K-anchor. Retrieve K-anchor with 18 turns to the right and POOH. (no PBR run) RIH with milling assembly and mill up the SAB-3 packer. Retrieve the packer and the remainder of the existing 5-1/2" completion. RIH with 7" RTTS and scraper on drillpipe spaced out to scrape 7"liner to 10,225' (to scrape across .EZSV setting depth) with RTTS set at 10,050'. Set RTTS at 10,050' and test the 9-5/8" casing and 7" x 9-5/8" liner lap to 4000psi. R/U wireline unit. Set EZSV at + 10220' (placed for window kick off at 10200'-10212'). R/D electric line unit. RIH with bottom trip whipstock and set on EZSV. Shear off and mill window in 7". POOH. 7. RIH with 6" drilling assembly with 4 phase resistivity LWD and tag TD of new hole. Displace well to drilling fluid, and drill section to TD of 14520' as per directional plan. 8. M/U and run ,-,4500' of 4-1/2" L80 IBT liner to 14520', cement liner in place and set liner hanger at + 10050'. Run cement evaluation log. o R/U and run 4-1/2" L80 completion with 7"x4-1/2" production packer set at _+ 10000' and standard WOA tailpipe. Circulate freeze protection to _+2,200'MD. Land completion and set packer. Tail pipe shoud be stung into 4-1/2" liner top. 10. Set and test BPV, ND BOP, NU tree. RDMO. Anadril] $chlu~berger Alaska District 3940 Azctic Blvd Anchorage, AK 99503 (907] 273-L700 ~ax 273-8537 DIRMCTrO14kL WELL PLA~I for SHARED SERVICES DRILLING Nell ......... : R-1LA (P3A] Field ........ : Pru_hdhoe Bay Computation..: Minimum Curvature Uni Ls ........ : FEET Surface Lat..: 70 ,34670242 N Surface Long.: 148 ,90033448 X LOCATIONS - ~tLASKA Zone: Legal Description Surface ...... : 112D FSL 3456 FEL S32 TI2N Tie-in survey: 3510 FSL 1456 FEL S06 · Targe~ 1 ..... : 353~ FSL 2510 FEL S06 Tl lN Ta~c3et 2 ..... : 3849 FSL 2934 FEL ~06 Tlll~ Target 3 ..... : 4099 FSL 3259 FEL S06 TllN Target 4 ..... : ~923 FSL 3826 FEL S06 T11N Target 5 ..... : 5273 FSL ~Q55 FEL $06 S~ .......... : 643 FSL (478 FEL S31 X-Coord Y-Coord 635464.91 5977~05,09 632247.51 ~974657,[6 631192.74 597466~.62 6307~2.15 ~974969,8~ 630432.71 5975213.93 629847.94 5976826.43 6296~1.67 5976374.19 629175,03 59770[6.35 PROPOSED WELL PROFELE Prepared ..... : 23 Sep 1998 vert sect az.: 320.43 KB elevation.: 49.~0 ft M~ne~fc Dcln: ~27,769 {E) Scale Factor.: 0.99992085 Convergence,.: +~.03561893 ~ KOP/~3RVE 18/[00 ~AT[ON ~ASURED E}{C~ DI~ION ~RT IC~-DEPT~ SE~ION CO0~I~TES rD~T I F[~T ~ 0N DE~H ~GLE ~ ~ ~ S~- SEA DEPOT WELL.AD S~%GR 8637.30 'T/E-IN S~VEY 10194.2O 32,42 227.30 8638.77 8589.47 -143.93 2889,52 1O2O0.0O 3~,35 237.25 8645.67 S59~.37 -144.10 2891.63 ~0~37.22 36.93 235.88 %674.30 8625,00 -143 59 2904.68 10150.00 38.63 23S.42 8684,40 8635.10 -~42 67 2908.92 S 3296,07 ALASKA Zone 4 TOOL DL/ X Y FACE [gO 632247.31 5974657.16 632245.06 $974655.0L 632228.71 597~641.6,7 632222.22 5974637.31 ~6OL 51R 1.22 43R 18.08 10300.00 45.70 246.74 8721,47 8672,[? 10350.00 53.2{ 253.22 8753.96 8704.66 10359,08 54.6~ 254,25 8759.30 -~22 65 -119.75 2924.19 S 3325.86 2937.06 S 3361.55 2939,12 S 33~8.59 632~92.70 597~62~.51 632157,26 5974607.99 632150.25 5974605.81 38R 18,00 31R 18,00 30R 18.00 (Anadrlll (c)98 RllAP3A 3,2C 4:28 PM P) ', ,' j R-JlA {g3A) ~. 23 Sep 1998 Page 2 END 18/100 CURVR cLrR %~ t8/100 END 18/100 CURVE TARGET 1 CU?.VE 10.75/L00 TARGET 2 90 5NCL I NAT~ON f~N]D 10.75/100 CLIRVE kO/lO0 b~EASURED DEPTH 10359.02 10400.00 10450.D0 lOSO0.00 lOSS0.00 11156.00 11200.00 11250.00 11300.00 L[346,02 11346.02 11879.03 11879.03 11900.00 ~L944,51 ~2000,00 12~90,91 12137.69 12200.00 PROPOSED WELL PROFIL~ INCLN DIRECTION VERTICAL-DEPT~{S SECTION COORf3ElC3LTES-~R~M ALASKA Zone 4 TOOL DL/ ~GLE AZIMUTH TVD SU'B-EFJL DEPART WELL}{EAD X Y FAC~ lO0 56.64 254.25 8759.30 8710.00 -119.~5 2939,12 S 3366-59 W 632150.25 5974605,81 30R 18.00 61.07 258,5% 8781.07 8731.77 -104..55 ~947.22 S 3402.25 I9 632116.75 597q597.10 2ER 18.00 69.08 263.05 8802.13 8752.83 -81.62 2954.42 S 34~6.96 W ~]2072.18 5994589.09 26R 18.00 77.19 267.12 8816-63 876~.33 -54.~1 2958.~8 S 3494.59 W 632024.64 5974584.18 20k 18.00 85.36 270.94 6824.21 8774.91 -23,59 2959,29 S 3543.95 ~ 631975.30 5974582.47 25R 18.D0 89.90 273.01 8825.35 8776.05 -5.24 2958.34 S 3571.61 91 6319~7.63 5974502.92 H8 18.00 89,90 273.01 8826.32 8777.02 386.02 2926.01 S 4149,[1 ~ 53156~,72 5974602.80 77R 0.00 91.64 ~80.73 8820.72 $776,42 4[V.87 2922.76 S 4192.75 W 651326.00 5974607,2~ 77R 18.D0 93.58 289.53 8823.44 8774,14 458.59 2909.73 S 4240.92 ~ 631277.61 5974619.42 78R 18.00 95.43 298.3~ 8819,50 8770.20 503.16 2889.53 S 4286.~3 P; 631231.94 $974638.8D 78R 18.00 97.03 506.54 8814.50 8765.20 546,64 2865.00 S 4325,00 ~ 631192,74 5974662.62 KS 97,03 306.~4 8814.50 $7~5.20 5~.64 ~$65.00 S 4325.00 ~ 63~192.74 5974662,62 RS 97.03 306.54 8749.30 8700,00 1060.I9 2550.00 S 4700.00 W 630762.