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Home My WebLink About200-168Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 8, 2025 Torin Roschinger PBW Operations Manager Hilcorp North Slope LLC 35800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number OTH-25-007 Notice of Violation – Missed Safety Valve Test Closeout Prudhoe Bay Unit S-103 (PTD 2001680) Dear Mr. Roschinger: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed Hilcorp North Slope LLC (Hilcorp)’s February 17, 2025, explanation regarding the failure to properly test the safety valve system on Prudhoe Bay Unit S-103. Hilcorp has satisfied the request made in our February 5, 2025, notice of violation. The AOGCC does not intend to pursue any further enforcement action regarding the Prudhoe Bay Unit S-105 safety valve system testing violation. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Phoebe Brooks Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.10.08 15:12:13 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.10.08 15:25:03 -08'00' Hilcorp North Slope, LLC Torin Roschinger, PBW OperaƟons Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 02/17/2025 Commissioner Jessie Chmielowski and Commissioner Greg Wilson Alaska Oil and Gas ConservaƟon Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Docket Number: OTH-25-007- Missed Safety Valve System Test for PBU Well S-103 (PTD# 2001680). Dear Commissioners Chmielowski and Commissioner Wilson, Following the discovery of the missed SVS test on PBU well S-103, Hilcorp iniƟated an invesƟgaƟon to determine the causes of the missed test and determined acƟons to prevent recurrence. The invesƟgaƟon determined the following: Overview In our well informaƟon database, past, current and future wellbores are diīerenƟated from each other through their disƟnct well names, associated PTDs and Well Status. An example of this is S-103 (PTD# 200168) (Oil Well) vs S-103A (PTD# 223059) (Not Completed). The database transiƟon point from one wellbore to the next is determined by a series of dates including the “EīecƟve Start Date” and “Spud Date” recorded for each bore. “EīecƟve Start Date” is the top in the hierarchy for a bore and is generally entered only once a new wellbore is drilled. In the absence of an “EīecƟve Start Date” being entered, the bore’s “Spud Date” would be used to determine when a wellbore became the acƟve current bore. The acƟve current wellbore is then referenced in downstream applicaƟons such as the SVS tracking tool used in Prudhoe Bay. Through an input error in our database, 7 permiƩed and undrilled sidetrack producƟon wells were given false “Spud Dates”. In the case of S-103, the current acƟve wellbore was superseded by the planned, upcoming S-103A sidetrack in the database to facilitate well work tracking. Since wellbore S-103A did not yet exist, and there was no producƟon data associated with this wellbore, the SVS tracking tool and reports did not Ňag the well as needing an SVS test when it was brought online on 8/20/2024. Based on a proacƟve internal audit, these “Spud Date” database errors were idenƟĮed and corrected on 1/30/2025 and S-103 showed as overdue for a SVS test in the automated reports the morning of 1/31/2025. The other 6 wells associated with this error were reviewed in the SVS tracking tool and all are current on their SVS tesƟng. The SVS tracking tool is used in Prudhoe Bay only and this error did not aīect SVS tesƟng in other Hilcorp-operated Įelds. This incident has been communicated to the database team and their work procedure will be updated to ensure that it does not happen again. Root cause of the incident: x The esƟmated “spud date” was modiĮed for upcoming sidetrack wellbores to facilitate the workŇow of post-rig wellwork, causing downstream applicaƟons to report inaccurately. ContribuƟng factors of the incident: x Inadequate awareness and review