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Home My WebLink About201-113CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-107 (PTD #2011130) Tubing patch removed pre CTD Date:Tuesday, August 12, 2025 1:39:07 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, August 12, 2025 1:02 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector S-107 (PTD #2011130) Tubing patch removed pre CTD Mr. Wallace, Injector S-107 (PTD #2011130) tubing patch was removed on 08/11 in preparation for CTD. The well is now classified as NOT OPERABLE and will remain shut in until tubing integrity is restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, January 22, 2022 10:20 AM To: Brodie Wages <David.Wages@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector S-107 (PTD #2011130) AA 22F.001 granted All, Injector S-107 (PTD #2011130) is now classified as OPERABLE for WAG service. Please review attached AA and place a laminated copy in the well house. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, January 9, 2022 1:37 PM To: Brodie Wages <David.Wages@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector S-107 (PTD #2011130) AA amendment in process. All, The AOGCC has given approval to keep S-107 online while they process the application to amend the AA to include MI. The Under Evaluation clock will be reset to track until the AA is processed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, November 12, 2021 6:31 AM To: Brodie Wages <David.Wages@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector S-107 (PTD #2011130) Temporary MI service All, The AOGCC granted another 60-days of monitoring on MI. The Under Evaluation clock will be adjusted accordingly. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Monday, September 13, 2021 3:05 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS- PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2- WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW-GC2- WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Matthew Linder <mlinder@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector S-107 (PTD #2011130) Temporary MI service All, Injector S-107 (PTD #2011130) is now classified as UNDER EVALUATION for temporary MI service for 60 days. Please bleed annuli as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Thursday, November 19, 2020 12:21 PM To: Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW- GC2-WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Matthew Linder <mlinder@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector S-107 (PTD #2011130) back on PWI All, Injector S-107 (PTD #2011130) was on MI from 11/01-11/16 at which time it was swapped back to PWI for operational needs. The AOGCC has granted approval to re-start the 60-day injection period for MI. Please notify Well Integrity when the well is ready for MI to begin the 60 day injection period. In the meantime, the well will be classified back to Operable while it is on PWI. Please respond with any questions Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Sunday, November 1, 2020 2:47 PM To: Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW- GC2-WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector S-107 (PTD #2011130) AOGCC approved temporary MI service All, Injector S-107 (PTD # 2011130) has known TxIA on MI and operates under Administrative Approval for PWI service only. Hilcorp has received AOGCC approval to put on temporary MI service for 60 days to monitor the IA re-pressurization rate with the intent of amending the current AA to include MI. The well will now be classified as UNDER EVALUATION to track the 60-day injection period on MI. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. By Grace Christianson at 1:33 pm, Jul 25, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.07.25 13:03:08 - 08'00' Sean McLaughlin (4311) 325-440 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. 10-407 JJL 8/5/25 SFD 8/11/2025 DSR-8/14/25*&: 8/14/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.14 13:12:10 -08'00' RBDMS JSB 081825 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: July 25, 2025 Re: S-107 Sundry Request Sundry approval is requested to set a whipstock in the S-107 wellbore as part of the drilling and completion of the proposed S-107A CTD lateral. Proposed plan: Prior to drilling activities screening will be conducted to MIT, pull patch and nipple reducer, and drift for whipstock. See S-107A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling and lands in the Kuparuk C. The lateral will continue in Kuparuk C to TD. The proposed sidetrack will be completed with a 3- 1/2"x3-1/4"x2-7/8” L-80 solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Aurora Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start August 2025) 1. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 2. Slickline : Pull Patch, Pull Nipple reducer, Dummy WS drift 3. Coil : Drift for Whipstock 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: x Reference S-107A Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,013 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 4-1/2" Packer Whipstock* at 13,900' MD oriented at 30 deg ROHS 3. Mill 3.80” Single String 4-1/2" Window 4. Drill build section: 4.25" OH, ~511' (18 deg DLS planned). 5. Drill production lateral: 4.25" OH, ~1,716' (12 deg DLS planned). Swap to KWF for liner. 6. Run 3-1/2” x 3-1/4” x 2-7/8” L-80 solid liner (swap to VBRs and test prior to running liner) 7. Pump primary cement job*: 39 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 8. Only if not able to do with service coil extended perf post rig – Perforate Liner 9. Freeze protect well to a min 2,200' TVD. * Alternate plug placement variance request per 20 AAC 25.112(i) ,p yppg(p completion will completely isolate and abandon the parent Aurora Pool perfs Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Post-CTD RPM/CBL and extended perforating (~500'). If needed, cement down squeeze (see future sundry). 3. Slickline : Contingent set LTP*. 4. E-line : Set tubing patch. Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3"or 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 13, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-107 PRUDHOE BAY UN AURO S-107 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/13/2025 S-107 50-029-23023-00-00 201-113-0 W SPT 6639 2011130 3200 1399 1396 1394 1397 253 306 310 310 REQVAR P Bob Noble 1/13/2025 2 year MIT-IA as per AA AIO 22F .001 to max injection pressure. 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 UN AURO S-107 Inspection Date: Tubing OA Packer Depth 1179 3533 3470 3459IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250113162020 BBL Pumped:5.2 BBL Returned:4.6 Thursday, March 13, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 9 year MIT-IA as per AA AIO 22F .001 James B. Regg Digitally signed by James B. Regg Date: 2025.03.13 10:10:33 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, February 21, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-107 PRUDHOE BAY UN AURO S-107 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/21/2023 S-107 50-029-23023-00-00 201-113-0 W SPT 6639 2011130 3500 823 821 826 820 156 422 405 395 REQVAR P Brian Bixby 1/10/2023 MITIA to MAIP as per AIO 22F.001 30 MinPretest Initial 15 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 UN AURO S-107 Inspection Date: Tubing OA Packer Depth 532 3798 3738 3724IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230111080116 BBL Pumped:6.1 BBL Returned:6.2 Tuesday, February 21, 2023 Page 1 of 1 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-107 Reinstall Tubing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-113 50-029-23023-00-00 16026 Conductor Surface Intermediate Production Liner 6824 80 4231 12390 3721 15938 20" 10-3/4" 7" 4-1/2" 6839 35 - 115 34 - 4265 31 - 12421 12259 - 15980 35 - 115 34 - 2903 31 - 6934 6871 - 6832 None 470 2470 5410 7500 None 1490 5410 7240 8430 11735 - 15938 4-1/2" 12.6# L-80 34 - 12263 6648 - 6839 Structural 4-1/2" Baker Premier Packers 11718 / 6639, 11823 / 6693, 12223 / 6858 11718, 11823, 12223 6639, 6693, 6858 Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028257, 028258 & 028256 34 - 6873 N/A N/A 5702 4499 1550 750 2518 925 N/A 13b. Pools active after work:Aurora Oil Pool No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Meredith Guhl at 4:05 pm, Jan 20, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.01.20 15:57:38 -09'00' Stan Golis (880) RBDMS JSB 012623 DSR-1/20/23 201-113 N/A PBU S-107 PRUDHOE BAY, AURORA OIL WCB 11-3-2023 Repair Well Its looks as though a 10-403 was not submitted. This is being looked into. -WCB Reinstall Tubing Patch Sundry Number ACTIVITY DATE SUMMARY 12/20/2022 T/I/O = SSV/640/70. Temp = SI. IA FL (SL). IA FL @ 70' (2 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00 12/24/2022 ****WELL S/I ON ARRIVAL**** DRIFT W/ 45KB PACKER/PATCH DRIFT TO 11'000 SLM (3.70" x 20.4' using 10' of 3 1/2" ST-L spacer pipe) BRUSH & FLUSH FROM 10500' TO 11000' SLM. SET 4-1/2" NIPPLE REDUCER IN X-NIP @ 12202' MD SET 2-7/8" XX-PLUG IN NIPPLE REDUCER @ 12202' MD ATTEMPT COMBO-MIT (fail 31bbl of diesel pumped) PULL 2-7/8" XX- PLUG @ 12202' MD ****JOB CONT, ON 12/25/2022**** 12/25/2022 ****CONT ON FROM 12/24/2022**** PULL & RE-SET 2-7/8" XX-PLUG @ 12202' MD PULL & RE-SET 4-1/2" NIPPLE REDUCER @ 12202' MD ATTEMPT TO COMBO-MIT WELL (FAIL) HES UNIT 759 DOWN ON WEATHER FOR TEMPS (SUB -40*). ****JOB SUSPENDED, DUE TO RETURN AT LATER DATE**** 12/25/2022 ***Job cont from 12-24-22 WSR*** Pumped 13 bbls Dsl down TBG/IA in attempt to bring up to test pressure. Pumped 21 bbls DSL in attempt to set Plug SLine in control of well upon departure FWHP= 500/550/50 12/26/2022 ***HES 759 WEATHER STANDBY*** HES 759 WEATHER HOLD ***CONT WEATHER STANDBY ON 12/27/2022*** 12/27/2022 T/I/O = 51/256/70. Temp - SI. Assist SL. Pumped 8 bbls DSL into TBG. *** Job continued to 12-28-2022 *** 12/27/2022 ***JOB CONT, FROM 12/25/2022*** HES UNIT 759 WEATHER HOLD FROM 00:00 TO 16:00 EQUALIZE & ATTEMPT TO PULL 2-7/8" XX- PLUG @ 12202' MD TROUBLE SHOOT TUBING OBSTRUCTION @ 3518' SLM, LRS PUMP TOTAL 13BBLS OF DIESEL ****WSR CONT, ON 12/28/2022**** 12/28/2022 ****WSR CONT, FROM 12/27/2022**** (patch tubing/liner) RAN 2.80" CENT, 1.75" SAMPLE BAILER TO 3,518' SLM (no sample) B&F W/ 4 1/2" BRUSH, 3.80" GAUGE RING TO 5,500' SLM (lrs pumped 75bbls 180* diesel) PULLED 2 7/8" XX-PLUG FROM NIPPLE REDUCER @ 11,202' MD PULLED 4 1/2" x 2 7/8" NIPPLE REDUCER FROM 11,202' MD SET 4 1/2" x 2 7/8" NIPPLE REDUCER W/ 2 7/8" XX-PLUG ON-SEAT IN SLIDING SLEEVE @ 11,967' MD LRS PERFORMED PASSING CMIT TxIA TO 3400psi (see lrs log for details) ***CONT WSR ON 12/29/22*** 12/28/2022 ***Continued From 12-27-2022*** Assist S/L. Pumped 78 bbls 180* DSL into TBG. S- Line set plug. Pumped 11.3 bbls Diesel down TxIA to reach test pressure CMIT TxIA PASSED to 3431/3440 PSI. Loss of 22/15 TxIA 1st 15 min, Loss of 13/11 PSI 2nd 15 min for a total loss of 35/26 psi during 30 min test. Bled back 9.7 bbls diesel. FWHP=500512/76 12/29/2022 ***Job Continued from 12-28-2022*** Rig off well, S-Line control of well upon departure Daily Report of Well Operations PBU S-107 SET 4-1/2" NIPPLE REDUCER IN X-NIP @ 12202' MD ) PULLED 2 7/8" XX-PLUG FROM NIPPLE REDUCER @ 11,202' MD@ PULLED 4 1/2" x 2 7/8" NIPPLE REDUCER FROM 11,202' MD The combo kept failing when the nipple reducer and plug were set in the nipple @12202', probably because of the known/past tubing leak at 12,165' (see WBS). The combo passed once the reducer and plug were set in in the SS profile. So, at least there seems to be PC integrity from the depth of the shallowest packer upwards. -WCB PULL & RE-SET 2-7/8" XX-PLUG @ 12202' MD@ PULL & RE-SET 4-1/2" NIPPLE REDUCER @ 12202' MD ATTEMPT TO COMBO-MIT WELL (FAIL) ) BRUSH & FLUSH FROM 10500' TO 11000' SLM. ATTEMPT COMBO-MIT (fail 31bbl of diesel pumped) SET 2-7/8" XX-PLUG IN NIPPLE REDUCER @ 12202' MD @ @ DRIFT W/ 45KB PACKER/PATCH DRIFT TO 11'000 SLM SET 4 1/2" x 2 7/8" NIPPLE REDUCER W/ 2 7/8" XX-PLUG ON-SEAT IN SLIDING SLEEVE @ 11,967' MD@ LRS PERFORMED PASSING CMIT TxIA TO 3400psi Daily Report of Well Operations PBU S-107 12/29/2022 ***CONT WSR FROM 12/28/22*** (patch tubing/liner) EQUALIZED & PULLED 2-7/8" XX PLUG FROM NIPPLE REDUCER @ 11,967' MD. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 1/1/2023 ***WELL SHUT IN ON ARRIVAL*** JOB SCOPE: SET PATCH PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1 7/16" CHD (1" FN), 2 1/8" CCL, 2 1/8" BRT, 2 1/2" SWITCH HOUSING, BKR #10 SETTING TOOL, & 4-1/2" BAKER FLO GUARD PATCH. TOOLS NOT WANTING TO FALL VERY WELL AFTER GETTING BELOW THE SVLN. DEVIATE OUT AT ~ 2450'. CALL OUT PUMP TRUCK. PUMP PATCH DOWN AT .5 - 1.3 BPM WITH DIESEL. LOG BELOW STA#3 TO CORRELATE. LOG CORRELATED TO PDS LEAK DETECTION LOG DATED 10/07/2008 SET PATCH 10860' - 10879.5' ELEMENT TO ELEMENT. CCL OFFSET=13.3'. CCL STOP DEPTH=10,846.7'. TOP OF PATCH = 10858'. MIN ID= 2.45". OAL= 26.10'. ***JOB COMPLETE / FULLBORE UP NEXT*** 1/1/2023 ** ASSIST EL ** T/I/O= 626/697/73 Pumped 3 bbls 60/40 and 112 bbls 180* diesel down TBG to assist EL with running in hole with patch. FWHP=900/980/100 E-Line on lcoation upon departure 1/4/2023 ** MIT IA ** ( PASSED ) T/I/O= 579/563/75 Pumped 1.7 bbls diesel to test pressure of 585/1512/75. IA lost 45 psi. 1st 15 min and 6 psi. 2nd 15 min. Bled back 1.7 bbls to starting pressures. WV SV SSV closed MV open CV's OTG FWHP's 571/560/75 Tag hung on IA and DSO notified of well status upon departure. 1/6/2023 T/I/O = 587/610/76. Temp - SI. Conduct HPBD. Pumped 3 bbls 60/40 and 4 bbls 110* DSL into TBG. *** Job continued to 01-07-2023 *** 1/7/2023 *** Job continued from 01-06-2023 *** Pumped 195 bbls 180* DSL into TBG.Pad Operator notified upon departure. FWHP's = 600/1072/157 1/10/2023 T/I/O=823/532/156 AOGCC MIT IA PASSED to 3500 psi ( 3800 psi Max App ) ( Witnessed by Brian Bixby ) Pumped 6.1 bbls 140* diesel down IA to 3798 psi IAP lost 60 psi 1st 15 min IAP lost 14 psi 2nd 15 min Bled back ~6.2 bbls FWHPs=819/530/129 RIH W/ 1 7/16" CHD (1" FN), 2 1/8" CCL, 2 1/8" BRT, 2 1/2" SWITCH HOUSING, () BKR #10 SETTING TOOL, & 4-1/2" BAKER FLO GUARD PATCH TOP OF PATCH = 10858'. Pumped 1.7 bbls diesel to test pressure of 585/1512/75. IA lost 45 psi. 1st 15 min and 6 psi. 2nd 15 min. (g) EQUALIZED & PULLED 2-7/8" XX PLUG FROM NIPPLE REDUCER @ 11,967' MD AOGCC MIT IA PASSED to 3500 psi ( 3800 psi Max App ) ( Witnessed by Brian Bixby ) ** MIT IA ** ( PASSED ) () SET PATCH 10860' - 10879.5' ELEMENT TO ELEMENT PUMP PATCH DOWN AT .5 - 1.3 BPM WITH DIESEL. LOG BELOW STA#3 TO CORRELATE. LOG CORRELATED TO PDS LEAK DETECTION LOG DATED 10/07/2008 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-107 Pull Tbg Patch, Mill XN Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-113 50-029-23023-00-00 16026 Conductor Surface Intermediate Production Liner 6824 80 4231 12390 3721 15938 20" 10-3/4" 7" 4-1/2" 6839 35 - 115 34 - 4265 31 - 12421 12259 - 15980 35 - 115 34 - 2903 31 - 6934 6871 - 6832 None 470 2470 5410 7500 None 1490 5410 7240 8430 11735 - 15938 4-1/2" 12.6# L-80 34 - 12263 6648 - 6839 Structural 4-1/2" Baker Premier Packers 11718 / 6639, 11823 / 6693, 12223 / 6858 11718, 11823, 12223 6639, 6693, 6858 Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028257, 028258 & 028256 34 - 6873 N/A N/A Well Not Online 5702 1550 600 2518 2850 322-435 13b. Pools active after work:Aurora Oil Pool No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations to the best of my know December 3, 2022 By Anne Prysunka at 10:35 am, Dec 06, 2022 WCB 11-29-2024 RBDMS JSB 120623 ACTIVITY DATE SUMMARY 9/19/2022 ***WELL S/I ON ARRIVAL*** (CTD) BRUSH & FLUSH w/ 4 1/2" BLB & 3.80" GAUGE RING TO PATCH @ 10,863' MD. LRS PUMPED 160BBLS HOT DSL. ***JOB IN PROGRESS, CONTINUED ON 9/20/22 WSR*** 9/19/2022 T/I/O=160/580/91 Assist SL B&F Pumped 160 bbls 180* DSL down tbg Final WHP's 1050/908/158 SL on well at departure 9/19/2022 T/I/O= 1500/1100/50 Temp=S/I (TFS Unit 4 Pre SL with load and Kill) Loaded well with 3 bbls 60/40 followed by 297 bbls 1% Slick KCL followed by a 2 bbl 60/40 cap. Valve positions SV,WV,SSV= Closed MV=Open OAC, IAC= OTG. FWHP= 200/800/50 9/20/2022 ***CONTINUED FROM 9/19/22 WSR*** (CTD) JAR FOR 7 HRS ON BAKER 45KB STRADDLE PATCH AT 10,863' MD (Moving ~10' up / down). ***JOB IN PROGRESS, CONTINUED ON 9/21/22 WSR*** 9/21/2022 ***CONTINUED FROM 9/20/22 WSR*** (CTD) JAR ON PATCH @ 10,811' SLM FOR 7HRS TOTAL. ***JOB IN PROGRESS, CONTINUE FROM 9/22/22 WSR*** 9/22/2022 ***CONTINUED FROM 9/21/22 WSR*** (CTD) JARRED ON 45 KB PATCH @ 10863' MD FOR 3 HOURS (some movement up & down, unable to get patch past 10811' slm) ***JOB POSTPONED, WELL LEFT S/I, DSO NOTIFIED*** 9/25/2022 T/I/O= 2300/500/50 Assist SLickline (Load well) Road to location, RU and SB for Fluids ***Job cont. to 9-26-22 WSR*** 9/25/2022 ***WELL S/I ON ARRIVAL*** HES 759 R/U ***CONT WSR ON 09/26/2022*** 9/26/2022 ***CONT WSR FROM 09/25/2022*** PULL 45 KB PATCH FROM 10,863' MD RIG DOWN BRAIDED LINE ***CONT WSR ON 09/27/2022*** 9/26/2022 Job continues from previous day. (Load well) Pumped 5 bbls 60/40 down TBG followed by 250 bbls KCL. Pumped 4 bbls 60/40 spacer and 39 bbls Diesel for FP. Hang tags Slickline on location upon departure. 9/27/2022 ***CONT WSR FROM 09/26/2022*** PULL 4-1/2" NIPPLE REDUCER FROM X-NIPPLE @ 12,250' MD DRIFT W/ 20' OF 3.70" DUMMY WHIPSTOCK TO 12477' SLM ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS.*** Daily Report of Well Operations PBU S-107 () JARRED ON 45 KB PATCH @ 10863' MD FOR 3 HOURS (some movement up &@ down, unable to get patch past 10811' slm) PULL 45 KB PATCH FROM 10,863' MD RIG DOWN BRAIDED LINE PULL 4-1/2" NIPPLE REDUCER FROM X-NIPPLE @ 12,250' MD () JAR FOR 7 HRS ON BAKER 45KB STRADDLE PATCH AT 10,863' MD (Moving ~10' up / down) () JAR ON PATCH @ 10,811' SLM FOR 7HRS TOTAL Daily Report of Well Operations PBU S-107 10/1/2022 YELLOW JACKET E-LINE JOB OBJECTIVE: MILL NIPPLE AT 12250 FT MU MIRU WITH 9/32 LINE WELL TECH TRACTOR LOGGING TOOLS AND 3.804 MILL PRESSURE TEST SURFACE EQ 300 / 3000 CCL TO MILL TIP 33 FT CCL TAG DEPTH 12217 FT LOG CORRELATED TO TUBING TALLY PROVIDED WITH THE PROGRAM MILLING OPERATIONS WERE SUCCESSFUL - XN MILLED MILL OD UPON COMPLETION WAS 3.802" LOSS OF 2/1000" WELL SHUT IN UPON COMPLETION AND RETURN OVER TO WSC MILLING OPERATIONS WERE SUCCESSFUL - XN MILLED 6HW:KLSVWRFNIRU/DWHUDO 7.22.2022 By Anne Prysunka at 2:25 pm, Jul 22, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 R +LOFRUS$ODVND//&RX 7HFKQLFDO 6HUYLFHV$.'ULOOLQJ HPDLO PP\HUV#KLOFRUSFRP 5HDVRQ,DPDSSURYLQJWKLVGRFXPHQW 'DWH 0RQW\0 0\HUV DSR-7/22/22 BOPE test to 3500 psi. 24 hour notice to AOGCC. SFD 7/25/2022MGR05AUG22 10-404 dts 8/9/2022 8/9/2022 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date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´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¶0' E 3XOO´1LS5HGXFHUDW¶0' F 'ULIWSDVWZKLSVWRFNVHWWLQJORFDWLRQ 6HUYLFH&RLORU(OLQH0LOO;1LSSOH D 0LOOWKH;1QLSSOHWR´DWa¶0' 9DOYH6KRS3UH&7'7UHH:RUNDVQHFHVVDU\ 5LJ:RUN x 5HIHUHQFH3%86/37'VXEPLWWHGLQFRQFHUWZLWKWKLVUHTXHVWIRUIXOOGHWDLOV x *HQHUDOZRUNVFRSHRI5LJZRUN 0,58DQG7HVW%23(0$63ZLWKJDVSVLIWWRVXUIDFHLVSVL D *LYH$2*&&KUQRWLFHSULRUWR%23(WHVW 6HW:KLSVWRFN 0LOO:LQGRZ 'ULOO%XLOGDQG/DWHUDO 5XQDQG&HPHQW/LQHU 3HUIRUDWHRQO\LIQRWGRQHSRVWULJ )UHH]H3URWHFWDQG5'02 6HW/73 LIQHHGHGDQGSHUIRUDWHSRVWULJ $SSURYHGDOWHUQDWHSOXJSODFHPHQWSHU$$&L 7UHYRU+\DWW && :HOO)LOH 'ULOOLQJ(QJLQHHU -RVHSK/DVWXIND BOPE test to be witnessed by AOGCC. BOPE test to 3500 psi. mgr VHWDZKLSVWRFNLQ6 Sundry 322-435 PTD :HOO 'DWH 4XLFN7HVW6XEWR2WLV IW 7RSRI2WLV IW 'LVWDQFHVIURPWRSRIULVHU ([FOXGLQJTXLFNWHVWVXE 7RSRI$QQXODU IW C L Annular IW %RWWRP$QQXODU IW &/%OLQG6KHDUV IW &/3LSH6OLSV IW % % % % Kill Line Choke Line &/3LSH6OLS IW &/3LSH6OLSV IW 79 79 7 7 )ORZ7HH 0DVWHU 0DVWHU /'6 ,$ 2$ /'6 *URXQG/HYHO /3KRVHRSHQHQGHGWR)ORZOLQH CDR2-AC BOP Schematic &'55LJ V'ULS3DQ )LOO/LQHIURP+) 1RUPDOO\'LVFRQQHFWHG +3KRVHWR0LFURPRWLRQ +\GULO $QQXODU %OLQG6KHDU 3LSH6OLSV 3LSH6OLSV 3LSH6OLSV N0XG &URVV 3LSH6OLSV 3LSH6OLS +) QQHFHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHH MEMORANDUM TO: Jim Regg P.I. Supervisor , Z � z (ZF,1-7,, FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, December 21, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S-107 PRUDHOE BAY UN AURO S-107 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN AURO S-107 API Well Number 50-029-23023-00-00 Inspector Name: Adam Earl Permit Number: 201-113-0 Inspection Date: 12/9/2021 II1sp Num: mitAGE211213165753 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-107 Type Inj G ' TVD 6639 - Tubing 2642 , 2651 2645 - 2642 - -- PTD 2011130 Type Test, SPT- Test psi 3000 IA 560 3525 - 3437 - 3412 - BBL Pumped: 4.7 - 'BBL Returned: 4.6 OA 106 127 129- 129 - - — - - Interval REQvAR P/F P ✓ Notes' Tested as per AID 22.F001 MIT -IA well on trial of gas inj. Approved by AOGCC Mr. Wallace -Z Tuesday, December 21, 2021 Page 1 of 1 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Date:Thursday, November 18, 2021 10:50:45 AM Attachments:image003.png image005.png From: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Sent: Thursday, November 4, 2021 11:16 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Oliver, Thank you for the phone discussion on the well this morning. Your request for the additional 60 days evaluation is approved. Regards, Chris From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, November 4, 2021 10:45:52 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Chris, Per AOGCC approval, S-107 was placed under evaluation on temporary MI service on 9/13/2021. Over the course of the evaluation period no anomalous IA repressurization has been seen. Prior to submitting an amendment request to AIO 22F.001 to allow for WAG service, Hilcorp Alaska, LLC requests an additional 60 days to further evaluate the well for IA repressurization on MI. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Sent: Tuesday, November 17, 2020 2:44 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Oliver, Your request for 60 days MI monitoring is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, November 17, 2020 1:29 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Chris, S-107 was temporarily online with MI from 11/1-11/15/20. The well was swapped back to PWI service by operations on 11/15/20 due to needing the wells water injection capacity. Over the evaluation period no IA repressurization was seen (note the TIO and injection plots), but based on previous history the repressurization may just take some more time to manifest hence the requested 60 eval period. Once operations is able to put S-107 back on MI would it be ok to begin the 60 eval period again to get the necessary information to support an AA request? Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Sent: Friday, October 23, 2020 8:49 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Oliver, Your requested 60 days MI is approved. Chris From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, October 23, 2020 7:23:30 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: S-107 (PTD# 201113) request for temporary MI service Mr. Wallace, Per our discussion I would like to request approval for temporary MI service into well S-107 (PTD# 201113) for up to 60 days. This period will be used to evaluate for a potential amendment request to AIO 22F.001 which currently limits the well to PWI service due to slow TxIA communication when on MI. Target MI pressure is expected to be ~2400 psi. IA pressure will be maintained below 2100 psi, any repressurization would be managed by periodic bleeds. Diagnostics and testing history: 1/7/2020 AIO 22F.001 approved for continued PWI only due to IA repressurization on MI. 12/20/2019 AOGCC MIT-IA Passed to 3242 psi. 5/20/2019 LDL conducted, no leaks found. 3/27/2019 Under eval for IA repressurization while on MI. IA repress rate on MI= 23 psi/day 4/6/19à5/18/19 with MI pressure at ~2400psi 4/30/2009 AOGCC MIT-IA passed 3/10/2009 Patch set across leak. 10/7/2008 LDL logged found leak at 10860’ 7/10/2008 MIT-IA Failed 3 month TIO and injection plot: Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, youare hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptlyand permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data.No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, youare hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptlyand permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data.No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, youare hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptlyand permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data.No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, September 14, 2021 2:53 PM To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector S-107 (PTD #2011130) Temporary MI service From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, September 13, 2021 3:05 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector S‐107 (PTD #2011130) Temporary MI service Mr. Wallace, Injector S‐107 (PTD #2011130) is ready to be put on temporary MI injection for up to 60 days and is now classified as UNDER EVALUATION. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Thursday, November 19, 2020 12:21 PM To: Alaska NS ‐ PB ‐ EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Foreman <GC2Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad HUQ <AlaskaNS‐PBW‐GC2‐ WellpadHUQ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad LV <AlaskaNS‐PBW‐GC2‐WellpadLV@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad MN <AlaskaNS‐PBW‐GC2‐WellpadMN@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad RJ <AlaskaNS‐PBW‐GC2‐WellpadRJ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad S <AlaskaNS‐PBW‐GC2‐ WellpadS@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad W <AlaskaNS‐PBW‐GC2‐WellpadW@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad Z <AlaskaNS‐PBW‐GC2‐WellpadZ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Matthew Linder <mlinder@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector S‐107 (PTD #2011130) back on PWI All, 2 Injector S‐107 (PTD #2011130) was on MI from 11/01‐11/16 at which time it was swapped back to PWI for operational needs. The AOGCC has granted approval to re‐start the 60‐day injection period for MI. Please notify Well Integrity when the well is ready for MI to begin the 60 day injection period. In the meantime, the well will be classified back to Operable while it is on PWI. Please respond with any questions Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Sunday, November 1, 2020 2:47 PM To: Alaska NS ‐ PB ‐ EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Foreman <GC2Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad HUQ <AlaskaNS‐PBW‐GC2‐ WellpadHUQ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad LV <AlaskaNS‐PBW‐GC2‐WellpadLV@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad MN <AlaskaNS‐PBW‐GC2‐WellpadMN@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad RJ <AlaskaNS‐PBW‐GC2‐WellpadRJ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad S <AlaskaNS‐PBW‐GC2‐ WellpadS@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad W <AlaskaNS‐PBW‐GC2‐WellpadW@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad Z <AlaskaNS‐PBW‐GC2‐WellpadZ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector S‐107 (PTD #2011130) AOGCC approved temporary MI service All, Injector S‐107 (PTD # 2011130) has known TxIA on MI and operates under Administrative Approval for PWI service only. Hilcorp has received AOGCC approval to put on temporary MI service for 60 days to monitor the IA re‐pressurization rate with the intent of amending the current AA to include MI. The well will now be classified as UNDER EVALUATION to track the 60‐day injection period on MI. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 3 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Tuesday, November 17, 2020 2:44 PM To: Oliver Sternicki Cc: Alaska NS - PB - Field Well Integrity; Rixse, Melvin G (CED) Subject: RE: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Oliver, Your request for 60 days MI monitoring is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, November 17, 2020 1:29 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] Re: S-107 (PTD# 201113) request for temporary MI service Chris, S-107 was temporarily online with MI from 11/1-11/15/20. The well was swapped back to PWI service by operations on 11/15/20 due to needing the wells water injection capacity. Over the evaluation period no IA repressurization was seen (note the TIO and injection plots), but based on previous history the repressurization may just take some more time to manifest hence the requested 60 eval period. Once operations is able to put S-107 back on MI would it be ok to begin the 60 eval period again to get the necessary information to support an AA request? Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Friday, October 23, 2020 8:49 PM To: Oliver Sternicki Cc: Alaska NS - PB - Field Well Integrity Subject: Re: S-107 (PTD# 201113) request for temporary MI service Oliver, Your requested 60 days MI is approved. Chris From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, October 23, 2020 7:23:30 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Subject: S-107 (PTD# 201113) request for temporary MI service Mr. Wallace, Per our discussion I would like to request approval for temporary MI service into well S-107 (PTD# 201113) for up to 60 days. This period will be used to evaluate for a potential amendment request to AID 22F.001 which currently limits the well to PWI service due to slow TxIA communication when on MI. Target MI pressure is expected to be 2400 psi. IA pressure will be maintained below 2100 psi, any repressurization would be managed by periodic bleeds. Diagnostics and testing history: 1/7/2020 AID 22F.001 approved for continued PWI only due to IA repressurization on MI. 12/20/2019 AOGCC MIT -IA Passed to 3242 psi. 5/20/2019 LDL conducted, no leaks found. 3/27/2019 Under eval for IA repressurization while on MI. IA repress rate on M1= 23 psi/day 4/6/1945/18/19 with MI pressure at-2400psi 4/30/2009 AOGCC MIT -IA passed 3/10/2009 Patch set across leak. 10/7/2008 LDL logged found leak at 10860' 7/10/2008 MIT -IA Failed 3 month TIO and injection plot: 1 N Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Tuesday, January 7, 2020 10:10 AM 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; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: Injector S-107 (PTD #2011130) Under Eval clock reset All, Injector S-107 (PTD # 2011130) was made Under Evaluation on 12/06/19 to pursue Administrative Approval for Produce Water Injection. The AA request is currently in review with the AOGCC and the State has given approval to continue water only injection while the AA progresses. The Under Evaluation clock will be reset for tracking purposes while the State reviews the AA request. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 F om: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Se Friday, January 3, 2020 10:17 AM To:'ch ' Wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC ility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <A GC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOps bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeIIPadDFT com>; AK, OPS Well Pad HUQ <AKOPSWeliPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeliPadLV@bp.com>; A Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD OPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD W <AK ELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAr @bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Eng RESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com , ottingham, Derek <Derek.Nottingham@bp.com> \ Cc: 'Begg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.cohr>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp:com>; Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, January 3, 2020 10:17 AM 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, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Injector S-107 (PTD #2011130) Under Eval clock extended All, Injector S-107 (PTD #2011130) was made Under Evaluation on 12/06/19 to put on Produced Water Injection and perform an AOGCC witnessed MIT -IA with the intent to pursue an AA for water only injection. The well was put on water injection on 12/10/19 and an AOGCC witnessed MIT -IA passed to 3,242 psi on 12/20/19. BP has submitted the AA request to the State. The Under Evaluation clock will be extended four days to cover the agreed upon 28 days of water injection while awaiting the State's review of the AA request. Plan forward: 1. Operations: Put on Injection - Done 2. DHD: State Witnessed MIT -IA- Done 3. Well Integrity Engineer: Pursue AA— In progress Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: O Well Integrity Engineer Sent: Friday, Dece 2019 4:40 PM To:'chris.wallace@alaska.gov ' wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2Facill bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS ellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Contro opsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeliPadDFTN2@bp.com>; AK, OPS Well Pad HUQ <AK IIPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeliPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp. AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS We W <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt MEMORANDUM State of Alaska Permit Number: 201-113-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ��f,C9 �Z'z7l��i / DATE: Friday, December 27, 2019 SUBJECT: Mechanical Integrity Tests i f BP Exploration (Alaska) Inc. Packer Depth Pretest Initial S-107 FROM: Bob Noble PRUDHOE BAY ON AURO S-107 Petroleum Inspector 6639 Src: Inspector 873 Reviewed By: 877 P.I. Supry (�Z NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-107 API Well Number 50-029-23023-00-00 Inspector Name: Bob Noble Permit Number: 201-113-0 Inspection Date: 12/20/2019 Insp Num: mitRCN19I220131027 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I Sa07 ITypeInj w'TVD 6639 - Tubing 873 875 877 878 ' PTD 2011130 'Type Test SPT Test psi 1660 IA 363 3293 - 3251 - 3242 - BBL Pumped: 5.3 " BBL Returned: 5.3 OA too - z93 zsa zn Interval IOTHER P/F P Notes: Known TxIA Common MI. Test is to pursue an AA for water injection only. ✓ Friday, December 27, 2019 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, December 6, 2019 4:40 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; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras 1 Subject: UNDER EVALUATION: Injector S-107 (PTD #2011130) MIT -IA to pursue AA All, WAG Injector S-107 (PTD # 2011130) was made Not Operable on 05/22/19 for having TxIA communication while on Miscible Gas Injection. An offline MIT -IA passed to 2,448 psi on 05/22/19. The State has given BP approval for a 28 day injection period on water only to perform an AOGCC witnessed MIT -IA and pursue an AA. If the MIT -IA passes, BP will seek Administrative Approval for continued operation on Water Only Injection. The well is now classified as UNDER EVALUATION to perform aforementioned work. Plan forward: 1. Operations: Put on Injection 2. DHD: State Witnessed MIT -IA 3. Well Integrity Engineer: Additional diagnostics as needed/pursue AA Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: Ak—,'&W-0 WeII Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, 22, 2019 8:27 AM To: 'ch ris.wallace @alaska.' <chris.wallace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSG ilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; PS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Pro4or Pad DFT N2 <AKOPSWeIIPadDFTN2@bp.com>; AK, OPS We Pad LV <AKOPSWeIIPadLV@bp.com>; AK, OPS Well Pad MN <akopsprodcontrollersl@bp.com>; AK, OPS Well IQ <AKOPSWeliPadHUQ@bp.com>; AK, OPS Well PadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.c >; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RE East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWel t2@bp.com>; (CASED HOLE Well Log Transmittal To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE, Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) 201113 31147 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Leak PointTM Survey 2) Signed Print Name: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2 — 1 900 Benson Blvd. Anchorage, AK 99508 GANCPDCgUSAANC hou xwh BP corn and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 20 -May -19 S-107 CD RECEIVE® AUG 2 92019 AOGCC 50-029-23023-00 Date : IDLY PROACTIVE DIAGNOSTIC SERVICES, INC., 130W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CDMEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM httpsPreadcasedhole-my_shuspoim coWpersonal/dieneod lams_reedcesedhme_comDocuments DesktopBP_Tomsem does Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Wednesday, June 26, 2019 10:59 AM To: AK, GWO Well Integrity Engineer Cc: Regg, James B (CED); AK, GWO Well Integrity Well Information Subject: RE: Permission to put Injector S-107 (PTD #2011130) on water injection Andrew, Approved for the requested 28 days water injection as per the plan below. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7' Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276- 7542 (fax), chrismallace0alaska.eov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or ch(is.wallace@alaska.gov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, June 26, 2019 10:04 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; AK, GWO Well Integrity Well Information <a kgwowel I integritywe@bp.com> Subject: Permission to put Injector S-107 (PTD #2011130) on water injection Mr. Wallace, Injector S-107 (PTD #2011130) is a WAG injector that was made Not Operable on 05/22/19 for TxIA communication while on miscible gas injection. On 5/20/19 a Leak Detect Log was performed, but did not identify any leak signatures. After the well was shut-in, a passing MIT -IA was performed on 05/22/19 to 2,448 psi. BP plans to pursue an AA for water injection only and is requesting your approval to put the well Under Evaluation for 28 days so it can be placed on water injection with the intent of performing an AOGCC witnessed MIT -IA. If the MIT -IA passes, BP will apply for Administrative Approval to operate the well for water injection only. The Under Evaluation period would begin when the surface kit is reconfigured for water injection and Operations can support putting the well on injection. Please respond at your earliest convenience. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Wednesday, May 22, 2019 8:27 AM 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, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector S-107 (PTD #2011130) TAA communication on MI All, WAG Injector S-107 (PTD #2011130) was Under Evaluation for anomalous IA repressurization while on MI. On 05/20/19 Slickline performed a leak detect log and the results are currently being processed. The well will now be classified as NOT OPERABLE. The Anchorage Engineers will analyze the leak detect log and determine a repair. If a leak is not identified, an AA for water only injection will be pursued. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, April 24, 20191:20 PM To:'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPad DFTN2@bp.com>; AK, OPS Well Pad HUQ <AKOPSWeliPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPad LV@bp.com>; AK, OPS Well Pad MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeIIPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Nottingham, Derek <Derek. Nottingham @ bp.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, April 24, 2019 1:20 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 OFT 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 5; 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 1; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Injector S-107 (PTD #2011130) Under Eval clock extended due to SIMOPs delaying LDL All, Injector S-107 (PTD # 2011130) was made Under Evaluation on 03/27/19 for anomalous IA casing repressurization. On 03/29/19 the Well Head Technician performed a passing PPPOT-T. The town engineering team submitted a plan to perform a LDL, but CDR -2 is currently on S-105 and it has been determined that the locations are too close in proximity to perform SIMOPs safely. The Under Evaluation clock will be reset to allow sufficient time for the CTD rig to move off location then perform the required diagnostic work. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Wednesday, March 27, 2019 2:38 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK; OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPad DFTN2@bp.com>; AK, OPS Well Pad HUQ<AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com> AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>;'AK,,QPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB.East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsapt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Nottingham, Derek <De re k. N ott i n g h a m@ b p. c o m> RECEIVED • 2 0 11 13 MAR 19 2018 WELL LOG TRANSMITTAL#904586567 29 14 2 AOGCC To: Alaska Oil and Gas Conservation Comm. March 14, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: S-107 Run Date: 1/21/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 S-107 Digital Log file 1 CD Rom 50-029-23023-00 Production Profile (Final Field Print) SCANNED 1 Color Log 50-029-23023-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRSANC@halliburton.com&AKGDMINTERNAL@bp.com /2MDate: / ( � Signed: Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Wednesday, March 27, 2019 2:38 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 J Subject: UNDER EVALUATION: Injector S-107 (PTD #2011130) anomalous IA casing repressurization Attachments: S-107.pdf All, WAG Injector S-107 (PTD #2011130) is currently on MI and was flagged on 03/27/19 for anomalously high Inner Annulus casing pressure. The T/I/O pressures were reported to be 2150/1100/100 psi. The IA was recently bled On 03/14/19 from 1,150 psi to 500 psi. The rate of IA repressuirzation could indicate possible TxIA communication. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Well Head Tech: Perform PPPOT-T 2. DHD: Bleed IA pressure 3. DHD: Perform Daily monitors 4. Well Integrity Engineer: Additional diagnostics as needed 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 l\ DATE: Wednesday,May 03,2017 P.I.Supervisor e9ei S(It jt SUBJECT: Mechanical Integrity Tests L BP EXPLORATION(ALASKA)INC. S-107 FROM: Lou Laubenstein PRUDHOE BAY UN AURO S-107 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-107API Well Number 50-029-23023-00-00 Inspector Name: Lou Laubenstein Permit Number: 201-113-0 Inspection Date: 4/27/2017 Insp Num: mitLOL170427132549 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-I07 Type Inj W' TVD 6639, Tubing 1258 1259 , 1259 • 1258• PTD 2011130 ' Type Test SPT Test psi 1660 - IA 380 2196 • 2160 - 2154 - BBL Pumped: 6.3 -BBL Returned: 3.1 ' OA 110 141 - 143 143 - Interval 4YRTST P/F P ✓ Notes: scAtitiED AUG 2 42017, Wednesday,May 03,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 08,2013 TO: Jim Regg e----, P.I.Supervisor 1 1 5/10{1i SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC S-I 07 FROM: Jeff Jones PRUDHOE BAY UN AURO S-107 Petroleum Inspector Src: Inspector Reviewed Byrrom�� P.I.Supry Jgr NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-107 API Well Number 50-029-23023-00-00 Inspector Name: Jeff Jones Permit Number: 201-113-0 Inspection Date: 4/29/2013 Insp Num: mitJJl30430144736 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min _.. In' TVD IA 1835 1841 1846 Well S 107 � !Type J G• 6639 711 1868 I 1829 j PTD I 2011130 Type Test!SPT Test psi 1659 ! OA 123 128 130 132 133 135 - 4YRTST ! P 1 g 2384 2384 I 2382 F 2381 2380 2380 Interval 1P/F I Tubin ! Notes: 2 BBLS methanol pumped.Test fluid temp. 10 degrees,well head temp. 105 degrees.75 min.data:Tbg-2384,IA-1852;OA-136.Inspection Supervisor Jim Regg will determine pass/fail staus of this test. I well inspected,no exceptions noted.Per J.Regg-Pass. FEB 2 0 gl, 4 �NEp Wednesday,May 08,2013 Page 1 of 1 • ~ bp BP Exploration (Alaska) Inc. ~ Attn: Weil Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ Enclosed please find a spreadsheet with a list of wells from S-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 letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ° ' ,'~~~ ~~ ~ ~' ~; ~..E ~m (z ~°; "r ~ (i r°; ~.a ,,, , Torin Roschinger BPXA, Well Integrity Coordinator ~ • BP Exploration (Alaska ) inc. Surface Casing by Conductor An~ulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404)_ S-pad n~e RMSM009 W ell Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top ott date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al S-018 1952020 0.25 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 0.25 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 S-oa 1830790 0 NA 0 NA o.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-O88 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1971230 0.5 NA 0.5 NA 3.4 5/31/2009 5-71 B 1990530 0.25 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 7.7 6/1/2009 5-13 1821350 B NA 8 NA 55.3 6/1I2009 5-15 1840170 025 NA 025 NA 3 6J2/2009 S-77C 2020070 025 NA 025 NA 2.6 6/1/2009 S-78A 2027630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 79705~0 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27/2009 S-3o 1900660 0.5 NA 0.5 NA 5.t 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.d 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3,4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .e5in 5/31/2009 S-36 1921160 0.~5 NA 0.75 NA 425 5/27/2009 S37 1920990 125 NA 125 NA 11.9 5/27/2009 S-38 1921270 025 NA 025 NA 102 5/27/2009 S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA o.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5l28/'2009 S-t00 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 125 NA 125 NA 17.9 5/29/2009 5-702Lt 2031560 725 NA 125 NA ~7.7 5/31/2009 5-703 2007680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 1625 NA 1625 NA 174.3 6/2/2009 S-107 ~ 2017130 225 NA 225 NA 28.9 5/18/2009 S-toe 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 77.75 NA 11.75 MA 98.6 5/3W2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 5-712 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.~5 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 1.25 NA 125 NA 102 5/30/2009 5-115 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 S-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5-717 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 5-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-122 2050810 3 NA 3 NA 213 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.a 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 S-125 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 725 NA 75.3 6/1/2009 S-200 1972390 1.25 NA 125 NA 14.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29I2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 025 NA 025 NA 1.7 6/i/2009 S-400 2070740 2 NA 2 NA 9.4 5/29/2009 5-401 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 ~ ~.J MEMORANDUM TO: Jim Regg / P.I. Supervisor ~~'~ ~ ~~'l ~Z~~t EROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 04, 2009 SUBJECT: Mechanical lntegity Tests BP EXPLORATION (ALASKA) INC 5-107 PRUDHOE BAY iIN AURO 5-107 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,~'(-'-- Comm Well Name: PRUDHOE BAY UN AURO 5-107 Insp Num: mitRCN090430141247 Rel Insp Num: API Well Number: 50-029-23023-00-00 Permit Number: 201-113-0 Inspector Name: Bob Noble Inspection Date: 4/30/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-lo7 Type Inj. w 'I'VD 6639 IA s9o zzoo - z17o u6o P.T.D 2011130 TypeTest sPT Test psi 2200 ~ QA 460 570 560 560 Interval OTHER p~, P r Tubing 1125 1125 1125 1125 NOtes: Rrove TxIA comm mitigated with a tubing patch ,~ Monday, May 04, 2009 Page 1 of 1 OPERABLE: 5-107 (PTD #201~0) Patch Restored Tubing Integrity • Page 1 of 3 Regg, James B (DOA) From; NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~j6 `~, Sent: Friday, May 01, 2009 11:09 AM ~~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Well Pad SW; Collins, Patrick J; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: S-107 (PTD #2011130~atch Restored Tubing Integrity All, Well S-107 (PTD #2011130) passed an MIT-IA to 2200 psi on 04/30/09. The passin~ test confirms the success of the tubing patch in restoring integrity. el~well has been reclassified as Operable and may remain on injection. -° Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 ~ ~ 4`'. ` u ,;.' , ' ~ 41 ~~ ~ ;~ G~ll,'; Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, March 22, 2009 10:28 AM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Well Pad SW; Collins, Patrick J; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S-107 (PTD #Z011130) Patch Restored Tubing Integrity - Needs AOGCC MITIA Post Injection All, Well S-107 (P7D #2011130) has passed an MITIA after the patch was set to restore tubing integrity. The well has been reclassified as Under Evaluation so that slickline may pull the plug, Operations may place the well on injection, and an AOGCC witnessed MITIA for UIC compliance may be conducted. Please let us know if you have any questions. Thank you, Anna ~u6e, ~P. E. Well fntegrity Caordinator GPB Wells Graup Phone: {907) 659-5102 8/6/2009 OPERABLE: 5-107 (PTD #201~0) Patch Restored Tubing Integrity • Page 2 of 3 Pager: {907j 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, September 19, 2008 2:33 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operetions Supervisor; Daniel, Ryan Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P(ASRC) Subject: NOT OPERABLE: S-107 (PTD #2011130) TxIA communication All, Weii S-107 (PTD# 2011130) was secured with a downhole piug on 09/19/08 as evidenced by a passing CMIT- TxIA to 3500 psi. The well has been reclassified as Not Operable and shall remain shut-in until the tubing integrity has been restored. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, August 26, 2008 4:15 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Young, Jim Subjed: UNDER EVALUATION: S-107 (PTD #2011130) Possible TxIA communication Jim and Tom, After a bleed on well S-107 (PTD #2011130) that took place on 08/26/08, the IAP was found to be tracking the tubing pressure after a 30 minute monitor. An AOGCC witnessed MIT-IA recently passed on 07/31/08. The weil has been reclassified as Under Evaluation for further diagnostics. We intend on keeping the weli on water injection for all diagnostics. The plan forward for the weil is as follows: 1. D: Bleed IAP - DONE, IAP tracked tubing 2. F: MIT-IA to 4000 psi 3. WIC: Eval for further diagnostics A wellbore schematic, TIO plot and Injection Plot have been inciuded for reference. « File: S-107 TIO & Injection plot.ZlP »« File: S-107.pdf» 8/6/2009 OPERABLE: 5-107 (PTD #201~0) Patch Restored Tubing Integrity ~ Page 3 of 3 Please call with any questions or concerns. 7hank you, Torin Rosc{iinger (Filling in for Anna Dube) Well Integrity Engineer Office (907) 659-5525 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1923 8/6/2009 ~~~~:~~~~~~ ~ STATE OF ALAS ALAS~IL AND GAS ~~WS~P~/ N COMMI~N REPORT OF SUyN~~1G;~~~,~L~~I~J4TIONS ~90 1. Operations Abandon ~ Repair Well Q_' Plug Per~~~~~p Stimulate~ Other ~ TUBING PATCH Performed: Alter Casing ~ Pull Tubing ~ ~ Pertorate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~elopment ~ Exploratory I! 201-1130 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service - 1~' 6. API Number: Anchorage, AK 99519-6612 50-029-23023-00-00~ 7. KB Elevation (ft): 9. Well Name and Number: 69.94 KB ^ S-107 - 8. Property Designation: 10. Field/Pooi(s): ADLO-028256 , PRUDHOE BAY Field/ AURORA OIL Pool 11. Present Well Condition Summary: Total Depth measured 15980 - feet Plugs (measured) None true vertical 6832 feet Junk (measured) None Effective Depth measured 15938 feet true vertical 6839 feet Casing Length Size MD ND Burst Collapse Conductor 115 20" 91.5# H-40 35 - 150 35 - 150 1490 470 Liner 3721 4-1/2" 12.6# L-80 12259 - 15980 6871 - 6832 8430 7500 Production 12390 7" 26# N-80 31 - 14421 31 - 6934 7240 5410 Surtace 4230 10-3/4" 45.5# L-80 35 - 4265 35 - 2903 5210 2480 y; ~ ~ `'° ~~~~~ ~~~`~ ~~ ~~' ~~ ~ ~~ ~~ Perforation depth: Measured depth: SEE ATTACHED - ,_ "` ` ` _ _ ~ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 34 - 12263 4" SINGLE SET TB PATCH 10563 10878 Packers and SSSV (type and measured depth) 4-1/2" Baker PRM Packer 11718 4-1/2" Baker PRM Packer 11823 4-1/2" Baker PRM Packer 12223 4-1/2" Baker ZXP Packer 12259 4" 45 "KB" STRADDLE PKR 10863 10878 4-1/2" EXT CSG PKR 15019 12. Stimulation or cement squeeze summary: I >~~ ~ ~ ~ '~~ ~ ntervals treated (measured): ~3r~ ~~ r,J,_ --~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Derelopment ~ Sen~ice ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil l~' Gas ~ WAG ~ GINJ 1 WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble '~~~~."~+~ ~ ~~'~:_ ` ~ `;• ;i '~~~~" Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date 4/8/2009 ~~~ Form 1 g _t ,~~~ ~yrY~of S-107 201-113 PERF ATT4CHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-107 7/17/01 PER 11,728. 11,730. 6,644.32 6,645.35 S-107 7/17/01 PER 11,949. 11,951. 6,751.47 6,752.33 S-107 7/18/01 SQZ 11,728. 11,951. 6,644.32 6,752.33 S-107 7/28/01 SL 15,127. 15,938. 6,991.66 6,839.26 S-107 7/31/01 BPS 11,900. 11,905. 6,729.51 6,731.83 S-107 7/31/01 PER 11,735. 11,737. 6,647.92 6,648.94 S-107 7/31/01 PER 11,850. 11,852. 6,705.73 6,706.7 S-107 8/2/01 BPP 11,900. 11,905. 6,729.51 6,731.83 S-10T 8/3/01 PER 11,900. 12,150. 6,729.51 6,830.09 S-107 8/9/01 STC 11,823. 12,223. 6,692.48 6,857.66 S-107 5/9/02 BPS 12,209. 12,219. 6,852.35 6,856.14 S-107 5/9/02 STO 11,823. 12,223. 6,692.48 6,857.66 S-107 6/9/02 BPP 12,209. 12,219. 6,852.35 6,856.14 S-107 9/18/08 BPS 11,633. 15,127. 6,594.33 6,991.66 S-107 9/19/08 BPP 11,633. 15,127. 6,594.33 6,991.66 S-107 2/23/09 BPS 12,236. 12,238. 6,862.61 6,863.37 S-107 3/11/09 STO 10,863. 10,878. 6,179.72 6,187.69 S-107 3/30/09 BPP 12,236. 12,238. 6,862.61 6,863.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET F!L FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ! S-107 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/1 T/I/0=1500/940/180 Temp=Sl Assist S-Line Brush & Flush (Patch tubing to restore tubing integrity) Spear in to TBG w/5 bls of ineth followed by 146 bbls of 180* diesel followed by 20 bbls of 20* diesel followed by 34 bbis of 1 SO" diesel. Final WHP=600/1000/200 Slickline has control of well on departure. 2/1/2009 ""'CONTINUED FROM WSR 01/31/09`*` RAN 3.80" GAUGE RING, 4 1/2 BRUSH TO 2743' SLM STOPPED DUE TO DEVIATION BRUSHED TBG TO 12274' SLM W/ 3.50" GAUGE RING, 4 1/2 BRUSH BRUSHED TBG W/ 3.80" GAUGE RING, 4 1/2 BRUSH TO 11968' SLM (UNABLE TO PASS SLIDING SLEEVE) BRUSHED TBG W/ 4 1/2 BRUSH , 3.625" GAUGE RING TO 12270' SLM "`CONTINUED ON WSR 02/02/09""' 2/2/2009 "'`'`CONTINUED FROM WSR 02/02/09"` TAGGED/BRUSHED XN NIPPLE @ 12.255' SLM W/ 3.805" CENT, 4 1/2 DRIFTED W/ 10' x 3 70" DMY PATCH TO 1~~~~' ~i nn STOP & POOH. DID NOT S/D. NO PROBLEMS. RIH W/ 3.85" GAUGE RING TO 2246' SLM (POSS. SVLN) 12,252' SLM PULLED NIPPLE REDUCER FROM 12,256' SLM """CONTINUED ON 2/3/09"" _ '""`'CONT. FROM 12/2/09 WSR""' ATTEMPT TO SET 4-1/2" x 2-7/8" NIPPLE REDUCER IN XN NIP. @ 12,252' SLM RAN 3.80" MAGNET TO SVLN @ 2246' SLM (MAGNET COVERED IN METAL 12.270' SLM (I~tAC_',NFT COVERED `*"CONTINUED ON WSR 02/04/09""" "`'"`CONT. FROM 2/3/09 WSR"`** MAKE 2 RUNS TO 12,270' SLM W/ 3.48 MAGNET, RECOVERED METAL ~HAVINC~S *'"`WELL S/I PAD OP NOTIFIED*"" • • 2/22/2009!"""**WELL S/I ON ARRIVAL**""* (pre patch) 'BRUSHED TUBING TO XN NIPPLE @ 12198' SLM, W/ 4 1/2" BRUSH & 3.805" {GAUGE RING i DRIFTED W/ 3.70" x 20' DUMMY PATCH TO 2226' SLM, SD UNABLE TO ~ WORK PAST I DRIFTED W/ 3.70 x 10' DUMMY PATCH TO 2226' SLM, SD 3 TIMES FELL `THROUGH SLOWLY STOPPED C~3 11000' SLM """""CONT ON WSR 2/22/09**'""' 2/22/2009,T/I/0=900/900/100 Temp=Sl Assist Slickline, Brush and Flush (Patch Tbg to 'restore Integrity) Pumped 5 bbls neat methanol and 200 bbls 180"F diesel down 'Tbg while Slickline brushed. *""Continued AWGRS on 2-23-09'`** 2/23/2009;T/U0=200/160/140 Assist Slickline, CMIT TxIA FAILED to 2500 psi ,(Tbg -: Patch) Pumped 20 bbls diesel down Tbg. Established LLR-T of 1 bpm @ 1540 ;. psi. *"'Continued on 2-24-09**" 2/23/2009=T/I/0= 250/300/150. Temp= SI. IA FL (Assist Slick Line). IA FL near surface. 2/23/2009';,*''''Continued AWGRS from 2-22-09""* Assist Slickline with brush and flush, ,~CMIT Tx IA FAILED to 2~00 ~.si ,(Tbg Patch) Pumped 50 bbls of diesel into Tbg ;while Slickline brushed. Pumped an additional 30 bbls of diesel into Tbg to attempt CMIT TxIA after plug was set. Did not reach test pressure after 30 bbls. „„, (DHD shot IA FL @ 30 ft.) Moved over to S-108 to hot the Tbg while Slickline reset the plug. Final WHP's= 250/300/140. Slickline on well at departure. 2/23/2009~*""`CONT FROM WSR 2/22/09**"" (pre patch) BRUSHED TUBING W/ 4 1/2" BRUSH & 3.805" G. RING FROM 1900' TO 2500' ;SLM ~LRS PUMPED 50 BBLS OF DIESEL @ 2 BPM € DRIFTED W/ 3.7" DMY PATCH TO 2234' SLM UNABLE TO WORK PAST ?c~rT ~~ in~~ .. n~ia~~ niinni r n~ni in~n ~~nn~n~ oi nn ATTEMPT TO CMIT TxIA. ( FAIL) ACHIEVED A RATE OF 1 BBU MIN @ 1600 """""'CONT ON WSR 2/24/09"'""` 2/24/2009'=.,T/I/0=700/220/160 Assist Slickline, ~CMIT-TxIA FAILED to 2500 psi (Tbg ° Patch) Pumped down Tbg with 62 bbls diesel at 1 bpm, could not reach test 'pressure. Assist Slickline with LDL. Speared into Tbg with 5 bbls neat methanol fand continued with 113 bbls of 120''F seawater."""WSR Continued on % 02/25/09""" ! ~ --.~ _.___ __ ___ _ ~__.~*** _.~~_ ~~___._____.____________ __*** __ ____~__._ ______ ~___~ _~__ __. 2/24/2009; Continued AWGRS from 2-23-09 Assist Slickline, CMIT TxIA to 2500 psi ; ~(Tbg Patch) No fluids pumped. Job postponed, Slick-line on well at departure. i ~ i ~ # ~ ~ } i x 's F t ? k ~ ! i i ~ 's ~~ ~~~~~~ 2/24/2009~*'`' CONT FORM WSR 02/24/09~"*"~~ (pre~patch) ~~~-~~~~~ ~~_"~~~ ~~~~~~.~~~~~~~~ € s LRS ATTEMPTED TO CMIT TXIA FAILED W/ A LLR OF 1 BPM C«~ 1580 LBS ; PULLED AND RESET 2 7/8" XX PLUG @ 12236' SLM ~ LRS ATTEMPTED TO CMIT TXIA FAILED W/ A LLR OF 1 BPM @ 1600 LBS ~ IN HOLE W/ SLB LDL ~"""'"`CONT ON WSR 2/25/09""**" ~~ ~ ~ a~ _~~..~ _~.__._ ~ ~~_ __ ._ ,.~a _ ~ m~.r_. ~_..~___ _.._ __~ `' _~_~ _ ~.__ _ __ ~.____._ ._____________~_.~.~.~ ~ ~ 2/25/2009:`MACHINING COST FOR CHROME SLIP CAGE REPLACEMENT SUB AND ?CYLINDERS AND CUTTING MULE SHOE FOR BOT KB ONE SET PATCH FORt S-107. x i ~ r__ ~ __..____._~ __. . .,m...._. .. .~_ ._ ._ ..__..~ . __. ....._.__. ~~.. . _._._~. ~~. _M~_ .. ~~~ . _..__~ _ ..____~ _.__~ 2/25/2009 ""* CONT FROM WSR 02/24/09 ""`' ; RAN SLB DL PER PROGRAM FROM 12250' MD TO SURFA('~~ EAK, ,,xFOUND @ 12165' MD~,,, x""'' WELL LEFT S/I, PAD OP NOTIFIED "''* 5 ~ ; i e.., ~__~.~~_________ ~~~ . _._~_~.___.....~..___~__~._.__~ __..~_..~_n_______a___~______~.._~_ ._...._w ~_~._____ .~.~ 2/25/2009; *"*Continued AWGRS from 2/24/09""* Assist Slickline with LDL (Tbg Patch) ; 3 Pumped down Tbg with 282 bbls seawater and 139 bbls 1% KCI during LDL. ~ Freeze protected Tbg with 3 bbls neat methanol and 38 bbls dieseL € si FWHP's=400/360/300. Slickline on well at departure ' ; ; i E I ~ y I _,.._ _ _~_..... . _~._~.~....._._,~.1.....~.._~........_____..,..___.,.____»~»....,..._____. ______.____.,..w~... ..,.,.W. ._._....~..,..~..~_...._. _..~..........,._.~.~....~..~. ~..~......~. ~.....sa...~ ~ ~ T/I/O = 10/150/140. Temp = SI. T& IA FL for E-Line. T FL @ 530' (8 bbl). IA FL near surface. SV, WV, SSV shut. MV open. IA & OA otg. NOVP. 3/10/2009;*""WELL SHUT IN ON ARRIVAL*"" =MASTER OPEN, SSV=CLOSED, WING CLOSED E INITIAL T/I/O = 100/190/170 PSI ~SET BAKER 45 "KB" SINGLE SET PATCH 3.70 OD 2.37 ID _- 15' ELEMENT TO ELEMENT PATCH FROM 10862.5'-10877.5' = FINAL T/I/O = 50/190/170 ;"**JOB CONTINUED ON 11-MARCH-09*"* 3/11/2009'°***JOB CONTINUED FROM 10-MARCH-09*"" ' PATCH SET FROM 10862.5'-10877.5' FINAL T/I/O = 50/190/170 "°WELL LEFT SHUT IN, MASTER OPEN, SSV=CLOSED, WING CLOSED ; ***JOB COMPLETE*"" 3/20/2009; Prep for up-coming job, continued on 2-21-09 3/21/2009`,,'T/I/0=0/170/0 Temp = SI MIT IA PASSED to 2200 psi 2nd test (Post patch) ; Pressured IA w/ 8.2 bbls neat methanol to test pressure. IA had no pressure loss ';in 30 mins Bled pressure to 0 psi. Final WHP=O/0/0 SV=C, WV=C, SSV=OTP, a MV=O, IAV=OTG, OAV=OTG ~ ~ ~ ~ 3/30/2009i`*" WELL S/I ON ARRIVAL **'` (post patch) ~ EQUALIZED 2 7/8" XX PLUG IN NIP RED ~"'* CONT ON 3/31/09 "''" 3/31/2009i*** CONT FROM 3/30/09 *'* (post patch) *** ICE PLUG @ 4504' SLM *** :RAN 2-7/8" GS, SET DOWN IN SLD SLV Q 11,952' SLM. WORKED ;THROUGH. SD IN NIP RED C«3 12,236' SLM (12250' MD), €COULDN'T LATCH. GS SHEARED. ;RAN 2 7/8" GR w/ STEEL PIN, SAT DOWN SOLID @ 4504' SLM. GR COME ; BACK W/ ICE ~ RAN 3.00" S-BAILER TO 4504' SLM, RECOVERED HYDRATES. ' PUMPED 1.5 bbl DIESEL, TBG PRESSURED UP TO 2000# WILL RETURN AFTER LRS PUMPS METH TO CLEAR ICE PLUG ;"** 2 7/8" XX PLUG HAS BEEN EQUALIZED. LEFT IN HOLE *.*" "'"* WELL LEFT S/I, PAD OP NOTIFIED """` __.___.._ .__, ____ .. _ .._._m .._ _~ _ ~. _~__ _.._~ _.__ _ ____.__. _M_ ~ ..______.__ 4/2/2009;T/I/0= 500/120/180, temp= S/I. Hydrate iceplugm~(Tubing Integrity). Pumped .8 ; bbis of 0" methonal down tubing, pressured up to 3000 psi. Monitored for 10 : minutes, no pressure change. Bled down tubing threw bleed hose to S-113 :flowline. Pumped .6 bbis of 0" methonal down tubing to pressure up to 3000 psi. ; Monitored for 10 minutes, no pressure change. Bled down tubing threw bleed ; hose to S-113 flowline. T/I/0= 300/120/180 Swab, Wing, SSV= closed. Master, IA, OA FLUIDS PUMPED BBLS 607 DIESEL 139 1 % KCL 23 METH 8.2 NEAT 777.2 Total UNDER EVALUATION: S-1(~TD #2011130) Patch Restored Tubil~Itegrity -Nee... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, March 22, 2009 10:28 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2MIRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Well Pad SW; Collins, Patrick J; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S-107 (PTD #2011130) Patch Restored Tubing Integrity -Needs AOGCC MITIA Post Injection All, Well S-107 (PTD #2011130) has passed an MITIA after the patch was set to restore tubing integrity. The well has been reclassified as Under Evaluation so that slickline may pull the plug, Operations may place the well on injection, and an AOGCC witnessed MITIA for UIC compliance may be conducted. Please let us know if you have any questions. Thank you, Anna 1~u6e, ~ E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: 'Friday, September 19, 2008 2:33 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; Daniel, Ryan Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: NOT OPERABLE: 5-107 (PTD #2011130) TxIA communication All, Well S-107 (PTD# 2011130) was secured with a downhole plug on 09/19/08 as evidenced by a passing CMIT- TxIA to 3500 psi. The well has been reclassified as Not Operable and shall remain shut-in until the tubing integrity has been restored. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/24/2009 UNDER EVALUATION: S-1~PTD #2011130) Patch Restored Tubi~ntegrity -Nee... Page 2 of 2 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, August 26, 2008 4:15 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Young, ]im Subject: UNDER EVALUATION: S-107 (PTD #2011130) Possible TxIA communication Jim and Tom, After a bleed on well S-107 (PTD #2011130) that took place on 08/26/08, the IAP was found to be tracking the tubing pressure after a 30 minute monitor. An AOGCC witnessed MiT-IA recently passed on 07/31/08. The well has been reclassified as Under Evaluation for further diagnostics. We intend on keeping the well on water injection for all diagnostics. The plan forward for the well is as follows: 1. D: Bleed IAP -DONE, IAP tracked tubing 2. F: MIT-IA to 4000 psi 3. WIC: Eval for further diagnostics A wellbore schematic, TIO plot and Injection Plot have been included for reference. « File: S-107 TIO & Injection plot.ZlP » « File: S-107.pdf » Please call with any questions or concerns. Thank you, Toxin RoSChinger (Filling in for Anna Dube) Well Integrity Engineer Office {907) 659-5525 Cefl (406) 570-9630 Pager {907) 659-5100 Ext. 1923 3/24/2009 03/18/09 R 1~ ~,~t)~ ,~~ 4i ;.1,~ ~~ ~/jt,_lFl ~~ ~.,,, ~g ~}``~- /,~ 1 ""0'1~` 4 ~~D~ ~~~ ~,~ ~- ~~ ~i~~ ~ .~ ~7b11~Y~~~r~~G1- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wnll .Inh ik 1 .... n.. s:-. N0.5133 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 J-27A AY3J-00010 CBL - -_ -_---( _-_ 02/21/09 v 1V~ 1 S-107 AWJB-26 MEM L L V ~ ~- 02/25/09 1 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE ' 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE ~ (fj '" 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) . ~ ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / G/ - 03/02/09 1 1 B-25 AVYS-00023 USIT - / t- /~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG ~- ~J / - 03/11/09 1 1 F-18 AVY5-00022 USIT f ,- O"% =' _ !j- ' - 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL ( 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~ - ( ~ 03/12/09 1 1 V-211 AY3J-00014 IPROF/RST WFL - ~ ~ 03/16/09 1 1 V-214 AY3J-00013 IPROF/RST WFL 03/15/09 1 1 K-06B AWJI-00017 MCNL ~ - 01/28/09 1 1 L5-15 12113027 RST . /O '~ / • 12/09/08 1 1 07-18 12071915 R5T 9 12/01/08 1 1 15-15C AWJI-00015 MCNL . / 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT / 12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT ./s- ( 01/04/09 2 1 H-18 11999064 RST / - 1 `~- .12/03/08 1 1 -- q ~ --.~...- r.v....v ..rrv°w~ ..w~.r . v. v~aanuvu MIYV nG1 VnwmV vlvq l.Vr~ CAI.n I V: BP Exploration (Alaska) Inc.. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: C ! I' ~ 3~l d-~- ; ~ c~ C`~, ~ ~ ~~G t ~, ecal 3 ~~ l o~ P~ Alaska Data & Consulting Services 2525 Gambell Strut ;~tyte dQ0 - T, Anchorage, AK 9~>5~~~~e ATTN: Beth Received bY: 19 ~ ~r .~ °'lli ;6 -F'Ta 5"'- }~ !/I/~~ L ProActive Diagnostic Services, Inc. • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907j 793-1225 '~~~~; ~; 3v; \ ~ ~,~~ L~i~ RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ~v-rc~~(-ii3 /fool ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 1) LeakDetection - WLD 07-0ct-08 5-107 2) Signed Print Name: ~~.ru~,t ~~n.~n.~Q-~z-- 1 Color Log / EDE 50-029-23023-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 FAX: (907)245-88952 E-IwA1L: ~ds~r.<~~a~r~CJraa~raz~sr~r~®~ WEBSITE: ;w;ntedv,r??erraar`rI~~.L~r~ ~j C:\Documenls and Settingsl0wner\Desktop\Transmit_BP.doc UNDER EVALUATION: 5-107 (PTD #2011130) Possible TxIA communication Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ Q~~Cfl~ Sent: Friday, August 29, 2008 1:38 PM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: S-107 (PTD #2011130) Possible TxIA communication Mr. Regg, The DHD crew is attempting to get a LLR today. If successful, I will have the well shut-in tonight and the IAP bled down. The town engineer will pursue a plan to fix the well early next week. Please call with any questions or concerns. Thank you, Toxin Roschittger (Filling in for Ann Dube} Weii Integrity Engineer ~,,,~~~~ ~~~ ~ ~ 7Q~~ Office {907) 659-5525 Cell {406) 570-9630 Pager {907) 659-5100 Ext. 1923 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, August 29, 2008 11:39 AM To: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: 5-107 (PTD #2011130) Possible TxIA communication How long to complete diagnostic work? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, August 26, 2008 4:15 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Roschinger, Toxin T.; Young, Jim Subject: UNDER EVALUATION: S-107 (PTD #2011130) Possible TxIA communication Jim and Tom, After a bleed on well S-107 (PTD #2011130) that took place on 08/26/08, the IAP was found to be tracking the tubing pressure after a 30 minute monitor. An AOGCC witnessed MIT-IA recently passed on 07/31/08. The well has been reclassified as Under Evaluation for further diagnostics. We intend on keeping the well on water injection for ali diagnostics. 8/29/2008 UNDER EVALUATION: 5-107 (PTD #2011130) Possible TxIA communication Page 2 of 2 • The plan forward for the well is as follows: 1. D: Bleed IAP -DONE, IAP tracked tubing 2. F: MIT-IA to 4000 psi 3. WIC: Eval for further diagnostics A wellbore schematic, TIO plot and Injection Plot have been included for reference. «S-107 TIO & Injection plot.ZlP» «S-107.pdf» Please call with any questions or concerns. Thank you, ~'orir2 Roscltiltger {Filling in far Anna Dube) Well Integrity Engineer Office (907) 659-5525 Cell (406} 570-9630 Pager (907} 659-5100 Ext. 1923 8/29/2008 PBU 5-107 PTD 201-113 August 26, 2008 TIO Pressures • • ~n a!o7 1n.,~15/07 11/75/07 12.'16/n? 07!15!0$ D2!16I09 Oanf.'!US? 04!12!OR 05;i'~!08 06it5!U8 07!20!08 09!20/Ud PBU 5-107 PTD 201-113 August 26, 2008 ection Plot 3,0<l0 2,300 2,F,~70 z. ano 2.200 2,000 1,~0 1,soo 1.apo 1,?OD 1 mn • 15,000 • 1 a,000 • 13.000 • ~ Z,oun • noon • 10,000 • a,tmo • 3,~p • 7,CCA) . a rcei • a.f~ • 3.000 2000 0911a1U7 10/1510. 11/15/07 12!16/07 O1i16103 02/16/03 llry,'13/03 04,~1R„~03 05113/03 06/19/03 07/20/D3 03!20! TREE = NA 'WELLHEAD = FMC (ACTUATOR= NA 'i KB. ELEV = 69.4' i BF. ELEV = 35.9' KOP = _ ~ ~ 700' i Max Angle = 101 @ 15229' I Datum MD = 11994' Datum TV D = 6700' SS • 10-3/4" CSG, 45.5#, L-80, ID = 9.980" ~~ 4265 Minimum ID = 3.725" @ 12250' 4-112" HES XN NIPPLE RA TAGS IN JT # 10 1161 ~ETY NOTES: WELL > 70° @ 12483' AND ~ 90° @ 13601'. 993' 10-3/4" TAM PORT COLLAR 2277' 4-112" HES HXO SSSV N, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3 6491 11628 3810 6522 57 58 KBG-2 KBG-2 DMY DMY BK BK 0 0 05/08/02 05/08/02 11654' ~ 4-112" HES X NIP, ID = 3.813" 1171$' 7" X 4-112" BKR PREM. PKR, ID = 3.890" 11$23' ~~7" X4112" BKR PREM. PKR, ID = 3.890" PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD ON 07!28101 ANGLE AT TOP PERF: 59 @ 11730' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE NA 4 11730 - 11732 S 07!17(01 NA 6 11735 - 11737 O 07131!01 NA 6 11850 -11852 O 07!31!01 4-5(8" 5 11900 - 12150 O 07(31/01 NA 4 11950 - 11952 S 07/17/01 4-518" SLOT 15127 - 15938 SLOT 08103(01 ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" S 7" CSG, 26#, L-80, ID = 6.276" 119-14-112" CMU SL~WG SLV, ID = 3.812" PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 12030 12096 6714 6740 67 68 KBG-2 KBG-2 'DMY DMY BK BK 0 0 10/22!07 08109/01 ' STA #1 -EXTENDED PACKING 12202' _ 4-1/2" HES X NIP; ID = 3.813" 12223' 7" x 4-1l2" BKR PREM. PKR, ID = 3.890" 12250' 4-112" HES XN NIP, ID = 3.725" 12259' 7" X 5" BKR ZXPPKR w / TIEBK, ID = 5.250" 12263' 4-1i2" WLEG; ID = 3.958" ELMD NOT LOGGED 12274' 7" X 5" BKR HMC LNR HGR, ID = 4.430" 15019' ~-{4-112" IXT CSG PKR, ID = 3.937" 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 1512T 4-112" SLTD LNR, 12.6#, L-80, ID = 3.958' 15938` ` ` =~ 4-112" LNR, 12.6#, L-80; .0152 bpf, ID = 3.958" 159$(j' I PBTD I DATE REV BY COMMENTS DATE REV BY COMMENTS 08!09/01 ORIGINAL GOM PLETION 10!22!07 RCTIPJC G_LV C/0 (01!13!07) _ 08118101 CH/TLH COMPLETION SCHEMATIC 10(22/07 RCTIPJC DRAFT CORRECTIONS 02107!02 JY/KAK PERF CORRECTIONIADD. 10122107 RCTIPJC GLV CIO 05!09102 DACltlh MANDREL CORRECTIONS 04/09103 DRSITP TV DIMD CORRECTIONS 10/14/06 CJN/TLH SLIDING SLV OPEN AURORA UN(I" WELL: 5-107 PERMIT No: 201113 API No: 50-029-23023-00 SEC 35, T12N, R12E, 4556' NSL & 4496' WEL BP Exploration (Alaska) OPERABLE: 5-107 (PTD #2011130) AOGCC MITIA Passed Page 1~2~ Regg, James B (DOA) ~ ~ ~ ~~z~'~, From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, August 01, 2008 3:35 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; Lirette, Todd; GPB, Optimization Engr Cc: Roschinger, Torin T.; Young, Jim; NSU, ADW Well Integrity Engineer Subject: OPERABLE: S-107 (PTD #2011130) AOGCC MITIA Passed Follow Up Flag: Follow up Flag Status: Yellow AII, / Well S-107 {PTD #2011130) passed an AOGCC witnessed MITIA on 7/31/08. The well has been reclassified as Operable and may continue to be on injection. Please call with any questions. Thank you, Anna ~u6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, July 28, 2008 9:03 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; ,Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod ntrollers; Lirette, Todd; GPB, Optimization Engr Cc: Roschinger, Torin T.; Young, Jim; NSU, ADW Well Integrity Engineer; Holt, Ry (ASRC) Subject: UNDER EVALUATION: 5-107 (PTD #2011130) MITIA passed post LV, Put on injection for AOGCC MITIA All, Weli 5-107 (PTD #2011130) passed an MIT after replacing the DGLV with a DGLV with extended packing. The well has been reclassified as Under Eval tion so that it may be returned to injection, Once the well is stable, an AOGCC witnessed MITIA will be con cted for UIC compliance. A MIT farm of the recent MITIt~'has been included for reference. Please return the yc~il to injection and watch for thermal expansion as the IA is liquid packed. Thank you ~a'~u6e, ~? E. Integrity Coordinator 8/29/2008 UNDER EVALUATION: 5-107 (PTD #2011130) MITIA passed post DGLV, Put on inje... Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, July 28, 2008 9:03 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; Lirette, Todd; GPB, Optimization Engr Cc: Roschinger, Torin T.; Young, Jim; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: S-107 (PTD #2011130) MITIA passed post DGLV, Put on injection for AOGCC MITIA Follow Up Flag: Follow up Flag Status: Yellow Attachments: MIT PBU S-107 07-27-08.x1s All, Wel! S-107 {PTD #2011130) passed an MITIA after replacing the DGLV with a DGLV with extended packing. The well has been reclassified as Under Evaluation so that if may be returned to injection. Once the well is stable, an AOGCC witnessed MITIA will be conducted for UIC compliance. A MIT form of the recent MITIA has been included for reference. «MIT PBU S-107 07-27-08.x1s» Please return the well to injection and watch for thermal expansion as the IA is liquid packed. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 17, 2008 7:43 PM To: NSU, ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; Lirette, Todd Cc: Holt, Ryan P (ASRC); NSU, ADW WI Tech; Young, Jim Subject: NOT OPERABLE: 5-107 (PTD #2011130) FAILED MIT-IA AI I, Well 5-107 {PTD #2011130) failed an MIT-lA performed on 07/17/08 with a triplex pump. The IA Peak rate was found to be 1 gpm at 4,000 psi. The well has been reclassified as Not Operable and injection needs to be ceased immediately. We will work with the town engineer to evaluate the well for a leak detect log. 8/29/2008 UNDER EVALUATION: 5-107 (PTD #2011130) MITIA passed post DGLV, Put on inje... Page 2 of 2 Please call with any questions. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Monday, July 07, 2008 8:48 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; Lirette, Todd Ce: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Young, Jim Subject: UNDER EVALUATION - S-107 (PTD #2011130) IA repressurization Hi all, Well S-107 (PTD #2011130) is exhibiting IA repressurization. The wellhead pressures were tubing/IA/OA equal to 1000/1000/180 on 7/5/08 when the IA pressure was bled from 1000 psi to 600 psi. The pressure built back 380 psi overnight. The well recently passed an AOGCC witnessed MITIA to 4000 psi on 06/23/08 for UIC compliance. The well is now classified as Under Evaluation. The plan forward is leave the well online and conduct an AOGCC witnessed MITIA. The plan forward includes: 1. Operator: Bleed IAP, monitor -BUILT PRESSURE 2. Fullbore: AOGCC MITIA, est LLR if fails 3. Well Integrity Engineer: Evaluate for leak detection log to find source of repressurization A wellbore schematic and TIO plot have been included for reference. Please call with any questions. Thank you, Anna ~Du6e, ~? E. Well Integrity Coardinator GPB Wells Group Phone: {907} 659-5102 Pager: (907} 659-5100 x1154 8/29/2008 • Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~~~ g 1~~~~~ FIELD /UNIT /PAD: Prudhoe Bay! PBU/ S-Pad DATE: 07/27/08 OPERATOR REP: Anna Dube AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test C] Packer De th Pretest Initial 15 Min. 30 Min. Well S-107 Type Inj. N TVD 6 639' Tubing 800 825 825 825 Interval O P.T.D. 2011130 Type test P Test psi 1660 Casing 800 3,000 2,940 2,920 P/F P Notes: MITIA post DGLV with extended packing. OA 180 180 180 180 Will return well to injection to obtain AOGCC witnessed MITIA. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE tNJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water 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 BFL 11/27/07 MIT PBU S-107 07-27-08.x1s PBU 5-107 PTD 201-113 4,000 --- 3,000 ~.-, tv1.4A~F 2,000 ~~ 1 ,004 `~ ~. hr1.4A ~F 0 417!2008 4r22I2008 5-107 TIC Plot 5l7E2008 5~22E2008 6AGr2008 6x21 x2008 7!7!2008 7Q2C2008 -~- Tbg -F IA -~- OA OOA OOOA • i To: Jim Regg ~ ~ `, U(~ J v P.I. Supervisor FROM: John Crisp Petroleum Inspector State ®#' Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 04, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-107 PRUDHOE BAY UN AURO S-107 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~ Comm Well Name: PRUDHOE BAY UN AURO 5-107 Insp Num: mitJCr080803140315 Rel Insp Num: API Well Number: 50-029-23023-00-00 Permit Number: 201-113-0 ~ Inspector Name• John Crisp Inspection Date: 7/312008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-Ia7 Type Inj. W ~ TVD 6639 IA 1900 4020 3980 3970 P.T. zoulso TypeTest ' SPT Test psi ~ I6s9.7s ~ pA I6o no ! vo t7o Interval OTHER p~, P / Tubing' soo soo i soo soo Notes• MIT-IA. 2.3 bbl's pumped for test. ~~~~~~~ ~JG t~ ~ ~'COc Monday, August 04, 2008 Page 1 of I l~E1VI® NDLTl~ • TO: Jim Regg 1C~ ~;` I P.I. Supervisor I l~~l i FROM: John Crisp Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July I5, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-107 PRUDHOE BAY UN AURO 5-107 Src: Inspector NON-CONFIDENTIAL Reviewed By.~: n P.I. Suprv ~~-JUP'- Comm Well Name: PRUDHOE BAY UN AURO S-107 Insp Num: mitJCr08071409t443 Rel Insp Num: API Well Number: 50-029-23023-00-00 Permit Number: 201-113-0 Inspector Name• John Crisp Inspection Date: 7/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-IO7 Type Inj. W TVD j 6639 IA ~ 3520 4000 ~ 3630 3540 P.T. zoI I Iso TypeTest SPT ~ Test psi 1659.75 OA ; zoo I zoo zoo ~ zoo ~ Interval °T~R p/F F Tubing I Iooo ~ Iooo Iooo Iooo NOteS• Note: 30 minute pressure readings on the test sheet are actually readings taken after 20 minutes. .5 bbl's pumped for retest. ~~~~ ~~ u ~ ~ ~~~~ Tuesday, July l5, 2008 Page I of I MEMORANDUM • T®~ Jim Regg ,~ P.I. Supervisor '~~~~ ~!1' ~ v FROM: John Crisp Petroleum Inspector State ®f Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, July I5, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-107 PRUDHOE BAY UN AURO 5-107 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `l~'~- Comm Well Name' PRUDHOE BAY UN AURO S-107 API Well Number' S0-029-23023-00-00 Insp Num: mitJCr080714090903 Permit Number: 201-113-o Rel Insp Num: Inspector Name' John Crisp Inspection Date: 7itoi2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-107 Type Inj. w ' TVD 6639 IA ~ 980 4000 ~ 3620 3520 P.T. ~ zoi i 13o TypeTest SPT Test psi i 16s9.7s pA i ao zoo zoo 200 Interval oTI~R p/F P ~ Tubing looo Iooo looo ~ looo Notes' Note: The 30 minute pressure readings on the test sheet are actually readings taken after 20 minutes. 3.3 bbl's pumped for test. This well was found with a ansi 1500 flange on the IA. This flange was changed out for PT. Tuesday, July I5, 2008 Page I of 1 a 1®'IEM®1~A1®1DU19/I • To: Jim Regg I\ U .Z `3G 6 C =~ P.I. Supervisor ~y FROM: Jeff Jones Petroleum Inspector State off Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 30, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) [NC 5-107 PRUDHOE BAY UN AURO 5-107 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .JP~--- Comm Well Name: PRUDHOE BAY UN AURO S-107 Insp Num: mitJJ080623 1 7 1 405 Rel Insp Num: Apj Well Number 50-029-23023-00-00 Permit Number: 201-113-0 Inspector Name• Jeff Jones Inspection Date: 6/23/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ S-107 'Type Inj. W TVD ~ 6639 IA i 180 ~ 4010 3950 I 3930 ~ p•T• i 2011]30 TypeTest SPT' Test psi i 1659.75 OA 140 ~ 165 ~ 165 165 ~ Interval aYRTST pn7 P Tubing o looo ! looo ; looo j i i Notes' 3.2 BBLS methanol pumped, no exceptions noted. ~~~~ AU G ~ ~ 208 Monday, June 30, 2008 Page I of 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfihn _ Marker.doc ~ ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: RepairWeliD Plu¡¡ PerforationsD Stimulate 00 OtherD AbandonD Alter CasingD Pull TubingO Perforate New PoolD WaiverD Time ExtensionO Change Approved Program 0 Operation ShutdownO Perforate D Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D Exploratory 0 2"1-1130 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceŒ 50-029-23023-00-00 7. KB Elevation (ft): 9. Well Name and Number: 69.94 S-107 8. Property Designation: 10. Field/Pool(s): ADL-OO28256 Prudhoe Bay Field 1 Aurora Oil Pool 11. Present Well Condition Summary: Total Depth measured 15980 feet true vertical 6831.8 feet Plugs (measured) None Effective Depth measured 15938 feet Junk (measured) None true vertical 6839.3 feet Casing Length Size MD TVD Burst Collapse Conductor 115 20" 91.5# H-40 35 - 150 35.0 - 150.0 1490 470 Liner 3721 4-112" 12.6# L-BO 12259 - 15980 6871.4 - 6831.8 8430 7500 Production 12390 7" 26# N-BO 31 - 12421 31.0 - 6933.8 7240 5410 Surface 4230 10-3/4" 45.5# L-BO 35 - 4265 35.0 - 2902.9 5210 2480 Perforation deDth: Measured depth: 11850 -11852,11900 -11949,11949 -11951,11951 -12150 True vertical depth: 6705.73 - 6706.7,6729.51 - 6751.47,6751.47 - 6752.33,6752.33 - 6830.09 RECEIVED Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 @ 34 - 12263 SEP 2 1 2004 Packers & sssv (type & measured depth): 4-1/2" Baker PRM Packer @ 11718 Alaska on & Gas Cons. Gommi8lion 4-112" Baker PRM Packer @ 11823 4-112" Baker PRM Packer @ 12223 Anchorage 4-1/2" Baker ZXP Packer @ 12259 4-112" External Casing Packer @ 15019 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11850 -12150 Treatment descriptions including volumes used and final pressure: 70 Bbls Gelled Diesel @ 1745 psig 55 Bbls 2 ppg Rock Salt in Gelled Diesel @ 2073 psig 75 Bbls 2 ppg 16120 Carbo lite in YF130LG @ 4742 psig 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casin¡¡ Pressure Tubing Pressure Prior to well operation: 0 0 -7561 1400 1720 Subsequent to operation: 0 0 -1237 540 1899 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations. ! OilD GasD WAGD GINJD WINJŒI WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact Garry Catron 303-335 Printed Name Garry Catron Title Production Technical Assistant Signature l1ßÃ AA r~- Phone 564-4657 Date 9/16/04 " v ORIGINAL SEP;¿l zoo~ BFL - Form 10 404 Revised 4/2004 RBDMS .~ ~ - S-107 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/10/03 HEAT 170 BBLS DIESEL IN VECO VAC TRUCK TO 90* F FOR HPBD. 11/10/03 T/I/O=1400/1350/450 SCHMOO-B-GONE TREATMENT. (PRE- HPBD) WELL INJECTING ON ARRIVAL. PUMPED 5 BBL NEAT MEOH SPEAR, 242 BBLS SBG. AFTER PUMPING BRING WELL BACK ON INJECTION TO CLEAR TUBNG OF SBG. PUMPED 40 BBLS MEOH TO FREEZE PROTECT TUBING, 5 BBLS MEOH FOR FLOWLINE. WELL LEFT SI. FINAL WHP'S 1650/1275/400 11/11/03 T/I/O=900/350/320 ASSIST WIRELINE WITH BRUSH AND FLUSH. PUMPED 5 NEAT AND 83 BBLS DIESEL DOWN TBG. PUMPED 6 BBLS NEAT DOWN FLOWLINE FOR FREEZE PROTECTION. FINAL WHP=1200/380/320 11/12/03 LOAD DIESEL TRANSPORT W 65 BBLS DIESEL @90*. HOLD 2500 PSI ON IA DURING FRAC. LOAD 70 BBLS DIESEL HEATED TO 90* ONTO DIESEL TRANSPORT. LOAD DIESEL TRANSPORT W 65 BBLS DIESEL @90*. HOLD 2500 PSI ON IA DURING FRAC. LOAD 70 BBLS DIESEL HEATED TO 90* ONTO DIESEL TRANSPORT. FLUIDS PUMPED BBlS 1820 Filtered Sea Water. Slicked with Guar (J877) 95 Gelled Diesel (Gelling agent J452, crosslinker J601) 135 Diesel 2050 TOTAL Page 1 l\'IEMORANDUM State of Alaska Alaska Oil and Gas Consenration Commi!ision . --:ì TO: Jim Regg l:." t'~'í b (/ (: Jo f P.I. Super\'i!ior \') ( :. l DATE: t<.londay. June 21. 200-1 SllBJECT: t<.kchamcallmegriry Tests BP EXPLOR...\.TlON (AL.o\S~o\l fNC 5-107 FROM: Jeff Jones Petroleum Inspector PRUDHOE SA Y UN AURO 5-107 Src: Inspector Re\'iewed By: ---t!. ,., Pol. Suprv ....j~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BA Y UN AURO 5-107 API Well Number: 50-0~9-23023-00-00 Insp Num: mitJJ04062 1064824 Permit Number: 201-113-0 Rellnsp Num: Inspector Name: Jeff Jones Inspection Date: 6/18/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-107 Type Inj. TVD 682.¡ IA 320 '¡OOO 3980 3980 P.T. 2011130 T~'peTest 5PT Test psi 1659.75 , OA 380 400 .¡OO 400 Inten'al .¡YRT5T PIF P ~ubing I 17.10 17'¡0 17.10 1740 Notes: Good test. Pre 1\11 swap. 5 BBl5 50/50 methanol pumped. I\londay, June 21,2004 Page I of J November 12, 2003 BP Exploration (Alaska) Inc 900 E Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage, AK 99501 Re: Sundry Notice for S-107 HPBD Dear Tom: A High Pressure Breakdown (HPBD) will be performed to stimulate injector S-107i. The HPBD will use fracturing equipment to provide short-term 40-50Mb/d Injection rates with viscous fluid and establish increased fracture conductivity to reservoir. Rock salt will be used to divert injection to more reservoir and achieve multiple fractures for maximum injectivity. If you have any questions, please contact Jim Young, Aurora Petroleum Engineer at 564- 5754 or by email at Yo'ung, j3 @bp.com. Sincerely, Jim Young Aurora Petroleum Engineer Enclosures (2) in duplicate Gc APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request: Abandon D Suspend D Operation Shutdown r-~ Perforated VarianceD Annular DisposalD Alter CasinQ [ Repair Well D Plu.cl Perforations [ StimulateD[] Time Extension[] Otherr~ Chan~e Approved Pro,ram D Pull Tubincl E~ Perforate New Pool [ Re-enter Suspended Well[] 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc, 201-1130 Development I-] Exploratory [-'"] 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r-] Service ~-~ 50-029-23023-00-00 7. KB Elevation (ft): 9. Well Name and Number: 69.94 KB S-107 8. Property Designation: 10. Field/Pool(s): ADL-0028256 Prudhoe Bay Field ! AURORA Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): IEffective Depth MD (ft)l Effective Depth TVD (ft): Plugs(md): Junk(md): 15980 6831.8 I 15938 6769.3 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 115 20" 91.5# H-40 35 150 35.0 - 150.0 1490 470 Liner 3721 4-1/2" 12.6# L-80 12259 - 15980 6871.4 - 6831.8 8430 7500 Production 12390 7" 26# N-80 31 12421 31.0 - 6933.8 7240 5410 Surface 4230 10-3/4" 45.5# L-80 35 4265 35.0 - 2902.9 5210 2480 Perforation Depth MD (ft) Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11850 - 11852 6706 - 6706.7 4.5" 12.6 # L-80 34 - 12263 11900 - 11949 6730 - 6751.47 11949 - 11951 6751 - 6752.33 11951 12150 6752 6830.09 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker PRM Packer 11718 4-1/2" Baker PRM Packer 11823 4-1/2" Baker PRM Packer 12223 / 4-1/2" Baker ZXP Packer 12259 4-1/2" External Casing Packer 15019 '~'}~,~(~,~? 12. Attachments: Description Summary of Proposal [~ 13. Well Class after proposed work: Detailed Operations Program E~] BOP Sketch U Exploratoryr'-I Developmentr"~ 14. Estimated Date for November 10, 2003 15. Well Status after proposed work: Commencing] Operatic Oil ~ Gasr"~ Pluggedr'-~ Abandonedr"~ 16. Verbal Approval: Date: WAG D GINJD WINJ[~ WDSPLO Commission Representative: Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Youn~ Printed Name James ¥OUrl~l Title Petroleum En~lineer Signature /~ ~.,,/~'[-v~ Phone 564-5754 11,12~03 ~ ,~ '- / f Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ~ ~.~' ~ ~ 5 Plug Integrity D BOP TestD Mechancial Integrity TestD Location Clearance ~ Other: Subsequent Form Required: ,,,,.~ ~." C'~ ~t !, ~p~Li C~ATE Approved by: ~-~~, J~,.~,~ [.~,i. J[~'~1 1~'*"~ ~"i'~'l .... ~- BYORDEROF THE COMMISSION Form 10-403 F~visec 2/2003 SUBMIT Aurctra Field bp Memorandum To: G ANC Wellwork Program Date: October 29,2003 From: Subject: Jim Young 564-5754, hm' 248-0133, cell' 440-8007 PE S-107 Straddle section closure PECT: IOR: Est. Cost: AULWPS107 5O0 $3,000 Distribution: J PY/Sl o peRVe I Ifi le Prior to pumping a planned high-pressure breakdown in well S-107i, it is desired to isolate the straddled section of this well in order to: · establish injectivity into the slotted liner section by isolating "thief" zone in the straddle · protect the straddle completion during the HPBD. S-107 O SBG S-107 S Shift CMU closed Needed pre-fullbore slickline work Needed pre-HBPD. 1. Pump SBG per attached 2. Shift Baker CMU sleeve at 11967' MD (66deg inclination) closed. 3. Return to injection. bp To: Gary McBride/John Smart Date: 10/30/2003 GPB Well Ops Team Leaders From: Laura J. Larson Technical Assistant - GPB Waterflood Subject: SBG Treatments for S-107 Cap Sust Tbg Wash Attached is the SBG treatment required for the well S-107. Contact the appropriate PE with any questions or comments. PE Pad/DS Facility Home Cell Pager Office Jim Young S-107 GC-2 248-0133 440-8007 ,. 564-5754 cc: w/a: Well File Jim Young Laura J. Larson '~I~E = ~ ~' WELLHEAD= FMC S 107 S'z~l' ETY NOTES: WELL > 70° ~ 12483' AN D ACTUATOR= NAI ~ · 90°6 13601'. KB. ELEV = 69.4'~ BF. ELEV = 35.9" KOP= 700' ':.----[~~--~10-3/4" TAM PORT COLLAR I Max Angle = 101 @ 15229' Datum MD = i 1994; Datum TVD = 6700, SS I I-i . ss' , I iI I I MD TVD TYPE VLV LATCH PORT DATE 3810 KBG-2 DV BK 08/09/01 11628 65221 58 KBG-2 DV BE 08/09/01 Minimum ID = 3.725" @ 12250' PRODUCTION MANDRELS L ST MD TVD DEV TYPE VLV LATCH PORT DATE 4-1/2" HES XN NIPPLE 2 12030 6714 67 KBG-2 DV BE 08/09/01 1 12096 6740 68 KBG-2 DV ~,K o8/o9/ol I i ' 1-14-1/2,, ID = 3.813" I 11654' HES XNIP, X X I x I I I I 11907' l--{4-1/2"CMUSUD'NGSLV,'D=3.812"I I' 12202' 1'~4-1/2" HES XNIP, ID= 3.813"I I i I ; I 12250' H4-1/2" HES XN NIP, ID= 3.725"I 4-1/2"TBG, 12.6#,L-80, .0152bpf, ID=3.958" I'~ 12262' I ~ I 12263' I--~4-1/2"WLEG, ID= 3.950"I 12274'I-~i7" x 5" BKR HMC CNa HGR, ID -- 4.430".I 1 7,, CSG, 26#, L-80, ~D = 6.276,, I...1 12421' ' I I/ I PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD ON 07/28/01 I I 15019' 4-1/2" EXT CSG PKR, ID = 3,937" ANGLE ATtOP PERf: 59 @ 11730' Note: Refer to Production DB for histodcaI perf data NA 4 11730-11732 S 07/17101I I i NA 6 11735 - 11737 0 07/31/01 ' NA 6 11850-11852 O 07/31/01 ~ · · 4-5/8" 5 11900 - 12150 0 07/31/01 NA 4 11950 - 11952 S 07117101 · 4-5/8" 5 15127 159~ O 08/03/01 DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 08/09/01 ORIGINAL COMPLETION WELL: S-107 08/18/01 CH/tlh COMPLETION SCHEMATIC PERMIT NO: 201113 02/07/02 JY/KAK PERF CORRECTION/ADD. APl No: 50-029-23023-00 05/09/02 DAC/tlh MANDREL CORRECTIONS SEC35, T12N, R12E, 4556' NSL &4496' WEL 04/09/03 DRS/TP TVD/MD CORRECTIONS BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS 08/09/01 ORIGINAL COMPLETION 08/18/01 CH/tlh COMPLETION SCHEMATIC 02/07/02 JY/KAK PERF CORRECTION/ADD. 05/09/02 DAC/tlh MANDREL CORRECTIONS 04/09/03 DRS/TP TVD/MD CORRECTIONS r 05/08/03 Schlumberger NO. 2775 Alaska Data and Consulting Services Company: Alaska Oil & Gas Cons Comm 3940 Arctic Blvd, Suite 300 Attn: Lisa Weepie Anchorage, AK 99503-5711 333 West 7th Ave, Suite 100 A TIN: Beth Anchorage, AK 99501 Field: Aurora Well Job# Log Description Date BL Sepia Color CD 3 o~- JCtg". S-114A RST UPFLOW WFL 03/01/03 1 d-°\'" \\3 S-107 INJECTION PROFILE 04/30/03 1 ( PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: Receiv ( RECEIVED MAY 1:3 2003 A1aaka o¡¡ & Gas Cons. Commtøioo Anchorage Permit to Drill 2011130 DATA SUBMITTAL COMPLIANCE REPORT 7~30~2003 Well Name/No. PRUDHOE BAY UN AURO S-107 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23023-00-00 MD 16026 - TVD 6824 -- Completion Dat 8/9/2001 "'" Completion Statu 1-OIL Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log N_9o Sample N_9o Directional Survey .~Ne-- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital ype Media Fmt ~ D (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments Directional Survey FINAL OH 8/7/2001 MWD Survey, Digital Data -.L"' L ,,.I,,e.- RS Reservoir Saturation ,l~C" Inj Injection Profile Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Slim Sonic Logging Tool Ultrasonic Imager Slim Sonic Ultrasonic Imager FINAL OH 8/7/2001 Dir Survey, Paper Copy FINAL OH 8/7/2001 IIFR Survey, Digital Data FINAL OH 8/7/2001 Dir Survey, Paper Copy FINAL OH 8/7/2001 Gyro Survey, Digital Data FINAL OH 8/7/2001 Dir Survey, Paper Copy 5 FINAL 10950 12314 CH 8/21/2001 10950-12314 Color Print 5 FINAL 10950 12314 CH 8/21/2001 10950-12314 Color Print 5 FINAL 6150 12100 CH 8/21/2001 5 Blu 1 11650 12180 Case 6/21/2002 5 Col 1 11570 12248 Case 5/13/2003 6150-12100 Color Print Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~ Chips Received? --¥-f-N Analysis R ~.c.~.iv~.d';> Daily History Received? i~.,,)/N Formation Tops ~¢~, / N Permit to Drill 2011130 MD 16026 TVD Comments: DATA SUBMITTAL COMPLIANCE REPORT 713012003 Well Name/No. PRUDHOE BAY UN AURO S-107 Operator BP EXPLORATION (ALASKA) INC 6824 Completion Dat 8/9/2001 Completion Statu 1-OIL Current Status WAGIN APl No. 50-029-23023-00-00 UIC Y Date: Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FI'N: Beth NO. 2775 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date BL Sepia Color CD lS-114A _~.~.O_~:j~_ ?~ T RST UPFLOW WFL 03101103 1 IS'-107 '~'~l I ! "~ INJECTION PROFILE 04/30103 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED MAY 13 200 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth ~ OS/08/03 WELL LOG TRANSMITTAL To: State of Alaska May 07, 2003 .Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: S-107 AURORA, AK-MM-11107 S-107 AURORA: Distal Log Images: 1 CDRom I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF' THE TRANSMITTAL LETTER TO THE ATTENTION' OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed: RECE!VED MAY '1 ,:3 2.003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ SCHMOO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development _ Explorato~__ Stratigraphic__ Service__X 4. Location of well at surface 723' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 5269' FNL, 772' FEL, Sec. 21, T12N, R12E, UM At effective depth 2681' FNL, 3779' FEL, Sec. 21, T12N, R12E, UM At total depth 2623' FNL, 3843' FEL, Sec. 21, T12N, R12E, UM (asp's 618930, 5980760L (asp°s 611992, 5986667) (asp's 608941, 5989210) (asp's 608876, 5989267) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 115' Surface 4230' Intermediate 12390' Liner 3721' 16026 feet Plugs (measured) 6824 feet 15938 feet Junk (measured) 6839 feet 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-107 9. Permit number / approval number 'Q' 201-113 10. APl number 50-029-23023-00 11. Field / Pool Prudhoe Ba)~ Field / Aurora Pool Size Cemented Measured Depth True Vertical Depth 20" 260 sx AS (Approx) 150' 150' 10-3/4" 860 sx ArcticSet Lite, 4265' 2903' 3218 sx Class 'G' 7" 565 sx Class 'G' 12421' 6934' 4-1/2" 247 sx Class 'G' 12259' - 15980' 6871' - 6832' Perforation depth: measured Open Perfs 11735'- 11737', 11850'- 11852', 11900'- 12150' Slotted Liner 15127' - 15938' true vertical Open Perfs 6648'-6649', 6706'- 6707', 6730' 6830'. Slotted Liner 6992' - 6839' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 12263' MD. Packers & SSSV (type & measured depth) 7" x 4-1/2" - (3) Baker PREM Packers @ 11718', 11823' & 12223' MD. 7"x 5" BKR ZXP PKR w/Tieback @ 12259'. 4-1/2" HES HXO SSSVN @ 2277'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 04/17/2003 Subsequent to operation 04/22/2003 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 8890 8O97 Casing Pressure Tubing Pressure 1932 1839 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil __ Gas __ Suspended Service Water Injection 17. I hereby ce.rtify that the foregoing is truce and correct to the best of my knowledge. ,~~'~.~~~ Title: Technical Assistant DeWayne R. Schnorr RII[ I FL NAY 0 R tGI NA L ,. Form 10-404 Rev 06/15/88 · Date APRIL 23, 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE S-107 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/19/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 04/20/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 04/22/2003 TESTEVENT --- INdECTION PRESSURE, PSI: 1,839 TYPE: PW VOLUME: 8,097 BWPD EVENT SUMMARY 04/19/03 PUMPED SCHMOO-B-GONE TREATMENT DOWN TUBING. 0~2~03 PUMPED SCHMOO-B-GONE TREATMENT DOWN TUBING. TOTAL PUMPED, 5 BBLS NEAT MEOH SPEAR, 300 BBLS SBG/FRESHWATER, 3 BBLS, NEAT METHANOL. DSO TO POP IN 6 HOURS. 04/22/03 TESTEVENT --- INJECTION PRESSURE, PSI: 1,839 TYPE: PW VOLUME: 8,097 BWPD Fluids Pumped BBLS 8 NEAT METHANOL 50 SCHMOO-B-GONE CONCENTRATE 250 FRESHWATER 3O8 TOTAL Page I ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL ~-~ GAS [~] SUSPENDED r-] ABANDONED [~] SERVICE Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 723' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At Top Producing Interval 5269' FNL, 772' FEL, Sec. 21, T12N, R12E, UM At Total Depth 2623' FNL, 3843' FEL, Sec. 21, T12N, R12E, UM (asp's 608876, 5989267) Elevation in feet (indicate KB, DF, etc.) RKB 70 feet 12. Date Spudded 06/29/2001 17. Total Depth (MD + TVD) 16026' MD / 6824' TVD (asp's 618930, 5980760) (asp's 611992, 5986667) WAG Injection 7. Permit Number 201-113 / 302-066 8. APl Number 50-029-23023-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-107 11. Field and Pool Prudhoe Bay Unit 6. Lease Designation and Serial No. ADL 028256 ~"~]~/~ Aurora Pool 3. Date T.D. Reached I14. Date Comp., Susp. Or A~;~..-~,~,' ;" 1,115. Water Depth, if offshore 116. No. of Completions 07/27/2001 I '~0~ (~' l U' ~ N/A feet MSL I One Ils. P~ug .B, ack Depth (,M,D + TVD)119. Directional Survey~ 120. Depth where SSSV set 121. Thickness of Permafrost 16026 MD / 6824 TVD lYES [-~ No [~ I (Nipple) 2277' MD I 1900' (approx) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU-DEN, PWD, USIT, CBL, CCL 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE 20" 91.5# H-40 30" 10-3/4" 45.5# L-80 13-1/2" 7" 26# N-80 9-7/8" 4-1/2" 12.6# L-80 SETTING DEPTH MD TOP BOTTOM Surface 115' 35' 4265' 31' 12421' 12259' 15980' 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf MD TVD 11900'- 12150' 6730'-6830' *3-3/8"gun Diameter, 6 spf MD TVD 11735'-11737' 6648'-6649' 11850'-11852' 6706'-6707' 4-1/2"Slotted Liner 15127'-15938' 6992'-6839' 15939'-15978' 6839'-6832' 6-1/8" I CEMENTING RECORD I AMOUNT PULLED ~260 SX Arctic Set (Approx.) 