[5 5974969,87 [77R 97.03 306.54 8749.30 8500.00 1060.19 2550.00 S 4750.00 W 630762-15 5974969.87 177R 94.78 3D6.68 6747.14 8697.84 10~0.41 2537.$~ S 4766.74 W 630745.19 5974982.00 I?~R 10.75 90.00 306.97 0745,29 8695.99 1123.65 2510.92 S 1802,33 W 630709.15 5975008.00 T77R 10.75 84,05 307,32 8748.k7 8698.87 1177.56 :477.47 S 4846.4~ W 630664.38 ~905040.64 ~77R 10.35 74.29 307.93 8765.23 8~15,93 1264.52 2423.03 S 4917.[2 W 630~92.78 5975093.75 74,29 307.93 8777.90 8728,60 1308.42 2395,35 S 4952.64 W 630556,77 5975120.82 HS 0,00 80.52 307.95 $791.48 8742.18 1367.82 2357,99 $ 5000.58 ~ 630608,16 5975157.30 HS ~0.00 TAkGE? 3 CURV~ t0/L00 90 INCLINATION 1229~.78 12300,00 12400,00 ]2494.99 1319T.40 13200.00 13242,56 13300.00 90.00 307.93 8799,30 8750.00 1459,93 2300.00 90.14 308,43 8799,29 8749.99 1465.04 2296.77 92.72 318.10 0796,79 8747,49 1564.10 2228.35 95,11 327.3~ 8790.3~ ~7~1,00 1658.68 2153,05 95.11 327.31 8728.29 8678,99 2347.33 1569,26 94.25 327.26 ~727.$9 8678.29 2355.84 1562.05 90.00 527,03 8726,02 8676.72 2398,06 1526.33 84,26 526.71 8728.89 86V9.59 2455~05 1478.31 (A_nadrilL (c}98 RllAP3A 3.2C 4:28 PM P) 5075.00 W 630432.71 5975213,93 5079.11 W 630428.55 5975217.09 5151.81 W 630354.62 59752~4.18 5209.18 W 630295,9l 5975358.~2 5583.79 P; 629910.%4 5975935 30 5588.42 5611.4~ 5642.83 629906.08 59?5942 43 629882.37 5975977 72 629850,17 5976025.16 75R 10.0~ ?5R 10.00 75R 10.00 H$ 10,00 1771 0,00 1791 10.00 177L 10.00 1771 R-11A (P3A~ 23 Sep 1998 Page PROPOSED 9tELL PROFILE STA'['I0~ MEASUkED ZNCLN D[I~C~ION IDENTZFiCATIO}( DEPTH ~GLd~ AZIMUTH TARGET ~ L3303.98 85.87 326.69 SND 10/100 CT~%~ 13346,5~ 79,62 326.44 CXJRVE 10/lO0 13542.~1 79.62 13600.00 85.40 326,76 90 INCLINATION 13646.08 90.00 320.05 VE~T ] CAL-DEPTHS SECFION COORDINATES- F~OM A~ASKA Zone q"JD SU~-SEA DEPART WELL}{EA]D X 8729.30 8680.00 2458.98 ~475.00 S 5645.00 6735.41 8686.11 2500.85 1439.88 $ 5668.19 8770.64 8721.34 2692,16 1279.57 S 5774.56 8778.19 8728.89 2749,2~ ~2J~.66 S 5806.~4 8780.04 $730.74 2794.94 ~[93.10 S 5831.~6 629847.94 597~026.43 619824,12 5976063.12 629714.88 5976221.48 629602.4~ 5956268.80 629656.63 5976306.90 TOOL DL/ FACE 100 = 177L H~ 10.00 3R 0.gO 3~ lO.OO 3R [0.00 L3700,00 95,38 327-37 SND 10/100 CI3~VE 13727.28 98,11 327.53 TA~RGET 5 1~727.28 98.L~ 325.53 CURVE ll.50/L00 14188.23 90.~1 327,~3 TAP, GET 6 14108.93 98.11 8777,50 8728.20 2848.41 1147.8A S 5860.42 8774,30 8725.00 2B75,29 1120.00 S 5875,00 8~74.30 8725.a0 2875,29 1125.~0 S 5875,0D 8709.30 8660.00 5328.14 740.00 S 6120.00 8709.30 866~,00 3318.L4 740,00 S 6X20.00 629626.66 5976351,62 3R 10.00 629611.67 5976374.19 ES lO.a0 6296[~.67 5996374.[9 ES ~0.00 629359.77 5976754.67 175L 629559.77 597675~.67 175L g.O0 END 11.50/100 CURV~ 4-~/2" LNR PT 14200.00 96.76 327.40 14300,00 B5,3L 316.36 L44a0,00 73,85 325.28 1~479.72 64.73 324.33 14519.79 64.73 32~.33 8707.78 8658.48 3339.72 730.16 S 6L26.28 6705.98 8656.68 3438.90 646.56 S 6180,8~ 8724,03 8674.73 35~6,65 565.32 S 6235.96 8752.20 8702.90 561g,93 504.44 S 6278.85 8769.3D 8720.00 3647.D~ 475.00 S 63OD.SO 629353.32 5976764.39 629297.29 59768~6.9B 62924D.69 5976927.2t 629196.68 5996987.3a 629~75.03 5977916.35 175L 1[.50 175L k[.50 1755 L[.Sg 11,50 o.oa TD HOT 00WC 14519.79 64.73 324.33 8769.30 8?20.00 90[4.30 8965.00 9070,30 902~.0a 3647.0B 475.00 S 63g0,00 W 629175.~3 5977016.35 CO (An~drill (c] 98 RILAP3A 3.2C 4:28 PM P) 89:/25/1998 18:43 907-561-8bd? ANADRILL DPC "-~ PAGE 86 SHARED SERVICES DRILLING P3A) pep Scale.: I inch = 1200 feet )o i lOPawn ..... : 23 Sep 1998 I · ..~ Markep Identif~ca[Jon MD BKB SECTN INCLN lO--- I " A1 TIE-IN SURVEY 10194 8639 -144 32.42 I 8) KOF/CURVE 18/100 10200 8644 ~144 32;3§ C) END 18/t00 CURVE 10578 8825 -5 89.90 ~0-~--~~ ............ D) CURVE 18/100 t1~§6 8826 386 89,90 El ENO 18/100 CURVE 11346 8814 547 97.0~ F) TARGET 1 11346 88~4 547 97,03 i G) CURVE ~0,75/~80 11879 8749 1060 ~.03 ,0 ! " HI TARGET 2 11879 8749 1060 97.03 I I) go INCLINATION 11945 8745 ~1~4 90.00 ' J) END 1~.?§/100 CURVE 12091 8765 1265 74.29 ....... KI CURVE ~0/100 12128 8778 1308 74.29 0 -- L) TARGET 3 12295 8799 ~460 §0.00 ~ ~) END 10/100 CURVE ~24§5 8790 1659 N) CURVE lO/JO0 lgJ91 8728 23~7 0 "' O] gO INCLINATION 13243 8726 2398 §0,00 P) TARGET ~ 13304 872§ 2459 B~.87 D) END 10/100 CURVE }3347 8735 2~01 79.62 ,._ RI CURVE 10/100 13542 8771 2692 79.62 0 S) gO INCLINATION 13646 8780 ~795 90.00 TI END 10/100 CURVE ~3727 8774 2875 98.tl U] TARGET 5 13727 8774 2875 98,11 D '' VI CURVE tl.50/100 14188 8709 3328 98.11 N) TARGET 6 ~4188 8709 3328 98.1! X) END 11.50/~00 CURVE ~4480 8752 36~1 64.73 ¥i 4-1/2" LNR PT 14520 8769 3647 64.73 Z] TB 14520 8769 3647 64.73 ~ ......... ~_ ...~. ......... . .... _ ............................. '" '- t I ;..., . ~. ,---: :.' :, r: f'"Fl~ * ~-, ~ ! .... - i !---,- :.-t-. ...' . ''- , $ .... ; . · .! / . '.. ~, ."r-,,,'.,--...