of potenƟal outcomes caused by the database change. x Inadequate process to review wells where the “Spud Date” was manipulated to correct the database for those wells that had been removed from the drilling schedule. AcƟons to prevent recurrence: x Update of Drilling Technologist procedure: o “EīecƟve start date” will be entered only once a new wellbore is drilled. o No esƟmated “spud dates” to be entered in the database. Should you have any further quesƟons, please contact me at (406) 570-9630. Sincerely Torin Roschinger PBW OperaƟons Manager Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.02.17 15:05:23 - 09'00' Torin Roschinger (4662) Well database team begins to enter estimated rather than actual spud date for upcoming wells in “Spud date” data field~2018“Spud_date” intentionally modified for upcoming sidetrack wellbores.2023PBU S-pad receives routine 180 Day SVS Testing 8/10/2024S-103 is PoppedSVS tracking tool is used by Operations to flag wells with on-time that require a miscellaneous SVS test.PBU Historic PracticePage 1/2Tool logic is such that “Current” wellbore is determined by looking at date well bore is considered to have startedEstimated “Spud_Date” s were brought forward artificially in time to show upcoming sidetracks as “current” wellboreSVS tracking tool looks for production/injection from a well’s “current” well bore to flag if a test is neededIn the absence of any entry in the 3 other data fields, SSSV tool will use “Spud_date” to determine “current wellbore”Wellwork management system would only allow for wellwork to be scheduled against system’s “current” assigned wellbore.S-103 last routine SVS test was on 2/10/2024, but well had been SI on 8/7/2024 and does not receive pad level SVS testing.8/20/2024S-103 Overdue SVS TestSVS tool shows S-103 as not requiring SVS test S-103’s production assigned to S-103 wellbore. SVS tool logic sees “current” S-103A wellbore with no assigned production and determines not test required. Operator checks SVS tracking tool to confirm if well needs testingChanges that affect “Current” wellbore will not be done without review of potential effects to compliance tools10-3 Inadequate Assessment of Potential Failure – Use of “Spud-Date” in downstream compliance applications not recognizedDate that bore is considered to have started is determined by SVS tool review of 4 wellbore data fields. Hierarchy for which date is used is 1)Effective_start_date, 2) Date_init_service, 3) Date_rig_release 4) Spud_dateEffective_start_date will be entered only once the new wellbore is drilled. This is reflected in updated “Well Headers (AOGCC)- Alaska Specific” procedure3-1 Lack of Knowledge of Hazards PresentEngineers requested ability to assign upcoming wellwork to upcoming sidetrack wellboresDate workaround instituted to satisfy Engineer request CFPBU S-103 is planned and permitted to be sidetracked as S-103A8/16/2023The S-103A wellbore “Spud_date” is set to 09/15/2023 to make S-103A visible as “current wellbore” in wellwork management systemIn the instance of canceled or delayed sidetracks, estimated spud date creates the potential for incorrectly assigned “current wellbore”4-1 Improper Decisions Making or Lack of Judgement8-5 Inadequate Management of Change System – Workaround change not reviewed with all stakeholders to confirm risks of changeAutomated check of wellbore “effective_start_date” created against wellbore “effective_end_date” to identify overriding or incorrectly entered datesOFIDate workaround was not reviewed against potential downstream affects to compliance tools9/1/24S-103 lapses SVS testing required within month of AugustS-103 is ultimately not sidetracked to S-103A and is instead left producing from original S-103 wellbore.1-111 Other - Following ProcedureOFI14.1 Lack of PSP for the task – There was no established procedure for removing wellbores that had been