653 sx AS Lite3, 513 sx Class 'G' 333 sx Sodium Silcate 'G', 709 sx 'G' 97 sx Class 'G' 25. TUBING RECORD ;IZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 12263' 11718', 11823', 12223' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 11730'-11732' & 11950'-11952' 17" Suicide Cement Sqz, 87 sx CemCrete 11735'-11737' & 11850'-11852' I *Open Perfs due to failed 7" Cementing l Ops, Trying to establish Circulation I Freeze Protect with 75 bbls of Diesel 27. PRODUCTION TEST Date FirstWaterlnjection June 10,2002 IMethod of Operation (Flowing, gas lift, etc.) Water Injection Production for IOIL-BBL GAS-MCF Test Period -> I Calculated IOIL-BBL GAS-MCF 24-Hour Rate > I Date of Test Flow Tubing Press. Hours Tested Casing Pressure 28. CORE DATA IWATER-BBL WATER-BBL ICHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - APl (corr) Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. JUL. I 2002 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate JUL 8 2002 29. ~. 30. "[ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Schrader Bluff M 8160' 4757' Schrader Bluff N 8586' 4967' Schrader Bluff O 8796' 5072' Base Schrader / 9326' 5358' Top Coville CMl 11424' 6481' Top of HRZ 11745' 6653' Top Kalubik 11869' 6715' Top Kuparuk C 11897' 6728' LCU / Top Kuparuk B 12320' 6895' LCU / Top Kuparuk B 13950' 7015' Kuparuk C 15976' 6763' 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports 7 Surveys were attached to the 10-407 dated 10/18/01. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed,~..e~2V,~z~_~,~)~~ Title Technical Assistant Date_June 26, 2002__ ~7' Sch;orr~,~_.- DeWayne R. Perpared By Name/Number: Dewayne R. Schnorr, 564-5174 S-107 201-113 / 302-066 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 04/14/2OO2 05/05/2002 05/05/2002 05/08/2002 05/08/2002 05/09/2002 05/11/2002 06/09/2002 06/10/2002 06/11/2002 06/13/2002 06/14/2002 06/20/2002 s-,o DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS WATERFLOW LOG: STATIC BO'I-FOM HOLE PRESSURE SURVEY HOT OILTBG WASH: BRUSH / BROACH HOT OIL TBG WASH: GAS LIFT--TO DUMMY VALVES WATERFLOW LOG.' GAS LIFT--TO DUMMY VALVES WATERFLOW LOG: MIT-IA WATERFLOW LOG: TUBING TAIL PLUG WATERFLOW LOG: IN]ECTIVI-FY TEST WATERFLOW LOG: TUBING TAIL PLUG WATERFLOW LOG: TUBING TAIL PLUG WATERFLOW LOG: AC-BLEED; AC-MITIA WATERFLOW LOG: AC-MITIA WATERFLOW LOG: INJECTION PROFILE ANN-COMM (UIC PROGRAM): AC-BLEED 04/14/02 O5/O5/O2 O5/O5/O2 05/08/02 05/08/02 O5/O9/O2 05/11/02 O6/O9/O2 06/10/02 06/11/02 EVENT SUMMARY (WELL SHUT IN ON ARRIVAL SSV CLOSED). RAN 2.50" CENTRALIZER & 1.75" SAMPLE BAILER TO 3150' SLM. RAN SBHPS W/TANDEM PETREDAT GAUGES & DUAL MRT GAUGES. GOOD DATA. SECURED WELL. TURN WELL OVER TO DSO. PUMP HOT DSL TO ASSIST SLICKLINE ON BRUSH AND FLUSH. BRUSH & FLUSH TBG W/. HOT DIESEL. PULL GLV FROM GLM # 4 THAT WAS BENT OUT INTO THE WELLBORE. PULL S/O FROM GLM #3. DUMMY OFF STA'S #3 AND #4, MITIA, SET PXN PLUG IN X-NIPPLE. MIT IA TO 3000 PSI PASSED. PUMPED 168 BBLS OF WATER AND 44 BBLS OF METH. SET PXN - TTP. OPEN BAKER CMU SLEEVE. SBHPS-STATIC SURVEY, GOOD DATA. <<<LEAVE WELL SHUT IN, SSV DUMPED, NOTIFY PAD OPERATOR>>>. PUMPED 290 BBLS OF WATER FOR INJECTION RATE OF 4.6 BPM @ 1725 PSI. ( WELL SHUT IN ON ARRIVAL ) DRIFT TO PLUG / PULL 4 1/2 PXN PRONG & PLUG @ 12220' AMS-SLM PULLED PXN PLUG AND RELEASED WELL FOR INJECTION. WATER INJECTION RATE WAS 1146 BBLS PER DAY WITH AN INJECTION PRESSURE OF 1095 PSI. <<<NOTIFY DSO OF WELL STATUS>>> MIT-IA TO 3000 PSI PASSED. (PRE-AOGCC) 1 S-107 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/13/02 MIT-IA TO 2500 PSI PASSED. (AOGCC WITNESSED) 06/14/O2 RUN WATERFLOW LOG TO DETERMINE INTEGRITY OF CEMENT. LOGGED STATIONS AT 11960', 11900', 11882', 11850', 11750', 11700'. INJECTING AT 2000 PSI, 9700 BPD, FULL OPEN CHOKE WHILE LOGGING. STATIONS SHOWED MOST OF THE FLOW ENTERING THE PERFS FROM 11900'- 12150'. ABOVE 11900', SMALL FLUID MOVEMENT WAS DETECTED UP TO 11700'. LOGGED TWO WARMBACK PASSES AFTER SI WELL. NOTIFY PAD OPERATOR: WELL ON INJECTION. 06/20/02 BLED IA FROM 1350 PSI TO 500 PSI. (EVAL HIGH lAP POST MITIA). Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 2 TESTS) 79 METHANOL 22 50/50 METHANOL WATER 458 WATER 375 HOT DIESEL 936 TOTAL TREE = NA ACTUAToR=WELLHEAD= FMCNA S '107 SAFETY NO'rES: WilL > 70 deg @ 12483' AND > 90 deg@ 13601 '. KB. ELEV = 69.4' BF..lEV = 35.9' KOP 700' -' -' -'-'--i 993' Max Angle = ....... 101 _~_ 15229' Datum MD = 12155' DatumTVD= 6745'SS I I I 2277' ~--~4-1/2"HESHXOSSSVN,~D:3.813"I 1~o-~,4"c~.4~.~#,,-~o,,~=o.~o" H 4~6~ ~ i~ GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 6491 3810 57 KBG-2 DV BK 08/09/01 3 11628 6522 58 KBG-2 DV BK 08/09/01 Minimum ID = 3.725" @ 12250' PRODUCTION MANDRILS 4-1/2"HESXNNIPPLE L ST MD TVD BEV TYPE VLV LATCH PORT DATE 2 12030 6714 67 KBG-2 DV BK 08/09/01 I 12096 6740 68 KBG-2 DV BK 08/09/01 I i I 116r~' 1-14-1'2""~s x"'P, 'D = 3.813" I I~ TAGSIN JT# 10 H 11665' I x i11718'H7"x4-1/2"BKRPREMPKR, ID=3.890"I X :x::; i 11823' I--~7"x4-1/2"BK. PRErvtPK..,D:3.890"I r i i i11967' H4-1/2,, CMUSLIDING SLV, ID= 3,812" I I i I 12202' H4-1/2"HESXNIP, ID=3.813" I X ~ J~7" x 4-1/2" BKRPREM PKR, D = 3.890"I I i ~4-1/2" HES XN NIP, ID: 3.725"I 14'l/2''TBG'12.6#'L'8°''°152bpf'D=3'958,' Id 12262' ' '-~ 1~~ 12259' Ifl?'X~".~.ZX~'.~.W,~.^C~,,~:~.~0" I ' ~ ~ I 12263'I-t~-~,~,, w.~. ,[,: ~.~,, I 12274' I--j7"x5" BKRHMCLNR HAMER, ID=4.430"I I 7" CSG, 26#, L-a0, ID= 6.276" H 12421' i · . PERFORATION survIVIARY REF LOG: SPI~,RY-SUN MWD OF 7-28-01 ,,,.----~ 1§019' H4-1/2" EXT CSG PKR, ID = 3.937"1 : Note: Refor to R'oduc~ion DBfor historical porf data 5127' TOP OF 4-1/2" SLTD LINER SI7E SPF INTEIWA/ OpWSqz DATE "· · ~ 4 11730 - 11732 S 07117/01 ~ 6 11735 ~ 11737 0 07131/01 ~ 6 11850-11852 O 07131/01 · · '· · 4-5/8" 5 11900 - 12150 O 07131/01 "- 4-5/8" 5 15127 - 15938 O i 08/03/01 1 4-1/2"SCOTmD1-N~ 12.6#, US0,,D=3.958" Iq 159a8' I 4-1/2"1_NR, 12.C:gt, 1_-80, 0.0152 bpCAf, ID=3.@58"H 15980' I I DATE REV BY GOMMBqTS DATE REV BY COMMENTS PF~JDHOEBAY t.~lT 08109101 ORIGN^I COMPLEFION WELl-: S-107i 08/18/01 CHI}h COMPLETION SOq~IATIC F~.M[I' No: 201-113 02107102 JY/KAK PERFCORREGTION/AI~. APl NO: 50-020-23023-00 0§/09/02 DAC/tlh MANDRIL GORREGI'IONS 455~' NSk & 4496' WIL, Soc. 35, T12N, R12fi I~ ~xploraflon {Alaska) PERFORATION survIVlARY REF LOG: SPI~,RY-SUN MWD OF 7-28-01 ANGLEATTOPPERF: 59 @ 11730' Note: Refer to R'oduc~on DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE NA 4 11730 - 11732 S 07/17/01 NA 6 11735 - 11737 O 07131/01 NA 6 11850 -11852 O 07131/01 4-5/8" 5 11900 - 12150 O 07131/01 NA 4 11950 - 11952 S 07/17/01 4-5/8" 5 15127 - 15938 O 08/03/01 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/09/01 ORIGNA L COMPLETION 08/18/01 CH~tlh COMPLETION SCHBVIATIC 02/07/02 JY/KAK PERF CORRECTION/ADD. 05/09/02 DAC/tlh MANDRIL CORRECTIONS 6/19/2002 Schlumberger Alaska Data and Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATrN: Beth NO. 2179 Company: Alaska Oil & Gas Cons Corem Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Well Job # Log Description Date Color Sepia BL CD L-109 ~':~ I.- c~O J 22271 PEX AlT BHC DATA (PDC) 06/01/02 1 L-109 22271 PEX AlT 06/01/02 1 L-109 22271 PEX DEN/NEUTRON 06/01/02 I L-109 22271 BriC 06/01/02 1 L-109 22271 PEX TRIPLE COMBO 06/01/02 1 L-109 22271 PEX SSTVD 06/01/02 1 L-109 ,,,,,,/ 22271 PEX HCAL-CALIPER LOG 06101/02 1 S-107 ~ C) J..-' I ~ k_~ EST WEE 06/14/02 1 , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Bivd, Anchorage AK 99508-4254 RECEIVED Date Delivered: Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATrN: Sherrie ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Revised: 02127102, Put on Line 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-113 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23023-00 4. Location of well at surface" ~~r 9. Unit or Lease Name 4557' NSL, 4497' WEL, SEC. 35, T12N, R12E, UM ": .~~_ Prudhoe Bay Unit At top of productive interval ~ __~-. ? .~ ~, . . 10' NSL, 773' WEL, SEC. 21, T12N, R12E, UM At total depth '~-' .: .. · 10. Well Number 2655' NSL, 3843' WEL, SEC. 21, T12N, R12E, UM" ...... ~'~"~ ...... ' ~ S-107 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Aurora Pool KBE = 69.94' ADL 028256 (Undefined) 12. Date Spudded. 6/29/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'7/27/2001 8/9/2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 16026 6824 FT 16026 6824 FTI [] Yes [] No (Nipple) 2277' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU-DEN, PWD, USIT, CBL, CCL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 115' 30" :)60 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 4265' 13-1/2" 853 sx AS Lite 3~ 513 sx Class 'G' 7" 26# N-80 31' 12421' 9-7/8" 333 sx Sodium Silcate 'G'~ 709 sx 'G' 4-1/2" 12.6# L-80 12259' 15980' 6-1/8" 197 sx Class 'G' , 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-5/8" Gun Diameter, 5 spf -~ 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 12263' 11718', 11823', 12223' MD TVD MD TVD 11900' - 12150' 6730' - 6830' 11735' - 11737' 6648' - 6649' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11850' - 11852' 6706' - 6707' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4-1/2" Slotted Liner 11730'- 11732' & 11950'- 11952' 7" Suicide Cement Sqz, 87 sx CemCrete 15127' - 15938' 6992' - 6839' 11735,- 11737, & 11850,- 11852, · Open Perf's due to failed 7" Cementing 15939' - 15978' 6839' - 6832' Cps, Trying to establish Circulation Freeze Protect with 75 Bbls of Diesel "'27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 27, 2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR :OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED O~L-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE ,,,2,8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. RECEIVED FEE] ,?'"~ :~'"~ ~.] ,r~'', 't ~ I1 ~. ] AlaskaOil & G~ Cons. Commissior~ Form 10-407 Rev. 07-01-80 AiqC~t'~%~ubmit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff M 8160' 4757' Schrader Bluff N 8586' 4967' Schrader Bluff O 8796' 5072' Base Schrader / Top Colville 9326' 5358' CMl 11424' 6481' Top of HRZ 11745' 6653' Top Kalubik 11869' 6715' Top Kuparuk C 11897' 6728' LCU /Top Kuparuk B 12320' 6895' LCU / Top Kuparuk B 13950' 7015' Kuparuk C 15976' 6763' 31. List of Attachments: Summary of Daily Drilling Report's and Surveys Were attached tO the 10~407 dated 10/1§/0i. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge " Signed TerrieHubble /'~~....~~ Title TechnicalAssistant Date (~,, ~'~"7, O~. S- 107 201 - 113 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 Icg on all types of lands and leases in Alaska. ITEM 1 .' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 (12/21./2(1{12 .15:21. FAX 907 564 4040 , Jim bp EXPLORAT] ON Cc: Subject: utOm_maunOer @ admin.stato.ak,us] st 02, 2001 4:35 PM Young, Jim Smith, Phil G (FAIR); Bob Crandall; Dawson, Bob S (PRA) Re: S-107i Zonal isolation confirmed ~_l 0 0 ] Card ~r Tom Maunder Gentlemen, Th~nks for your attention to my concern. Your explanation of the lithological and frac gradient differences ~ives you confidence that the fluids will be injected and confined to the intended strata. You also indicate that you intend to run diagnostic logs to confirm that such is the case. This is acceptable. Good luck with your completion. Please keep us informed of your progress. Tom Maunder, PE Petroleu~ Engineer AOGCC · "Young, Jim" wrote: Tom and Bob, The Kuparuk River Formation at the Aurora Oil Pool is overlain by the Kalubik, HRZ/CM1 shales, which have a combined thickness of approximately 268 feet in S-107i. (11424'-11900' md). The HRZ is a thick shale sequence, which tends to behave as a plastic me~[ium and can be expected to contain significantly higher pressures than sandstones of the Kuparuk River Formation. Mechanical properties determined from log and core data in well S-104 for the HRZ and Kalubik intervals indicate a fracture gradient from approximately 0.83 to 0.92 psi/ft. Maximum anticipated injection pressure in S-107 will be 2000psi at the surface with GC2 produced water yeilding a maximum bhp of 0.74psi/ft. This is well below the breakdown pressure of the above mentioned formations and gives us complete confidence that the open perforations at 11850-52' will not reach freshwater strata via formation breakdown or wellbore communication. A !eakoff test in well S-101 suggested a fracture Gradient of 0.73 psi/it at initial reservoir conditions; however a 0.65psi/it Gradient is exp. ected current reservoir conditions.based on a recent fracture treatment in S-]..02 (nearest offset to S-107'), We believe that at all the fluid during the circulation attempt went down a cement channel into the Kuparuk formatio:5 50' below at a.calculated pressure of 0.72psi/ft. This is why we decided[ not to pump cement due to concerns about formation damage. To avoid adding further complexity to the already comple~ ,~--~_~?ose to keep th~j~.ac.kers ~t thm-~ewi~? loc~P~i°r ~ ~n~'i~in~ ~on~-ter-m i~jecti~n~ ~e wili confirm with a. ~2~er-flow log that NO injection is enterin~ the perforations 11850'-52' and moving upward as to risk ~on~nnication to freshwater strata or our ability to contain injected fluids to the target reservoir. We are currently preparing to condition the well for ru'-~ning tSe ~-ompletion so an answer on this quickly (this afternoon or tommorrow) is requested.. will be out tommorrow, but Phil would be Glad to meet with you if necessary. Thanks, 02/~1/2002 15:21 l~X 907 564 4{140 bp EXI'I.,OIIATION > Jim Young > PE, GPB New Developments > youngj3~bp.com > (907) 564-5754 fax 5016 > > ..... Original Message ..... > From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] > Sent: Thursday, August 02, 2001 2:53 PM > To: Smith, Phil ~ (FAIR) > Cc: Young, Jim; Bob Crandall > Subject: Re: S-107i Zonal isolation confirmed > > Phil and Jim, > Bob Crandall and I looked at the proposed completion of S-107i. We agree > that your limited > injection test indicates there does not appear to any communication between > the > perforations. > Our concern is that your test demonstrated that the perforations will accept > fluid at 1 bpm > at 1300 psi. In your proposed completion, the perforations at 11850 will be > continuously >exposed to injection pressure, likely higher than 1300 psi, and fluid could > be pumped > through those perforations as well as the intended interval of 11900 - > 12150. Over the > long term, fluid might not be contained as planned. > I understand the reluctance to set an additional packer to isolate the p¢~rfs > at 1].850, but > I believe the benefit of the additional 50' of isolation (11850-11900) would > be > advantageous. Please provide additional information to mitigate our > concern. > Tom Maunder, PE > Petroleum Engineer > AOGCC > > "Smith, Phil G (FAIR)" wrote: > > > Tom, > > Below is copy of the plan we executed to ensure zonal isolation on S-107i. > > I'm also attaching a more detailed "plan forward" generated and followed > at > > the rig and a well diagram as the well is expected to be completed. The > > attached plan forward is more accurate and detailed than summary procedure > > listed below. > > The outcome of the procedure completed this mornin~ was as follows: > > * Stabbed cement stinger into the retainer at 11,825' > > * Attempted circulation through newly shot perfs at 11,850 and > 11,735 > > to' 2000 psi w/ 10.3 ppg mud (2600 psi equivalent injection pressure with > se~ > > water). > > * No return flow through upper perfs. Observed bleed-off to 900 psi > > in 8 minutes, then stable at 900 psi. Thereafter managed 1 bpm steady > > injection at 1300 psi for 5 bbls. Bled down to 9000 psi in 10 m~nutes > > (Frae'lng mud into formation assumed). > > > > We have concluded from the test that the cement is providing more than > > adequate isolation at the top of Kuparuk reservoir (11,900' MD) thougk~ the > > USIT log is inconclusive. > > > > Jim Young (pro~ction engineer) is planning 5o pre-produce the well > > > immediate diagnostics (WFL and/or Production log) if expected productJ, on > is 02/21/2002 15:22 FAX 907 564 4040 bp EXPLOITATION > >.not realized. Otherwise, the well will be converted to water injection > > status in October with a WFL / injection profile run within a week of > > injection start-up. Further diagnostics may be added if deemed prudent. > > > > Please respond after your consideration. > > Thanks, > > Phil > > > > <<S-107 Cmt Squeeze-Rev 1.doc>> <<S-107 diagram MSWord. ZIP>> > > > ..... Original Message ..... > > > From: Smith, Phil G (FAIR) > > > Sent: Tuesday, July 31, 2001 11:25 AM > > > To: 'jane_williamson~admin.state.ak.us' > > > Cc: Tom Maunder (E-mail); 'julie_heusser@ad/nin.state.ak.us'; Bunch, > > > Anthony S; Elmore, Gary 0 (Schlumberger); Wesley, Dave E; ~adsen, Alan D > > > (Fairweather) > > > Subject: S-107i Zonal isolation > > > Jane/Tom: > > > We lost returns while running in hole and during the primary cement job > on > > > the S-107i 7" casing. Subsequently we ran a USIT and determined the ' >'~ > cement was in poor condition. We then performed a "suicide squeeze" > > > through perforations at 11,950' MD and 11,730' MD (top Kuparuk target. > > > 11,900' MD). The squeeze was executed with Dowell's "liteCrete" slu:~'ry > > > which, by its nature, produced a questionable subsequent USIT log. > > > > > > We believe we have isolation in the first 100' or so abOve the top > > > Kuparuk though the USIT does not show this definitively. To give us the > > > most positive indication of cement integrity at the tod of Kupa. ruk > > > r~servoir, our plan forward is to, > > > 1) Set a cement retainer at 11,900' > > > 2) Perforate 2-ft intervals at 11,730' and 11,850' at 6 skots per foot > > > 3) Run cement retainer on drillpipe and set same at 11,825' > > > 4) Perform circulation test between two sets of perforations down > > > drillpipe. Maximu~ surface pressure: 4000 psi. > > > 5a) If circulation is possible, perform suicide squeeze with 30 bbls > class > > > G cement, hesitate as required. > > > 5b) If circulation is not possible, POH: Isolation confirmed. Squeeze > > > cement below retainer if injection is possible, else rig down cement,~rs. > > > 6) Drill out bridge plugs and cement, cleanout to top of 4-1/2" line:r > > > (12~259' MD). > > > 6a) Run USIT if'suicide squeeze was performed. Evaluate log fo~ > isolation > > > confirmation. > > > 7) Continue with straddle-pack completion procedure. > > > > > > Please respond with questions, concerns, or confirmation of plan for > > > isolation. > > > Thanks, > > > Phil Smith > > > Operations Drilling Engineer > > > 564-4897 > > ~ 003 > > Name: S-107 Cmt Squeeze-Rev 1.doc > > S-107 Cmt Squeeze-Rev 1.doc Type: WINWORD File (application/msword) > > Encoding: base64 >, > > > Name: S-107 diagram ~SWord. ZIP > > S-107 diagram MSWord. ZIP Type: Zip Compressed Data > (application/x-ziD-compressed) > > Encoding: base64 > 3 _' ~ UD DATE ~C~RANICAL iNTEGRITy REPORT - :~LL DATA .... Casing: Liner' Tub4_..=~=: L~I) Packer(,%b_ ~ TVB; ~Cet at ~0~)(o Zola Size and erfs ~%~ to ~~ Annulus Press Test: ; !5 rain ; 30 mit Co~ents: b~_CHA_NiC;i, iNTEGRITY - PART ~2 Cement Volumes :' ~nt. Liner Cmt v°l to cover oerfs Theoretical TOG c~.~=~ So~a nog (~ o= ~o) %~s CBL Evaluation, zone above peris rro~~o~ Log: _ , CONCLUSIONS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Conversion Alter casing _ Repair well _ ,Producer to Injector Change approved program_ Operational shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate_ Pull tubing _ Variance _ Perforate _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development Exploratory _ Stratigraphic __ Service__ 4. Location of well at surface 723' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 5269' FNL, 772' FEL, SEC 21, T12N, R12E, UM At effective depth 2681' FNL, 3779' FEL, Sec. 21, T12N, R12E, UM At total depth 2623' FNL, 3843' FEL, Sec 21 T12N, R12E, UM (asp's 618930, 5980760) (asp's 611992, 5986667) (asp's 608941,5989210) (asp's 608876, 5989267) 12. Present well condition summary Total depth: measured true vertical 16026 feet Plugs (measured) 6824 feet 6. Datum elevation (DF or KB feet) RKB 69.9 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-107 9. Permit number / approval number 201-1130 10. APl number 50-029-23023-00 11. Field / Pool Prudhoe Bay Field/Aurora Pool Other _X Effective depth: measured true vertical Casing Length Conductor ~ 115' Surface 4230' Intermediate 12390' Liner 3721' 15938 feet Junk (measured) 6839 feet Size Cemented Measured Depth 20" 260 sx AS (approx) 150' 10-3/4" 860 sx Arcticset Lite, 4265' 3218 sx Class 'G' 7" 565 sx Class 'G' 12421' 4-1/2" 247 sx Class 'G' 12259' - 15980' True vertical Depth 150' 2903' 6934' 6871'-6832' Perforation depth: measured Open Perf 11735' - 11737', 11850' - 11852', 11900' - 12150' Slotted Liner 15127' - 15938' Tubing (size, grade, and measured depth true vertical Open Perf 6648' - 6649', 6706' - 6707', 6730' - 6830' Slotted Liner 6992' - 6839' 4-1/2" 12.6#, L-80 TBG @ 12263'. Packers & SSSV (type & measured depth) RECEIVED /~laska Oil & Gas Cods. ~ss/0n 7" x 4-1/2" - (3) Baker PREM Packers @ 11718', 11823' & 12223' MD. 7" x 5" BKR ZXP PKR W/Tieback @ 12259'. 4-1/2" HES HXO SSSVN @ 2277'. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch 14. Estimated date for commencing operation 11 02/18/02 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas Suspended __ 17. I hereby certify tha_t the foregoing is true and correct to the best of my knowledge. Questions? Call Jim Young @ 564-5754. Signed ~, I,~, ~.~r~L~,._ ,,~ Title: Aurora Surveillance Engineer Date Februarv 12, 2002 Jim Youn~l / ~ - --~ ~ Prepared by DeWayne R. Schnorr 564-5174 -- -- ~ FOR COMMISSION USE ONLY Conditions of approval:PlugN°tify Commission s~ representative may witneSSintegrity_ BOP Test Location clearance I Appr°val n°' J~-O~'~6' ..... Mechanical Integrity T~e~t~_ -- ~ Subsequent form req-'~ired 10- ['~O'~ Approved by order of the Commission O~,~1~ ,(~,~ ,,¥. Commissioner Date ~.,,...~ Form 10-403 Rev 06/15/88 · OF IG[NAL SUBMIT IN TRIPLICATE · bp ( BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907') 561-5111 February 12, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for S-107 Conversion from Producer to Injector BP Exploration Alaska, Inc. proposes to convert well S-107 from a shut-in producer to an active injector (both water and MI (WAG flood)) as part of the Aurora Pool Flood Development project. S-107 produces -300 bopd at ~85% water-cut, quit taking AL gas on 2/10/01 and is currently freeze protected. Plans are to isolate the horizontal section and place the straddle section on injection. The procedure includes the following major steps: S SBHP, Set TTP in XN, DGLVs, Shift open CMU sleeve, SBHP 1. Obtain SBHP stop counts at: 11994' - 20-min, 111780' - 20min. 2. Set Tubing tail plug in XN-nipple at 12250' 3. Shift open baker CMU sliding sleeve. 4. DGLVs. ' 5. Obtain straddle SBHP stop counts at: 11994' - 30-min, 111780' - 20min. Due to debris or hydrates that may still be present in the tubing, a drift/tag and CT hot-oil treatment may be necessary to clear tubing for this work. MITIA to 3000 psi prior to and following ~p. ~Or~C_.r~"~,~,.~,~-~-,~-~,' If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5754, hm: 248-0133, cell: 440-8007 or e-mail me at YoungJ3 @ BP.com. Sincerely, Jim Young GPB Westend New Developments Petroleum Engineer TREE = NA WELLFIEAD= FMCS 107 SAFETY NOTES: WELL > 70 deg @ 12483' AND > 90 deg · ACTUATOR= NA ~ @ 13601' KB. ELEV = 69.4' BF. B_EV = 35.9' ~o~-- ~oo, " ---I I-I = 101 15229' Max Angle . ~ ........ .. -'= 993' 10-3/4" TAM PORT COLLAR I Datum MD = 12155' Datum TVD= 6745' SS I I I 2277' H4-11Z' HES HXO SSSVN, ID= 3.813" 110-3/4" CSG, 45.5#, L-80, ID = 9.980" H 4265' ~ GAS LIFT MA NDRB_S ST MD TVD DEV TYPE VLV LATCH POR'I DATE Minimum ID = 3.725" @ 12250' 4 6491 3810 57 KBG-2 ~ aK 08/09/01 3 11628 6522 58 KBG-2 DV BK 08/09/01 4-1/2" HES XN NIPPLE L 2 12030 6714 67 KBG-2 DV BK 08/09/01 1 12096 6740 68 KBG-2 DV BK 08/09/01 I i i ~r.' I-I~-~,~".~ x.,..,~= 3.813" I I IRA TAGS IN JT# 10 I--I 11665' , x x ~-p×4-~,~-~K...~.~,,.,~ x x i ~823' 1--17"x4-~/2"BK.~,~uP~,,D=3.890"I ' ' I ~""~' I-I~-'~'' c~u~..~,~ ~.v,,~: ~.~1~,, I I i I ~2202' 1--14-1rZ'HESXN'P,~D=3.813" I ;X~] X ~ 12223' H7"x4-1/2"BKRPREM. PKR, D=3.890"I I i I~2280' t-14-1/2" 'ES xN"~", 'D = 3.725" I 14-1/2'''I'BG'12.6#'L'80,'0152bpf'D=3.958'' I-t ~=~' ' ( ~ ...--I ~""' ' >~ I ~' I-I4'~'~'' vv..~, ,~= ~..~,, I " ~ H ~..OT.O~.~ I 17" CSG, 26#, b-80, ID= 6.276" H 12421' I ,~ ! PERFORATION SUMMA RY REF LOG: SPERRY-SUN MWD OF 7-28-01 i ~-~ 15019' H4-1/2'' EXTCSG PKR, ID = 3.937"I Note: Referto R'oduc~ion DB for historical per 0ara 5127' TO, OF4-1/2" SI_TD LINERI SIZE SPF INTERVAL Opn/Sqz DATE "... NA 4 11730 - 11732 S 07/17/01 NA 6 11735 - 11737 O 07/31/01 ' .. NA 6 11850 -11852 O 07/31/01 " - "" ,. 4-5/8" 5 11900 - 12150 O 07/31/01 , ". "'- .. NA 4 11950-11952 S 07/17/01 '"'- ''.--1"~H~' I 4-5/8,, 5 15127 - 15938 0 08/03/01 14-1/2,' sL°TTED LNP'12'6#' L'8°' 'D= 3'958'' H ~.~"' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOEBAY UNIT 08/09/01 ORIGNAL COMPLETION WELL: S-107i 08/18/01 CH/tlh COMPLETION SCHEMATIC PERMIT No: 201-113 02/07/02 JY/KAK PERFCORRECTION/ADDITION APl No: 50-029-23023-00 4556' NSL & 4496' WEL, Sec. 35, T12N, R12E BP Exploration (Alaska) PERFORATION SUMMA RY REF LOG: SPERRY-SUN MWD OF 7-28-01 ANGLEATTOPPERF: 59 @ 11730' Note: Refer to R'oduc'don DB for historical perf dala SIZE SPF INTERVAL Opn/Sqz DATE NA 4 11730 - 11732 S 07/17/01 NA 6 11735 - 11737 O 07/31/01 NA 6 11850 -11852 O 07/31/01 4-5/8" 5 11900 - 12150 O 07/31/01 NA 4 11950 - 11952 S 07/17/01 4-5/8" 5 15127 - 15938 O 08/03/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas I-I Suspended [] Abandoned r"l Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 201-113 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~..~'~i 50-029-23023-00 4. Location of well at surface '"'.'~i'.! !'i'.' i:?; :',~:.' ~L-~ .~- I 9. Unit or Lease Name At top of productive interval i, ~ ~?, 2¥ ~ S .................... ,, 10' NSL, 773' WEL, SEC. 21, T12N, R12E, UM '~.'ii~i;::::':. , ;,' ..... ~---,,~,.~,-- 10. Well Number At total depth i. ....... ~.~._ ~ ....... ,~" ................ S-107 2655' NSL, 3843' WEL, SEC. 21, T12N, R12E, UM ,. .................... -;.~::: 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Aurora Pool KBE = 69.94' ADL 028256 (Undefined) Ius, I °'c°mp' 'i°nsone 17. Total Depth (MD+TYD) 118. Plug Back Depth (MD+TYD) 119. Directional Survey 1 20. Depth where SSS¥ set121. Thickness of Permafrost 16026 6824 FTI 16026 6824 FTI [] Yes [] NoI (Nipple) 2277' MDI 1900' (Approx.) 22. Tgpe Electric or Other Logs Run MWD, GR, RES, NEU-DEN, PWD, USIT, CBL, CCL CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 115' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 4265' 13-1/2" 653 sx AS Lite 3r 513 sx Class 'G' 7" 26# N-80 31' 12421' 9-7/8" 333 sx Sodium Silcate 'G'~ 709 sx 'G' 4-1/2" 12.6# L-80 12259' 15980' 6-1/8" 197 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD)' 4-5/8" Gun Diameter, 5 spf -~ 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 12263' 11718', 11823', 12223' MD TVD MD TVD 11900' - 12150' 6730' - 6830' 11735' - 11737' 6648' - 6649' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11850' - 11852' 6706' - 6707' , , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4-'1/2" Slotted Liner 11730'- 11732' & 11950'- 11952' 7" Suicide Cement Sqz, 87 sx CemCrete 15127' - 15938' 6992' - 6839' 11735,- 11737,8,11850,- 11852, ~' Open Perf's due to failed 7" Cementing 15939' - 15978' 6839' - 6832' OpE, Trying to establish Circulation Freeze Protect With 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL'BBL GAS'MCF WATER'BBL CHOKE SIZE I GAS'OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL 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. RECEIVED OCT 1 9 ; 001 _,, 0~ I C I~! ~,I A'a~'a0il&?.a~shCnr°nJ;c°mmissi°" 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 recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff M 8160' 4757' Schrader Bluff N 8586' 4967' Schrader Bluff O 8796' 5072' Base Schrader / Top Colville 9326' 5358' C M 1 11424' 6481' Top of HRZ 11745' 6653' Top Kalubik 11869' 6715' Top Kuparuk C 11897' 6728' LCU /Top Kuparuk B 12320' 6895' LCU/Top Kuparuk B 13950' 7015' RECEIVED Kuparuk C 15976' 6763' OCT ~ 9 ~001 Alaska 0il & Gas Cons. Commissio~ Anchorage 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 TerrieHubble~"'/~~ _. Title TechnicalAssistant Date /(~)°/(~'~)/ S-107 201-113 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS (~ENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form10-407 Rev. 07-01-80 0f~ IC~It~AL Legal Name: S-107 Common Name: S-107 : Te~a~ :: :~:.: i: TeStTy~e Te~P~(~D):::~:~ept. h(T'VD) i/ :::Surface:Pressure Leak Off Pressure (BHP) EMW 7/6/2001 LOT 4,305.0 (ft) 2,920.0 (ft) 9.35 (ppg) 800 (psi) 2,218 (psi) 14.62 (ppg) 7/19/2001 FIT 12,453.0 (ft) 6,946.0 (ft) 10.40 (ppg) 950 (psi) 4,703 (psi) 13.03 (ppg) Printed: 8121/2001 3:59:46 PM BP EXPLORATION Page 1 of 11 Operations Summa Report Legal Well Name: 8-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/28/2001 16:00- 21:30 5.50 RIGU P PRE Cantilever floor in place. Rig accepted at 1600 hrs, 612812001. NU annular BOP and drlg nipple. RU floor and put 600 bbls 8.8 ppg spud mud in pits. Put DP and BHA in pipe shed. 21:30 - 22:30 1.00 RIGU N RREP PRE Made electrical repairs to top drive controls. Partial repair completed. Full repair requires parts ETA PM of 6/29/2001. 22:30 - 00:00 1.50 P PRE Pick up drill pipe and stand back in derrick. 6/29/2001 00:00 - 07:30 7.50 RIGU P PRE Pick up 5" DP and HWDP. 07:30 - 08:30 1.00 RIGU P PRE Pick up monel drill collars and stand back in derrick. 08:30 - 12:30 4.00 RIGU P PRE Make up MWD BHA. 12:30 - 13:00 0.50 RIGU P PRE Prespud meeting. 13:00 - 13:30 0.50 RIGU P PRE Fill hole and check for leaks-OK. 13:30 - 17:00 3.50 DRILL P SURF Spud at 1330 hrs, 6/29/2001. Drill from 115' tpo 262'. 17:00 - 18:00 1.00 DRILL N RREP SURF Repair Top Drive. Change out dynamic brake chopper and grabber dies. 18:00 - 19:00 1.00 DRILL P SURF Run gyro survey on wireline. 19:00 - 00:00 5.00 DRILL P SURF Drill from 262' to 307' 6/30/2001 00:00 - 00:00 24.00 DRILL P SURF Directional drill from 307' to 1517' MD. AST = 10.25 hfs; ART = 8.25 hrs; survey & orient = 3 hrs. Last gyro survey at 803' MD at 1000 hrs. RD slick line at 1630 hrs. 7/1/2001 00:00 - 05:00 5.00 DRILL P SURF Dir. drill from 1517' to 1832'. ART=I.5 hrs; AST=2.25 hrs. 05:00 - 06:00 1.00 DRILL P SURF Circ. and condition mud for bit trip. 06:00 - 08:30 2.50 DRILL P SURF POOH. Pump out 4th and 6th stand (1500' to 1350' MD) 08:30 - 09:00 0.50 DRILL P SURF Download MWD and reload tools. 09:00 - 10:30 1.50 DRILL P SURF Change BHA stabilizer location. 10:30 - 13:00 2.50 DRILL P SURF RIH to TD with new BH^ and bit. 13:00 - 14:00 1.00 DRILL P SURF Displace hole with new 8.8 ppg spud mud. 14:00 - 00:00 10.00 DRILL P SURF Dir. drill from 1832' to 2703'. ART = 3.5 hrs; AST = 4.25 hrs. 7/2/2001 00:00 - 15:30 15.50 DRILL P SURF Dir drill from 2703' to 4285', 10 3/4" surf csg point. AST = 1.25 hrs; ART = 9 hrs; survey & orient = 1 hr. 15:30 - 17:30 2.00 DRILL P SURF Circ & cond. hole. Pump sweep. 17:30 - 18:30 1.00 DRILL P SURF POOH from 4285' to 3182'. OK. 18:30 - 22:00 3.50 DRILL P SURF POOH. Work tight hole. Pump out from 2010' to 1840'. 22:00 - 00:00 2.00 DRILL P SURF Work tight hole between 1840' and 1730'. 7/3/2001 00:00 - 02:30 2.50 DRILL P SURF Trip to bit to wipe hole. 02:30 - 03:00 0.50 DRILL P SURF Download MWD. 03:00 - 07:00 4.00 DRILL P SURF Trip in to TD. Wash and ream 1800' to 2100'. 07:00 - 09:00 2.00 DRILL P SURF Circ. & condition mud and hole. 09:00 - 15:00 6.00 DRILL P SURF POOH to BHA. 15:00 - 17:00 2.00 DRILL P SURF Lay down BHA. 17:00 - 21:30 4.50 CASE P SURF PJSM. Rig up casing tools and prepare floor to run 10 3/4" csg. 21:30 - 00:00 2.50 CASE P SURF Run 10 3/4", 45.5 #, L-80, BTC surf. csg. 37 of 102 joints run by 23:59hrs. Run bow centralizers and Bakerlok per plan. 7/4/2001 00:00,06:00 6.00 CASE P SURF Run 10 3/4" surf. csg. Land with FMC fluted mandrel hanger. Shoe at 4273' MD. 06:00 - 07:00 1.00 CASE P SURF Circulate and condition hole and mud. Pump 1.5 annular volume at 7.5 BPM at 500 psi 07:00 - 07:30 0.50 CASE P SURF Rig down Franks fillup tool. Rig up cementing equipment on rig floor. 07:30 - 08:00 0.50 CASE P SURF Circulate. PJSM for cementing. 08:00 - 12:00 4.00 CASE P SURF Mix and pump 75 bb110.4 ppg weighted spacer; 516 bbl 10.7 ppg Arcticset lead slurry; 106 bb115.8 ppg tail slurry. Displ with Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 2 of 11 Operations Summa Report Legal Well Name: S-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/4/2001 08:00 - 12:00 4.00 CASE P SURF 395 bbl mud using rig pumps at 10 bpm. Bumped plug to 3000 psi. ClP at 1210 hrs. Recip csg during cementing. Full returns. 60 bbls of cement to surface. 12:00 - 15:00 3.00 CASE P SURF Check floats. Held OK. Rig down cement equip, and remove from floor. 15:00 - 23:00 8.00 BOPSUF P SURF ND annular preventer. Install FMC speedhead and PT seal to 1000 psi/10 min. NU BOP. Change upper pipe rams. Install 4 1/2 X 7" variable rams. 23:00 - 00:00 1.00 BOPSUF P SURF PJSM. Prep equipment for BOP test. AOGCC witnessing of BOP test waived by John Spaulding. 