~-.t-,-o-.--...- .... '",(;... ~ " .-,_..~.?~ ;,,'~.. · :._[ '::.~ ' 4.....~ ~---- · ..... ~ .... _ .~.,.-.. : : ~ -. : -- ~.. :. ~ ' ...'... , ~.~ I i~ -_ ................ . .......... J .... SHARED ,, SERVICES DR ILL I NG ,~ II I II I I t /~nadr j ] ] Schlumberger Fl-llA (P3A) VERTICAL SECTION VIE~ Sectson at: TVD Scale,: Dep Scale.: Drawn ..... : 320.43 t inch = 500 feet I inch = 500 feet 23 SelD t998 I i _ i _ i , ,1 ~larker IdenLific~tion I40 BKB SECTN ~NCLN A) TIE-IN SUBVEY ~0194 B639 -~44 32,42 B) KOP/CURVE 18/100 ~0200 9644 -~44 32,35 C) END ~B/~OO CURVE 10578 8625 -5 89.90 [) ga [NCL[NA?[ON ~]9~5 8745 ~24 90.0 ~) END 10/t00 CURVE 12495 8790 ~659 ' O) 90 INCLINATION ~3243 6726 2~98 BO.C P> TA"GEI 4 13304 8729 2459 83,E S) gO ]NCLENATI~ 13~6 8790 ~7g5 gO.C ]) END ~O/lO0 OURVE 137~7 B774 a875 ~8.' U1 1&RBET5 ~37~7 B77~ ~eZ5 ......... V} CURVE ~t.50/~00 ~4lBB 8709 3328 98,' W) TARGEf 6 t~tBB 8709 3328 96.' X) END ~t,50/100 CURVE 14~80 8752 5611 64.' ......... ~ ....... ~ ..... Y) 4-1/2' LNR Pt ~4520 876~ ~647 6~.' Z) fD 14520 8769 3647 , ~'~r-~¢~ ..... ~ ........................ ~ ..... ~ ..... ='- ............ ~ - ' '~- ~" ---'~ ................... "' ' ~ ........ ~ - ~>S ..... ~ ............................................................................................... / ,~ ................ ~,_ ,~ ........ 1 ' I I ....................I i i 73 73 .73 -500 -250 0 250 500 750 1000 4.250 tS00 ~750 2000 2250 2'500 2750 , , 3000 3250 3~0 ,3750 4000 Section Departure ,, ~ il - : - ! Ic)g,~ Nll~P3~ 3.~ 4:04 Aq PI ,..D ,..D. OD 987-561-855'7 ANADRILL DPC PAGE 88 i SHARED R-] A (P3A) PLAN V I EW SERVICES ORILLING CLOSURE ' 63~8 fee[ a[ Azimuth 265,59 DECLINATION.' +27,769 (E) SCALE · I inch = 500 fee~ !DRAWN ' 23 Sep 1998 AnadrJ ]] Soh]umberger :rr Marker Identification MO N/S E/W A) TIE-IN SURVEY ]0194 2890 S 327t B) KOP/CURVE 18/100 10200 2892 S 3273 C) END 18/100 CURVE 10578 2958 S 3572 0) CURVE 18/100 J1~56 2928 S 4149 E) END 18/~00 CURVE 11346 2865 S 4325 FI TARGET 1 11346 2865 S 43~5 6) CURVE 10,75/J00 ~1879 2550 S 4750 HI TARGET 2 1~879 2550 S 4750 I) go INCLINATION ~945 25~ B 4802 J} END t0.75/t00 CURVE ~209t 2423 S 4917 K) CURVE 10/100 t2~38 2395 S 4953 L) TARGET 3 ~2295 2300 S 5075 M) END tO/JO0 CURVE J2495 2153 S 5209 N) CURVE ~0/~00 13~91 1569 S 5584 O) 90 INCLINATION 13243 J526 S 55~t P) TARGET 4 23304 t475 S 5645 ' ~' ~"~vFi~ ............. I R) U t I00 ~3642 ]2~0 S i775 W 1 .... '~ cu,w ~,.~o/,~o ~ TARGET 740 W Yl ~-1/2' I',~R PT ZI TD ~ ~4~20 475 S 300 W ' . .... .... - .... .... --. . .... I ........... A ':.-' " ! ~': !. ~'- :.':_:- :: ~ ' - '--~ ga~ d- , -" ,'y'~ ,-.-.'::~v~t.:.(.].'/.',~.--: :.. ::. ; ; .;-.. . ~ i -., . '.,.'1-~ ~-'~ -','-.~ -~-, _ -. q ..... '-~ ,, Z'...- ~ ;~ ,¢r'l '-:~ ~ ~ ~ :, :-... :. ~,_.~.L .- ~ 2 '.; ';-'" . .... . ~ . , ~ ,, .. ,. __ ~t 2 Point) ..... Tap~~ I 1. DATE OF SURVEY-$EP. :29, 199.3. 2. REFERENCE iFIEU) BO(O< ~A~DA (PGS. 5 THRU 8); ~ ~ ..? 3. ALASKA STATE PJ..ANE:CO(X~DINATES ARE ZONE'S, 'AI~- j..SKA,'-N~I~..27.~ 4. PAD SCALE'.,.FA.C~':-~'.:o,ggg9209.?..." 5. HORIZONTAC POSITION ..-'BASED/..4)N ~ AS-STAKE WELLS · EXISTING WELLS SURVEYOR'S CERTIFICATE I HERD3Y CERllFY ll-I^T I AM PROPERLY RE(::~TERED AND UCI~ISED :...3HE:. STATE OF' ALASKA~ANO 'II-IAT 1TflS PL~T REPRCSENTS-A St.tR'VE"l' R PAD MON',(JMEN~-.TS MI A.S.Po . NO. J COORDINATES ' ~2 j×~_ ~,.~o~,.~,~ /y' 5,'§~7,1.39.10 ~ 3.3 iX: 6:~4,761:'78: ' ~¥ ~5 I)~= 634~478.17 'F I-I ' '.'qd",lD.: )TRACI'LL'D PLN'4T ~OINATES 'N. 21,~3:3o E. -1999.71 ' N; 229~.;13 E. :1999,71 N. 1504.02 E. 2370.76 N. 2585.10 £. 2000.! 4 32, 'r. 12 N., GEODETIC POS~llON 70'20'~-5.978' 699' FSL 148'54'17.681' 20.3' 1258° FWL 70"20'43.671" 668' FSI. 148'54-'21.992' 20.4". 1111' FWLi 70'20'48;850' 148'54'01.653' 20.0' 70'?.0°4.3.082" 148'54'30.3~ 2' 20.2' ' - I/~DE;BY UE OR UNOER I, IY D~ECT ' - ~'~~(DN AND ~AT ~ · ·-~ .... .:, .- ~~S:~D 0~ ~TN~ ~ ' :.: ~=..:. - - 13 · ' ~o~. ~~ ' ~.BELL & ASSOCIATES .. . 10/2/9:3 ORI~NAL AS-BUILT ISSUE~ DATE REVISIONS ~~.BP EXPLORATleN:' 1194' FSI ~' r. R PAD 6o8' ,~ CONDUCTOR AS-BUILT 826' WELLS 52, 55, 54, 55 I -I i"''~ I~ -!-~,' I"'~"'" ' / -I I 1"'=400' i / - I RPADA8 /°"^'~lcHEc~! I / "~^°'~ I '~'' I° STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COigF~ISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: i~ Abandon _~ Suspend X Plugging ~ Time Extension ~ Perforate ~ Alter Casing ~ Repair Well ~ Pull Tubing '~ Variance ~ Other BPAddressName Exploration of Operator (Alaska)~.' Changelno.Approved Program'--Operation Shutdown ~ Re-EnterI 5. Suspended Well ~ Stimulate 6. Datum Elevation KBEPlUg = 55.1 Back (DF 0' for or AMSL Sidetrack KB) P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: ~ Development ~ Exploratory ~ Stratigraphic ,.