removed from drilling schedule.Addressed by the update of “Well Headers (AOGCC) – Alaska Specific” procedure to discontinue the use of Pre spud dates. CFOpportunity for ImprovementCritical/Causal FactorOFIS-103 flagged as overdue in automated compliance report that query's SVS tool1/31/205Corrective Action System CauseImmediate CausePage 2/2HAK performs self audit of Well Types with respect to Production Accounting and AOGCC well databasesJanuary 2025Discrepancies noted in 7 undrilled future sidetrack wells incorrectly showing as current wellbore 1/30/2025Artificial “Spud_dates” removed on future sidetrack wells“Current Bores” on 7 undrilled sidetracks revert to correct existing boresAOGCC emailed of missed SVS test on S-103Discrepancies attributed to artificial “Spud_date”s entered for well workflow managementWitness notification made for SVS test of S-103 (waived) and test performed (passed)Remaining 6 wellbores that had been supersede by undrilled future sidetracks identified and confirmed to have received their routine SVS tests where requiredS-103 Overdue SVS TestPending Corrective Action Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govFebruary 5, 2025 CERTIFIED MAIL – RETURN RECEIPT 7017 2400 0000 5648 0992 Mr. Torin Roschinger, Operations Manager Operations Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH 25-007 Notice of Violation Missed Safety Valve System Test PBU S-103 (PTD 2001680) Dear Mr. Roschinger: On January 31, 2025, the Alaska Oil and Gas Conservation Commission (AOGCC) was notified in email correspondence from Hilcorp North Slope LLC (Hilcorp)’s Well Integrity Supervisor of a missed safety valve system test at Prudhoe Bay Unit (PBU) S-103. The well was shut in during the PBU S-pad 180-day safety valve system tests completed on August 10, 2024. Hilcorp reported that PBU S-103 was returned to production on August 20, 2024, and continued to produce without the required safety valve system test. AOGCC records confirm Hilcorp neither notified AOGCC for witness nor provided results of a safety valve system test on PBU S-103. The facts reported by Hilcorp indicate a failure to test an operable safety valve system, which would be a violation of State regulations. Hilcorp’s Well Integrity Supervisor indicated in email correspondence that Hilcorp is currently investigating the cause of this violation. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a copy of Hilcorp’s investigation report describing how this missed safety valve system happened and what has or will be done in the future to prevent its recurrence at Hilcorp-operated fields. The AOGCC reserves the right to pursue additional enforcement action in connection with this Notice of Violation. Questions regarding this letter should be directed to Jim Regg at (907) 793-1236 (jim.regg@alaska.gov). Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: P. Brooks AOGCC Inspectors Oliver Sternicki (oliver.sternicki@hilcorp.com) Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.02.05 15:04:20 -09'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.05 15:35:27 -09'00' CAUTION: 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:Oliver Sternicki To:Regg, James B (OGC) Cc:Torin Roschinger; Wyatt Rivard; Lau, Jack J (OGC); Rixse, Melvin G (OGC) Subject:S-103 (PTD# 200168) Overdue SVS Test Self Report Date:Friday, January 31, 2025 3:37:37 PM Mr. Regg, S-103 was due for routine SVS testing in August 2024, the previous test passed 2/10/2024. The well was shut-in on 8/7/2024 and did not get a routine test with the rest of the pad on 8/10/2024. The well was then placed on production on 8/20/2024 and has been flowing since then. Our automated systems did not pick up this overdue test until the well started showing in reports today. AOGCC inspectors were contacted earlier today and waived witness, the lead operator executed the test immediately and the test passed, We are currently investigating the cause of our SVS tracking application not flagging this well as being due for testing and our automated reporting system not properly alerting. I will relay these findings to you when we have some answers. Let me know if you have any questions. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor 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, 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. 7.7.2023 By Grace Christianson at 2:39 pm, Jul 07, 2023 323-377 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.07.07 10:46:05 -08'00' Monty M Myers DSR-7/7/23 10-407 Variance to 20 AAC 25.112(i) approved for alternate plug placement with fully cemented liner on upcoming CTD sidetrack. BOPE test to 3500 psi. MGR10JUL23 MDG 7/17/2023JLC 7/17/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:13:30 -05'00'07/18/23 RBDMS JSB 071823 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: July 6, 2023 Re: PBU S-103 Sundry Request Sundry approval is requested to set a whipstock and mill the window in S-103 as part of the drilling and completion of the proposed S-103A CTD lateral. Proposed plan for S-103A Injector: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. Service coil or eline will mill four XN nipples to 2.80". E-Line will set a 3-1/2"x7" HEW (whipstock) with the DPU (for slow set). See S-103A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set pre-rig, a 3-1/2"x7" HEW whipstock will be set with the rig. A 2.80" window +10’ of formation will be milled out of the 7” casing. The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 2-3/8” L-80 solid liner and cemented in place. The well will be selectively perforated post rig (see future perf sundry). This completion will completely isolate and abandon the parent Kuparuk perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start in August 2023): 1. Coil or E-Line: Mill four XN nipples a. Mill to 2.80” 2. Slickline: Dummy WS drift and Caliper a. Drift past whipstock setting location b. Caliper 7” for whipstock setting location 3. Fullbore: MITs to 2,500 psi 4. E-line: Set 3-1/2”x7” HEW (Whipstock) a. Set top of whipstock at 9,554’ MD b. Set highside (0° ROHS) c. Utilize DPU for slow set 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU S-103A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,292 psi 2. Set HEW (whipstock) – only if not done pre-rig 3. Mill Window 4. Drill Lateral 5. Run and Cement Liner* 6. Freeze Protect and RDMO 7. Set LTP* (if needed) and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Sundry 323-377 pyp This completion will completely isolate and abandon the parent Kuparuk perfs. 2-3/8"LNR, 4.7#, L-80, Hyd 511 12155' Milled to 2.80" 3-1/2" x 7" FLOTHRU WS (__, __, __) MILLOUT WINDOW (S-103A) 9558' - ____ A ___-___ -01-00 9556' 9400'2-3/8" Top of Liner / Cement PROPOSED A 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 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" 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 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,July 25, 2017 9:44 AM To: s AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK,OPS Prod Controllers;AK, OPS WELL PAD S;AK, OPS Well Pad SW;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie; Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions 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; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer S-103 (PTD#2001680) Barriers Confirmed All, Online diagnostics on Producer 5-103 (PTD#2001680)was reported to have inner annulus pressure over NOL on 06/22/17. A warm TIFL passed on 07/24/17 and a passing MIT-IA on 9/26/05 indicate two competent well barriers. At this time the well is reclassified as Operable. Work Completed/Plan Forward: 1. Downhole Diagnostics:Cold TIFL—Failed 06/23/17 2. Operations: POP well—Completed 07/08/17 