7/5/2001 00:00 - 01:00 1.00 BOPSUF P INT1 Rig up to test BOPs 01:00 - 06:00 5.00 BOPSUF P INT1 Test BOPE, choke manifold, kelly valves, and inside BOPs to 250 psi and 4000 psi/10 min. Hydril to 250 psi and 3500 psi/10 min. Function test accumulator unit. AOGCC test witnessing waived by John Spaulding. 06:00 - 06:30 0.50 BOPSUF P INT1 RD BOP test equip. Run long wear bushing. 06:30 - 11:00 4.50 DRILL P INT1 Pick up 126 jts of 5" DP and stand in derrick. 11:00 - 14:30 3.50 DRILL P INT1 PJSM. Make up BHA No. 4 14:30 - 16:00 1.50 DRILL P INT1 Upload MWD. PJSM. Load RA sources in MWD. 16:00 - 17:00 1.00 DRILL P INT1 LD excess HWDP. 17:00 - 19:00 2.00 DRILL P INT1 Pick up DP singles and RIH. 19:00 - 20:00 1.00 DRILL P INT1 Circ. &cond. mud at 2000'. Thick cement contaminated mud. Test MWD. 20:00 - 21:30 1.50 DRILL P INT1 Pick up DP singles and RIH to 4022'. 21:30 - 22:30 1.00 DRILL P INT1 Circ. &cond. cement contaminated mud. Slip & cut drilling line. 22:30 - 23:30 1.00 DRILL P INT1 Wash down and drill cmt stringers from 4167' to 4180' 23:30 - 00:00 0.50 DRILL P INT1 Circ. BU. Rig up test equip, for casing PT. 7/6/2001 00:00 - 01:00 1.00 DRILL P INT1 Pressure test 10 3/4" casing to 3500 psi for 30 min. OK 01:00 - 03:00 2.00 DRILL P INT1 Drl. float collar (4181' DP tally), firm cmt in shoe joints, float shoe (4264' DP tally), and 20' of new hole to 4305'. Tagged 13 .5" OH at 4285'. PU to csg shoe. 03:00 - 04:30 1.50 DRILL P INT1 Circ. BU. Perform LOT. With 9.3+ ppg mud in hole, determined LOT press, to be 800 psi yielding a 14.6 ppg EMW. 04:30 - 05:30 1.00 DRILL P INT1 Dir. drill to 4402'. Displace to 9.3 ppg LSND mud while drilling. 05:30 - 06:00 0.50 DRILL P INT1 Established baseline ECD's & drilling parameters. 06:00 - 00:00 18.00 DRILL P INT1 Dir. drill from 4402' to 6129'. AST = 3.9 hrs; ART = 10 hrs. 7/7/2001 00:00 - 01:00 1.00 DRILL P INT1 Dir. drill from 6129' to 6224'. Start pumping hole sweep.AST = 0.25 hrs; ART = 0.75 hrs. 01:00 - 01:30 0.50 DRILL P INT1 Complete hole sweep. Flow check. OK. 01:30 - 07:00 5.50 DRILL i p INT1 POOH. Short trip to csg shoe. Pull tight. Wash and back-ream from 6040' to 4400'. Pull up to 4240'. 07:00 - 08:00 1.00 DRILL P INT1 RIH to 6130'. OK. Circ. and wash to 6224', precautionary. Pump sweep. 08:00 - 00:00 16.00 DRILL P INT1 Dir. drill to 7471'. AST = 1.25 hrs; ART = 9.75 hrs. 7/8/2001 00:00 - 12:30 12.50 DRILL P INT1 Dir. drill to 8235'. AST = 2.25 hrs; ART = 6.5 hrs; ADT = 8.75 hrs. 12:30 - 13:00 0.50 DRILL P INT1 Circ. sweep plus 1/2 hole volume. Survey. Flow check. OK. 13:00 - 18:00 5.00 DRILL P INT1 POOH. Back-ream from 7100' to 6400'. Some tight spots. 18:00 - 18:30 0.50 DRILL P INT1 Pump slug. Refill trip tank. Flow check at shoe. OK. 18:30 - 20:00 1.50 DRILL P INT1 Pull BHA. Flow check. OK. 20:00 - 00:00 4.00 DRILL P INT1 Change BHA arrangement. PJSM and remove RA sources in LWD tools. PU Sec. PDC bit and Slickbore mudmotor. Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 3 of 11 Operations Summa Report Legal Well Name: S-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYEN Rig Release: 8/9/2001 Rig Name: DOYEN 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/9/2001 00:00 - 02:00 2.00 DRILL P INT1 MU new BHA. Download/upload MWD. PJSM. Install RA sources. 02:00 - 04:30 2.50 DRILL P INT1 RIH to 4230'. (Fill pipe on 20th & 40th std.) 04:30 - 06:00 1.50 DRILL P INT1 Slip & cut drlg. line. Service topdrive. 06:00 - 10:00 4.00 DRILL P INT1 RIH to 4310'. Check MWD ECD & drilling parameters in OH. RIH. Wash & ream from 6000' to 8235' as needed for tight spots. Precautionary wash & ream last two stands to bottom. 10:00 - 00:00 14.00 DRILL P INT1 Dir. drill from 8235' to 9212'. AST = 2 hrs; ART = 7.25 hrs; ADT = 9.25 hrs. 7/10/2001 00:00 - 06:30 6.50 DRILL P INT1 Drill 9 7/8" directional hole 9212 ft to 9786 ft. 06:30 - 07:30 1.00 DRILL P INT1 Circ sweep to surface @ 9786 ft. PJSM. Flow check. Well static. 07:30 - 10:00 2.50 DRILL P INT1 Wiper trip to 8063 ft. Hole in good shape. Precaution ream last two stands to btm. 10:00 - 00:00 14.00 DRILL P INT1 Drill 9 7/8" directional hole 9786 ft to 10936 ft. 7/11/2001 00:00 - 07:00 7.00 DRILL P INT1 Drilling from 10,936 to 11,507 pumping weighted barofibre sweeps every 400 ft. or as hole dictates. 07:00 - 08:00 1.00 DRILL P INT1 Pump sweep S-S in preparation of short trip. 08:00 - 11:30 3.50 DRILL P INT1 Observe well. Short trip to 9,634. Wash last 200 ft. to bottom as precaution only. No adverse hole conditions or fill. 11:30 - 00:00 12.50 DRILL P INT1 Drilling 9 7/8 hole from 11,507 to 11,893. Hole in good shape. No excess drag on connections. Some signs of minor packoff on connections. Having problems with dirctional work in HRZ/Kuparuk transition zone. 7/12/2001 00:00 - 15:30 15.50 DRILL P INT1 Drilling 9 7/8 hole from 11,893 to intermediate T.D. @12,433. Pump weighted barofibre sweeps to assist in hole cleaning. Hole in good shape--no fill or overpull on connections. 15:30 - 18:00 2.50 DRILL P INT1 Circulate Sweep surface to surface prior to short trip to shoe. 18:00 - 00:00 6.00 DRILL P INT1 Observe well. POH with 15 stands and pump dry job. Continue short trip to shoe working 30k overpulls at base of "Ugnu" (7,305). Wipe clean and continue to shoe. Minimal overpull noted on remainder of trip to shoe. Depth at crew change---4,518. 7/13/2001 00:00 - 02:00 2.00 DRILL P INT1 Cut drilling line and service top drive at 10 3/4 shoe. 02:00 - 07:00 5.00 DRILL P INT1 RIH wiping all sections of hole as needed. Wash last stand to bottom as precaution only. Hole appears to be in good shape. No fill on bottom. 07:00 - 09:00 2.00 DRILL P INT1 Circulate weighted barofibre sweep around. Circulate until shakers cleaned up. Lots of cuttings seen back with sweep. Pump dry job. 09:00 - 22:30 13.50 DRILL P INT1 Observe well. POH lxl with 5 inch drill pipe. No tight spots needing work on trip out. 22:30 - 00:00 1.50 DRILL P INT1 PJSM. Lay down BH^. 7/14/2001 00:00 - 02:30 2.50 DRILL P INT1 Lay down BH^. 02:30 - 03:00 0.50 DRILL P INT1 Pull wear ring. 03:00 - 06:30 3.50 CASE P INT1 PJSM. Change bales. R/U Franks tool. Change out damaged rubber on Franks circ. tool. PJU casing equipment. 06:30 - 13:30 7.00 CASE P INT1 P/U and bakerlok shoe track. Check floats. RIH with 7" 26# L-80 BTC. 13:30 - 14:30 1.00 CASE P INT1 Circulate casing volume at 10 3/4 casing shoe.(4,265) Pumped at 425 gpm @ 710 PSI with no losses. 14:30 - 22:30 8.00 CASE P INT1 Continue to run in hole with 7 inch casing. Begin seeing slight losses at app. 9,500 ft. Down wts. continues to be consistant Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 4 of 11 Operations Summa Report Legal Well Name: 8-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations ,,, 7/14/2001 14:30 - 22:30 8.00 CASE P INT1 with no tight hole. Slow slackoff speeds and continue in hole. Start seeing no returns during slackoff at app. 11,000. 22:30 - 00:00 1.50 CASE IR INT1 Break circulation slowly while reciprocating pipe. Returns while picking up, but none while slacking off with no pumps. Circulate slowly while breaking gel strengths and building surface volume. Deliver app. 300 bbls. from mud plant.(Mud being stored by 9-ES) Lost a total of 210 bbls. while circ. and running in hole. 7/15/2001 00:00 - 02:30 2.50 CASE P INT1 Continue to run in hole with 7" 26# BTC L-80 intermediate casing. 02:30 - 06:00 3.50 CASE P INT1 P/U hanger and circ. last joint to bottom. Mandrel hanger hanging up in stack cavity. Pull stack over with turnbuckles. Land casing with hanger. Unable to reciprocate once landed on bottom. Break circ. @ 10 SPM with 610 PSI. No returns while pumping. Pull 495K in attempt to move pipe off bottom-to no avail. Mix and spot 50 bbl. LCM pill in casing. Lay down "Franks" tool and P/U cement head and prepare to pump cement. 06:00 - 09:30 3.50 CEMT P INT1 PJSM. Pump cement as per program: 50 bbls. CWl00, 75 Bbls. Mudpush, 165 Bbls. lead @ 11.5 ppg.., 151.5 tail @ 15.8 ppg.. Kick out plug and displace, bumping plug at calculated strokes. (96% pump eft.) Test floats and bleed to zero. 09:30 - 12:00 2.50 CEMT P INT1 Lay down landing jr., cement head and clear floor of all vendors excess equipment. 12:00 - 13:30 1.50 BOPSUR P INT1 Change top rams to 2 7/8 X 5 variables. 13:30 - 15:30 2.00 BOPSUR P INT1 Change top drive saver sub to accommodate new string of drill pipe. 15:30 - 16:00 0.50 BOPSUR P INT1 Install test plug and test joint and prepare to test BOP's. 16:00 - 18:00 2.00 BOPSUR N RREP INT1 Test IBOP and floor valve. Leak developed in 1" hydraulic hose going to Annular Preventer. Sprayed inner walls and wheelhouse. All was contained inside temporary containment (Herculite) Stop operations and clean and wipe walls. Change out hose with new and test same. 18:00 - 00:00 6.00 BOPSUR P INT1 Continue to test BOP,s. Hydril failed Iow and high test. Prepare to change out failed hydril. 7/16/2001 00:00 - 05:30 5.50 CASE N RREP INT1 Change out complete hydril. Failed Iow/high test during weekly test. 05:30 - 07:30 2.00 BOPSUR P INT1 Test newly installed hydril. R/D test equipment and install wear ring. 07:30 - 08:00 0.50 CASE P INT1 PJSM on P.U. drill pipe. Inspect and veiw work area after installation of new hydril. P/U and store away any tools / equipment, if needed. 08:00 - 13:00 5.00 DRILL P INT1 Pick up and rack back enough drill pipe to drill 6 1/8 section. (App.3500') 13:00 - 20:30 7.50 DRILL P INT1 Rig up and run "USlT" log to verify cement job. Tool not working when surface checked. Trouble shoot and repair took app. 1 hour. (Broken wire) RIH and log up from app. T.D. to 6,200 ft. No "Good cement" until 11,590 to 11,620 showed app. 70% bondage. Other area's from 5 to 20%. Another 6 ft. interval showed bondage of 100% at a depth of 11,000. From 11,000 to app. 6,500 ft. there were signs of cement varying in quantity. Inadequate cement coverage over the top of Kuparuk. Line up tools for Squeeze job. Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 5 of 11 Operation Summa Report Legal Well Name: S-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/16/2001 20:30 - 21:30 1.00 DRILL !P INT1 Test 7" casing to 4,000 for 30 minutes on chart. Good test. 21:30 - 23:00 1.50 DRILL N WAIT INT1 Mobilize perf. guns. 23:00 - 00:00 1.00 DRILL N DPRB INT1 PJSM with Schlumberger. Rig up lubricator and extension. 7/17/2001 00:00 - 05:00 5.00 CASE N DPRB INT1 E-line perforate f/11951'- 11949' (4 SPF) & 11730'- 11728' (4 SPF). 05:00 - 08:30 3.50 CASE N DPRB INT1 RU & RIH w/EZSV squeeze packer on E-line and set @ 11891'. 08:30 - 09:00 0.50 CASE N DPRB INT1 RD E-line. 09:00 - 14:00 5.00 CASE N DPRB INT1 TIH w/Cement squeeze assembly picking up DP from pipe shed to 5100'. 14:00 - 15:00 1.00 CASE P INT1 Slip and cut drill line. 15:00 - 21:30 6.501 CASE N DPRB INT1 Continue TIH with cemeting assembly. Tag top of EZSV packer@ 11891'. PU to 11826'. 21:30 - 00:00 2.50 CASE N DPRB INT1 Circulate and condition mud for cement job. Evacuate rig 2 times due to H2S and High Gas alarms. Check for H2S and Gas. False alarms. 7/18/2001 00:00 - 01:00 1.00 CASE N DPRB INT1 Continue to circulate and condition mud. 01:00 - 02:00 1.00 CASE N DPRB INT1 Sting into EZSV pkr. Establish circulation. Stage circulation to 3 BPM @ 1200 psi. 02:00 - 04:00 2.00 REMCM'I'N DPRB INT1 PJSM. Pmp 2 BBL water. Test lines to 4000 psi. Pmp 3 BBL water. Pmp 37 BBL CemCRETE blend D962 cement (87 sxs) mixed with 1% BWOC D167 + 0.40% BWOC D800 + 0.30% BWOC D046 + D046 + D110. Pmp 5 BBL water behind. Switch to rig pumps and displace with 116 BBL 10.3 ppg mud. 04:00-05:00 1.00 REMCM'I'N DPRB INT1 Pull out of pkr to11875'. Reversecirculatel l/2 DP volume. 31 BBL cement and contaminated mud in returns. 05:00 - 11:00 6.00 REMCM'I'N DPRB INT1 RD circulating tools. Change out bales. POOH. 11:00 - 16:00 5.00 DRILL P PROD1 MU BHA # 6 with 6 1/8 mill tooth bit, MWD/LWD. 16:00 - 17:00 1.00 DRILL P PROD1 Up load MWD. 17:00 - 17:30 0.50 DRILL P PROD1 Continue to MU BHA #6. 17:30 - 18:00 0.50 DRILL P PROD1 Surface test MWD, 60 SPM, 1200 psi. 18:00 - 23:30 5.50 DRILL P PROD1 TIH with 4" DP to 11738'. 23:30 - 00:00 0.50 DRILL P PROD1 Wash f/11738'- 11848'. 7/19/2001 00:00 - 01:00 1.00 DRILL P PROD1 Continue to wash down f/11848' - 11891'. 01:00 - 02:00 1.00 DRILL P PROD1 Drill EZSV @ 11891'. Drill cement to 12035'. 02:00 - 03:00 1.00 DRILL P PROD1 Wash to 12334' (FC @ 12336'). 03:00 - 05:30 2.50 DRILL P PROD1 Drill FC @ 12336', shoe track, FS @ 12421'. Clean old hole to 12433'. 05:30 - 06:00 0.50 DRILL P PROD1 Rotary drill 20' new formation fl 12433' - 12453'. 06:00 - 07:00 1.00 DRILL P PROD1 Circulate bottoms up for FI']'. 07:00 - 07:30 0.50 DRILL P PROD1 FIT with 10.4 ppg MW, 950 psi, 6946' 'rVD for 13 ppg EMW. 07:30 - 09:00 1.50 DRILL P PROD1 PJSM. Swap mud system to 10.3 ppg KCL. 09:00 - 09:30 0.50 DRILL P PROD1 Slow pump rates and establish ECD baseline. 09:30 - 20:00 10.50 DRILL P PROD1 Drill f/12,453' - 12,595'. AST: 4.25 hrs, ART: 4.5 hrs, ADT: 8.75 hrs. 20:00 - 21:00 1.00 DRILL P PROD1 Circulate bottoms up. PJSM. Flow check. Pump slug. Prepare to trip for bit. 21:00 - 00:00 3.00 DRILL P PROD1 POOH (7265' @ rpt time). 7/20/2001 00:00 - 03:30 3.50 DRILL P PROD1 Continue to POOH. SLM ok. 03:30 - 06:00 2.50 DRILL P PROD1 Handle BHA. PJSM RA source. Remove RA source. 06:00 - 14:30 8.50 DRILL N DPRB PROD1 RU E-line. USl / CBL log f/12336' - 9336'. RD E-line. 14:30 - 19:00 4.50 DRILL P PROD1 MU BHA #7 with bit #6 (PDC). PJSM RA source. Uplodoad Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: S-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours iActivity Code NPT Phase Description of Operations 7/20/2001 14:30 - 19:00 4.50 DRILL P PROD1 MWD/LWD. Install RA source. Surface test, 50 SPM 1100 psi.. 19:00 - 22:30 3.50 DRILL P PROD1 TIH. Fill pipe every 30 stds to 8110'. 22:30 - 23:30 1.00 DRILL P PROD1 Slip and cut drill line. 23:30 - 00:00 0.50 DRILL P PROD1 Continue TIH. 8395' @ report time. 7/2112001 00:00 - 02:30 2.50 DRILL P PROD1 Continue TIH to 12329'. 02:30 - 05:30 3.00 DRILL P PROD1 Wash down to 12433'. Wash and ream 12433' - 12521'. Taking weight and tight from new hole section. Attempt to slide to bottom. Slide 12521' - 12555'. Tight hole and packing off. Pull one stand with pumps off and stand back. Wash and ream to casing shoe @ 12521'. Wash and ream back to bottom @ 12595'. 05:30 - 00:00 18.50 DRILL P PROD1 Drill fl 12595' - 13285'. Pump sweeps @ 400' intervals or as hole dictates. Hole in good shape. No adverse conditions or fill on connections. ART: 10.75, AST: 3.5, ADT: 14.25 .7/22/2001 00:00 - 01:00 1.00 DRILL P PROD1 Drill f/ 13285' - 13380'. 01:00 - 02:30 1.50 DRILL P PROD1 Circulate sweep around. Check for flow. 02:30 - 03:30 1.00 DRILL P PROD1 Wiper trip to 7" casing shoe @ 12421'. Hole in good condition. Max pull 15 - 35 k over. 03:30 - 04:00 0.50 DRILL P PROD1 Check for flow. TIH. Wash last stand to bottom. 04:00 - 00:00 20.00 DRILL P PROD1 Drill fl 13380' - 14085'. Pump sweeps @ 400' intervals or as hole dictates. Hole in good shape. No adverse conditions or fill on connections. ART: 9.75, AST: 5.75, ADT:15.5. 7/23/2001 00:00 - 04:30 4.50 DRILL P PROD1 Directionaly drill f/14085' - 14246'. 04:30 - 06:00 1.50 DRILL P PROD1 Circulate weighted barofibre sweep around. Condition mud. Check flow. 06:00 - 07:30 1.50 DRILL P PROD1 TOOH to 13190'. No problems on short trip. Max. overpull 25K. Check flow. 07:30 - 08:00 0.50 DRILL P PROD1 TIH, wash last stand to bottom. No fill on bottom. 08:00 - 00:00 16.00 DRILL P PROD1 Directionaly drill f/14246' - 14693'. Pump sweeps @ 400' intervals or as hole dictates. Hole in good shape. No adverse conditions or fill on connections. Reduced viscosity and add lubricant to help sliding & ECD. ART: 13.75, AST: 3.00, ADT: 16.75. 7/24/2001 00:00 - 15:30 15.50 DRILL P PROD1 Drilling 6 1/8 hole from 14,693 14,886 with following parameters. 5-7 WOB---235 GPM @ 2,800 PSI off bottom---12.3 ECD's Attempt to build from 917 up to 99. Wall hanging and stalling motor while attempting to slide. Pump beads and continue to bring up lubricant concentration. (Currently at 5%) Rotating at 125-185 FPH. Sliding ROP 4-5 FPH. Will not meet wellbore objectives without building angle. POH for BHA change. 15:30 - 17:30 2.00 DRILL P PROD1 Pump Weighted Barofibre sweep S-S. Perform flow check. 17:30 - 00:00 6.50 DRILL P PROD1 POH to casing shoe with no adverse hole conditions. Pump dry job. Continue trip out for BHA change. At 2,200 @ report time. 7/25/2001 00:00 - 00:30 0.50 DRILL P PROD1 Service rig. 00:30 - 02:00 1.50 DRILL P PROD1 Compl. POOH. 02:00 - 05:00 3.00 DRILL P PROD1 LD flex collar. Remove RA sources. Download MWD. LD bit. Changeout mud motor. 05:00 - 06:00 1.00 DRILL P PROD1 Clear floor and pull wear bushing. 06:00 - 07:00 1.00 BOPSUF~ P PROD1 PJSM. Rig up for BOP test. 07:00 - 11:30 4.50 BOPSUR P PROD1 Test BOPE, choke manifold, kelly valves, and inside BOPs to 250 psi and 4000 psi/10 min. Hydril to 250 psi and 3500 psi/10 Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 7 of 11 Operations Summa Report Legal Well Name: 8-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYEN Rig Release: 8/9/2001 Rig Name: DOYEN 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/25/2001 07:00 - 11:30 4.50 BOPSUR P PROD1 min. Function test accumulator unit. Test witnessed by John Spaulding, AOGCC. 11:30 - 12:00 0.50 DRILL P PROD1 Run wear bushing. 12:00 - 15:30 3.50 DRILL P PROD1 Make up BHA. Upload MWD. Insert RA sources. Function check. 15:30 - 20:00 4.50 DRILL P PROD1 RIH to 12325'. 20:00 - 21:00 1.00 DRILL P PROD1 Slip and cut drilling line. Service topdrive. 21:00 - 21:30 0.50 DRILL P PROD1 Break circ. with bit at 12440'. Circ 30 min. to break gels. 21:30 - 23:00 1.50 DRILL N RREP PROD1 Repair foot throttle on drawworks. 23:00 - 00:00 1.00 DRILL P PROD1 RIH at 14,045 at report time. 712612001 00:00 - 01:30 1.50 DRILL P PROD1 RIH from 14,045' to 14, 886'. Wash and ream tight spot at 14,210'. 01:30 - 00:00 22.50 DRILL P PROD1 Dir. drill from 14,886' to 15,450'. AST = 1.1 hr; ART = 17.25 hrs; ADT = 18.35 hrs. 7/27/2001 00:00 - 17:00 17.00 DRILL P PROD1 Dir. drill from 15,450' to 16,026'. AST = 0 hrs; ART = 14.25 hrs; ADT- 14.25 hrs. 17:00 - 19:30 2.50 DRILL P PROD1 Circ. & condition mud. Pump hole sweep. 19:30 - 20:00 0.50 DRILL P PROD1 Flow check and prep for short trip. 20:00 - 21:30 1.50 DRILL P PROD1 POH, 21-stand short trip (to 14,029'). 21:30 - 22:30 1.00 DRILL P PROD1 RIH. Wash and ream last 2 standsto bottom, precautionary. Good hole conditions. 22:30 - 00:00 1.50 DRILL P PROD1 Pump hole sweep and ¢irc out. 7/28/2001 00:00 - 02:30 2.50 P LNR1 Circ. and condition hole and mud. Pump hole sweep and circ. out. Spot liner running pill. Flow check, OK. 02:30 - 10:00 7.50 DRILL P LNR1 POOH. SLM. Flow check at 12,330' and 10,311', OK. Pmp dry job at 10,311' and POOH to BHA. 10:00 - 13:00 3.00 DRILL P LNR1 LD jars, make service breaks, LD flex collars, flush Sperry tools. Pull RA sources and download MWD. LD Sperry tools. SLM-no correction. 13:00 - 14:30 1.50 CASE P COMP Rig up floe rand tools to run 4 1/2" Bonzai liner. 14:30 - 15:00 0.50 CASE P COMP PJSM to run 4 1/2" Bonzai liner. 15:00 - 21:00 6.00 CASE P COMP Run 4 1/2", 12.6#, L-80, IBT liner. Ran shoe, solid jt., pack-off bushing, 21 jts. slotted, 2 jts. solid, ECP packer, indicator sub, HMCV, indicator sub, 65 jts solid, 62 jts w/turbulator centralizer. 21:00 - 22:00 1.00 CASE P COMP Remove 4 1/2" csg. tools. Rig up floor to run 2 7/8" inner string. 22:00 - 00:00 2.00 CASE P COMP Run 2 7/8" inner string. 7/29/2001 00:00 - 06:30 6.50 CASE P COMP RIH with 2 7/8" inner string. 06:30 - 07:30 1.00 CASE P COMP Space out 2 7/8" inner string. PU liner hanger and make up. Run 1 stand of DP. String weight = 93K. 07:30 - 08:00 0.50 CASE P COMP Circ. one liner volume at 3830'. Pmp at 3 BPM and 650 psi. 08:00 - 13:30 5.50 CASE P COMP RIH with 4 1/2" Bonzai liner on 4" DP to 12,373'. PU = 200K; SO = 120K. 13:30 - 15:30 2.00 CASE P COMP Circ. bottoms up at 7" csg. shoe. Circ. at 25 spm and 950 psi. 15:30 - 18:00 2.50 CASE P COMP RIH with liner on DP to 15,980' MD. 18:00 - 21:00 3.00 CASE P COMP Circ. bottoms up at 3 BPM at 1550 psi. PJSM for hanging and cementing liner. 21:00 - 22:00 1.00 CASE P COMP Drop setting ball and circ. to seat in slick stick. Set hanger and release setting tool from hanger. 22:00 - 23:00 1.00 CASE P COMP Lay down 2 joints of drill pipe. Install long bales. Rig up to cement. 23:00 - 00:00 1.00 CASE P COMP Press. test lines to 5000 psi. Cycle Bonzai stinger and mark Printed: 812112001 3:59:54 PM BP EXPLORATION Page 8 of 11 Operations Summa Report Legal Well Name: S-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 712912001 23:00 - 00:00 1.00 CASE P COMP positions for ECP and HMCV. Inflate ECP inflatable packer with 0.5 bbl fluid indicating 7 314" OH diameter. 7/30/2001 00:00 - 02:00 2.00 CASE P COMP Open HMCV and establish circ. Shear ball seat. Drop wiper , plug and displace, circ thru HMCV. No clear indication of wiper i plug seating or releasing inner dart. Repositioned cup tool and pumped 6 bbls past calc. vol. to seat dart, no indication. Positioned cup tool in blank pipe. Cups OK. Repositioned cup tool across HMCV. Could not circulate. 02:00 - 04:30 2.50 CASE P COMP Reposition cup tool several times to re-establish circ. thru HMCV without success. Continued working tool and got indication of slight circ. Continue to pump and circ. slowly increasing. Checked cup integrity in blank pipe. Possible cup leakage. 04:30 - 09:30 5.00 CASE N DFAL COMP Review tool status and confer on plan forward. 09:30 - 10:00 0.50 CASE P COMP Set liner packoff by setting 50K down with setting tool. 10:00 - 12:00 2.00 CASE P COMP Change out bales and POH. 12:00 - 14:00 2.00 CASE P COMP Flow check. Hole swabbing while POH. Close Hydril and pump dn annulus to fill. Open annular and flow check, OK. 14:00 - 15:00 1.00 CASE P COMP POH slowly to clear cup tool from 4 1/2" liner to minimize swabbing. Getting proper fillup volumes. Flow check, OK. 15:00 - 20:00 5.00 CASE P COMP POH with 4" DP to liner running tool. 20:00 - 21:00 1.00 CASE P COMP Lay dn. liner running tool. Rig up to lay down 2 7/8" tbg. Change elevators. PJSM to lay down pipe. 21:00 - 00:00 3.00 CASE P COMP POH laying down 2 7~8" FOX tubing. 7/31/2001 00:00 - 02:30 2.50 CASE P COMP POH. LD 2 7/8" FOX tbg., Baker cup tool, and stinger. 02:30 - 03:30 1.00 EVAL N DPRB COMP Rig up Schlumberger electric line tools. 03:30 - 06:00 2.50 EVAL N DPRB COMP Run 6" gauge ring to 12,000', OK. 06:00 - 08:00 2.00 EVAL N DPRB COMP Change wireline heads. Make up head for plug setting. 08:00 - 12:00 4.00 EVAL N DPRB COMP RIH with Halliburton's Fas-Drill composite BP. Tie-in correlation and set at 11,900'. 12:00 - 13:45 1.75 EVAL N DPRB COMP Change wireline heads. Make up head for perforating. Pick up shooting lubricator. 13:45 - 16:00 2.25 EVAL N DPRB COMP RIH with Schlumberger's big hole squeeze guns loaded at 6 jspf. Tie-in and perforate from 11850'-52'. POH. 16:00 - 18:00 2.00 EVAL N DPRB COMP RIH with second gun run and tie-in. Perforate 11735'-37' at 6 jspf. POH. 18:00 - 19:00 1.00 EVAL N DPRB COMP Change wireline head to run and set retainer. 19:00 - 20:30 1.50 EVAL N DPRB COMP RIH, tie-in, and set Halliburton's EZ-SV cement retainer at 11,823'. 20:30 - 22:30 2.00 EVAL N DPRB COMP POH and rig down wireline. 22:30 - 23:30 1.00 EVAL N RREP COMP Adjust crown-o-matic. 23:30 - 00:00 0.50 EVAL N DPRB COMP Pick up drill pipe pup and EZ-SV star guide and stinger on drill 8/1/2001 00:00 - 00:30 0.50 EVAL N DPRB COMP ~ ~omp. pick up star guide and stinger on DP. 00:30 - 04:30 4.00 EVAL N DPRB COMP ~RIH to 11,802'. 04:30 - 07:00 2.50 EVAL N DPRB COMP 'Circ. & cond. mud for possible cmt. sqz. Slip & cut DL and change out bales while circ. 07:00 - 08:00 1.00 EVAL N DPRB COMP Sting into EZSV retainer. Press. to 2000 psi. Bled to 900 psi in 8 min. Estab. inj. rate of 1 BPM at 1300 psi. Pmp. 5 bbl. Could not estab, circulation with perfs at 11,735-37'. 08:00 - 09:00 1.00 EVAL N DPRB COMP Change out bales. LD TIW, pump-in sub, and cement lines. 09:00 - 13:30 4.50 EVAL N DPRB COMP POH and LD stinger. 13:30 - 15:00 1.50 CLEAN P COMP RU to press, tst BOPE. Pull wear bushing. Install test plug. Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 9 of 11 Operations Summa Report Legal Well Name: 8-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/1/2001 15:00 - 18:00 3.00 CLEAN P COMP Test BOPE, choke manifold, kelly valves, and inside BOPs to 250 psi and 4000 psi/10 min. Hydril to 250 psi and 3500 psi/10 min. Function test accumulator unit. Test witnessing by AOGCC was waived by Chuck Sheve. 18:00 - 19:00 1.00 CLEAN P COMP RD test equip. Pull test plug and install wear bushing. 19:00 - 21:00 2.00 CLEAN P COMP Make up cleanout BHA. 21:00 - 00:00 3.00 CLEAN P coMP RIH. Break circ. at 60 stds. 8/2/2001 00:00 - 03:00 3.00 CLEAN P COMP RIH to 11,823' 03:00 - 09:30 6.50 CLEAN N DPRB COMP Drill out EZSV at 11,823'. Push composite BP at 11,900' to liner top at 12,259' and drill out. 09:30 - 10:00 0.50 CLEAN P COMP Circ and prepare to displace drilling mud with 10.2 ppg brine. PJSM 10:00 - 13:30 3.50 CLEAN P COMP Displace drlg. mud w/20 bbl hi-visc spacer; 20 bbl caustic wash; 25 bbl Barakleen FL flush; 30 bbl hi-visc spacer; 25 bbl fresh water followed by 10.2 ppg brine. 13:30 - 15:30 2.00 CLEAN P COMP Clean ditches and flush lines for filtering brine. 15:30 - 17:00 1.50 CLEAN N SFAL COMP Repair union of Bariod filter unit. 17:00 - 23:30 6.50 CLEAN P COMP Circ. and clean wellbore w/filtered brine at 3 bpm. NTU after 2 hours= 117. Continued to decline. Last hour of readings averaged 65 NTU with the last reading of 50 NTU. 23:30 - 00:00 0.50 CLEAN P COMP POOH. 8/3/2001 00:00 - 03:30 3.50 CLEAN P COMP POOH :03:30 - 04:30 1.00 CLEAN P COMP LD jars, drill collars, junk baskets. 04:30 - 05:00 0.50 PERF P COMP Clear floor. Pick up HES tools, champ packer, jars. ,05:00 - 08:00 3.00 PERF P COMP PJSM. Pick up HES DPC Millennium Super DP perforating guns and firing head with packer assembly. 08:00 - 15:00 7.00 PERF P COMP RIH with DPC perforating guns. Tag TOL at 12,259'. : 15:00 - 16:00 1.00 PERF P COMP Space out and position guns for firing. Pressure test lines to 3000 psi. Set Champ packer. 16:00-18:00 2.00 PERF P COMP PJSM. Breakcirc. Pressure ann. to 500 psi for 2 min. Inc. pressure on annulus. Guns fired at 2300 psi. Continued to pressure ann. to 2700 psi for assurance. Bled press, to 300 psi. Obs. well. Open by-pass and obs. well-static. Reverse circ. 2 DP volumes. Obs. well-static. Unseated packer and circ. BU. Lost 19 bbls during perforating. Perforating interval 11,900' to 12,150'. 18:00 - 19:00 1.00 PERF P COMP Flow check-OK. Pull 5 stands. Flow check-OK. Pull 5 stands. Flow check-OK. 19:00 - 23:00 4.00 PERF P COMP POOH 23:00 - 00:00 1.00 PERF P COMP Lay down HES packer assembly. 8/4/2001 00:00 - 02:00 2.00 PERF P COMP PJSM. LD HES DPC perf guns. All shots (1155) fired. Clear floor. LD handling tools. 02:00 - 04:30 2.50 REST N DPRB COMP PU BHA components. MU cleanout BHA. 04:30 - 08:30 4.00 REST N DPRB COMP RIH and tag TOL at 12259'. 08:30 - 10:30 2.00 REST N DPRB COMP Attempt to enter liner w/cleanout BHA. Rotate and circ. Could not enter liner. 10:30-17:00 6.50 REST N DPRB COMP Flowcheck-OK. POH wet to 9359'. Flowcheck-OK. Attempt to open PBL circ sub. Would not open. POOH wet. 17:00 - 18:30 1.50 REST N DPRB COMP LD cleanout BHA. Clear floor. 18:30 - 20:30 2.00 REST N DPRB COMP Pick up components for milling BHA. PJSM. Make up milling BHA to enter liner. 20:30 - 22:00 1.50 REST N DPRB COMP RIH. 22:00 - 23:30 1.50 REST P COMP Slip and cut drilling line. Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 10 of 11 Operations Summa Report Legal Well Name: 8-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours ,Activity Code NPT Phase Description of Operations 8/4/2001 23:30- 00:00 0.50 REST N DPRB COMP RIH at 4864'. 8/5/2001 !00:00 - 03:00 3.00 REST N DPRB COMP RIH w/liner hanger cleanout BHA to 12,245'. Broke circ. at 9310'. 03:00 - 03:30 0.50 REST N DPRB COMP Circ. and clean mill water courses. Slightly plugged. 03:30- 09:00 5.50 CLEAN N DPRB COMP Mill from 12,259' (TOL) to 12,284'. Recovered considerable amount of packer rubber, EZSV material, and composite BP material. 09:00 - 10:30 1.50 REST N DPRB COMP Rotate and reciprocate while circulating hi-visc sweep. 10:30- 16:00 5.50 CLEAN P COMP POH. Lay down drill pipe. 16:00 - 17:00 1.00 CLEAN P COMP RIH with 43 stands DP racked in derrick. 17:00- 00:00 7.00 CLEAN P COMP POH. Lay down drill pipe. 8/6/2001 00:00 - 00:30 0.50 CLEAN P COMP Lay down drill pipe. 00:30- 02:00 1.50: CLEAN N DPRB COMP LD cleanout BHA. 02:00 - 03:00 1.00 RUNCO~' COMP Rig up to run 4 1/2" completion string. Pull wear bushing. 03:00 - 12:00 9.00 RUNCO~ COMP PJSM. Run 4 1/2" tubing. Pick up and run profile nipples, Baker Premier packers, GLM, sliding sleeve. 151 its in at tour change. 12:00 - 17:30 5.50 RUNCO~ COMP PJSM. Run 4 1/2" completion string to SSSV mandrel. 17:30 - 19:30 2.00 RUNCO~ COMP Pick up SSSV mandrel and pups. Hook up and test ss dual control lines to 5000 psi for 10 min. OK. 19:30 - 23:00 3.50 RUNCO~/P COMP Run remaining 4 1/2" completion string (302 its). Banding control lines with ss straps every joint. 23:00 - 00:00 1.00 RUNCO~ COMP Change out bales. Make up pump- in sub on landing it. 8/7/2001 00:00 - 02:00 2.00 RUNCO~ COMP Establish circulation at 12,247'. Attempt to stab WLEG into liner top. PU while circulating and pressure bled off. Make second attemt to stab into liner top. Tag up approximately 10' high. 02:00 - 12:00 10.00 RUNCO~ DPRB COMP RD circulating equipment and spaceout joint. RU tubing for wireline. RU slickline to retrieve dummy SSSV sleeve. Retrieve sleeve. RIH to retrieve RHC plug. 12:00 - 14:00 2.00 RUNCO~I DPRB COMP POOH with slickline. RD slickline. Retrieve RHC plug. 14:00- 15:30 1.50 RUNCO~I DPRB COMP MIRU Eline. PJM 15:30 - 19:00 3.50 RUNCO~I DPRB COMP RIH w/eline GPJCCL to tie in to liner top, tubing jewelry, and RA tag. Unable to get eline out of tubing tail. 19:00- 19:30 0.50 RUNCO~I DPRB COMP RD eline. 19:30-21:30 2.00 RUNCO~ DPRB COMP MIRU slickline. PJSM. 21:30 - 00:00 2.50 RUNCO~I DPRB COMP RIH w/slickline to set RHC plug. 8/8/2001 00:00 - 03:00 3.00 RUNCO~ DPRB COMP Continue w/slickline operations. Set RHC plug and set dummy SSSV sleeve. RD slickline. 03:00 - 04:00 1.00 RUNCO~ COMP RU to circulate conventionally to check that tubing is clear. Flush control lines while rigging up. Establish circulation, 280 psi at 3 bpm. RD circulating equipment. 04:00 - 07:30 3.50 RUNCO~ COMP Space out tubing into top of liner. Land hanger to ensure access back into liner top. Pull 10' above landing ring. 07:30 - 09:00 1.50 RUNCO~ COMP Reverse circulate inhibited brine. 09:00 - 10:30 1.50 RUNCO~ COMP Land tubing hanger. RILDS. Drop ball/Rod. 10:30 - 12:00 1.50 RUNCO~ P COMP Set packer and test tubing to 4,100 psi for 30 minutes. Bleed tubing to 1500 psi. Pressure test annulus to 3500 psi for 30 minutes. Bleed off tubing to shear the RP valve. Note: 67 SS control line bands run on tubing. 12:00 - 14:00 2.00 RUNCO~ COMP LD landing joint. Set TVVC and test from below to 1500 psi. 14:00 - 17:00 3.00 RUNCOr~ COMP ND BOPE. Change out saver sub on top drive. PJSM. Printed: 8/21/2001 3:59:54 PM BP EXPLORATION Page 11 of 11 Operations Summa Report Legal Well Name: 8-107 Common Well Name: S-107 Spud Date: 6/29/2001 Event Name: DRILL+COMPLETE Start: 6/28/2001 End: Contractor Name: DOYON Rig Release: 8/9/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours ActivityCode NPT Phase Description of Operations 8/8/2001 17:00 - 19:30 2.50 RUNCO~ COMP NU tubing head adapter flange and tree. Install control lines. 19:30 - 21:00 1.50 RUNCO~ P COMP Test control lines to 5000 psi. Test tubing hanger to 5000 psi. Test tree to 5000 psi. RU hot oil to freeze protect. 21:00 - 22:30 1.50 RUNCO~ COMP RU DSM to pull TWC. Pull 'I'WC. 22:30 - 23:00 0.50 RUNCO~ COMP RU pump in sub to reverse circulate. Test lines for circulation. 23:00 - 00:00 1.00 RUNCO~ COMP Reverse circulate 75 bbls diesel freeze protection at 1 bpm 1500 psi. / 8/9/2001 00:00 - 00:30 0,50 RUNCO~ COMP Continue to reverse circulate 75 bbl of diesel freeze protection. 00:30 - 04:00 3.50 RUNCO~ COMP U-tube freeze protection. 04:00 - 05:30 1.50 RIGD P POST PJM. Set BPV and secure tree. 05:30 - 07:00 1.50 RIGD P POST Skid floor and prepare rig for move. Release rig at 0:700 on 8/9/01. Printed: 8/21/2001 3:59:54 PM Well: S-107 Rig Accept: 06/28/01 Field: Prudhoe Bay / Aurora Pool Rig Spud: 06/29/01 APl: 50-029-23023-00 Rig Release: 08/09/01 Permit: 201-113 Drilling Rig: Doyon 14 POST - RIG WORK 09/05/01 Pull 4-1/2" DSSSV, ball and rod. Run SBHP gauges, 1st stop 11994', 2® at 11780', 3rd at 11994'. All 30 minute stops. Set 4-1/2" Whiddon C-Sub. 09/06/01 Pulled 09/07/01 Pulled bailer. dummy gas lift valves and set gas lift valves. Pulled 4-1/2" Whiddon C-Sub. RHC plug body. Tag fill with 3" bailer at 12241' sim. Retrieved sample of large metal chunks in 09/09/01 Bailed out metal debris from 12229' sim, broke through and went down to 12400'. Got hung up and lost jar action. Flowing well to try and free tools. 