~] Service 4. Location of well at surface 1121' NSL, 1824' EWL, SEC. 32, T12N, R13E, UM At top of productive interval 1768' SNL, 1447' WEL, SEC. 06, T11N, R13E, UM At effective depth 1956' SNL, 1645' WEL, SEC. 06, T11N, R13E, UM At total depth 2013' SNL, 1705' WEL, SEC. 06, T11N, R13E, UM 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number R-11i 9. Permit Number 83-3 10. APl Number 50-029-20893 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool -~, t' ~ ? ~, ,~r~ 12. Present well condition summary Total depth: measured 10904 feet true vertical 9152 feet Effective depth: measured 10737 feet true vertical 9107 feet Casing Length Size Structural Conductor 110' 20" x 30" Surface 2655' 13-3/8" Intermediate 10121' 9-5/8" Production Liner 993' 7" Plugs (measured) Junk (measured) Fill at 10737' MD (09/88) Cemented MD TVD 8 cu yds concrete 110' 110' 3720 cuft Permafrost II 2689' 2689' 1412 cu ft Class 'G', 130 cuft PF 'C' 10155' 8606' 408 cu ft Class 'G' 9911' - 10904' 8403' - 9152' Perforation depth: measured true vertical 10204' - 10240' (Sag River) 10344' - 10375', 10390' - 10450', 10480' - 10500' (Ivishak) Sqzd: 10500' - 10520' subsea 8593' - 8623' (Sag River) 8712' - 8846' (three Ivishak intervals) Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to top of 7" liner at 9911' Packers and SSSV (type and measured depth) 9-5/8" Baker packer at 9847" 7" Otis WD packer at 10461' with 4-1/2" tailpipe assembly to 10476'; 5-1/2" SSSV at 1999' 3. Description summary proposal ~ Detailed operations program ~ BOP sketch Attachments of 4. Estimated date for commencing operation October 9, 1998 I16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: _ Oil ~ Gas __ Suspended Service Water & Gas Injector Contact Engineer Name/Number: Philippa Stevenson, 564-5738 Chris Brown, 564-5582 Prepared By Name/Number: 17. I hereby cerCfy/~or~e~e and correct to the best of my knowledge Signed JameC~.4E. Smith for Dan StoY~e Terrie Hubble, 564-4628 Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity _'% BOP Test __ Location clearance __ ~Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission ~ ~_..C,). ~---" Form 10-403 Rev. 06/15/88 J Approval No. ~'-~)~ Commissioner Date//~)--/¢---~¢9~ Submit In Triplicate H 142921 I o?;~/Ssl · VENDOR ALASKAST DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 09159~ cKogl._,,98a i00,.,, uO i00. u,~ HANDLINg INST' S/P, TERRI HUBBL£ X4628 ......... n cHI=C. IS IN PAYMENT FOR il~aS DE~RIBED ABOVE. li[t]lllrA-lll ~ ~ ¢*"~0. O0 ~ 0~.-';. O0 · WELL PERMIT CHECKLIST COMPANY f~ ¢ ~ WELt. NAME ~ I~L.L.. ~ - k I ,~ PROGRAM: exp [] dev [] redrll¢l~ serv ,1~ wellbore seg I] ann. disposal para req, ~ ADMINISTRATION . DALE_, INIT CLASS __ \/t/ P-- ~ L'~'- ENGINEERING APPR ~? GEOLOGY A~?,,~) R DA'f% 1 Permit fee attached ....................... 2. Lease number appropriate ................... 3 Unique well name and number .................. 4 Well located in a defined pool ................. 5. Well Iocaled proper dislance front drilling unit boundary 6. Well located proper distance from other wells .......... 7. Sufficienl acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permil can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOL AREA UNIT# . l( (m J._~ _ ON/OFF SHORE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl vol adequate to circulate on conductor & surf csg ..... 17 CMf vol adequate to tie-in long string to surf csg ........ 18. CMI' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a '10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip Iisi adequale ..... 25. BOPEs, do they meet regulation ...... ,,,.,,,,~ ...... 26. BOPE press rating appropriate; test to ,_.'..~o~ I.,) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ......... ........ 32 Seismic analysis of shallow gas zones. ' ~ Y N 33. Seabed conditiorsurvey (if~ ..... Y N 34. Contacl.namelp . eekly Y N e only] progress reports ....... _ ............................................................................................................................. ANNULAR DISPOSAL 35. APl:q? DATE With proper cementing records, this plan ([~) will not contaminate freshwater; or cause drilling waste to surface; (C) wilt iiol impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or irnpair recovery from a pool; and ...... (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N .G__E._0.1:~ .G_ ¥: ENGINEERING: UlC/Annular COMMISSION: Comments/Instructions: RPC ~ BEW WM JDH Mcheklisl f¢!v ()512919~1 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . . . ............................ . ....... SCHLUMBERGER ....... * ............................ . COMPANY NAlV~ : BP E~PLORATION WELL NAME : R-11A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NLrMBER : 50-029-20893-01 REFERENCE NO : 99085 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-l~f 15:25 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 99/02/24 ORIGIN · FLIC REEL NAME : 99085 CONTINUATION # : PREVIOUS REEL : COP~4ENT : BP EXPLORATION, R-llA, PRUDHOE BAY, API #50-029-20893-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/02/24 ORIGIN : FLIC TAPE NAME : 99085 CONTINTJATION # : 1 PREVIOUS TAPE : CON~4ENT · BP EXPLORATION, R-11A, PRUDHOE BAY, API #50-029-20893-01 TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN 1 ......... 99085 NUTTER RUSSELL SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL : FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING R-11A 500292089301 BP EXPLORATION SCHLUNZBERGER WELL SERVICES 24-FEB-99 BIT RUN 2 BIT RUN 3 32 12N 13E 3429 1966 51.15 49.75 19.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 4.500 14520.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB-i~.u/ 15:25 3RD STRING PRODUCTION STRING REM~ARKS: THIS TAPE CONTAINS THE LDWG FOMATTED LWD IMPULSE DATA AQUIRED ON BP EXPLORATION'S R-11A WELL. DEPTH SHIFTING IS WAIVED PER STEVE JONES VIA DAVE DOUGLAS. THE DATA IS AQUIRED IN FOUR BIT RUNS. $ $ PAGE: **** FILE H~ER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTuTqBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMPIARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 14559.0 10185.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS THIS FILE CONTAINS THE EDITED IMPULSE DATA. THE CURVES ARE MERGED AT THE DEPTHS SHOWN ABOVE. THE CURVES ARE CLIPPED AT FIRST AND LAST VALID READING. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. MERGE TOP MERGE BASE 1 10185.0 10300.0 2 10300.0 10520.0 3 10520.0 12776.0 4 12776.0 14559.0 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-lb~-_~-~j 15:25 PAGE: 3 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUN~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD 0H~4000300 O0 000 O0 0 1 ! 1 4 68 0000000000 RPM MWD 0I~4M4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OHIVff~4000300 O0 000 O0 0 1 i 1 4 68 0000000000 RPX MWD OH2~q4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OH~M 4000300 O0 000 O0 0 1 i 1 4 68 0000000000 RAD MWD OHMM4000300 O0 000 O0 0 1 1 1 4 68 0000000000 RAM MWD OHMM4000300 O0 000 O0 0 1 ! 1 4 68 0000000000 RAS MWD OH~ 4000300 O0 000 O0 0 1 ! 1 4 68 0000000000 RAX NIWD 0tff4~4000300 O0 000 O0 0 1 t 1 4 68 0000000000 ** DATA ** DEPT. 14559.000 FET.MWD -999.250 ROP.MWD 30.720 GR.MWD -999.250 RPD.MWD -999.250 RPM.MWD -999.250 RPS.MWD -999.250 RPX.MWD -999.250 RPXX.MWD -999.250 RAD.MWD -999.250 RAM. MWD -999.250 RAS.I~D -999.250 RAX.MWD -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB-lg~ 15:25 PAGE: DEPT. 10185.000 FET.MWD -999.250 ROP.MWD -999.250 GR.MWD RPD.MWD -999.250 RPM. MWD -999.250 RPS.MWD -999.250 RPX.MWD RPXX. MWD -999.250 RAD.MWD -999.250 RAM. MWD -999.250 RAS.MWD RAX. MWD -999.250 80.233 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 10182.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 10349.9 i4-DEC-98 v5 oc O/R V5. OX 10 _ MEMORY 14560.0 10185.0 14560.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-l~ 15:25 PAGE BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMU~ ANGLE: 32.4 98.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAZR4A RAY IMP IMPULSE RESISTIVITY $ TOOL NUMBER GR IMP ENPO02 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 6. 000 14520.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~R4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT (MT): 6~ QKDRLN 8.70 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: RUN 1 was for Gamma Ray tie-in point RUN2 was to set whipstock ************* 6 inch hole section ********** DRILLED: 10232 ft to 10350 ft LOGGED: 10190 ft to 10308 ft IMPulse s/n 002 software version 5.OX 53 IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.43 ft Resistivity - 42.06 ft Survey - 47.26 ft Gamma Ray corrected for bit size and mud weight. ***************** RUN4 ******************** ************* 6 inch hole section ********** DRILLED: 10350 ft to 10570 ft LOGGED: 10308 ft to 10528 ft IMPulse s/n 002 software version 5.OX 53 _ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB- 1 ~/ 15: 25 PAGE: IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.36 ft Resistivity - 41.99 ft Survey - 47.19 ft Gamma Ray corrected for bit size and mud weight. ***************** RUN5 ******************** ************* 6 inch hole section ********** DRILLED: 10570 ft to 12835 ft LOGGED: 10521 ft to 12786 ft IMPulse s/n 002 software version 5. OX 53 IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 56.31 ft Resistivity - 48.94 ft Survey - 54.14 ft Gamma Ray corrected for bit size and mud weight. Run 6 was for orienting - clean out run ***************** RUN 7 ******************** ************* 6 inch hole section ********** DRILLED: 12835 ft to 14560 ft LOGGED: 12789 ft to 14513 ft IMPulse s/n 031 software version 5.OX 53 _ IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 53.87 ft Resistivity - 46.50 ft Survey - 51.70 ft Gamma Ray corrected for bit size and mud weight. Thank you for using Schlumberger. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-15~ 15:25 PAGE: TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 S 4000300 O0 000 O0 0 2 1 1 4 68 0000000000 TVDE LW1 FT 4000300 O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 LW1 F/HR 4000300 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 S 4000300 O0 000 O0 0 2 1 1 4 68 0000000000 AiOH LW1 0H~4000300 O0 000 O0 0 2 1 1 4 68 0000000000 A16H LW1 0~4~4000300 O0 000 O0 0 2 1 1 4 68 0000000000 A22H LW1 OHN~q4000300 O0 000 O0 0 2 1 1 4 68 0000000000 A28H LW1 0H~44000300 O0 000 O0 0 2 1 1 4 68 0000000000 A34H LW1 0H~4~4000300 O0 000 O0 0 2 1 1 4 68 0000000000 PiOH LW1 0HP~44000300 O0 000 O0 0 2 1 1 4 68 0000000000 P16H LW1 0H~44000300 O0 000 O0 0 2 1 1 4 68 0000000000 P22H LW1 0HI~f4000300 O0 000 O0 0 2 1 1 4 68 0000000000 P28H LW1 0H~4000300 O0 000 O0 0 2 1 1 4 68 0000000000 P34H LW1 0H~4000300 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 4000300 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10182.500 TAB.LW! 0.089 TVDE.LW1 8630.967 ROPS.LW1 TABR.LW1 100.000 AiOH.LW1 0.108 A16H.LW1 0.100 A22H. LWi A28H. LWl O. 261 A34H.LW1 300. 000 PiOH.LW1 O. 195 P16H.LW1 P22H. LW1 0. 234 P28H. LW1 O. 150 P34H. LW1 1. 000 GR. LW1 DEPT. 10349. 500 TAB.LW1 2.111 TVDE.LW1 10349. 484 ROPS.LW1 TABR.LW1 5950.000 AIOH. LW1 31.384 A16H. LW1 19.738 A22H. LW1 A28H.LWl 17. 621 A34H.LW1 15. 850 PiOH.LWl 9. 091 P16H.LW1 P22H. LW1 9. 086 P28H. LW1 9. 004 P34H. LW1 8. 857 GR. LW1 -999. 250 0.100 0.206 78. 470 35.020 18.774 9.089 107.565 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB-i~-~~ 15:25 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE · 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFJMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ~BER: 2 DEPTH INCREMENT: 0. 5000 FILE SUA~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10290.5 10569.9 LOG HEADER DATA DATE LOGGED: ! 4 -DEC- 98 SOFTWARE: SURFACE SOFTWARE VERSION: V$ OC O/R DOWNHOLE SOFTWARE VERSION: VS. OX 10 _ DATA TYPE (MEMORY or REA~-TIME) : MEMORY TD DRILLER (FT) : 14560.0 TOP LOG INTERVAI~ (FT) : 10185.0 BOTTOM LOG INTERVAL (FT) : 14560.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: 32.4 MAXIMUM ANGLE: 98.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~4A RAY IMP IMPULSE RESISTIVITY $ TOOL NUMBER GR IMP ENPO02 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-lb-~J 15:25 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 6.000 14520.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT (MT): 6% QKDRLN 8.60 0.112 0.106 0.148 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: RUN 1 was for Gamma Ray tie-in point RUN2 was to set whipstock ***************** RUN3 ******************** ************* 6 inch hole section ********** DRILLED: 10232 ft to 10350 ft LOGGED: 10190 ft to 10308 ft IMPulse s/n 002 software version 5.OX 53 _ IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.43 ft Resistivity - 42.06 ft Survey - 47.26 ft Gamma Ray corrected for bit size and mud weight. ***************** RUN4 ******************** ************* 6 inch hole section ********** DRILLED: 10350 ft to 10570 ft LOGGED: 10308 ft to 10528 ft IMPulse s/n 002 software version 5.OX 53 _ IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.36 ft Resistivity - 41.99 ft Survey - 47.19 ft Gamma Ray corrected for bit size and mud weight. ************* 6 inch hole section ********** DRILLED: 10570 ft to 12835 ft LOGGED: 10521 ft to 12786 ft IMPulse s/n 002 software version 5.OX 53 _ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB- l'~f 15: 25 PAGE: 10 IDEAL/SPM software version 5. Oc_O/r Bit to sensor offsets: GR - 56.31 ft Resistivity - 48.94 ft Survey - 54.14 ft Gamma Ray corrected for bit size and mud weight. Run 6 was for orienting - clean out run ***************** RUN 7 ******************** ************* 6 inch hole section DRILLED: 12835 ft to 14560 ft LOGGED: 12789 ft to 14513 ft IMPulse s/n 031 software version 5. OX 53 _ IDEAL/SPM software version 5. Oc_O/r Bit to sensor offsets: GR - 53.87 ft Resistivity - 46.50 ft Survey - 51.70 ft Gamma Ray corrected for bit size and mud weight. Thank you for using Schlumberger. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN #4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-l~gJ15:25 PAGE: 11 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 4000300 O0 000 O0 TAB LW2 S 4000300 O0 000 O0 TVDE LW2 FT 4000300 O0 000 O0 ROP5 LW2 F/HR 4000300 O0 000 O0 TABR LW2 S 4000300 O0 000 O0 AiOH LW2 OP~Vk44000300 O0 000 O0 A16H LW2 OHff~t 4000300 O0 000 O0 A22H LW2 OH~I 4000300 O0 000 O0 A28H LW2 0t~4~4000300 O0 000 O0 A34H LW2 OH~4 4000300 O0 000 O0 PiOH LW2 0H~2~4000300 O0 000 O0 P16H LW2 OIHvIM 4000300 O0 000 O0 P22H LW2 OH~ff44000300 O0 000 O0 P28H LW2 OH~ff4 4000300 O0 000 O0 P34H LW2 OH~ff44000300 O0 000 O0 GR LW2 GAPI 4000300 O0 000 O0 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10290.500 TAB.LW2 TABR.LW2 0.000 AiOH. LW2 A28H. LW2 17.687 A34H. LW2 P22H. LW2 12.826 P28H. LW2 DEPT. 10569.500 TAB.LW2 TABR.LW2 3260.000 AiOH. LW2 A28H. LW2 5.116 A34H.LW2 P22H. LW2 4.858 P28H.LW2 0. 000 TVDE. LW2 8747. 600 ROP5. LW2 30.148 A16H.LW2 18,782 A22H.LW2 16. 884 PiOH. LW2 14. 980 P16H.LW2 12.380 P34H, LW2 12,298 GR. LW2 1. 203 TVDE. LW2 8812. 967 ROP5. LW2 4. 791 A16H. LW2 4. 937 A22H.LW2 5. 054 PIOH.LW2 4,749 P16H. LW2 4. 901 P34H. LW2 4. 915 GR. LW2 -999.250 17.938 13.721 109.769 95.745 5.075 4.800 31.476 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE · 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB-I'~ 15: 25 PAGE: 12 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LOG HEADER DATA FILE HEADER FILE NIIMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10418.5 12835.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIFiE) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MitXIMIIM ]INGLE: TOOL STRING (TOP TOBOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~VA RAY IMP IMPULSE RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) MUD VISCOSITY (S) : MUD PH: 14-DEC-98 v$ oc o/~ VS. OX 10 _ MEMORY 14560.0 10185.0 14560.0 32.4 98.2 TOOL ArO?~BER GR IMP ENPO02 6.000 14520.0 68 QKDRLN 8.60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-l~9--9~9~ 15:25 PAGE: 13 MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.112 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 0.106 MUD CAKE AT (lifT): O. 148 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: RUN1 was for Gamma Ray tie-in point RUN2 was to set whipstock ***************** RUN 3 ******************** ************* 6 inch hole section ********** DRILLED: 10232 ft to 10350 ft LOGGED: 10190 ft to 10308 ft IMPulse s/n 002 software version 5.0X_53 IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.43 ft Resistivity - 42.06 ft Survey - 47.26 ft Gamma Ray corrected for bit size and mud weight. ***************** RUN4 ******************** ************* 6 inch hole section ********** DRILLED: 10350 ft to 10570 ft LOGGED: 10308 ft to 10528 ft IMPulse s/n 002 software version 5.0X_53 IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.36 ft Resistivity - 41.99 ft Survey - 47.19 ft Gamma Ray corrected for bit size and mud weight. ************* 6 inch hole section ********** DRILLED: 10570 ft to 12835 ft LOGGED: 10521 ft to 12786 ft IMPulse s/n 002 software version 5.0X_53 IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - $6.31 ft Resistivity - 48.94 ft Survey - 54.14 ft Gamma Ray corrected for bit size and mud weight. Run 6 was for orienting - clean out run ***************** RUN7 ******************** ************* 6 inch hole section ********** DRILLED: 12835 ft to 14560 ft LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FBB-19~ 15:25 PAGE: 14 LOGGED: 12789 ft to 14513 ft IMPulse s/n 031 software version 5.OX 53 _ IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 53.87 ft Resistivity - 46.50 ft Survey - 51.70 ft Gamma Ray corrected for bit size and mud weight. Thank you for using Schlumberger. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN #5. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB AH]FiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000300 O0 000 O0 0 4 1 t 4 68 0000000000 TAB LW3 S 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 TVDE LW3 FT 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 ROP5 LW3 F/HR 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 TABR LW3 S 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 AIOH LW3 Otfiv~14000300 O0 000 O0 0 4 1 1 4 68 0000000000 A16H LW3 0H~I44000300 O0 000 O0 0 4 1 1 4 68 0000000000 A22H LW3 OB?4M4000300 O0 000 O0 0 4 1 1 4 68 0000000000 A28H LW3 OHMM4000300 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SES-£~' 15 ..25 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUNfl~ SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) A34H LW3 0tflv~44000300 O0 000 O0 0 4 1 1 4 68 0000000000 PiOH LW3 0H~944000300 O0 000 O0 0 4 1 1 4 68 0000000000 P16H LW3 OH~ff44000300 O0 000 O0 0 4 1 1 4 68 0000000000 P22H LW3 OHMS4000300 O0 000 O0 0 4 i 1 4 68 0000000000 P28H LW3 OH~ff44000300 O0 000 O0 0 4 1 1 4 68 0000000000 P34H LW3 OH~ff44000300 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI 4000300 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10418. 500 TAB.LW3 O. 050 TVDE. LW3 8795. 