3. DHD: Warm TIFL—Failed 07/11/17 4. Slickline:Change out orifice gas lift valve—Completed 07/23/17 5. DHD:Warm TIFL—Completed 07/24/17 6. Well Integrity Engineer: Additional Diagnostics as required Please reply if in conflict with proposed plan. Thanks, Matt Ross (Alternate: Josh Stephens) SCANNED At-IG 9 2017 Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday,July 19, 2017 5:08 AM To: AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S; AK, OPS Well Pad SW;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie;Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: UPDATE 07/19/17: UNDER EVALUATION: Producer S-103 (PTD#2001680) Inner Annulus over NOL - Failed TIFL All, Online diagnostics on Producer S-103 (PTD#2001680)were delayed due to a pad shut-down.Slickline is scheduled to change out the orifice gas lift valve within the next week.The Under Evaluation clock is reset for an additional 14 days. Work Completed/Plan Forward: 1. Downhole Diagnostics: Cold TIFL—Failed 06/23/17 2. Operations: POP well—Completed 07/08/17 3. DHD: Warm TIFL—Failed 07/11/17 4. Slickline: Change out orifice gas lift valve 5. DHD:Warm TIFL 6. Well Integrity Engineer: Additional Diagnostics as required Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska ww11,i% 0 '7 701 i (Alternate:Jack Lau) SCrMw�� 0:(907)659-5102 C:(907)943-0296 H:2376 From: AK, GWO - tegrity Engineer Sent: Friday, June 23, 21 • 5 AM To: AK, GWO Well Integrity Engineer, - I'S GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; A , :• OC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, •' ELL PAD S; Regg, James B(DOA) (jim.regg@alaska.gov); Youngmun, Alex Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AKIMS App • • Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, • , R; Worthington, Aras J; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer S-103 (PTD#2001680) Inner Annulus over NOL - Failed - 1 i • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday,June 23, 2017 5:15 AM To: AK, GWO Well Integrity Engineer;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S; Regg,James B (DOA);Youngmun,Alex Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer S-103 (PTD#2001680) Inner Annulus over NOL- Failed TIFL All, Gas lifted Producer S-103 (PTD#2001680)exceeded NOL on the inner annulus and failing a subsequent TIFL on 06/22/17. Operations could not pop the well for a warm TIFL due to a pad shutdown. The current estimate for S pad to come back online is 06/30/17. At this time the well is classified as Under Evaluation,and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Operations- POP well 2. Down Hole Diagnostics: Perform Warm TIFL 3. Well Integrity Engineer:Additional Diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 SCANNED 42017 1 Ima~ ?rojectWell History File Cover( age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O O- ] ~2 ~ Well History File Identifier Organizing RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: OVERSIZED (Scannable) [] Maps: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation ~ x 30 = ? ~ BY: BEVERLY ROBIN VINCENT SHERYL~INDY [] Other Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: / ~5 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ~i YES ~ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAF~"W~RE FOUND: YES .