09/10/01 Stuck in hole at 12400' sim. Put well on production. Well finally unloading off bottom. Attempting to rock well to free stuck tools. 09/11/01 Dropped second Kinley cutter. Cut wire, retrieved cutter bar and left approximately 4300' of .125 wire in the hole. First Kinley cutter with running assembly (9' total length), and 32' tool string, left in hole. 09/12/01 Ran 3.5" Lib to wire top. 09/13/01 Ran 4-1/2" G-Bait sub on 4-1/2" wire finder with 4 prong wire grab, 68" total length to 8224' sim. Sheared off. Attempt to get back to fishing assembly. Appears to have wire on top. 4-1/2" bait sub, 4- 1/2" wire finder and 4-1/2" wire grab left in hole at 8226' sim. 09/24/01 Run in hole with wire finder / Lib. 09/25/01 Tagged wire at 8228' sim, pushed down to 8246' sim. Hung up and pulled to 8202' sim. Tagged top of wire and lost bait sub at 8202' sim. And pushed to 8215' sim (solid now). Lib shows bait sub with curled wire above and to the side. Ran baited wire grab to 8195', hooked into wire. Sheared GR two times. Latched bait with GS, beat up 2-1/2 hours. 09/26/01 Latch 4-1/2" bait sub and grab at 8192' sim. Jarred up two hours. Pull out of hole with 115' wire. Ran 3.7 Lib to 8225' pushed down to 8230', inconclusive. Ran 3.25" Lib to 8230' sim, pushed to 8251' sim. S-107, Post Rig D&C Work Page 2 Pulled out of hole with picture of wire. Ran bait sub and grab assembly to 8251'. Grabbed wire and strung up to 8219' sim. Sheared GR and left grab assembly at 8221' sim. 09/27/01 Latched bait sub and grab at 8221' sim. Jarred up 1-1/2 hours. Pulled bait sub out of hole with 16' of wire on grab. Ran 3.5" Lib to 8260'. Shows impression of more wire at 8260'. Ran wire grab, get 17' wire. Ran grab again and got 8' of wire. Ran 3.5" Lib to get picture. Push wire and or bait sub down hole. 09/28/01 Ran 3.5" Lib to 8281' sim. Pushed down to 8293' sim. Pulled out of hole with picture of balled wire. Ran grab on GR to 8293' sim. Jarred down to 8300' sim, pulled up hole stringing wire at 1600# to 8265' sim, sheared GR. Ran GS to 8265', jarred one hour. Shear off bait sub. Make two runs with GS pinned with aluminum. Sheared easy. Make run with GS pinned with brass. Beat 1-1/2 hours. Tried to shear off for one hour. Got movement down to 8276'. Work wire up and down. Broke free. Pulled out of hole with 26' of wire. Total wire out is 186'. Original tool string, wire, wire grab, and bait sub assembly is still in hole. 01-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE SURVEY Re: Distribution of Survey Data for Well S-107 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 'MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 0 7 2001 AlalIa Oil & Gas Cons. Commi~ion Anchorage DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-107 S-~07 Gyro Job No. AKMM11107, Surveyed: 27 July, 2001 SURVEY REPORT 1 August, 2001 Your Ref: AP1-500292299900 Surface Coordinates: 5980759.77 N, 618930.16 E ('/0= 21' 21.9134" N, Kelly BuShing: 69.94ft above Mean Sea Level 149° 02' 02.8561" W) DRI L L I.,Nt~ glRVlCi~Jl A Halliburton Company' S~rvey Ref: svy10869 Sperry. Sun Drilling Services Survey Report for S.107 Gyro Your Reft API-500292299900 Job No. AKMMlff07, Surveyed: 27 July, 2001 North Slope Alaska Measure Sub-Sea Vertical Lo¢=al Coordinate; d Depth Incl, Azim. Depth Depth Northings Eastings Northings (ft) (ft) (ft) (ft) (ft) Global Coordinates 0.00 0.000 0.000 -69.94 0.00 0.00 N 0.00 E 5980759.77 N 71.00 0.250 72.000 1.06 71.00 0.05 N 0.15 E 5980759.82 N 160.00 0.250 267.000 90.06 160.00 0.10 N 0.14 E 5980759.87 N 252.00 0.700 297.000 182.06 252.00 0.34 N 0.56 W 5980760.10 N 340.00 1.150 285,000 270.04 339.98 0.81 N 1.90 W 5980760.55 N 428.00 2.500 292,000 358.00 427.94 1.76 N 4.53 W 5980761.46 N 523.00 4,650 295,500 452.81 522.75 4.20 N 9,92 W 5980763.81 N Eastings (ft) 618930.16 E 618930.31 E 618930.30 E 618929.59 E 618928.25 E 618,925.60 E 618920.17 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.475° (26-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 311.140° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 523.00ft., The Bottom Hole Displacement is 10.78ff., in the Direction of 292.921 ° (True). Alaska Drilling & Wells PBU WOA S Pad Dogleg Vertical Rate Section Comment (°/100ft) 0.352 0.557 0.543 0.554 1.552 2.274 0.00 -0.08 -0.04 0.65 1.96 Tolerable Gyro 4.57 10.24 1 Aug,/st, 2001.21:24 Page 2 of 3 DdllQ~/est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S.107 Gyro Your Reft API-500292299900 Job No, AKMMl ff07, Surveyed: 27 July, 2001 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad Survey tool program for S-107 Gyro From To Measure Vertical Measure d d Depth Depth Depth (~) (ft) (~) 0.00 0.00 523.00 Vertical Depth (fi) 522.75 Survey Tool Description Tolerable Gyro 1 August, 2001 - 21:24 Page 3 of 3 DdllQ~esl 2.00.08.005 01-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE SURVEY Re: Distribution of Survey Data for Well S-107 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 16,026.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUGO 7 2001 Ala~a 0il & Gas Cons. Comm~ion An~era~e DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-~07 S-~07 Job No. AKZZf1107, Surveyed: 27 July, 2001 S UR VEY REPORT August, 2001 Your Ref: API-500292299900 Surface Coordinates: 5980759.77 N, 618930. f6 E ('/0~ 21' 21.9134" N, Kelly Bushing: 69.94ft above Mean Sea Level 149°02'02.856~"H0 A Halliburton Company Survey Ref: svy10915 Sperry-Sun Drilling Services Survey Report for S-107 Your Reft API-500292299900 Job No. AKZZ11107, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth fit) Incl. Azim. S-107 Gyro 0.00 71.00 160.00 25200 340.00 428.00 523.00 S.107 0.000 0.250 0.250 0,700 1.150 2,500 4,650 0,000 72,000 267,000 297.000 285,000 Sub-Sea Depth (ft) -69.94 1.06 90.06 182.06 270.04 358.00 452.81 Vertical Depth (ft) 0.00 71.00 160.00 252.00 339.98 427.94 522.75 645.83 8.210 306.660 574.85 644.79 734.97 12010 317,760 662.60 732,54 831.22 13,180 318,990 756.53 826.47 927.64 15,130 317.700 850.02 919.96 1018.19 15,210 318,510 937.41 1007.35 1118.88 15,970 316,090 1034.40 1104.34 1213.35 17.930 316,000 1124.76 1194.70 1308.91 19,970 319,310 1215.14 1285.08 1404.81 21.210 320.490 1304.91 1374.85 1499.42 24.020 317,360 1392.24 1462.18 1595.44 23,670 317,050 1480.07 1550.01 lC::~9.88 25,350 315.320 1565.99 1635.93 1789.53 30.610 314.080 1653.97 1723.91 1886.54 36.460 312.130 1734.80 1804.74 1981.19 41.850 313.340 1808.16 1878.10 Local Coordinatel Global Coordinates Northings Ealting~ Northinga Eastings (ft) fit) fit) fit) 0.00 N 0.00 E 5980759.77 N 618930.16 E 0.05 N 0.15 E 5980759.82 N 618930.31 E 0.10 N 0.14 E 5980759.87 N 618930.30 E 0.34 N 0.56W 5980760.10 N 618929.59 E 0.81 N 1.90 W 5980760.55 N 618928.25 E 1.76 N 4.53 W 5980761.46 N 618925.60 E 4.20 N 9.92 W 5980763.81 N 618920.17 E Alaska Drilling & Wells PBU_WOA S Pad Dogleg Vertical Rate Section Comment (°/lOOft) 0,352 0,557 0,543 0,554 1.552 2,274 11.58 N 21.46W 5980771.01 N 618908.52 E 3058 22.25 N 32.80 W 5980781.50 N 6t8897.01 E 4.772 37.94 N 46.74 W 5980796.97 N 618882.83 E 1.247 55.55 N 62.42 W 5980814.32 N 618866.87 E 2049 73.19 N 78.24 W 5980831.70 N 618850.77 E 0.250 93.05 N 96.60 W 5980851.28 N 618832.10 E 112.88 N 115.72 W 5980870.80 N 618812.67 E 135.84 N 136.58 W 5980893.43 N 618791.45 E 161.64 N 155.29 W 5980918.88 N 618769.32 E 189.02 N 182.23 W 5980945.87 N 618744.95 E 0.993 2,075 2.412 1.363 3,230 0,387 1.934 5,310 6.131 5,751 217.50 N 208.60 W 5980973.94 N 618718.13 E 245.76 N 235.73 W 5981001.75 N 618690.55 E 278.60 N 268.98 W 5981034.08 N 618656.79 E 315.15 N 308.14 W 5981069.99 N 618617.06 E 355.72 N 351,99 W 5981109.85 N 618572.57 E 0.00 -0,08 -0,04 0,65 1 96 4.57 10.24 Tolerable Gyro 23.78 39.34 60.16 83.55 107,07 133.97 161,41 192.23 225.56 261.59 300.19 339.22 385.86 439.40 499.11 AK-6 BP IFR-AK I Augusg, 2001 - 21:22 Page 2 of' 10 DrlllO~est 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S.107 Your Reft API-500292299900 Job No. AKZZffl07, Surveyed: 27 July, 2001 North Slope Alaska Meas u re d Depth (ft) .Incl, Azim. 2076.80 45.630 313.700 2172.92 50.080 312.820 2268.60 57.840 313.540 2364.80 60.950 313.480 2460.62 62.720 315.420 Sub-Sea Depth 1877.23 1941.71 1997.96 2046.93 2092.16 Vertical Local Coordinatea Global Coordinates Depth Northinga Eastlng8 Northing8 Eastings (ft) (ft) (ft) (f~) (ft) 1947,17 2011.65 2067,90 2116.87 2162,10 2556.08 65.250 314.680 2134.03 2203.97 2652.07 64.260 313.590 2174.97 2244.91 2747.46 64.650 312.340 2216.10 2286.04 2843.37 66_440 311.960 2255.81 2325.75 2939.21 65.840 313.560 2294.58 2364.52 3036.07 65170 315.180 2334.74 2404.68 3131,54 65.310 311.760 2374.73 2444.67 3227.28 65.080 312.170 2414.90 2484.84 3322.74 65.380 311.830 2454.89 2524.83 3419.63 66.810 309.650 2494.16 2564.10 3515.53 69.150 306.700 2530.12 2600.05 3610.81 68.520 306.990 2564.52 2634.46 3703.83 66.990 308,350 2599.73 2669.67 3800.35 65.890 308.200 2638.31 2708.25 3896.79 65.320 309.790 2678.15 2748.09 401,23 N 399,91 W 5981154,60 N 450,05 N 451,81 W 5981202,59 N 502,96 N 508,17 W 5981254,60 N 559,96 N 568,21 W 5981310,64 N 619,12 N 628,50 W 5981368,83 N 679,82 N 689,11 W 5981428,57 N 740,28 N 751,41 W 5981488,03 N 798,94 N 814,39 W 5981545,68 N 857,52 N 879,12 W 5981603,23 N 917,03 N 943,47 W 5981661,70 N - 978,66 N 1006,48 W 5981722,33 N 1038,29 N 1069,38 W 5981750,95 N 1096,40 N 1134,00 W 5981838,03 N 1154,40 N 1198,42 W 5981898,00 N 1212,19 N 1265,53 W 5981951,72 N 1267,12 N 1335,42 W 5982005,52 N 1320,40 N 1406,52 W 5982057,67 N 1373,00 N 1474,67 W 5982109,19 N t427,81 N 1544,13 W 5982162,88 N 1483,07 N 1612,39 W 5982217,05 N 1540,61 N 1680,05 W 5982273,51 N 1597,26 N 1745,30 W 5982329,12 N 1654,53 N 1810,77 W 5982385,34 N 1685,01 N 1845,11 W 5982415,27 N 1737.68 N 1904,71 W 5982466.99 N 3994.78 64.710 310.970 2719.54 2789.48 4090.31 64.820 310,960 2760.27 2830.21 4186.05 65.790 311.390 2800.26 2870.20 4236.46 65.490 311.790 2821.05 2891.00 4324.23 64. 480 311.1 50 2858.17 2928.11 618523,93 E 618471,26 E 618414,07 E 618353.13 E 618291.91 E 618230,35 E 618167,09 E 618103,18 E 618037,54 E 617972,25 E 617908.27 E 617844,43 E 617778.89 E 617713,57 E 617645,54 E 617574,79 E 617502,85 E 617433,88 E 617363.56 E 617294,43 E 617225.87 E 617159.73 E 617093.35 E 617058.53 E 616998.10 E Dogleg Rate (°/'lOOft) 3.962 4.679 8.133 3.233 2.569 2.740 1.456 1.251 1.901 1.650 1.672 3.256 0.457 0.451 2.532 3,753 0.720 2.130 1.149 1.61 4 1.257 0.116 1.092 0.936 1.327 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 565.15 636.35 713.61 796.32 880.65 966.23 1052.93 1138.95 1226.24 1313.85 1401.85 1488,45 1575.35 1662.02 1750.58 1839.35 1927.95 2013.88 2102.25 2190.01 2278,82 2365.23 2452,22 2498.14 2577.67 1 August, 2001 - 21:22 Page 3 of 10 DdllOues~ ?.00.08.005 Sperry. Sun Drilling Services Survey Report for S. 107 Your Ref: API-500292299900 Job No. AKZZI1f07, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinate8 Global Coordinates Depth Northings Eastings Northings Eastings Ct) Ct) Ct) Ct) 4423.12 63,590 310.080 2901.47 2971,41 4517.88 65.340 :308,630 2942.32 3012,26 4613.95 64.920 308,600 2982.72 3052,66 4709.54 66.350 308,730 3022.15 3092.09 4804.49 65.730 308,590 3060.71 3130.65 4900.51 64.760 308.410 3100.92 3170.86 4996.62 65.970 309.870 3140.98 3210.92 5092.39 65.110 309.760 3180.64 3250.58 5187.97 66.610 308.430 3219,73 3289.67 5285.64 67.280 309,700 3257.98 3327.92 5380.20 66.240 309.830 3295,29 3,365.23 5477.19 65,480 309,130 3334.95 3404.89 5572.14 64.900 308.910 3374.79 3444.73 5667.75 66,030 310.170 3414.50 3484.44 5764.63 66.010 310,580 3453.87 3523.81 5860.34 64.970 310,920 3493.58 3563.52 5955.54 63.610 310.540 3534.87 3604.8t 6051.78 61.920 310,670 3578.92 3648.86 6146.58 59. 260 310.210 3625.46 3695.40 6241.91 57.850 310.850 3675.20 3745.14 1795,56 N 1972.19 W 5982523.79 N 1849.77 N 2038.31 W 5982576.95 N 1904.16 N 2106,41 W 5982630.25 N 1958.57 N 2174.40 W 5982683.57 N 2012.77 N 2242.15 W 5982736.69 N 2067.05 N 2310.39 W 5982789.88 N 2122.20 N 2378.15 W 5982843.94 N 2178.02 N 2445.11 W 5982698.69 N 2233.01 N 2512,80 W 5982952,60 N 2289.65 N 2582,57 W 5983008.13 N 2345.22 N 2649.36 W 5983062.63 N 2401.50 N 2717.67 W 5983117,82 N 2455.76 N 2784.63 W 5983171.01 N 2511.13 N 2851.70 W 5983225.31 N 2568.47 N 29t9.14 W 5983281.57 N 2625.31 N 2985.11 W 5983337.36 N 2681,28 N 3050. t0 W 5983392,29 N 2736.97 N 3115.07 W 5983446,94 N 2790.54 N 3177.91 W 5983499,50 N 2843.39 N 3239.73 W 5983551.36 N 2897.40 N 3301.19 W 5983804.39'N 2950.27 N 3360.28 W 5983655.32 N 3004.39 N 3420.90 W 5983709.47 N 3058.41 N 3481.65 W 5983762.52 N 3112.69 N 3542.56 W 5983815.82 N 6338.66 57.650 311.770 3726.82 3796.76 6432.79 57.1 20 311.870 3777.56 3847.50 6529.80 56.680 311.640 3830.54 3900.48 6626.12 58.460 311,660 3882.19 3952.13 6721.85 58.450 311.740 3932.27 4002.21 616929.71 E 616862.74 E 616793.78 E 616724.94 E 616656.33 E 616587.24 E 616518.62 E 616450.78 E 616382.23 E 616311.56 E 616243.90 E 616174.71 E 616106.89 E 616038.95 E 615970.62 E 615903.75 E 615837.87 E 615772.03 E 615708.34 E 615645.70 E 615583.39 E 615523.47 E 615461.99 E 615400.39 E 615338.63 E Dogleg Rate (°/lOOft) 1.325 2,306 0,438 1.501 0,667 1.024 1 869 0.904 2019 1.379 1.107 1.024 0.646 1.683 0,387 1,134 1.473 1.760 2.838 1.586 0,830 0,570 0.495 1.848 0.072 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 2666.57 2752.03 2839.10 2926.10 3012.78 3099.89 3187.19 3274.34 3361 50 3451.31 3538.17 3626.64 3712.76 3799.70 3888.21 3975.30 4061.07 4146.63 4229.20 4310.52 4392.34 4471.63 4552.89 4634.18 4715.76 1 August, 2001.21:22 Page 4 of 10 DdllQ~lest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-107 Your Reft API-500292299900 Job No. AKZZffI07, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (fi) Incl. Azim. Sub-Sea Vertical Local Coordlnatea Global Coordinates Depth Depth Northings Eastings Northings Eastings (f~) (f~) (ft) (ft) (ft) (ft) 6817.33 57.790 312.220 3982.70 4052.64 6913.42 56.840 312.060 4034.59 4104.53 7008.39 57.960 310.450 4085.76 4155.70 7104.57 57.820 310.820 4136.88 4206.82 7199.80 57.320 310.630 4187.95 4257.89 7295.42 56.430 310.920 4240.20 4310.14 7391.60 56.870 311.230 4293.08 4363.02 7486.88 56.890 311,770 4343.73 4413.67 7582.76 58.680 312.120 4393.42 4463.36 7677.90 56.070 311.760 4443.31 4513.25 7775.49 59.530 312.520 4493.86 4563.80 7870.63 59.080 312.250 4542.43 4612.37 7966.28 60.170 311.560 4590.80 4660.74 8062.08 60.240 311.1 70 4638.40 4708.34 8156.58 59.770 311.000 4685.64 4755.58 8260,03 59.940 310.600 4737.59 4807.53 8355.21 60.630 310,740 4784,77 4854.71 8449.71 61.040 310.860 4830.83 4900.77 8548.19 61.050 310.740 4878.50 4948.44 8643.25 60.490 309.860 4924.92 4994.86 3166.92 N 3602.83 W 5983869.09 N 3221.18 N 3662,80 W 5983922.39 N 3273.93 N 3722.95 W 5983974,18 N 3326,98 N 3784.77 W 5984026.24 N 3379.42 N 3845.69 W 5984077.71 N 3431.72 N 3906.33 W 5984129.04 N 3484.51 N 3966.90 W 5984180.86 N 3537.98 N 4027.33 W 5984233.37 N 3592.79 N 4088.32 W 5984287.20 N 3646.93 N 4148.58 W 5984340.38 N 3702.94 N 4210.47 W 5984395,40 N 3758.09 N 4270.90 W 5984449.58 N 3813.20 N 4332,31 W 5984503,71 N 3868.14 N 4394.71 W 5984557,65 N 3921.93 N 4456.40 W 5984610.45 N 3980.38 N 4524. t2 W 5984667.83 N 4034.25 N 4586.81 W 5984720.70 N 4088.17 N 4649.28 W 5984773.62 N 4144.48 N 4714.51 W 5984828.88 N 4198.14 N 4777.78 W 5984881.52 N 4251.58 N 4841.09 W 5984933.96 N 4305.06 N 4903.64 W 5984986.44 N 4358.16 N 4965.27 W 5985038,55 N 4411.25 N 5027.01 W 5985090.65 N 4463.65 N 5087.59 W 5985142.09 N 8738.85 59.670 310.480 4972.61 5042.55 8834.77 58.520 310.580 5021.87 5091.81 8930.56 57.730 310.920 5072.45 5142.39 9027.07 57.340 310.470 5124.26 5194.20 9122.43 56.930 311.240 5176.01 5245.95 615277.50 E 615216.68 E 615155.70 E 615093.04 E 615031.30 E 614969.84 E 614908.44 E 614847.17 E 614785.32 E 614724.21 E 614661.43 E 614600.14 E 614537.85 E 614474.60 E 614412.06 E 614343.42 E 614279.88 E 614216.56 E 614150.45 E 614086.34 E 614022.18 E 613958.79 E 613896.33 E 613833.75 E 613772.35 E Dogleg Rate (°/lOOft) 0.812 0.999 1.852 0.357 0.551 0.965 0.531 2.174 0.381 0.718 1.638 0.532 1.298 0,361 0.521 0.373 0.736 0.448 0.107 1.000 1.026 1.202 0.878 0.564 0.803 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 4796.83 4877.69 4957.69 5039.15 5119.53 5199.61 5279.95 5360.64 5442.63 5523.63 5607.09 5688.88 5771,40 5854.53 5936.37 6025.83 6108.49 6191.01 6277.18 6360.12 6442.97 6525.26 6606.61 668803 6768.13 1 August, 2001 - 21:22 Page 5 of 10 DdllQ,est 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S-107 Your Ref: API-500292299900 Job No. AKZZfff07, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordlnatea Global Coordinates Depth Northings Ea.tinga Northing. Eastings fit) (ft) (ft) (ft) fit) 9218.50 56.570 310.440 5228.68 5298.62 9313.48 56.320 310.970 5281.18 5351.12 9410.43 56.460 310.630 5334.85 5404.79 9505.77 56.080 311.460 5387.79 5457.73 9601.99 56.470 310.160 5441.21 5511.15 9696.95 57.790 309.390 5492.75 5562.69 9792.15 57.530 309.750 5543.68 5613.62 9888.86 57.190 309.580 5595.84 5665.78 9983.32 57.370 311.300 5646.90 5716.84 10078.83 57.980 311.740 5697.97 5767.91 10174.42 57.380 312.300 5749.08 5819.02 10270.10 57.070 312.450 5800,87 5870.81 10367.19 57.700 311.230 5853,20 5923.14 10462175 59.560 311.030 5902.95 5972.89 10558.04 59.470 311.060 5951.29 6021.23 10554,23 58.910 311.770 6000.56 6070.50 10749.50 58.510 311.790 6050.04 6119.98 10845.48 58.050 311.560 6100.50 6170.44 10941.56 57.550 311.400 6151.70 6221.64 11036,79 57.770 311.940 6202.64 6272.58 4516.19 N 5148.37 W 5985193.65 N 4567.81 N 5208.37 W 5985244.31 N 4820.57 N 5269.49 W 5985296.09 N 4572.63 N 5329.29 W 5985347.20 N 4724.93 N 5389.87 W 5985398.53 N 4775.95 N 5451.16 W 5985448.58 N 4827.19 N 5513.17 W 5985498.62 N 4879.17 N 5575.86 W 5985549.80 N 4930.72 N 5636.34 W 5985600.38 N 4984.22 N 5698.76 W 5985652,92 N 5338.29 N 5756.78 W 5985706.03 N 5092.51 N 5816.2t W 5985759.30 N 5147.06 N 5877.13 W 5985812.87 N 5200.72 N 5938.59 W 5985865.56 N 5254.64 N 6000.52 W 5985918.49 N 5309.29 N 6062.48 W 5985972.15 N 5363.54 N 6123.19 W 5986025.42 N 5417.82 N 6164.17 W 5986078.73 N 5471.67 N 9245.08 W 5986131.61 N 5525.16 N 6305.18 W 5986154.14 N 5579.38 N 6365.58 W 5986237.39 N 5633.15 N 6426.92 W 5986290.19 N 5686.67 N 6485.89 W 5986342.75 N 5740.82 N 6545.01 W 5986395.96 N 5795.76 N 6604.30 W 5986449.95 N 11132.77 57.710 311.890 6253.87 6323.81 11228.69 57.280 311.420 6305.42 6375.36 11324.05 57.460 312.160 6356.84 6426.78 11419.18 57.400 312.820 640805 6477.99 11515.27 57.140 312.810 6460.00 6529.94 613710.74 E 613649.92 E 613587.97 E 613527.35 E 613465.96 E 613403.86 E 613341.05 E 613277.55 E 613216.25 E 613154.99 E 613094.12 E 613033.84 E 612972.05 E 612909.75 E 612846,97 E 612784.16 E 612722.59 E 612660.76 E 612599.03 E 612538.06 E 612476.81 E 612415.52 E 612354.80 E 612294.83 E 612234.67 E Dogleg Rate (°/100ft) 0.791 0,534 0.326 0.826 1,195 1.548 0,420 0.381 1.544 0,748 0,799 0.350 1.241 1.955 0,098 0.861 0,420 0.521 0,539 0.532 0.076 0.610 0.680 0.588 0.271 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 6848.47 6927.61 7008.36 7087.64 7167,67 7247.40 7327.80 7409.21 7488.67 7569.38 7650.15 7730.58 7812.35 7893.94 797605 8058.67 8140.08 8221.71 8303.02 8383.47 8464.63 8545.52 8625.82 8705.97 8786.77 1 Augus(, 2001 - 21:22 Page 6 of 10 DHIIO,esg 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S-107 Your Ref: API-500292299900 Job No. AKZZffl07, Surveyed: 27 July, 200~ North Slope Alaska Measure d Depth Incl. Azim. Sub-Sea Vertical Local Coordinatea Global Coordinates Dogleg Depth Depth Northings Eastings Northings Eastings Rate (fi:) (fi:) (fi:) ('fi) (fi:) (ft) (°/'~OOft) 11611.33 56.560 312.850 6512.53 6582.47 11706.88 58.940 313.360 6563,52 6633.46 11801 99 59.720 312.010 6612.03 6681.97 11898,12 62.190 311.740 6658.70 6728.64 11994.34 66.520 311.970 6700,33 6770.27 1 2090.11 67.780 312.030 6737.52 6807.46 12186.22 67.860 312.200 6773.80 6843,74 12281.38 67.360 311.760 6810.05 6879.99 12344.46 67.130 311.500 6834.45 6904.39 12449,72 67,860 308.640 6874.75 6944.69 12482.50 72.170 309.870 6885.95 6955.89 12515.62 76.810 309.840 6894.80 6964,74 1 2546.57 77.520 313.430 6'901.68 6971.62 12579.58 80.530 312.870 6907.95 6977.90 12611.55 82.900 313.110 6912.57 6982.51 5850.43 N 6663.29 W 5986503.68 N 5905.65 N 6722.28 W 5986557.95 N 5961.11 N 6782.41 W 5986612.45 N 6017.20 N 6844,99 W - 5986567,54 N 6075.06 N 6909.58 W 5986724.37 N 6134,12 N 6975.16 W 5986782,38 N 6193.80 N 7041.18 W 5986841.00 N 6252.65 N 7106.59 W 5986898.81 N 6291.30 N 7150.06 W 5986938.76 N 6353.88 N 7224.48 W 5986998.15 N 6373.37 N 7248.32 W 5987017.26 N 6393.82 N 7272.81 W 5987037.32 N 6413.87 N 7295.36 W 5987057.01 N 6436.02 N 7319.00 W 5987078.79 N 6457.60 N 7342.14 W 5987099.99 N 6479.10 N 7365.90 W 5987121,12 N 6503.75 N 7394.14 W 5987145.31 N 6520.93 N 7413.94 W 5987162.17 N 6540.94 N 7437.26 W 5987181,81 N 6603.48 N 7510,35 W 5987243,19 N 6664.39 N 7580.78 W 5987302.97 N 6727.73 N 7653.55 W 5987365.15 N 6790.92 N 7725.97 W 5987427.17 N 6854.02 N 7797.23 W 5987489.13 N 6918.58 N 7868.88 W 5987552.55 N 12643.77 65.380 311.210 6915.86 6985.80 12681.31 88.210 311.010 6917.96 6987.90 12707.54 88.030 310.880 6918.82 6988.76 12738.29 87.970 310.380 6919.89 6989.83 t 2834.55 87.840 310.730 6923.41 6993.35 612174.83 E 612114.97 E 612053.96 E 611990.51 E 611925.01 E 611858.49 E 611791.53 E 611725.20 E 611681.12 E 611605,72 E 611561.57 E 611556.75 E 611533.89 E 611509.90 E 611466.42 E 611462.33 E 611433.70 E 611413,63 E 611389.99 E 611315.92 E 611244.53 E 611170.76 E 611097.35 E 611025.10 E 610952.43 E 12927.70 89.260 310.980 6925.77 6995.71 13024.19 88.890 311.0cJO 6927.33 6997.27 13120.31 89.080 311.1 20 6929.03 6998.97 13215.50 89.260 311.930 6930.41 7000.35 13311.97 88.650 312.110 6932.17 7002.11 0.605 2.531 1.471 2,581 4.505 1.317 0.184 0,677 0,527 2.604 13.613 14.010 11,540 9.269 7.45O 9.677 7.557 0.846 1.637 0.388 1.548 0.400 0.200 0.872 0.659 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 8867.16 8947.91 9029.68 9113.71 9200.43 9288.67 9377.65 946563 9523.8O 9621.01 9651.79 9683.69 9713.86 9746,24 9777.86 9809.90 9847.38 9873.60 9904.33 100(X).52 10093.63 10190.11 10286.21 10381.39 10477.83 1 August, 2001.21:22 Page 7 o¢ 10 D~fllQuest 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S.107 Your Ref: API-500292299900 Job No. AKZZfl107, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (n) Incl. Azim. Sub-Sea Depth (n) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings fit) fit) (n) fit) fit) 13408.74 88.830 312,440 6934.29 7004.23 13505.22 89.080 311.200 6936.05 7005.99 13601.06 90.430 309,570 6936.46 7006.40 13696.55 87.480 309.200 6938.20 7008,14 13791 34 88.220 309.000 6941,76 7011.70 13889.24 89.510 310.330 6943.70 7013.64 13984.68 87.290 310.120 6946.36 7016.30 14080.49 86.620 310.610 6951.45 7021.39 14177.66 86.550 311.730 6957.24 7027.18 14272.46 87.350 311.220 6962,29 7032.23 14369.19 87,600 311.820 6966.55 7036,49 14465.20 86.550 310.680 6971.45 7041.39 14560.19 88.280 310.620 6975.73 7045.67 14655.82 91.410 309.540 6975.99 7045.93 14752.62 92,890 309.240 6972.36 7042.30 14848,28 95.860 307.680 6965.08 7035.00 14943.86 98,940 308.710 6952.75 7022.69 1 5038.76 99.710 308.660 6937.38 7007.32 15135.03 100.830 309.860 6920.21 6990.15 15229.07 101.020 309.710 6902.39 6972.33 310,340 311.030 311.260 311.060 311.260 6953.49 6935.32 6917.53 6899.47 6881.06 6883.55 6865.38 6847.59 6829.53 6811.12 6983.66 N 7940.47 W 5987616.49 N 7047.98 N 8012.35 W 5987679.66 N 7110.07 N 8085.35 W 5987740.58 N 7170.65 N 8159,14 W 5987799.98 N · 7230.39 N 8232.64 W 5987858.54 N 7292.86 N 8307.99 W 5987919.81 N 7354.47 N 8380.83 W 5987980,26 N 7416.43 N 8453.72 W 5988041.06 N 7480.28 N 6526,74 W 5988103,74 N 7542.98 N 6597,66 W 5988165.30 N 7607.04 N 8670.02 W 5988228.~ N 7670.26 N 8742.11 W 5988290,27 N 7732.07 N 8814.10 W 5988350.93 N 7793.64 N 8887,26 W 5988411.33 N 7855.02 N 8962.02 W 5988471.52 N 7914.34 N 9336,59 W 5988529.64 N 7972.94 N 9111.17 W 5988587.05 N 8031.47 N 9184.27 W 5988644.41 N 8091.41 N 9257.62 W 5988703.19 N 8150.50 N 9328.57 W 5988761.14 N 6214.00 N 9404.18 W 5988823.43 N 6275.38 N 9475.58 W 5988883.67 N 8335.54 N 9544.43 W 5988942.73 N 8397.71 N 9815.56 W 5989003.77 N 8461.08 N 9688.04 W 5989065.97 N 15329.59 100.580 15425.48 101.270 15518.63 100.750 15614.81 100.900 15712.83 100.750 610879.82 E 610806.92 E 610732.95 E 610658.21 E 610583.76 E 610507.44 E 610433.63 E 610359.76 E 610285.74 E 610213.83 E 610140.46 E 6t0067.38 E 609994.42 E 609920.29 E 609844.57 E 609768.96 E 609693.55 E 609619.54 E 6O9545.25 E 609473.36 E 609396.76 E 6O9324.39 E 609254.59 E 6O9182.49 E 609109.01 E Dogleg Rate (°l'~00ft) 0.388 1.311 2.208 3.114 0.809 1.892 2.336 0.866 1.153 1.000 0.671 1.613 1.822 3.462 1.560 3.505 3.395 0.813 1.691 0.256 0.755 1.008 0.609 0.257 0.252 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 10574.56 10671.02 10766.84 1 0862.26 10956.92 11054.77 11150.15 11245.82 11342.81 11437.47 11534.11 11629.99 11724.88 11820.48 11917.16 12012.42 12107.07 1 2200.63 12295.30 12387.61 12486.33 12580.48 12671.91 12766.38 12862.66 I August, 2001 - 21:22 Page 8 o¢ 10 DifllQ,est 2.00.08,005 Sperry. Sun Drilling Services Survey Report for S-107 Your Ref: API-500292299900 Job No. AKZZfff07, Surveyed: 27 July, 2001 North Slope Alaska Measure Sub-Sea Vertical Local Coordinates d Depth Incl, Azim. Depth Depth Northings Eastings Northings (ft) (ft) (ft) Ct) (ft) (ft) Global Coordinates 15809.23 100.900 311.360 6793.01 6862.95 8523.58 N 9759.16 W 5989127.34 N 15904.96 100.460 311.880 6775.27 6845.21 8586.06 N 9829.49 W 5989188.70 N 15959,83 100.190 311.800 6765.44 6835.38 8622.07 N 9869.70 W 5989224.06 N 16026.00 100.190 311.800 6753.73 6823.67 8665.48 N 9918.25W 5989266.70 N Eastings (ft) 60cJ036.91 E 608965.60 E 608924.82 E 608875.58 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well. Northings and Eastings are relative to Well, Magnetic Declination at Surface is 26.475° (26-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US), Vertical Section is from Well and calculated along an Azimuth of 311.143° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16026.00ft., The Bottom Hole Displacement is 13170.51ft., in the Direction of 311.143° (True). Dogleg Rate (°/100ft) 0.186 0.704 0.513 0.000 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 12957.34 13051.41 131O5.39 13170.51 Projected Survey 1 August, 2001 - 21:22 Page 9 of 10 DdllQ,est 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S.107 Your Reft API.500292299900 Job No. AKZZfff07, Surveyed: 27 July, 2001 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad Comments Meas u re d Depth (~) 16026.00 Station Coordinates TVD Northings Eastings Ct) (ft) 6823.67 8665.48 N 9918,25 W Comment Projected Survey Survey tool program for S. 107 From To Measure Vertical Measure Vertical d d Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0,00 0.00 645.83 644.79 645,83 644.79 t6026.00 6823.67 Survey Tool Description Tolerable Gyro (S-107 Gyro) AK-6 BP_IFR-AK (S-107) 1 August, 2001.21:22 Page 10 of 10 DffllOuest 2.00.08.005 01-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-107 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 16,026.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AU$ 0 ? 2001 Alalm Oil & Gas Cons. North Slope Alaska Alaska DHIling & Wells PBU_WOA S Pad, Slot S-~07 S-~07 MWD Job No. AKMM11107, Surveyed: 27 July, 2001 S UR VEY REPORT August, 2001 Your Reft API.500292299900 Surface Coordinates: 5980759.77 N, 618930.16 E ('/0~ 21' 21.9134" N, 149° 02' 02.8561" W) Kelly Bushing: 69.94fl above Mean Sea Level O Pti L.:. L. I N'd" 'JmPIVicmll S[/rvey Ref: svy10916 A HalRburton Company Sperry. Sun Drilling Services Survey Report for S. 107 Your Ref: API-500292299900 Job No. AKMMflf07, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (it) Incl. Azim. S-107 Gyro Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -69.94 0.00 71.00 0.250 72.000 1.06 71,00 t60.00 0,250 267.000 90.06 160,00 25200 0.700 297.000 182.00 252,00 340.00 1.150 285.000 270.04 339,98 428.00 2.500 292.000 358.00 523.00 4.650 295,500 452.81 S-107 MWD 574.85 662.60 756.53 850.02 937.41 645.83 8.210 306.230 734.97 12.010 317.460 831.22 13.180 318.720 927.64 15.130 317.580 1018.19 15.210 318.650 427.94 522.75 644.79 732.54 826.47 919.96 1007.35 1118.88 15.970 315.980 1034.40 1104.34 1213.35 17.930 315.700 1124.76 1194.70 1308.91 19.970 319.160 1215,14 1265.00 1404.81 21.210 320.510 1304.91 1374,85 1499.42 24.020 317.360 1392.24 1462.18 1595.44 23.670 317.260 1480.07 1550.01 1689.88 25.350 315.640 1565,99 1635,93 1789.53 30.610 314.360 1653.97 1723.91 1886.54 36.460 312.230 1734.80 1804.74 1981.19 41.850 313.310 1808.17 1878.11 Local Coordinates Global Coordinates Northings Eaetlng. Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5980759.77 N 618930.16 E 0.05 N 0.15 E 5980759.82 N 618930.31 E 0.10 N 0.14 E 5980759.87 N 618930,30 E 0.34 N 0.56W 5980760.10 N 618929.59 E 0.81 N 1.90 W 5980760.55 N 618928.25 E 1.76 N 4,53 W 5980761.46' N 618925.60 E 4.20 N 9.92 W 5980763.81 N 618920,17 E Dogleg Rate (°ll00ft) 0.352 0.557 0.543 0.554 1.552 2.274 11.53 N 21.50 W 5980770.95 N 618908,48 E 3.047 22.13 N 32.91 W 5980781.37 N 618896.91 E 4.783 37.75 N 46.92 W 5980796.77 N 618882.65 E 1.249 55.30 N 92.66 W 5980014.07 N 618866.63 E 2.043 72.94 N 78.48 W 5980831.46 N 618850.53 E 0.322 92.82 N 96.83 W 5980851.04 N 618831,87 E 112.57 N 116.02 W 5980870.49 N 618812.37 E 135.45 N 136.97 W 5980893.03 N 618791.06 E 161.23 N 158.71 W 5980918.46 N 618768.91 E 188.61 N 182.64 W 5980945.45 N 618744.55 E 217.14 N 208.95 W 5980973.57 N 618717.78 E 245.52 N 235.95 W 5981001.51 N 618690.33 E 278.53 N 269.04 W 5981034.00 N 618656.73 E 315.21 N 308.08 W 5981070.05 N 618617.12 E 355.80 N 351.91 W 5981109.94 N 618572.64 E 1.038 2.077 2.436 1.384 3.233 0.367 1.916 5.312 6.150 5.740 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 0.00 -0.08 -0.04 0.65 1.95 4.53 10.16 Tolerable Gyro 23.66 39.23 60.11 83.56 107.14 134.09 161.58 192.47 225,90 262.03 300.70 339.77 386.46 440.01 499.75 MWD Magnetic 1 August, 2001 - 23:43 Page 2 of 10 DriliCtuest 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S. 107 Your Ref: API-500292299900 Job No. AKMMf ff07, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (rt) Or) (ir) (ft) 2076.80 45.630 313.740 1877.23 1947.17 2172.92 50.080 312.630 1941.71 2011.65 2268.60 57.840 313.170 1997.96 2067.90 2364.80 60.950 313.700 2046.93 2116.87 2460.62 62.720 315.870 2092.16 2162.10 2556.00 65.250 314.660 2134.03 2203.97 2652.07 64.260 314.000 2174.97 2244.91 2747.46 64.650 312.960 2216.11 2286.05 2843.37 66.440 312.600 2255.81 2325.75 2939.21 65,840 316.1 O0 2294.59 2364.53 3036,07 65.170 314.240 2334.75 2404.69 3131.54 65,310 311.400 2374.74 2444.68 3227.28 65.080 314.380 2414.91 2484.85 3322.74 65.380 313.070 2454.91 2524.85 3419.63 66.810 310.190 2494.18 2564.12 3515.53 69.150 309.800 2530.13 2600.07 3610.81 68.520 310.880 2564.53 2634.47 3703.83 66.990 308.870 2599.75 2669.69 3800.35 65.890 311.660 2638.34 2708.28 3896.79 65.320 310,990 2678.17 2748.11 40t .32 N 399.83 W 5981154.69 N 450.06 N 451,79 W 5981202,60 N 502.70 N 508.41 W 5981254.33 N 559.62 N 568.53 W 5981310.30 N 619.13 N 628.46 W 5981368.85 N 680.06 N 688.84 W 5981428.81 N 740.73 N 750.95 W 5981488.49 N 799.95 N 813.40 W 5981546.71 N 859.24 N 877.48 W 5981604.97 N 920.50 N 940.14 W 5981665.23 N 983.01 N 1002.28 W 5981728.74 N ' 1041.92 N 1065.86 W 5981784.64 N 1101.06 N 1129.52 W 5981842.76 N 1160.97 N 1192.16 W 5981901.67 N 1219.79 N 1256.37 W 5981959.43 N 1276.93 N 1326.47 W 5982015.48 N 1334.44 N 1394.20 W 5982071,91 N 1389.64 N 1460,26 W 59821 28.05 N 1446.81 N 1527.77 W 5982182.14 N 1504.81 N 1593.73 W 5982239,08 N 1563.96 N 1659.97 W 5982297.18 N 1621.07 N 1724.82 W 5982353.25 N 1678.32 N 1790.30 W 5982409.45 N 1709.19 N 1824.29 W 5982439.78 N 1762.23 N 1883.56 W 5982491,88 N 3994.78 64.710 312.540 2719.56 2789.50 4090.31 64.820 310.200 2760.29 2830.23 4186.05 65.790 312.120 2800.29 2870.23 4236.46 65.490 312.370 2821.00 2891.02 4324.23 64.480 311.280 2858.20 2928.14 618524.01 E 618471.28 E 618413.83 E 618352.82 E 618291 .g5 E 618230.61 E 618167.55 E 618104.16 E 618039.15 E 617975.52 E 617912,40 E 617847,89 E 617783.30 E 617719.72 E 617652,59 E 617563.58 E 617514.95 E 617448.02 E 617379.61 E 617312.75 E 617245.57 E 617179.82 E 617113.44 E 617078.96 E 617018.86 E Dogleg Rate (°/lOOft) 3.966 4.708 8.123 3.267 2.720 2.885 1.204 1.065 1.897 3.398 1.879 2.705 2.836 1.285 3.092 2.469 1.247 2.589 2.884 0.866 1.563 2.219 2.005 0.747 1.610 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 565.83 637.07 714.37 797.14 881.53 967.19 1053.96 1140.01 1227.31 1314.88 1402.91 1489.59 1576.48 1663.13 1751.68 1840.51 1929.31 2015.32 2103.72 2191.54 2280.35 2366.74 2453.70 2499.62 2579.15 1 At,gust, 2001.23:43 Page 3 of 10 DflllOuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S. 107 Your Ref: API-500292299900 Job No. AKMM11107, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth fit) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) fit) fit) fit) fit) (o/loort) 4423.12 63.590 310.590 2901.50 2971.44 4517.88 65,340 308.220 2942.35 3012.29 4613.95 64.920 308.660 2982.75 3052.69 4709.54 66.350 309.580 3022.18 3092,12 4804.49 65.730 311.370 3060.75 3130.69 4900.51 64.760 313.220 3100.96 3170.90 4996.62 65.970 313.360 3141.02 3210.96 5092.39 65,110 311.500 3180,67 3250.61 5187.97 66.610 310.120 3219.76 3289.70 5285.64 67.280 311.390 3258.01 3327.95 5380.20 66.240 310.650 3295.33 3365.27 5477.19 65.480 310.260 3334.99 3404.93 5572.14 64.900 309.870 3374.83 3444,77 5667.75 66.030 311.010 3414.54 3484.48 5764.63 66.010 310.580 3453.91 3523.85 1820.49 N 1950.72 W 5982549.06 N 1874.75 N 2016.79 W 5982602.26 N 1928.93 N ' 2085.06 W 5982655.36 N 1983.87 N 2152.61 W 5982709.22 N 2040.19 N 2218.61 W 5982764.48 N 2098.86 N 2283.11 W 5982822.12 N 2158.76 N 2346.70 W 5982881.01 N 2217.58 N 2411.03 W 5982938.79 N 2274,57 N 2477.05 W 5982994.73 N 2333.24 N 2545.12 W 5983052.3t N 2393.27 N 2610.67 W 5983108.29 N 2447.70 N 2678.02 W 5983164.64 N 2503.17 N 2743.98 W 5983219.06 N 2559.5g N 2810.17 W 5983274.42 N 2617.43 N 2877.18 W 598,3331.19 N 2674.22 N 2943.20 W 5983386.92 N 2729.83 N 3008.