768 ROPS.LW3 TABR.LW3 0.000 AiOH.LW3 0.192 A16H. LW3 0.109 A22H. LW3 A28H. LW3 0.137 A34H.LW3 0.100 PiOH. LW3 0.511 P16H. LW3 P22H. LW3 O. 442 P28H. LW3 O. 329 P34H. LW3 O. 325 GR. LW3 DEPT. 12835. 000 TAB. LW3 4. 476 TVDE. LW3 8777. 400 ROP5. LW3 TABR.LW3 15714.813 AiOH.LW3 7.982 A16H.LW3 7.943 A22H.LW3 A28H. LW3 7. 857 A34H. LW3 7. 525 PiOH. LW3 7. 990 P16H. LW3 P22H. LW3 9.361 P28H. LW3 9. 590 P34H. LW3 9. 715 GR. LW3 -999.250 0.127 0.579 33.412 61. 417 8. 012 8. 817 26. 891 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 16 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~4ARY VENDOR TOOL CODE START DEPTH MWD 12245.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GANmfA RAY IMP IMPULSE RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 14559.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE '. MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): 14 -DEC- 98 V5 0C O/R VS. OX 10 MEMORY 14560.0 10185.0 14560.0 32.4 98.2 TOOL NUMBER GR IMP ENPO02 6.000 14520.0 6~ QKDRLN 8.60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB- i~9~ 15: 25 PAGE: 17 EWR FREQUENCY (HZ): 20000 REMARKS: RUN1 was for Gamma Ray tie-in point RUN2 was to set whipstock ***************** RUN 3 ******************** ************* 6 inch hole section ********** DRILLED: 10232 ft to 10350 ft LOGGED: 10190 ft to 10308 ft IMPulse s/n 002 software version 5.OX 53 _ IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.43 ft Resistivity - 42.06 ft Survey - 47.26 ft Gamma Ray corrected for bit size and mud weight. ***************** RUN4 ******************** ************* 6 inch hole section DRILLED: 10350 ft to 10570 ft LOGGED: 10308 ft to 10528 ft IMPulse s/n 002 software version 5. OX 53 IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 49.36 ft Resistivity - 41.99 ft Survey - 47.19 ft Gamma Ray corrected for bit size and mud weight. ************* 6 inch hole section ********** DRILLED: 10570 ft to 12835 ft LOGGED: 10521 ft to 12786 ft IMPulse s/n 002 software version 5.OX 53 _ IDEAL/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 56.31 ft Resistivity - 48.94 ft Survey - 54.14 ft Gamma Ray corrected for bit size and mud weight. Run 6 was for orienting - clean out run ***************** RUN7 ******************** ************* 6 inch hole section ********** DRILLED: 12835 ft to 14560 ft LOGGED: 12789 ft to 14513 ft IMpulse s/n 031 software version 5.OX 53 _ ID~/SPM software version 5.0c_O/r Bit to sensor offsets: GR - 53.87 ft Resistivity - 46.50 ft Survey - 51.70 ft Gamma Ray corrected for bit size and mud weight. Thank you for using Schlumberger. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN #7. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB-I~9~ 15:25 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 4000300 TAB LW4 S 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 TVDE LW4 FT 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ROP5 LW4 F/HR 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 TABR LW4 S 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 AIOH LW4 0H~94 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 A16H LW4 OH~4 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 A22H LW4 0H3~4 4000300 O0 000 O0 0 $ 1 1 4 68 0000000000 A28H LW4 OH~f 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 A34H LW4 OHMM 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 PiOH LW4 OH~4M 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P16H LW4 0H~94 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P22H LW4 OH~4M 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P28H LW4 OHI~M 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 P34H LW4 OH~ff44000300 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW4 GAPI 4000300 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24 -FEB-~9~ 15: 25 PAGE: 19 DEPT. 12245. 000 TAB. LW4 TABR.LW4 O. 000 AiOH.LW4 A28H. LW4 0.100 A34H.LW4 P22H. LW4 O. 518 P28H. LW4 DEPT. 14559. 500 TAB. LW4 TABR. LW4 4539. 984 A1 OH. LW4 A28H. LW4 43. 824 A34H. LW4 P2 2H . LW4 28. 887 P2 8H. LW4 O. 000 TVDE. LW4 O. 123 A16H. LW4 O. 100 P1 OH. LW4 O. 628 P34H. LW4 1. 525 TVDE . LW4 17. 250 A16H. LW4 42. 606 P1 OH. LW4 34. 152 P34H. LW4 8784.510 ROPS. LW4 O. 100 A22H. LW4 O. 307 P16H.LW4 O. 754 GR. LW4 873 6. 783 ROPS. LW4 27. 600 A22H.LW4 14. 951 P16H.LW4 37. 895 GR.LW4 4995. 663 0.100 O. 401 31.348 30.982 38.967 21.703 21.122 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION . O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT · DATE : 99/02/24 ORIGIN : FLIC TAPE NAME · 99085 CONTINUATION # : 1 PREVIOUS TAPE : COI~fENT · BP EXPLORATION, R-11A, PRUDHOE BAY, API #50-029-20893-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/02/24 ORIGIN : FLIC REEL NAME : 99085 CONTINUATION # : PREVIOUS REEL : CON~4ENT : BP EXPLORATION, R-11A, PRUDHOE BAY, API #50-029-20893-01