~ _.O RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE; IS~ Quality Checked 12/10/02Rev3NOTScanned.wpd • • ~ BP Exploration (Alaska) Inc. ~ Attn: Well Integriry 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, :ybtl~r~'f~iPli~~ J~Jf.. t~a 't` ~~~ i Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report W Sundry Operetions (10-404) Spad ~ Date 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Cortosion inhibitor Cortosion inhibitod sealant date ft bbls it na al S-Ot8 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 7325 NA 1325 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 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-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 S-os 1821040 1.5 NA 1.5 NA 9.a 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-718 1990530 0.25 NA 0.25 NA t.7 5/27I2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/t/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 075 ~ NA OJS 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 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 7901270 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 5-26 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 5-288 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-30 1900660 0.5 NA 0.5 NA 5.1 513t/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.a 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 S35 1921480 0 NA 0 NA .85in 5/31/2009 S36 1921160 0.75 NA 0.75 NA 425 5/27/2009 537 1920990 7 25 NA 125 NA 11.9 5/27/2009 5-38 1921270 025 NA 0.25 NA 102 5/27l2009 S-47 1960240 1.5 NA 1.5 NA 17.7 5/30/2009 S-42 7960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 5-44 1970070 025 NA 0.25 NA 1.7 5/28/'2009 5-700 2000780 2 NA 2 NA 21.3 5/29l2009 5-101 2001150 125 NA 1.25 NA 71.9 5/29/2009 S-102L1 2031560 125 NA 125 NA 11.1 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 5-104 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 ~74.3 6/2/2009 S-707 2011130 225 NA 2.25 NA 28.9 5/18/2009 S-toe 2011000 3.5 NA 3.5 NA a0 5/30/2009 S-to9 2022450 2 NA 2 NA 27.3 5/3N2009 S-110 2011290 11.75 NA 17.75 NA 98.s 5/30/2009 S-7 t ~ 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 2021350 0 NA 0 NA 0.5 5/30/2009 S-713 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-11aA 2021980 125 NA 125 NA tOZ 5/30/2009 5-115 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 5-116 2031810 1.5 NA 7.5 NA 13.6 5/28/2009 5-717 2030120 1.5 NA 1.5 NA 15.3 5/29l2009 5-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-77s 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5129/2009 5-127 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050870 3 NA 3 NA 27.3 5/29/2009 5-123 2041370 7.5 NA 1.5 NA 20.4 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 5-726 20710970 125 NA 125 NA 15.3 6/7/2009 5-200 1972390 1.25 NA 125 NA /4.5 5/28/2009 S-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 &1/2009 5-216 2001970 4.75 NA 4.75 NA 5t 5/29/2009 5-277 2070950 0.25 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 5-401 2060780 16 NA 16 NA 99.5 6/2/2009 S-50a 0 NA 0 NA 0.85 5/28/2009 STATE OF ALASKA tp¿ .f/l'>/(!(6 ALASKAa AND GAS CONSERVATION C.ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Other o Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028258 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 109' 3087' 10057' Perforation Depth MD (ft): Perforation Depth TVD (ft): 64.61' 10079 7009 9972 6940 4. Well Class Before Work: 181 Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 200-168 6. API Number: 50-029-22981-00-00 9. Well Name and Number: PBU 5-103 10. Field / Pool(s): Prudhoe Bay Field / Aurora Pool feet feet Plugs (measured) 9972 feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 109' 109' 1490 470 9-5/8" 3087' 2830' 5750 3090 7" 10057' 6994' 7240 5410 9551' - 9832' 6670' - 6850' 4-1/2", 12.6# x 3-1/2", 9.2# 9489' L-80 Tubing Size (size, grade, and measured depth): 9332' 9432' 7" x 3-1/2" Baker 'S-3' Packer; Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker 'S-3' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft MAY 1 6 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowle ge. Sundry Number or N/A if C.O. Exempt N/A o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram t at t e oregolng IS true an Aras Worthington. 