~ W 5983441.49 N 2785.31 N 3073.65 W 5983495.93 N 2839.22 N 3136.19 W 5983548.64 N 2892,25 N 3197.65 W 5983600.89 N 2946.37 N 3259.22 W 5983654.02 N 2999.45 N 3318.12 W 5983706.16 N 3053.79 N 3378.55 W 5983759.53 N 3108.27 N 3438.88 W 5983813.06 N 3163.00 N 3499.38 W 5983866.82 N 5860.34 64.970 310.830 3493.61 3563.55 5955,54 63.610 310.000 3534.91 3604.85 6051.78 61.920 310.840 3578.96 3648.90 6146.58 59.260 310.680 3625.50 3695.44 6241.91 57.850 310.720 3675.23 3745,17 616950.78 E 616883.86 E 616814.74 E 616746.33 E 616679.44 E 616614.02 E 616549.49 E 616484.23 E 615417.31 E 616348.32 E 616281.87 E 616213.62 E 616146.79 E 616079.71 E 616O11.79 E 615944.88 E 615878.70 E 615812.68 E 615749.29 E 615686.80 E 615624.57 E 615564.84 E 615503.56 E 615442.37 E 615381.00 E 6338.65 57.650 312.090 3726.86 3798.80 6432.79 57,1 20 311.960 3777.60 3847.54 6529.80 56.680 311.970 3830.58 3,,000.52 6626.12 58.460 312.200 3882.23 3952.17 6721.85 58.450 312060 3932.31 4002.25 1.097 2.916 0.603 1.734 1.842 2.020 1.266 1,983 2.049 1,379 1.314 0.865 0.716 1.604 0.406 1,112 1.630 1.920 2,810 1.480 1.215 0.575 0.454 1.859 0.125 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 2668.03 2753.42 2840.38 2927.31 3014.03 3101.22 3188.57 3275.74 3362.92 3452.76 3539.62 3628.08 3714.20 3801.13 3889.61 3976.66 4062.39 4147.91 4230.45 4311,75 4393.56 4472.84 4554.11 4635.40 4716.99 1 August, 2001 - 23:43 Page 4 of' 10 DHIIOtlest 2.00,08.005 Sperry. Sun Drilling Services Survey Report for S. 107 Your Ref: API.500292299900 Job No. AKMMfff07, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Lo=al Coordlnatea Global Coordinates Depth Northings Eastings Northlngs Eastings (~) (ft) fit) (ft) (~) 6817.33 57.790 313.210 3982.74 4052.68 6913.42 56.840 311.900 4034.63 4104.57 7008,39 57.960 310.670 4085.80 4155.74 7104.57 57.820 311.010 4136.92 4206.86 7199.80 57.320 310.770 4187.99 4257.93 7295,42 56.430 312.290 4240.24 4310,18 7391.60 56.870 312.690 4293.12 4363,08 7486.88 56.890 312.250 4343.78 4413.72 7582.76 58_680 312.220 4393.47 4463.41 7677.90 58.070 311.720 4443.35 4513.29 7775,49 59.530 312.600 4493.91 4563.85 7870.63 59.080 312.730 4542.47 4612.41 7966.28 60.170 312.860 4590.84 4660,78 8062,08 60.240 312.210 4638.44 4708.38 8156.58 59. 770 312.270 4685.69 4755.63 8260.03 59,940 311.560 4737.64 4807.58 8355.21 60.630 311.570 4784.82 4854.76 8449,71 61.040 311.690 4830.87 4900.81 8548.19 61.050 312.010 4878.55 4948.49 8643.25 60.490 310.730 4924.97 4994.91 3217.91 N 3559.03 W 5983920.78 N 615320.49 E 3272.61 N 3618.60 W 5983974.52 N 615260.06 E 3325.39 N 3678.72 W 5984026.34 N 615199.11 E 3378.67 N 3740.35 W 5984078.63 N 615136.64 E 3431.29 N 3801.12 W 5984130.28 N 615075.05 E 3484.37 N 3861.06 W 5984182.40 N 615014.26 E 3538.64 N 3920.31 W 5984235.73 N 614954.17 E 3593.12 N 3979.83 W 5984289.25 N 614893.79 E 3648.24 N 4040.54 W 5984343.40 N 614832.21 E 3702.41 N 4100.77 W 5984396.61 N 614771.12 E 3758.44 N 4162.64 W 5984451.65 N 614708.37 E 3813.89 N 4222.80 W 5984506.14 N 614647.34 E 3869.95 N 4263.35 W 5984561.23 N 614585.91 E 3926.15 N 4344.61 W 5984616.45 N 614523.76 E 3981.17 N 4405.20 W 5984670.50 N 614462.31 E 4040.93 N 4471.77 W 5984729.20 N 614394.80 E 4095.78 N 4533.62 W 5984763.05 N 614332.08 E 4150.60 N 4595.30 W 5984836.89 N 614269.54 E 4208.09 N 4659.49 W 5984893.35 N 614204.45 E 4262.91 N 4721.74 W 5984947.18 N 614141.34 E 4316.88 N 4784.61 W 5985000.14 N 614077.61 E 4370.36 N 4847.17 W 5985052.62 N 614014.22 E 4423.46 N 4908.80 W 5985104.73 N 613951.76 E 4477.32 N 4969.86 W 5985157.62 N 613889.84 E 4530.99 N 5029.32 W 5985210.34 N 61 3829.54 E 8738.85 59.670 310.550 4972.65 5042.59 8834.77 58.520 310.500 5021.92 5091.86 8930.56 57.730 311.000 5072.50 5142.44 9027.07 57.340 311.830 5124.30 5194.24 9122.43 56.930 312.320 5176.05 5245.99 Dogleg Rate (°/lOOft) 1.2'34 1.515 1.607 0.333 0.566 1.624 0.574 2.156 0.221 0.782 1.683 0.487 1.146 0.593 0.500 0.616 0.725 0.448 0.285 1.314 0.873 1.200 0.936 0.831 0.609 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 479606 4878.93 4958.92 5040.36 5120,71 5200.78 5281.12 5361.81 5443.81 5524.82 5608.29 5690.10 5772.62 5855.75 5937.60 6027.05 6109.71 6192.22 6278.39 6361.33 6444.15 6526.41 6607.73 6689.14 6769.24 1 August, 2001.23:44 Page 5 of 10 DtfllO{~est 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S-107 Your Ref: API-500292299900 Job No. AKMM11107, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings fit) fit) (f~) (ft) (f~) 9218.50 56.570 310.790 5228.73 5298.67 9313.48 56.320 311.730 5281.23 5351.17 9410.43 56.460 311.500 5334.89 5404.83 9505.77 56.080 311.640 5387.83 5457.77 9601.99 56.470 309.490 5441.26 5511.20 9696.95 57.790 308.570 5492.80 5562.74 9792.15 57.530 309.800 5543.73 5513.67 9888.86 57.190 310.510 5595.89 5665.83 9983.32 57. 370 312.580 5646.95 5716.89 10078.83 57.980 312.830 5698.02 5767.96 10174,42 57.380 312.850 5749.13 5819.07 10270.10 57.070 312.850 5800.92 5870.86 10367.19 57.700 312.610 5853.25 5923.19 10462.75 59.560 312.900 5903.00 5972.94 10558.04 59.470 312.490 5951.34 6021.28 10654,23 58.910 312.360 6000,61 6070.55 10749.50 58.510 312.490 6050.09 6120.03 10845.48 56.050 311.830 6100.55 6170.49 10941.56 57.550 311.740 6151.75 6221.69 11036.79 57.770 312.560 6202.69 6272.63 4584.28 N 5089.43 W 5985262.67 N 4636.48 N 5148.93 W 5985313.92 N 4690.10 N 5209.30 W 5985366.58 N 4742.71 N 5268.62 W 5985418.24 N 4794.75 N 5329.41 W 5985469,30 N 4844.97 N 5391.37 W 5985518.53 N 4895.79 N 5453,71 W 5985568.36 N 4948.30 N 5515.95 W 5985619.87 N 5001.00 N 5575.43 W 5985671.63 N 5055,74 N 5634.73 W 5985725.42 N 5110.67 N 5693.97 W 5985779.40 N 5155.38 N 5752.95 W 5985833.16 N 5220.87 N 5813.02 W 5985887.69 N 5276.26 N 5872.92 W 5985942.12 N 5331,94 N 5933.28 W 5985996.84 N 5387.68 N 5994.26 W 5986051,60 5442.60 N 6054.36 W 5986105.58 5497,40 N 6114.67 W 5986159.39 5551.57 N 6175.50 W 5986212.60 5605.57 N 6235.15 W 5986265.64 5660.50 N 6294.g0 W 5986319.62 5714,41 N 6355.21 W 5986372.56 5768.12 N 6414,90 W 5986425.32 5823.10 N 6473,24 W 5986479.37 5878.72 N 6531.90 W 5986534.05 11132,77 57.710 312.630 6253.92 6323.65 11228,69 57.280 310.950 6305.47 6375.41 11324,05 57.460 313.010 6356.89 6426.83 11419.18 57.400 313.590 6408.11 6478.05 11515,27 57.140 313.370 6460.06 6530.00 613768.59 E 613708,27 E 613647.06 E 613586.91 E 613525.30 E 613462.55 E 613399.41 E 613336.34 E 613276.04 E 613215.87 E 613155.77 E 613095.93 E 613034.99 E 612974,21 E 612912.98 E N N N N N' 612851.12 E 612790.16 E 612728.78 E 612667,30 E 612606.80 E 612546.19 E 612485,03 E 612424.49 E 612365.28 E 612305.75 E Dogleg Rate (°/'lOOft) 1.384 0.866 0.245 0.417 1.902 1.611 1.125 0.711 1.853 0.676 0.628 0.324 0.681 1.964 0.383 0.594 0.436 0.756 0.526 0.763 0.088 1 544 1.829 0.518 0.332 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 6849.57 6928.71 70O9.44 7088.73 7168.71 7248,33 7328.64 7410.02 7489.48 7570.18 7650.96 7731.41 7813.18 7894.77 7976.88 8059.50 8140.91 8222.55 8303.85 8384.31 8465.47 8546.36 8626.66 8706.81 8787.63 1 August, 2001 - 23:44 Page $ of 10 DrillQues~ 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S.107 Your Ref: API-500292299900 Job No. AKMM11107, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordlnatea Global Coordinates Depth Northings Easting8 Northing8 Eastings (ft) (ft) (ft) (ft) fit) 11611.33 56.560 313.330 6512.59 6582.53 11706.88 58.940 313.940 6563.57 6633.51 11801.99 59.720 312.820 6612.09 6882.03 11898.12 62.190 309.710 6658.76 6728,70 11994.34 65.520 312.930 6700,41 6770.35 12090.11 67.780 313.510 6737.59 6807.53 12186, 22 67.860 313.440 6773.88 6843.82 12281,38 67.360 312,990 6810.12 6880,06 12344.46 67.130 312.160 6834, 52 6904.46 12449.72 67.860 309.230 6874.82 6944.76 12482.50 72.170 310.430 6886.02 6955.96 12515.62 76.810 310.480 6894.88 6964.62 12546.57 77.520 314.530 6901.75 697t .69 1 2579.58 80.530 314.550 6908.04 6977.98 12611,55 82.900 315,500 6912,64 6982.58 t 2643.77 85.380 313.660 6915.93 6985.87 12681,31 88.210 314.540 6918.03 6987.97 12707,54 88.030 315.100 6918.89 6988.83 12738.29 87.970 312.990 6919.97 6989.91 12834,55 87.840 3t4.680 6923.49 6993.43 5933.93 N 6590.38 W 5986588.32 N 5989.69 N 6648.86 W 5986643.15 N 6045.88 N 6708,32 W 5986698.38 N 6101.27 N 6771.49 W 5986752.77 N 6158.55 N 6835.58 W 5986809.01 N 6218.99 N 6900.89 W 5986868.41 N 6280.22 N 6965.47 W 5986928.62 N 6340.47 N 7029.59 W 5986987.84 N 6379,82 N 7072.43 W 5987026.51 N 6443.22 N 7146.15 W 5987088.72 N 6462,95 N 7169,80 W 5987108.07 N 6483.65 N 7194.08 W 5987126.39 N 6504.03 N 7216.32 W 5987146.42 N 6526.76 N 7239.41 W 5987170.77 N 6549.14 N 7261.77 W 5987192.80 N 6571.63 N 7284.60 W 5987214.92 N 6597.71 N 7311.51 W 5987240.57 N 6616.19 N 7330.11 W 5987258.76 N 6637.56 N 7352.20 W 5987279.77 N 6704.18 N 7421.58 W 5987345,26 N 6767.36 N 7489.97 W 5987407.36 N 6829.26 N 7563.95 W 5987468.08 N 6889.86 N 7638.55 W 5987527.49 N 6952.34 N 7710.33 W 5987588.82 N 7019.95 N 7779.10 W 5987655.33 N 12927,70 89.260 310.790 6925.64 6995.78 13024.19 88.890 309,040 6927.40 6997,34 13120.31 89.080 309.140 6929.10 6999.04 13215.50 89,260 31 2940 6930.46 7000.42 13311.97 88.650 316.080 6932.24 7002.18 612246.40 E 612187.05 E 612126.70 E 612062.66 E 611996.67 E 611931.41 E 611865.86 E 611800.79 E 611757.34 E 611682.62 E 611658.66 E 611634.05 E 611611.49 E 611588.04 E 611565.33 E 611542.15 E 611514.82 E 611495.94 E 611473.51 E 611403.08 E 611333.70 E 611258.73 E 611183.19 E 611110.43 E 611040.59 E Dogleg Rate (°/100ft) 0.605 2.549 1.303 3.821 5.417 1.429 0.107 0.684 1.267 2.663 13.591 14.010 12.963 9.119 7.975 9.566 7.894 2.241 6.860 1.760 4.444 1.854 0,223 3.996 3.315 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 8868.04 8948.82 9030.61 9114.62 9201.31 9289.55 9378.53 9466.51 9524.68 9621.87 9652.64 9684.52 9714.69 9747.07 9778.67 9810.69 9848.15 9874.34 9905.06 0001.22 10094.31 10190,70 10286.66 10381,79 10478.16 1 August, 2001 - 23:44 Page 7 o~ 10 DtfllQ~mst 2.00.08.005 Sperry. Sun Drilling Services Survey Report for 8.107 Your Ref: API.500292299900 Job No. AKMMlff07, Surveyed: 27 July, 2001 North Slope Alaska Measure d Depth (ft) Incl. Aziml Sub-Sea Depth Vertical Local Coordlnatel Global Coordinates Depth Northings Eastlngs Northinga Eastings (ft) (ft) (ft) (ft) (ft) 13408.74 88.830 317.120 6934.37 7004.31 13505.22 89.080 313.290 6936.13 7006.07 13601.06 90.430 314.620 6936.54 7006.48 13696.55 87.480 314.000 6938.28 7008.22 13791.34 88.220 311.790 6941.84 7011,78 13889.24 89.510 310.690 6943.78 7013.72 13984,68 87.290 313.090 6946.44 7016.38 14080.49 86.620 314.470 6951.53 7021.47 1417766 86.550 317.640 6957.32 7027.26 14272.46 87.350 313.940 6962.37 7032.31 14369,19 87. 600 313.260 6966.63 7036.57 1 4465.20 86.550 313.500 6971.53 7041.47 14560.19 88.280 3t0.310 6975,81 7045.75 14655,82 91,410 311.500 6976.07 7046,01 14752.62 92.890 315.780 6972.44 7042.38 14848.28 95.860 315.030 6965.14 7035.08 14943.86 98.940 3t 1.570 6952.63 7022.77 15038.76 99.710 310.710 6937.45 7007.39 15135.03 100.830 312.110 6920.29 6990.23 15229.07 101.020 312.120 6902.47 6972.41 7090,24 N 7845.58 W 7158,68 N 7913.53 W 7225.20 N 7982.52 W 7291.68 N 8050.83 W 7356.35 N 8120.22 W 7420.87 N 8193.82 W 7484.57 N 8264.83 W 7550.76 N 8333.91 W 7620.59 N 8401,21 W 7688.43 N 8467.21 W 7755.07 N 8537.19 W 7820.93 N 8606.68 W 7884.30 N 8677.49 W 7946.91 N 8749.76 W 8013.65 N 8819.75 W 8081.56 N 8886.70 W 8148.55 N 8955.66 W 8208.16 N 9026.18 W 8270.81 N 9O97.23 W 8332.74 N 9165.72 W 8398.09 N 9239.73 W 8460.50 N 9310.22 W 8523.40 N 9376.58 W 8590.13 N 9443.44 W 8658.63 N 9512.86 W 15329.59 100.580 310.770 6883.63 6953.57 15425.48 101 270 312.280 6865.46 6935.40 15518.63 100.750 314.650 6847.66 6917.60 15614.81 103.900 315.240 6829.60 6899,54 15712.83 100.750 312.470 6811.19 6881.13 5987724.58 N 610973.01 E 5987791.91 N 610903.98 E 5987857.33 N 610833.94 E 5987922.92 N 610764.58 E 5987986.28 N . 610694.17 E 5988049.~ N 610619.56 E 5988112.18 N 610547.54 E 5988177.27 N 610477.43 E 5988246.02 N 610409.02 E 5988312.81 N 610341.96 E 5988378.33 N 610270.93 E 5988443.07 N 610200.20 E 5988505.31 N 610128.59 E 5988566.76 N 610055.34 E 5988632.38 N 609984.~ E 5988699.22 N 609916.27 E 5988763.11 N 609846.29 E 5988823.60 N 609774.80 E 5988885.11 N 609702.77 E 5988945.94 N 6O9633.30 E 5989010.11 N 609558.26 E 5989071.40 N 609486.79 E 5989133.23 N 609419.45 E 5989198.90 N 609351.53 E 5989264.48 N 609281.06 E Dogleg Rate (°/100ft) 1,090 3.978 1.977 3.157 2.457 1.732 3.425 1 599 3.257 3.988 0.748 1.122 3.817 3,502 4.675 3.202 4.824 1.207 1.844 0.202 1.390 1.705 2.559 0.622 2.780 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 10574.64 10670.96 10766,76 10862.16 10956.88 11054.74 11150.12 11245.76 11342, 54 11437.02 11533.63 11629.50 11724.37 11819.96 11916.64 12011.87 12106.61 1 2200.24 12294.95 12387.29 12486.01 12580.15 12671.56 12765.93 12862.16 1 August, 2001 - 23:44 Page 8 o~ 10 DdllQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-107 Your Ref: API-500292299900 Job No. AKMMfff07, Surveyed: 27 July, 2001 North Slope Alaska Measure Sub-Sea Vertical Local Coordinates d Depth Incl. Azim. Depth Depth Northings Eastings Northinga (ft) (f~) (ft) (ft) (ft) (ft) Global Coordinates 15809.23 100.900 313.010 6793.08 6863.02 8721.09 N 9582,40 W 5989327.63 N 15904.96 100.460 313.960 6775.34 6845.28 8785.83 N 9850,65 W 5989391.27 N 15959.83 100.190 312.530 6765.51 6835.45 8822.81 N 9689.97 W 5989427.63 N 16026.00 100.190 312.530 6753.80 6823.74 8866,83 N 9737.97 W 5989470.88 N Eastings (ft) 609210.51 E 609141.24 E 609101.34 E 6O9052.65 E Dogleg Rate (°/~OOft) 0.572 1.078 2,611 0.000 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 12956.84 13O5O.89 13104.87 13169.99 Projected Survey Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.475° (26-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is fi.om Well and calculated along an Azimuth of 312.319° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16026.00ff., The Bottom Hole Displacement is 13169.99ft., in the Direction of 312.319° (True). f August, 2001.23:44 Page 9 of 10 DrtllOuest 2.00.08.005 Sperry. Sun Drilling Services Survey Report for S.107 Your Ref: API.500292299900 Job No. AKMM~I1107, Surveyed: 27 July, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Comments Measure Station Coordinates d Depth TVD Northings Eastings (ft) (fi) (fi) (ft) 16026.00 6823.74 8866.83 N 9737.97 W Comment Projected Survey Survey tool program for S-107 MWD From To Measure Vertical Measure Vertical d d Depth Depth Depth Depth (ft) Ct) (ft) (ft) 0.00 0.00 645.83 644.79 645.83 644.79 16026.00 6823.74 Survey Tool Description Tolerable Gyro (S-107 Gyro) MWD Magnetic (S-107 MWD) 1 August, 2001 - 23:44 Page 10 of 10 DdliO,est 2.00.08.005 8/7/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. t 356 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-107 2'1350 USIT 07116101 2 S-107 21350 USITISCMT 07120101 2 S-'107 2'1350 SLIM SONIClCBL 07120101 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED AUG 21 2001 AJaska 0il & Gas Cons. Commission ,~lchorage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie [Fwd: S-107i Zonal isolation confirmed] Subject: [Fwd: S-107i Zonal isolation confirmed] Date: Fri, 03 Aug 2001 07:31:32-0800 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: Lisa Weepie <lisa_weepie~admin.state.ak.us> Lisa, Please route to the file. PTD # is 201-113. Thanks. Tom Reply sent at 1635 08/02/01 Gentlemen, Thanks for your attention to my concern. Your explanation of the lithological and frac gradient differences gives you confidence that the fluids will be injected and confined to the intended strata. You also indicate that you intend to run diagnostic logs to confirm that such is the case. This is acceptable. Good luck with your completion. Please keep us informed of your progress. Tom Maunder, PE Petroleum Engineer AOGCC Subject: Re: S-107i Zonal isolation confirmed Date: Thu, 02 Aug 2001 16:24:08 -0800 From: Robert Crandall <Bob_Crandall~admin. state.ak.us> Organization: DOA-AOGCC To: "Maunder, Thomas" <tom_maunder~admin.state.ak.us> Tom: These fracture gradients he mentions are in line with almost all other fract, gradients for these litho!ogies, if someone had asked me I would have guessed .85 psi/ft.. let me know what you think RPC "Young, Jim" wrote: > > Tom and Bob, > > The Kuparuk River Formation at the Aurora Oil Pool is overlain by the > Kalubik, HRZ/CM1 shales, which have a combined thickness of approximately > 268 feet in S-107i. (11424 '-11900' md). > > The HRZ is a thick shale sequence, which tends to behave as a plastic medium > and can be expected to contain significantly higher pressures than > sandstones of the Kuparuk River Formation. Mechanical properties determined > from log and core data in well S-104 for the HRZ and Kalubik intervals > indicate a fracture gradient from approximately 0.83 to 0.92 psi/ft. > > Maximum anticipated injection pressure in S-107 will be 2000psi at the > surface with GC2 produced water yeilding a maximum bhp of O. 74psi~ft. This > is well below the breakdown pressure of the above mentioned formations and > gives us complete confidence that the open perforations at 11850-52' will > not reach freshwater strata via formation breakdown or wellbore > communication. > 1 of 4 8/3/01 7:39 AM [Fwd: S-107i Zonal isolation confirmed] > A leakoff test in well S-lO1 suggested a fracture gradient of O. 73 psi/ft at > initial reservoir conditions; however a O. 65psi/ft gradient is expected at > current reservoir conditions based on a recent fracture treatment in S-102 > (nearest offset to S-107'). We believe that at all the fluid during the > circulation attempt went down a cement channel into the Kuparuk formation > 50' below at a calculated pressure of O. 72psi~ft. This is why we decided not > to pump cement due to concerns about formation damage. > > To avoid adding further complexity to the already complex completion; we > propose to keep the packers at the existing locations. Prior to continuing > long-term injection; we will confirm with a water-flow log that NO injection > is entering the perforations 11850'-52' and moving upward as to risk > communication to freshwater strata or our ability to contain injected fluids > to the target reservoir. > > We are currently preparing to condition the well for running the completion > so an answer on this quickly (this afternoon or tommorrow) is requested. I > will be out tommorrow, but Phil would be glad to meet with you if necessary. > Thanks, > Jim Young > PE, GPB New Developments > youngj3~bp, corn > (907) 564-5754 fax 5016 > > ..... Original Message ..... > From: Tom Maunder [mailto:tom maunderSadmin.state.ak, us] > Sent: Thursday, August 02, 2001 2:53 PM > To: Smith, Phil G (FAIR) > Cc: Young, Jim; Bob Crandall > Subject: Re: S-107i Zonal isolation confirmed > > Phil and Jim, > Bob Crandall and I looked at the proposed completion of S-107i. We agree > that your limited > injection test indicates there does not appear to any communication between > the > perforations. > Our concern is that your test demonstrated that the perforations will accept > fluid at 1 bpm > at 1300 psi. In your proposed completion, the perforations at 11850 will be > continuously > exposed to injection pressure, likely higher than 1300 psi, and fluid could > be pumped > through those perforations as well as the intended interval of 11900 - > 12150. Over the > long term, fluid might not be contained as planned. > I understand the reluctance to set an additional packer to isolate the perfs > at 11850, but > I believe the benefit of the additional 50' of isolation (11850-11900) would > be > advantageous. Please provide additional information to mitigate our > concern. > Tom Maunder, PE > Petroleum Engineer > AOGCC > > "Smith, Phil G (FAIR)" wrote: > > > Tom, > > Below is copy of the plan we executed to ensure zonal isolation on S-107i. > > I'm also attaching a more detailed "plan forward" generated and followed >at 2 of 4 8/3/01 7:39 AM [Fwd: S-107i Zonal isolation contirmed] > the rig and a well diagram as the well is expected to be completed. The > attached plan forward is more accurate and detailed than summary procedure > listed below. > > The outcome of the procedure completed this morning was as follows: > * Stabbed cement stinger into the retainer at 11,825' > * Attempted circulation through newly shot perfs at 11,850 and 11,735 > to 2000 psi w~ 10.3 ppg mud (2600 psi equivalent injection pressure with sea > water). > * No return flow through upper perfs. Observed bleed-off to 900 psi > in 8 minutes, then stable at 900 psi. Thereafter managed 1 bpm steady > injection at 1300 psi for 5 bbls. Bled down to 9000 psi in 10 minutes > (Frac'ing mud into formation assumed). > > We have concluded from the test that the cement is providing more than > adequate isolation at the top of Kuparuk reservoir (11,900' MD) though the > USIT log is inconclusive. > > Jim Young (production engineer) is planning to pre-produce the well and run > immediate diagnostics (WFL and/or Production log) if expected production is > not realized. Otherwise, the well will be converted to water injection > status in October with a WFL / injection profile run within a week of > injection start-up. Further diagnostics may be added if deemed prudent. > > Please respond after your consideration. > Thanks, > Phil > > <<S-107 Cmt Squeeze-Rev 1.doc>> <<S-107 diagram MSWord. ZIP>> > > ..... Original Message ..... > > From: Smith, Phil G (FAIR) > > Sent: Tuesday, July 31, 2001 11:25 AM > > To: 'jane williamson~admin.state.ak, us' > > Cc: Tom Maunder (E-mail); 'julie heusserSadmin.state.ak, us'; Bunch, -- > > Anthony S; Elmore, Gary 0 (Schlumberger); Wesley, Dave E; Madsen, Alan D > > (Fairweather) > > Subject: S-107i Zonal isolation > > Jane/Tom: > > We lost returns while running in hole and during the primary cement job on > > the S-107i 7" casing. Subsequently we ran a USIT and determined the > > cement was in poor condition. We then performed a "suicide squeeze" > > through perforations at 11,950' MD and 11,730' MD (top Kuparuk target > > 11,900' MD). The squeeze was executed with Dowell's "liteCrete" slurry > > which, by its nature, produced a questionable subsequent USIT log. > > We believe we have isolation in the first 100' or so above the top of > > Kuparuk though the USIT does not show this definitively. To give us the > > most positive indication of cement integrity at the top of Kuparuk > > reservoir, our plan forward is to, > > 1) Set a cement retainer at 11,900' > > 2) Perforate 2-ft intervals at 11,730' and 11,850' at 6 shots per foot > > 3) Run cement retainer on drillpipe and set same at 11,825' > > 4) Perform circulation test between two sets of perforations down > > drillpipe. Maximum surface pressure: 4000 psi. > > 5a) If circulation is possible, perform suicide squeeze with 30 bbls class 3 of 4 8/3/01 7:39 AM [Fwd: S-107i Zonal isolation confirmed] . > > > G cement, hesitate as required. > > > 5b) If circulation is not possible, POH: Isolation confirmed. Squeeze > > > cement below retainer if injection is possible, else rig down cementers. > > > 6) Drill out bridge plugs and cement, cleanout to top of 4-1/2" liner > > > (12,259' MD). > > > 6a) Run USIT if suicide squeeze was performed. Evaluate log for > isolation > > > confirmation. > > > 7) Continue with straddle-pack comple~ion procedure. > > > Please respond with questions, concerns, or confirmation of plan for > > > isolation. > > > Thanks, > > > Phil Smith > > > Operations Drilling Engineer > > > 564-4897 > > > > > > > > > > > > > > > > Name: S-lO7 Cmt Squeeze-Rev 1.doc S-lO7 Cmt Squeeze-Rev 1.doc Type: WINWORD File (application/msword) Encoding: base64 S-107 diagram MSWord. ZIP Name: S-107 diagram MSWord. ZIP Type: Zip Compressed Data > (applica tion/x-zip-compressed) > > Encoding: base64 > > S-lO7 Name: S-107 tops.xls tops.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 4 of 4 8/3/01 7:39 AM. S-107i Zonal isolation confirmed · Subject: Date: From: To: CC: S-107i Zonal isolation confirmed Wed, 1 Aug 2001 19:56:14.0500 "Smith, Phil G (FAIR)" <SmithPGl@bp.com> '"Tom Maunder (E-mail)"' <tom_maunder@admin.state.ak.us> "Bunch, Anthony $" <bunchas@bp.com>, "Vaughan, Lance A (Fairweather)" <VaughaLA@bp.com>, "Wesley, Dave E" <WesleyDE@bp.com>, "'jane_williamson@admin.state.ak. us'" <jane..williamson@admin.state.ak. us>, "Young, Jim" <YoungJ3@bp.com> Tom, Below is copy of the plan we executed to ensure zonal isolation on S-107i. I'm also attaching a more detailed "plan forward" generated and followed at the rig and a well diagram as the well is expected to be completed. The attached plan forward is more accurate and detailed than summary procedure listed below. The outcome of the procedure completed this morning was as follows: * Stabbed cement stinger into the retainer at 11,825' * Attempted circulation through newly shot perfs at 11,850 and 11,735 to 2000 psi w/10.3 ppg mud (2600 psi equivalent injection pressure with sea water), * No return flow through upper perfs. Observed bleed-off to 900 psi in 8 minutes, then stable at 900 psi. Thereafter managed 1 bpm steady injection at 1300 psi for 5 bbls. Bled down to 9000 psi in 10 minutes (Frac'ing mud into formation assumed). We have concluded from the test that the cement is providing more than adequate isolation at the toP of Kuparuk reservoir (11,900' MD) though the USlT log is inconclusive, Jim Young (production engineer) is planning to pre-produce the well and run immediate diagnostics (WFL and/or Production log) if expected production is not realized. Otherwise, the well will be converted to water injection status in October with a WFL / injection profile run within a week of injection start-up. Further diagnostics may be added if deemed prudent. Please respond after your consideration. Thanks, Phil <<S-107 Cmt Squeeze-Rev 1.doc>> <<S,107 diagram MSWord.ZIP>> > ..... Original Message ..... > From: Smith, Phil G (FAIR) Sent: Tuesday, July 31, 2001 11:25 AM To: ~ane..williamson@admin. state, ak. us' Cc: Tom Maunder (E-mail); ~julie_heusser@admin. state, ak. us'; Bunch, Anthony S; Elmore, Gary 0 (Schlumberger); Wesley, Dave E; Madsen, Alan D (Fairweather) Subject: S- 107i Zonal isolation Jane/Tom: We lost returns while running in hole and during the primary cement job on the S-107i 7" casing. Subsequently we ran a USIT and determined the 1 of 2 8/2/01 10:14 AM S-107i Zonal isolation confirmed cement was in poor condition. We then performed a "suicide squeeze" through perforations at 11,950' MD and 11,730' MD (top Kuparuk target 11,900' MD). The squeeze was executed with Dowell's "liteCrete" slurry which, by its nature, produced a questionable subsequent USIT log. We believe we have isolation in the first 100' or so above the top of Kuparuk though the USIT does not show this definitively. To give us the most positive indication of cement integrity at the top of Kuparuk reservoir, our plan forward is to, 1) Set a cement retainer at 11,900' 2) Perforate 2-ft intervals at 11,730' and 11,850' at 6 shots per foot 3) Run cement retainer on drillpipe and set same at 11,825' 4) Perform circulation test between two sets of perforations down drillpipe. Maximum surface pressure: 4000 psi. Sa) If circulation is possible, perform suicide squeeze with 30 bbls class G cement, hesitate as required. 5b) If circulation is not possible, POH: Isolation confirmed. Squeeze cement below retainer if injection is possible, else rig down cementers. 6) Drill out bridge plugs and cement, cleanout to top of 4-1/2' liner (12, 259' MD). 6a) Run USIT if suicide squeeze was performed. Evaluate log for isolation confirmation. 7) Continue with straddle-pack completion procedure. Please respond with questions, concerns, or confirmation of plan for isolation. Thanks, Phil Smith Operations Drilling Engineer 564-4897 i' Name: S-107 Cmt Squeeze-Rev 1.doc ':1 ~,S-!0,7 Cmt Squeeze-Rev 1 .doc:l Type: WINWORD File (applicationlmsword)il ;i Encoding: base64 .t Name: S-107 diagram MSWord.ZIP ':1 ~S-107 dia.qram MSWord.ZIP Type: Zip Compressed Data (applicationlx-zip-compressed)'I Encoding: base64 iI . 2 of 2 8/2/01 10:14 AM W~.LHEAD: I~C 13 5/8' ACTUATOR=- KB. ELB/= 6g.4 BF. E~EV = 35.9 KOP = 30~ Mm; Angle =100 O 15.809' Dabm MD= 12,155' D~l~m '~ D= ~745' ss 10-3~4' TAM Prat C~ar 4-1/2' 12.6~/ft L-80 NSCT Tubing IMk-,in~umlD = 3.725" XNnipple I PERFORATION SUMMKRY REF LO~: ANGLE AT TOP PERF: I 6 11.T35-11.737Open 7/31/2001 0 11.85G-11.852Opm 7/31r21N)1 4 11.950-11.952SQZ 7117/2001 5 11,900-12,150Open 7' 2e~ L-80 m-BTC S-107i x- I~pple. 3~813' ID o,.-[ "~l ~°°'1 I I 6u~ 11.a0Ol2 ~ above top pmck3a~ I · ~ \, :, · ,? , ,. ,, 4-1/2' X. $813' B 4-'1/2' XN. 3,.TZS' ID BAleRS' x7' Lber Tm Badr ~hmm 1-1!MC~ H~dlla.lk: 4-I~ x 6-3/4'" ECP ~$,019' MD '12.6 ~ L-aO. I[rc.-MOd Solid Liner 4-'1 ~?" 1Z6,t. L-80. BTC-Mod Shied Li~ W.,TO 16,026' MD End U.~r15,980' MD DATE" REv aY ....... C~ 02/02~1 j. vOUng Orig~al'l~p'o~C~l~laUm ................ -,~,,,, ~ ,.,,~.d.~,~,,~,;,.,~ ....... · .... '" :,',',,' ..... FRUIDHOEBAY t~IITIAURORA FI:ID WELI~ S-16fl PERMIt' No: 201-113 APl Nec 51Y029.-2~023 Plan Forward S-107i 7/31/01 (Rev. 1) 1900 hfs Through further review of the zone isolation process, revisions have been made to the cement squeeze procedure outlined earlier. Prepare and perform cemem squeeze, in 7" casing: 1. Set Halliburton's "Fas-Drill" composite bridge plug on Schlumberger's E-line at 11,900'. (Done) 2. Perforate squeeze holes at 11,850-52' and 11,735-37' using Schlumberger's big hole squeeze guns, each loaded at 6 jspf. This requires two gun runs. 3. Pick up Halliburton's EZ-SV drillable cement retainer on E-line and RIH. 4. Set the cement retainer at 11,825'. 5. POH and rig down Schlumberger. 6. Pick up Halliburton's star-guide and stinger for the EZ-SV on 4" drill pipe. 7. RIH to the top of the cement retainer and circulate, surface to surface, to condition mud in hole before stinging in. (Mud has not been turned over in 2 days. Thin the mud sufficiently to provide better circulating opportunities through the squeeze hole without jeopardizing ability to keep weight material in suspension.) 8. Hook up chart recorder to record pump pressures and make sure it functioning properly. 9. Sting into retainer and slowly bring pump on to establish injection/circulation rate. Carefully monitor returns and keep accurate accounting of volume pumped and volume returned. Determine if return rate improves with time. · On initial circulation attempt, limit pumping pressures to 1000 psi. (Note: Previous squeeze got circ. of 3 BPM at 1200 psi and leakofftest performed on csg. shoe was 950 psi with 10.3 ppg mud in the hole.) · If unable to pump into perfs at 1000 psi, slowly increase pressure in 200 psi increments to establish circulation or injection rate. Do not exceed 2000 psi (equivalem to 100 psi over anticipated formation face injection pressures with seawater injection.). · Do not pump more than 5 bbls if circulation is n~t established. 10. Assuming circulation rate is established, proceed with cement squeeze as follows: PJSM with all crews. Pump 2 bbls of water. Test Dowell lines to 3500 psi. Pump additional 3 bbls of water followed by 25 bbls of Dowell's 15.8 ppg Class G squeeze formulation with fluid loss control and retarder. Actual placement of cement will depend on the circulation/injection rate achieved in Step 9. If rate is low, will unsting before pumping and spot cemem to the stinger then sting back in for squeeze. · When stung in, pump 15 bbls ofcement slurry below retainer. Unsting and spot the remaining 10 bbls of slurry on top ofretainer by pmnping 7 bbls more which leaves 3 bbls inside drill pipe as a balanced plug. 11. POH 2 stands above anticipated cemem top (est. at 11,400' if circulation is achieved, assuming gauge hole between perfs and full returns). 12. Circulate out (long way) any excess cemem in the drill pipe and casing. Carefully monitor volume returns to assure them are no losses downhole through the perfs open above the retainer. 