564-4102 Printed Name Terrie Hubble Signature /fíi Form 10-404 Revised 04/2006 Title Technical Assistant Phone Date O~ cf1 O(p Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 e e S-103 Rig Workover Prudhoe Bay Unit 50-029-22981-00 200-1 68 Accept: Spud: Release: Ri: PRE-RIG WORK 11/25/05 CORRELATED TO SWS SLIM CEMENT MAPPING TOOL AND JEWELRY LOG DATED 23-MAR-2001 (PRE RWO) TUBING PUNCH AT 9358' - 9360', STRING SHOT FROM 9367' - 9379'. 11/26/05 CORRELATED TO SWS SLIM CEMENT MAPPING TOOL AND JEWELRY LOG DATED 23-MAR-2001. CUT TBG AT 9378'. WHEN TOOL CAME TO SURFACE, LOWER CHEM TUBE WAS SPLIT VERTICALLY AND THE CUTTER HEAD HAD BEEN LEFT DOWN HOLE. NOTIFIED PE AND FSM. 11/27/05 ATTEMPING TO FISH ElL CHEMICAL CUTTER FROM 9423' SLM. 11/28/05 RUN CENTER SPEAR W/1" GRAPPLE AND 1 3/4" RS ON 21/2" JUS PULLING TOOL. LATCHED AND PULLED CHEMICAL CUTTER FROM 9423' SLM. e e BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: S-1 03 Common Well Name: S-1 03 Spud Date: 11/6/2000 Event Name: WORKOVER Start: 4/24/2006 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/24/2006 06:00 - 06:30 0.50 MOB P PRE Held PJSM on Move rig off PM2-11a 06:30 - 08:00 1.50 MOB P PRE Move rig off well and to edge of pad 08:00 - 09:30 1.50 MOB N WAIT PRE Wait on Security, Their crew change 09:30 - 10:00 0.50 MOB P PRE Held PJSM on rig travel from PM2 to S-103. 10:00 - 23:00 13.00 MOB P PRE Mobilze rig towards S-Pad On Spine between F and J Pad at 17:30 hrs 16:45hr 1/2mile past J pad 17:00 gave AOGCC 24hr notice for BOP test. Chuck Shevie called back at 21 :20 21 :35 rig across bridges and on Spine Rd 1/2 way to S pad turn-off 23:00 - 00:00 1.00 MOB P PRE Rig arrived on location at 23:00 hrs 4-24/2006 Remove 7-1/16" BOP's from cellar 4/25/2006 00:00 - 01 :00 1.00 MOB P PRE Meet with DSO and filled out unit work permit. Loaded cellar with refurbished 4-1/16" 5k Production tree, riser for 13-5/8" BOP stack and adaptor flange 01 :00 - 01:1 0 0.17 MOB P PRE PJSM and review procedures and hazards pulling over well 01:10 - 02:30 1.33 MOB P PRE Pull over well and level up rig. Installed Handi-Berm and cutting tank 02:30 - 05:15 2.75 MOB P PRE Acceptd rig at 0230 hrs 4-25-2006 Take on 265 bbl 9.8ppg brine. Spopt tiger tank. MU hoses and manifold to circulate and kill well 05:15 - 10:26 5.18 BOPSUF P PRE Circulated 265 bbl clean 9.8ppg brine followed by 265 bbl of 9.8 ppg brine with SafeSurf 0 and displace tubing with clean 9.8ppg brine 10:26 - 12:00 1.57 BOPSUF P PRE SO and monitor well RU to set (dryrod) BPV. Set FMC's BPV. Installed IA and OA pressure transducers. PT below to 500 psi. OK make ready to NO tree 12:00 - 12:30 0.50 BOPSUF P PRE Held PJSM on NO Tree and NU 13-5/8" BOP's 12:30 - 17:30 5.00 BOPSUF P PRE NO landing, SV and flow tee, load outside. Remove SSV as single unit and lay outside. Conducted visual on hanger threads (OK) Tried to screw in XO and shoulder up with only 4 threads screwed in. Took to Machine shop to lengthen bore back on thread. 17:30 - 18:00 0.50 BOPSUF P PRE Wait on 11" X 13-5/8" DSA from Price Pad 18:00 - 18:20 0.33 BOPSUF P PRE PJSM. Review procedures and hazards for NU adapter flange and 13-5/8" BOP stack, Discuss the use of hydraulic torque wrench. Minimal use of hammer wrenches and their inherent dangers. Overhead loads. Calm clear communications when using radios. Correct use of trolley winches when moving BOP stack. 18:20 - 00:00 5.67 BOPSUF P PRE Screw-in 4-1/2" NSCT XO to tbg hanger, 8 turns which is good. NU DSA adapter flange. Move in BOP stack and lift into position over DSA. MU bolt rows. Drop steam hose into stack to warm up. MU choke and kill line. Hook-up hyd control lines. 4/26/2006 00:00 - 00:30 0.50 BOPSUF P PRE Continue NU BOPE control lines. 