13. POH with drill pipe. This procedure is subject to change as conditions change. Please be prepared for changes. All accidems are preventable. If there are questions, just ask. No one's safety will be jeopardized for the sake of the job. Know who the Spill Champions are and what your duties are. Thanks, Lance/Bret Re: Si 107i Zonal isolation Subject: Re: S-107i Zonal isolation Date: Tue, 31 Jul 2001 16:49:38 -0800 From: Jane Williamson <Jane_Williamson~admin.state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> I spoke with Phil today at 4:30. I told him that you would have to look at this tomorrow. He said that he sent the full plans by e-mail. He indicated they have done everything they can do at this point. The do have some cement to 9250' md. They lost returns on both primary and secondary cementing. He said the Pressure test will be the definitive information for whether they have isolation. They are currently on step 2 of the procedure below. Jane "Smith, Phil G (FAIR)" wrote: Jane/Tom: We lost returns while running in hole and during the primary cement job on the S-107i 7" casing. Subsequently we ran a USIT and determined the cement was in poor condition. We then performed a "suicide squeeze" through perforations at 11,950' MD and 11, 730 ' MD (top Kuparuk target 11,900 ' MD) . The squeeze was executed with Dowell's "liteCrete" slurry which, by its nature, produced a questionable subsequent USIT log. We believe we have isolation in the first 100' or so above the top of Kuparuk though the USIT does not show this definitively. To give us the most positive indication of cement integrity at the top of Kuparuk reservoir, our plan forward is to, 1) Set a cement retainer at 11,900' 2) Perforate 2-ft intervals at 11,730' and 11,850' at 6 shots per foot 3) Run cement retainer on drillpipe and set same at 11,825' 4) Perform circulation test between two sets of perforations down drillpipe. Maximum surface pressure: 4000 psi. Sa) If circulation is possible, perform suicide squeeze with 30 bbls class G cement, hesitate as required. 5b) If circulation is not possible, POH: Isolation confirmed. Squeeze cement below retainer if injection is possible, else rig down cementers. 6) Drill out bridge plugs and cement, cleanout to top of 4-1/2" liner (12,259' MD) . 6a) Run USIT if suicide squeeze was performed. Evaluate log for isolation confirmation. 7) Continue with straddle-pack completion procedure. Please respond with questions, concerns, or confirmation of plan for isolation. Thanks, Phil Smith Operations Drilling Engineer 564-4897 1 ofl 8/1/01 1:22 PM ALASKA OIL AND GAS CONSERYA~I~ION COPl~TISSION Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. '7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit S-107 BP Exploration (Alaska) Inc. Permit No:201-113 Sur Loc: 4556' NSL, 4496' WEL. SEC. 35, T12N, R12E, UM Btmhole Loc. 2516' NSL, 3671' WEL, SEC. 21, T12N, R12E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. According to the rules provided in our letter of November 30, 2000, your request for an exception to the Diverter requirements of 20 AAC 235.035(c) is granted. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit S- 107. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the CommisSion to witness a test of BO?E installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. -- ' Daniel T' Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 2_'~ day of June, 2001 jjc/EnclOsures CCi Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Drill [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone [] Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 69.4' Prudhoe Bay Field / Aurora 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028256 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4556' NSL, 4496' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 43' NSL, 804' WEL, SEC. 21, T12N, R12E, UM S-107 Number 2S100302630-277 At total depth 9. Approximate spud date 2516' NSL, 3671' WEL, SEC. 21, T12N, R12E, UM 06/22/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028255, 1607' MDI No Close Approach 2560 15781' MD / 6855' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 97 ° Maximum surface 2769 psig, Attotal depth (TVD) 6659'/3435 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin.q Len,qth MD TVD MD TVD (include sta,qe data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 133' 133' 260 sx Amtic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC 4417' Surface Surface 4450' 2934' 579 sx AS Lite 3, 596 sx Class 'G' 9-7/8" 7" 26# L-80 BTC-M 12467' Surface !Surface 12500' 6963' 332 sx Sodium Silcate, 730 sx 'G' 6-1/8" 4-1/2" 12.6# L-80 NSCT 3431' 12350' 6839' 15781' 6855' 197 sx Class 'G' ,, , , ,,, ,,,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate LinerPr°ducti°n ~ l:{~ ~, I!!' I~/~ D Perforation depth: measured .~'~]aSI('~i O.iJ & ~{-~'S (;,'.:'!".!s. {~o~I~!li}:~jSsjO~ true vertical ' ~' ~ 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: Phil Smith, 564-4897 "' Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing jsjrue and c~o the best of my knowledge ' _ , Permit Number APl Number ,Approval Date See cover letter -~---_C) (' --'/"/.~ 50- C~ ~ ~ _ ~_. ,~ C~ :Z~ .~ . . ~, \.'~. C'~'~ {..) ~ . for other requirements ... conditions of Approval: samples' Required '1-1 Yes [] No'" Mud L'ogIR'equire(Jl [] Yes j~ No Hydrogen Sulfide Measures [] Yes ~ No Directional Survey Required <l~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 1OK [] 15K ~.3.5K psi,J~la~PU Other: Qr,~,~N,,~.,.~-.~A.,,3~X~,~,,,(~,.¢:~<~'~ \'~'"' ORIGINAL SIGNED BY by order of ~ I~_~ ~ _~pproved By ~ Taylor ~a~rr~,~v..~ ~ ~ ~ ~ , Commissioner the commission Date '~ Form 10-401 Rev. 12-01-85 Submit In Triplicate To: Commissioner, AOGCC Date: May 31, 2001 From: Phil Smith Subject: Dispensation for 20 AAC 25.035 (c) on Aurora S-107i BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale of the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent ten Aurora/Polaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first ten surface holes for the Aurora/Polaris development were drilled no deeper than the shale underlying the SV-1 sands; S-107i is planned to TD in the shallower SV-3 shale, as did the most recent wells (apart from S-106 where a diverter was installed). The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is' +500' TVD above the Ugnu horizon. The shallowest and most recent RFT points recorded in the area are from S-201, recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding 8.7 ppg EMW above 3700' TVDss. S-107i is planned to reach 9.6 ppg mud weight before TD at 2,800' TVDss. This planned mud weight, and the aforementioned RFT data, is plotted on the attached chart. Supporting surface hole gas detection information is on file with the AOGCC from recently drilled S-105. Your consideration of the waiver is appreciated. Sincerely, ADW Engineer 564-4897 0 5OO 1000 1500 2000 25OO 3000 3500 4000 Aurora/Polaris Surface Hole Mud Weight MW (ppg) 8 9 10 ~ Pore Pressure -~-S-lO0 ---- S-101 ..... --A-- S-102 ---- S-105 --e--S-103 I S-201 _ --B-- S-216 ----- S-213 .... S-104 ............. ,,~111,,~ ............ S-106 - '"'B--S-107 Plan PGS 5/31/2001 S-107i Drilling Permit I Well Name: IS-107i Drill and Complete Plan Summary I Type of Well (service ! producer ! injector): I Pre-Produced Injector Surface Location: As-Staked Target Location: Kuparuk "C" sands Bottom Hole Location: X = 618,930.16' Y = 5,980,759.77' 4556' FSL (723' FNL), 4496' FEL (783' FWL), Sec. 35, T12N, R12E Umiat X = 611,960.0' Y = 5,986,700.0' 43' FSL (5235' FNL), 804' FEL (4475' FWL), Sec. 21, T12N, R12E Umiat X = 609,050.0' Y = 5,989,130.0' 2516' FSL (2763' FNL), 3671' FEL (1607' FWL), Sec. 21, T12N, R12E Um I AFENumber: 15M0015 I I Rig: I Doyon14 I Estimated Start Date:16/22/2001 I I Operating days to complete: 135.8 I MD:1~5,78~'1 I TVD: 16,855' I I BF/MS: 135.9' I I Well Design (conventional, slimhole, etc.): I Slimhole 3-strinq I RKB' 169.4' I Objective: I Kuparuk Formation (Target zones C sands) Mud Program: 12-1/4" Surface Hole (0-4,450'): Fresh Water Surface Hole Mud Density Viscosity Yield Point APl FL PH (ppg) (seconds) (Ib/100ftz) (mls/30min) Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5 - 9.5 below -2000' MD 9.2 - 9.5 100 - 200 30 - 45 < 10 8.5 - 9.5 interval TD 9.6 max 100 25 - 35 < 10 8.5 - 9.5 9-7/8" Intermediate Hole (4,450' - 12,500' ,: Fresh Water LSND Interval Density Viscosity YP ' PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 9.2 - 10.3 40-60 20-29 8-15 8.5-9.5 6cc to 4 <10 by shoe to HRZ HRZ 6-1/8" Production Zone (12,500'- 15,781'1 4% KCI Pol'~mer Interval Density ~)isCosity YP ' PV pH ' APl Gels (ppg) (seconds) Filtrate Production 10.3 40-60 20-25 10-15 8.5-9.5 <10 5/10-10/25 Hole S-107i Permit to Drill Page 1 Hydraulics: (Wellplan Model) Surface Hole: 13 1/2" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2,000 650 5" 19.5# 1 oo 2000 10.5 N/A 4xl 6 2,000-4,478 650 5" 19.5# 100 2600 11.2 N/A 4xl 6 Intermediate Hole: 9 7/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 4,478-12,556 650 5" 19.5# 220 3250 11.1 N/A 6xl 4 0.902 Production Hole: 6 1/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 12,354 245 4" 14.0# 280 3225 11.4 8 14-14-14 0.451 15,782 245 .4" 14.0#280 3375 11.9 8 14-14-14 0.451 Directional: Ver. Sperry WP-13 KOP: 300' Maximum Hole Angle: 97° inverted horizontal well Close Approach Wells: All wells pass major risk criteria. Nearby well S-103 (at 15' center will be as close as 16.2' center-center until 500' MD, diverging thereafter. S-106 is at 45 center, diverging to a maximum of 127' at 1440' MD, converging and crossing the S-106 trajectory at approximately 2600' MD with a center-center distance of 98'. Logging Program: Surface Intermediate Hole Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu-Den / PWD Open Hole: None Cased Hole: USIT cement evaluation (after 4.5" liner) Drilling: MWD / GR / Res / Neu-Den / PWD Open Hole: None Cased Hole: None S-107i Permit to Drill Page 2 Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV6 1729 1580 Base Permafrost 2103 1860 SV5 2689 2210 SV4 3161 2390 SV3 4179 2765 SV2 4559 2905 Fault 4850 3010 SVl 5507 3300 UG4 6078 3600 UG3 6706 3930 Top Schrader {Ma) 8134 4680 8.7 WS2 Schrader Na 8552 4900 8.6 WSl Schrader OA 8752 5005 8.5 Base Obf 9313 5300 8.2 Colville mudstone 9313 5300 CMl {False HRZ) 11,1 21 6250 HRZ 11,625 6515 10.8 ppg required mud weight Kalubik 11,888 6645 Kuparuk Top {T1) 11,921 6659 Target Sand 7.7 ppg EMW due to S-100 offtake Kuparuk Top {T2) 15,781 6786 9.7 virgin pressure TD 15,781 6786 TD Criteria TD in inverted horizontal when HRZ is penetrated Casin(,/Tubing Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' G L 133/133 13-1/2" 10-3/4" 45.5# L-80 BTC 4417' GL 4450'/2934' 9-7/8" 7" 26# L-80 BTC-M 12,467' GL 12,500'/6963' 6-1/8" 4-1/2" 12.6# L-80 NSCT 3431' 12,350/6839' 15,781¥6855' Tubing 4-1/2" 12.6# L-80 NSCT 12,317 GL 12,350'/6839' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casino. Basis: Size 110-3/4" Surface Lead: Based on 2100' of annulus in the permafrost @ 175% excess and 1000' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -3100' MD (2434' TVDbkb). Lead 1 458 bbl / 2572 ft~ / 579 sks of Dowell ARTICSET Lite 3 at 1 10.7 ppg and 4.44 cf/sk. Tail 122 bbl / 685 ft~ / 596 sks of Dowell Premium 'G' at 15.8 ppg and 1.15 cf/sk. S-107i Permit to Drill Page 3 Casin~. Basis: Size 17" Intermediate Longstring I Lead: Based on TOC 500' above top of Schrader Ma formation (top hydrocarbons encountered in S-106) & 30% excess above top of Tail Lead TOC: 7300' MD, 4250' TVDbkb ITotal Cement Volume: Tail: Based on TOC 1000' TVD above top of Kuparuk C4B target and 30% excess + 80' shoe volume Tail TOC: 10,000' MD, 5719' TVDbkb Lead 1165 bbls / 926 ftc/332 sks of Dowell sodium silcate at 1 11.5 ppg and 2.79 cf/sk. Tail 1156 bbls / 876 ftc/730 sks of Dowell Premium 'G' at 1 15.8 ppg and 1.20 cf/sk. I Casing Size 1 4-1/2" Bonzai Production liner I ITail: Based on full annulus volume + 10% excess. ECP est. depth: 14,800' MD Tail TOC: 12,350' MD IT°talCementV°lume: I Lead 142bbls/236ft~/197sksofDowellpremiumGat15'8ppgand1.2cf/sk. Well Control: Surface hole will be drilled with diverter. The intermediate hole, well c'ontrol equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: · Maximum surface pressure: 3435 psi @ 6659' TVDss - Kuparuk C -Sands 2769 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 3500 psi · Planned completion fluid: 10.2 ppg filtered seawater / 6.8 ppg Diesel Disposal'. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-107i Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in p/ace. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. 4. Operations: MIRU Doyon 14. Nipple up diverter spool and riser. PU 5" DP as required and stand back in derrick. MU 13 Y2" drilling assembly and drill surface hole to +/-100' TVD below the SV3 sand top. Run and cement the 10 3,4", 45.5# surface casing back to surface. A TAM port collar will be positioned at ___1000' as contingency in the event cement does no fully circulate to surface. 5. ND diverter spool and riser and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 9 7/8" rotary steerable drilling assembly and RIH to float collar. Test the 9 5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and 20' new hole and perform LOT. Displace well to LSND drilling fluid. 8. Drill per directional plan (trip @ base Ugnu for PDC bit) through the secondary target at the Kuparuk C4B and land the intermediate hole section in the lower Kuparuk reservoir sands. 9. Short trip, circulate and condition mud, POH LDDP. 10. Run 7" 26#/ft long string casing to TD and cement to 500' TVD above the Schrader Ma, set on mandrel hanger. Displace cement with mud. 11. Freeze protect 7" x 10 3,4" annulus with dead crude to 2000' TVD by downsqueeze method after cement has gained initial compressive strength. 12. RIH with 6-1/8" directional assembly on 4" drill pipe and cleanout to 7" casing shoe. Test casing to 3500 psi. Drill out shoe and 20' new formation and perform FIT to 13 ppg EMW. 13. Change mud to 10.3 ppg 4% KCI. Drill as per directional plan Back up into Kuparuk C4B sand and TD well in the HRZ (inverted horizontal profile). 14. Short trip, circulate and condition mud, POH. 15. Run and cement 4-1/2" solid x slotted liner. ECP packer setting depth will be provided after reviewing LWD results. 16. Change well over to 10.2 ppg brine. 17. RU Schlumberger USIT log and log 7" casing from top of 4 Y2" liner to the top of tail cement 1000' TVD above the Kuparuk reservoir. 18. Pick up DPC perforating guns and perforate 500 psi underbalance with diesel in the upper Kuparuk sands through the 7" casing. Reverse circulate, POH, LD guns. 19. Run 4-1/2", 12.6# L-80 straddle completion string (w/3 Y2" tailpipe) positioning the WLEG into the liner tieback receptacle. 20. Set packers and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 21. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 22. Freeze protect the well to ~2200' and secure the well. 23. Install BPV. Secure the well and rig down / move out. Estimated Spud Date: 6-22-2001 Phil Smith Alaska Drilling & Wells 564-4897 S-107i Permit to Drill Page 5 Job 1: MIRU Hazards and Contingencies ~ Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad in the last 12 months was on S-40 @ 70 ppm, (January 2001). The closest wells to S-107i are S-103, and S-104i. Both measured 8 ppm at their last tests. S-100 and S-101 are the closest BHLs to S-107i, with readings of 8 ppm. Well S-103 is located 15' north of planned well center and will require shut-in for the rig move. Lines will be depressurized and freeze protected as required. Materials have been staged on S-Pad as contingency for bridge outage. Reference RPs Operational Specifics · Job 2: Drillinq Surface Hole Hazards and Contingencies No faults are expected to be penetrated by S-107i in the surface interval. S-103 and S-106 wells both have close approach issues in the surface hole. All wells pass major risk criteria. Nearby well S-103 (at 15' center will be as close as 16.2' center-center until 500' MD, diverging thereafter. S-106 is at 45 center, diverging to a maximum of 127' at 1440' MD, converging and crossing the S-106 trajectory at approximately 2600' MD with a center-center distance of 98'. ~ The SV4 sand may contain gas hydrates, though little or none have been encountered thus far in the recent S-pad development. Hydrates will be treated at surface with appropriate mud products. Reference RPs Operational Specifics · Job 3: Install surface Casinc~ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 10 port collar will be positioned at _+1000'MD to allow a secondary circulation as required. Reference RPs Operational Specifics S-107i Permit to Drill Page 6 Job 4: Drillinq Intermediate Hole Hazards and Contingencies ;> S-107i will cross a 90' throw fault in the SV2 interval. S-106 experienced losses in the fault, though crossed in the surface hole and halted after 250 bbls lost. The well trajectory is designed to pass through the fault below the surface casing and to pass over a second smaller fault just after the first. Pre-treat with LCM before crossing the fault. ;> The surface casing point is chosen just below the SV3 sands, leaving the SV1 exposed for the j¢ ~,~ ~/~ .3¢¢ hole. The Kuparuk reservoir will also be exposed at the toe of the intermediate hole section and the upper sands are expected to be depleted by S-100 to an EMW of 7.7 ppg. The potential for differential sticking is high in this hole section, but especially prevalent in the Kuparuk. Keep tight tolerances on mud properties to produce a thin filter cake; the BHA will incorporate an adjustable gauge stabilizer to reduce sliding time. These, coupled with proper drilling practice and mud/LCM maintenance, can adequately manage the differential sticking concern. ;> 10.3 ppg mud is recommended to reduce differential sticking and breathing experienced on S- 106. This is lower than the required mud weight for this hole angle as indicated on the HRZ plot, however recent experience has suggested that the HRZ may be more forgiving in this area of the field than in the main Prudhoe Bay. Nevertheless, it will be prudent to watch for signs of shale instability after drilling the HRZ and weight up to as high as 11.0 ppg if required. ~> KICK TOLERANCE: Intermediate 9 7/8" open hole section is 106 bbls, assuming an influx from the Kuparuk interval at -12,000' MD. This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.3 ppg mud in the hole. Rig will perform LOT after drilling 20 ft of new formation. Contact Drilling Superintendent if LOT >12.5 ppg EMW cannot be obtained. Reference RPs Operational Specifics Job 6: Case/Cement Intermediate Hole Hazards and Contingencies ;> The Ugnu 4A is not expected to be oil bearing; S-106 showed significant hydrocarbons only as high as the Schrader Ma sands. For this reason the 7" casing will be cemented to 500' above the Schrader Ma. This should be verified with LWD resistivity Icg. After freeze protecting the 7" x 10 3A" casing annulus with 65 bbls of dead crude, the hydrostatic pressure alone will be less than the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Expect trapped annulus pressure after pumping the dead crude. Reference RPs Operational Specifics S-107i Permit to Drill Page 7 Job 7: Drill Production Hole Hazards and Contingencies ~ Two fault crossings are planned shortly after drilling out the 7" shoe. The first faults has 200' throw, the second approximately 40' The fault of lesser throw is more apt to create mud losses, though both have the potential to do so. Y The fault crossings will result in considerable geologic uncertainty in the 6-1/8" hole section. The well will not be "geo-steered" per se, but drilled back through the Kuparuk at high angle until the Kalubik overlying the Kuparuk is encountered. Reference RPs Operational Specifics Job 9: Case & Cement Production Liner Hazards and Contingencies ~ Verify that the hole is in the best possible condition prior to POH for liner. Frictional forces and gravity will be working strongly against getting the liner to bottom in this inverted (98°) profile. Reference RPs Operational Specifics Job 10: Perforate Well Hazards and Contingencies ~ The well will be perforated 500 psi underbalanced. Ensure all responsibilities are clearly communicated with respect to perf gun and fluid handling. Watch hole fill closely while POH with perf guns. Reference RPs Operational Specifics Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be perforated and open via the slotted liner. Reference RPs S-107i Permit to Drill Page 8 Operational Specifics Job 13: ND/NU/Release Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics S-107i Permit to Drill Page 9 WELLHEAD= FMC 13 5/8" ACTUATOR= KB. ELEV = 69.4 BF. ELEV = 35.9 KOP = 300' Max Angle =97.6 @ 14,595' Datum MD = 12,155' Datum TVD= 6745' ss 10-3/4" TAM Port Collar 9-5/8" 40# L-80 BTC ! 4-1/2" 12.6#/ft L-80 NSCT Tubing Minimum ID = 2.813" @ X nippleI S-107i \FETY NOTES: ACTUAL DEFTHS WILL · ,E PROVIDED BEFORE COMPLETION 2300' ] I X-Nipple, 3.813" ID I STA MD TVD I DEV ITYPEMAN LATCH I I GLM4 3800' GLM3 11,800 2 jts above top packer I MMGW 6750 3-1/2" x 1-1/2" MrVlGW 6800 3-1/2" x 1-1/2" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: ~ Noto: Refer to Production DB for historicalperf ata SIZE SPF INTERVAL Opn/Sqz DATE I 7" 26# L-80 m-BTC I I 12500' 4-1/2" 12.6 #Iff, L-80, BTC-Mod Solid Liner 111880' I I4-1/2'' x' 3'813'' ID I Ill,9°°' I I Baker Premier PKR I 112,°°°' I 4'1/2" X' 3'813" ID I I 1 2,0SO' [ 1 2,'i40' I 4-1/2" Ported Nipple, 3.25" no-go ID XO, 4-1/2" x 3-1/2" J 12,240' Camco Inj. MMGW 12,300' Camco Inj. MMGW 12,370' 3-1/2" X, 2.813" ID 12380' Baker Premier PKR 12,390' I I 3-1/2"X, 2.813" ID I I BAKER 5' x 7" Liner Tie Back Sleeve 1 2,400'MD ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 4-1/2" x 6-3~4" ECP 14,700' MD 4-1/2" 12.6 #Iff, L-80, BTC-Mod Slotted Liner Well TD 15781' MD PBTD 15700'MD DATE REV BY COMMENTS 02/02/01 J. Young Original Proposed Completion 06/11/01 PGS Revised Proposed Completion PRUDHOE BaY UNIT/AURORA FIELD WELL: S-107i PERMIT No: APl No: 50-029- BP Alaska Drilling and Wells A asks Drdhng & Wells $-107 WP13 Current Well Properties : Proposal Data for S-107 WP13 Well: S-107 Horizontal Coordinates: Ref. Global Coordinates: 5980759.77 N, 618930.16 E Reft Structure Reference : 112.54 S, 1011.78 E Ref. Geographical Coordinates: 70 21' 21.9134" N. 210' 57 57.1439" E RKB Elevation: 69 40ft above Mean Sea Level 69.40ft above Structure Reference North Reference: True North Units: Feet (US) Begin Blt @ 1.500/100ff: 300.00ft MD, 300.00fl TV[} Increa~ in DJ{ Rale @ 2.50*/100fJ: 60O.0OfJ MD 599.69ft TVD 1500 3OOO 4500 6000 7500 \ Begin [}ir ¢~ 6,OO°/100ff: 5086.72ft ~,~D, 3168,68a TVD D~rease in Dir Rate ¢' 4.00 /100~t: $089.77ft MD, 3169.80ff TVD End Dir, Start Sail @ 58,300~; 5343,26ft~D,3283.19ftTVD ~0o o0 DDI = 6.3 i I 0 1500 3000 4500 6000 7500 9000 10500 12000 ~ 3500 o Scale: 1 inch = 1500ft Vertical Section Section Azimuth: 311.1 o7" (True Nodh) 4500 oooo 3ooo '%.~°° ~ Begin Oir ~ ~,~/lO01t: ~86.7 t MD, 3168.68~ TVD Horizontal C~rdinates; 4" cas~ 500 Ref. Global Coordinates:5980759.77 N, 618930.16 E ~o s~ 8o0 oo Ref. Structure Reference : 112.54 S, 1011.78 E 4450,37' MD Ref. Geographical Coordinates: 70~ 21' 21.9134" N, 210' 57' 57.1439" E 2934,3o, TVD ~500 00 RKB Elevation: 69 40ft above Mean Sea Level ~ End Pit, Slad 88il 8 68,388"; 2839,52ftMD,2341,00ftTVD 69,40ft above Structure Reference ~, / ~ North Reference · True N rth ~0 t~; JE~ pit, start sait ~ 45.2~s~ :2032,3~ft~P,~STg.4OftTW 10500 9000 ~7500 -6000 4500 3000 ~ 500 0 Scale: ~ inch = ~ 500fi Easfings Reference Js True No~h DDJ = Sperry-Sun Anticollision Report Date: 06/05/2001 Time: 14:22:40 Co-ordinate(NE) Reference: Well: S-107, True North Vertical (TVD) Reference: Plan S-107 69.4 69.4 Page: Company: BP Amoco 1 Field: Prudhoe Bay Reference Site: PBS Pad Reference Well: S-107 Reference Wellpath: Plan S-107 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/10O0 of reference - There are 'l~t~g~mldls in this fl~qfllcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 33.20 to 15781,42 ff Scan Method: Trav Cylinder North Maximum Radius: 1774.82 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 01/29/2001 Validated: No Version: 34 Planned From To Survey Toolcode Tool Name ft ft 33.20 1000.00 Planned: S-107 wp13 V1 CB-GYRO-SS Camera based gyro single shots 1000.00 15781.42 Planned: S-107 wp13 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MDft TVD ft Diameter in Hole Size in7"4103/4" 1/2" Name· ....... 4450.63 2934.40 10.75 12.25 12556.00 6978.74 7.00 9.88 15812.99 0.00 4.50 6.12 Summary Site ' · Well ' . · Wellpath ':'. .... ' MD .'. '. 'MD' Distance Area. ' Deviation ' Warning · ' .' ' . . . ' = .' . ' ." . ' ' ..'.ft: '' .':"ft ' , '.ft · "ft' ' ftl ,' '" .. :RiSk' :': i RiSk: : ':: Plan S-108 Vi 1 :Plan: S. · 449,28 Plan S-110 VlO Plan.'. S 498.36 Plan S-112 v5 Plan: S- 625;37 S-200PB1 V4 471.10. S-200 V2 Plan: Undefin '471.10 S-201 V2 275.00 S-201PB1 V9 '275.00 · Plan S-202 V0 Plan: S- 449.09 S-213 V6 398.22 Plan S-214 V1 Plan: S- 398.11 S-216 V9 348.92 450.00 500.00 625.00 475.O0 475;00 275.0O 275.O0 450.00 '40O.00 400.00 350.00 .:::i:1:6:~:51!':;:;"::58~:92. PaSs'::Maj0r':R:iSk .:::~::::: ,:: ::.NO;Ref:erence: Casings i,;~1 45.64 10.47 35.18 Pass: Major Risk 76.13 11.56 64.57 Pass: Major RiSk 59.73 13.76 45.96 Pass: MajOr Risk ~!:~ 256.46 · 8.82 247.66 Pass: Major Risk 256.46 · 8.93 247.55 Pass: Major Risk 30.83 ' 6.04 24.78 Pass: Major Risk 30.83 ' 6.00 24.83 Pass: Major Risk 60.96 10.09 50.88 Pass: Major Risk 211.12 7~57 203.56 Pass: Major Risk 225.50 7.92 217.58 Pass: Major Risk 240.57 · 8.19 232.38 Pass: Major Risk . .. Reference · · · Semi;Major.Axis: "'" ..... Cfr-Cfr: No-G° .Allow-able .. .. MD. MD .. TVD · Ref ' offset· TFO~AZI T.FO.HS' casing . ··Distance Area Deviation· Warning.. 'i ft :' "ft" ft '. ' . .ft '.. ft "'ft"." deg" deg ' in.' :' '"'ft ' ' ft .' · ft .... .. · ~' ........................................... ~ ................................... ~-~,-:~-~..~ .......... ~...,~ .........~.-~--_~ .._~.; ................. .,:.,..- ................ .L.,.. .............. ~ .......... 33.20 33.20 33.20 .33.20 0.00 · 0.00 0.51 0,51 .12.25 45,27. 1.02 44.25 Pass 50,00 50.00 , 0,04 1.64 43.64 ' 75.00, ':, ::43!03 ': i' 100,00:::::, i::i, := :': ::' :125:00 ': '0.24':::: ,= 0;33 150,.00 ' :150100 ~ : :1:50:00 :: !4577:::: :::~;i~i: :i: ~::: :pa~S 175.00:: :' .;i:75.00}. :': :1'75:00 .::: ::0.4!:': :: 0:~8! :: :: !0;51:::': ::.::::!:: I! .:4S.'27~:.: = ::5'~:1;I:;::: :pass:.:::;:. '200;00 200::i00 ::200 00 i::!:200;00 ::: .::::: 0:50: :: 0:54:. ::: 0:51;':? :.~; ::,c :45127: :";:~.'5.8(~ : 39 47 : pass: :i: ':' :::: :225.00 ':. 225i00:::: 2251o0:~i::::',:: :;225;0o :::;.~o',55;::: :.i:.: ::.0~59:: :: ;:i 0146: ': ~::: ~:::: ! ;:~5':3o:. ;613(i:: :38194, '..::pass.:: :. :: :: : 25O.oo :.:: :: :250ioo 250:00/ :25o:Oo: ;:.!?.o:61:.i'.:::~ ~.; ::0163: ::: ::;.0i26 ;::: i: o::26:;:::.: ;: !;~ 1:45;;41::' h;6.:9o::j.:::: 38.51 .: :.ipass:. : ::: 'THIS NOTICE IN THE DOGHOUSE ~" S-107i Ri_qsite Summary of Drilling Hazards ,/ Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad in the last 12 months was on S-40 @ 70 ppm, (January 2001). The closest wells to S-107i are S-103, and S-104i. Both measured 8 ppm at their last tests. S-100 and S-101 are the closest BHLs to S-107i, with readings of 8 ppm. v' Well S-103 is located 15' north of planned well center and will require shut-in for the rig move. Lines will be depressurized and freeze protected as required. v' S-103 and S-106 wells both have close approach issues in the surface hole. All wells pass major risk criteria. Nearby well S-103 (at 15' center will be as close as 16.2' center-center until 500' MD, diverging thereafter. S-106 is at 45 center, diverging to a maximum of 127' at 1440' MD, converging and crossing the S-106 trajectory at approximately 2600' MD with a center-center distance of 98'. v' The SV4 sand may contain gas hydrates, though little or none have been encountered thus far in the recent S-pad development. Hydrates will be treated at surface with appropriate mud products. v' S-107i will cross a 90' throw fault in the SV2 interval. S-106 experienced losses in the fault, though crossed in the surface hole and halted after 250 bbls lost. Pre-treat with LCM before crossing the fault. v' The surface casing point is chosen just below the SV3 sands, leaving the SVl exposed for the 8-3/4" hole. The Kuparuk reservoir will also be exposed at the toe of the intermediate hole section and the upper sands are expected to be depleted by S-100 to an EMW of 7.7 ppg. The potential for differential sticking is high in this hole section, but especially prevalent in the Kuparuk. v' 10.3 ppg mud is recommended to reduce differential sticking and breathing experienced on S-106. This is lower than the required mud weight for this hole angle as indicated on the HRZ plot, however recent experience has suggested that the HRZ may be more forgiving in this area of the field than in the main Prudhoe Bay. Nevertheless, it will be prudent to watch for signs of shale instability after drilling the HRZ and weight up to as high as 11.0 ppg if required. v' Intermediate 9 7/8" open hole section is 106 bbls based on planned hole conditions. ¢' Two fault crossings are planned shortly after drilling out the 7" shoe. The first faults has 200' throw, the second approximately 40' The fault of lesser throw is more apt to create mud losses, though both have the potential to do so. v' Verify that the hole is in the best possible condition prior to POH for liner. Frictional forces and gravity will be working strongly against getting the liner to bottom in this inverted (98°) profile. v' The well will be perforated 500 psi underbalanced. Ensure all responsibilities are clearly communicated with respect to perf gun and fluid handling. Watch hole fill closely while POH with perf guns. v' Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be perforated and open via the slotted liner. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. VENDOR ALASKAOILA O0 DATE ' INvOIcE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT ' "~ET 051401 CK05140li 100.00 100.00 PYMT COMMENTS: Peen it to, Drill Fee HANDLING INST: S/H - Te~rie Hubble X4628 ,. THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DE$CRIBED ABOVE. m,l[e]lL,1~ "~ 100. O0 100. O0 PAY BP, (ALASKA) INC, ..ST.AT, O.^'.^N. OF AS.~... ~J AFFILIATE OF RO. BOX 196612 NATIONAL,CITY BANK ANCHORAGE, ALASKA 99519-6612 C'EVELAND O.~O 56,389 ~ 412 DNE:,. HUNDRED & OO/100~-w-~-~..x-~~'.~-..x-~,~ No. Hi'' CONSOLIDATED T,O The ORDER O~ ',ALASKA OI, L AND QAS ""ii:~0NE~ERv~T I oN .CoMMI SS ION '~??,:I~IES~'. 7TH AVENUE sUITE ~OO. ANCHORAeE AK 9950 T ~RANSMITAL LETTER CHECK LIST{ CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 CHECK WHAT APPLIES STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D~POSAL ('~-) NO ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES + SPACING EXCEPTION "CLUE" The permit is for a new wellbore segment of existing well , Permit No, ~ APl No. ~. Production should continue to be reported as a function of the original AP1 number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and APl number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... : Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated Enclosed is the approved application for permit t° drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are Ioc'XCate~m ............................. drive~jody\templates ~_~ WELL PERMIT CHECKLIST FIELD & POOL _~ ADMINISTRATION COMPANY ,~,,r · INIT CLASS ENGINEERING WELL NAME ~'--/'~:~ ,~ PROGRAM: exp ~ ~.v.~ /-~/ GEOL AREA 1. Permit fee attached; ...................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ............ 14. Conductor string provided ................... 15. Surface casing protects all known USDWs...' ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T. B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. dev ~ redrll ~ serv~ wellbore seg ann. disposal para req ~ GEOLOGY 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ........... ..~... 26. BOPE press rating appropriate; teSt to "~,~'['~ ~ psigl 27. Choke manifold complies w/APl RP-53 (May 84) .... .... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. ,,~ .~,-,;) UNIT# // ~',~ ~ ON/OFF SHORE ~ ,, J 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ..... ........ 33. Seabed condition survey (if off-shore).... ......... 34. Contact name/phone for weekly progress reports [exploratOry ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well'used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25;252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular _ COMMISSION: Comments/Instructions: 0 Z 0 rn Z .-I -1- c:\msoffice\wordian\diana\checklist (rev. 11/01//00)