00:30 - 03:30 3.00 BOPSUF N PRE After a recent annular rebuild the annulars head needed to be tightened about 1/4 turn. Bled off all residual hydraulic pressures within the annular that may have risen from warming it. Able to MU but lacking about 3 more inches to install the head lock screw. Hook-up control lines to annular. PU jt DP and function annular. This might help relax packing unit enough to tighten. Printed: 5/1/2006 1:31:41 PM BP EXPLORATION Page 2 of4 Operations Summary Report Legal Well Name: S-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: WORKOVER Start: 4/24/2006 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/26/2006 00:30 - 03:30 3.00 BOPSUF N PRE Torqued up and installed lock screw. 03:30 - 05:30 2.00 BOPSUF P PRE NU riser. Function test all control lines. 05:30 - 12:00 6.50 BOPSUF P PRE Working at getting BPV removed, hitting lip on hanger, finally got the BPV out and installed TWC. Make up test jt and service valves. Filled stack and conducted body test PT failures on kill lines. passed body test 12:00 - 21:30 9.50 BOPSUF P PRE PT to 250 /3500 psi per 5 min wittness be Lou Grimaldi w/ AOGCC Flange below blinds leaking, tighten and retested. RU and pulled TWC 21 :30 - 22:05 0.58 PULL P DECOMP RU to pull completion. Screwed into hanger 9 rds. Backed out LOS and RU cir line. 22:05 - 22:15 0.17 PULL P DECOMP PJSM on pulling completion, circulating SafeSurf out of well and LD completion 22:15 - 23:00 0.75 PULL P DECOMP PU on completion, came out of hanger at 45k. PU to 60k and string popped free. String wt fell to 48k. PU 6 ft above tubing spool. Closed annular and lined up to circulate to TT and recover SafeSurf. 23:00 - 00:00 1.00 PULL P DECOMP Circulating down tubing Q p = 4.00 / 4.23 bpm Pp = 883 psi Density = 9.81 ppg WHP = 300 psi. Pumped 260 bbls, the retum fluid looked clean with smeel of SafeSurf 4/27/2006 00:00 - 01 :45 1.75 PULL P DECOMP Make ready to Pull completion. PUH and LD Hanger, 1 jt 4-1/2" and 4-1/2" X 3-1/2" Crossover. RU tongs and fill trip tank 01 :45 - 05:30 3.75 PULL P DECOMP POOH LD 3-1/2" Completion. String Wt starting = 49k LD 97 jts at 05:30 hrs 05:30 - 07:00 1.50 PULL P DECOMP Unloaded pipe shed of 100 jts 3-1/2" tubing Safety Meeting, Crew change & Rig Service 07:00 - 10:30 3.50 PULL P DECOMP POOH LD 3-1/2" completionSeen some thread loss on joint 175 to 200 out 10:30 -11:30 1.00 PULL P DECOMP Unloaded pipe shed of 100 jts 11:30 - 13:10 1.67 PULL P DECOMP POOH LD 3-1/2" Completion 249 jts down 13:10 - 13:35 0.42 PULL P DECOMP Unload pipe shed 13:35 - 14:50 1.25 PULL P DECOMP POOH LD 3-1/2" Completion Looking good for having it all. Recovered 296 jts of tubing 3 GLM's 1 X Nipple and hanger The chemical cut conducted in Nov 2005 was a text book cut. Called SLB and reported findings. 14:50 - 16:00 1.17 PULL P DECOMP Cleaned out pipe shed and make ready to start loading 4-1/2" tubing and prep 16:00 - 19:30 3.50 PULL P DECOMP Loading Pipe shed with completion tubulars 19:30 - 20:00 0.50 RUNCO! P RUNCMP Held PJSM concerning crane lift and. Loaded HES Symphony Equipment in Pipe shed with Crane 20:00 - 23:00 3.00 RUNCO! P RUNCMP Loading pipe shed with completion tubulars 23:00 - 23:30 0.50 RUNCO! P RUNCMP SO loading pipe and held PJSM with SLB Wireline on running GB & LIB and hazards assoicated with task. 23:30 - 00:00 0.50 RUNCO! P RUNCMP RU SLB Slick line 4/28/2006 00:00 - 02:00 2.00 RUNCOr p RUNCMP RU Wireline 02:00 - 03:20 1.33 RUNCOr p RUNCMP RIH with 6.07" 00 GRlJB and tagged at 9,380 ft WLMD POOH to run LIB 03:20 - 06:00 2.67 RUNCOr p RUNCMP RIH with 6.00" LIB Tagged at 9380 ft e e Printed: 5/1/2006 1:31:41 PM e e BP EXPLORATION Page 30t 4 Operations Summary Report . Legal Well Name: S-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: WORKOVER Start: 4/24/2006 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/28/2006 03:20 - 06:00 2.67 RUNCO! P RUNCMP POOH, OOH, no marks on LIB, ordered 5-1/2" LIB 06:00 - 08:00 2.00 RUNCm p RUNCMP Wait on 5-1/2" LIB from slickline. Dress up LIB 08:00 - 09:45 1.75 RUNCm p RUNCMP RIH with 5.5" LIB and roller stem. Tagged at 9395 ft, hit down 3 times, POOH OOH, clean imprint of 3-1/2" stub on bottom of LIB. Stub is laying off to 1 side of 7" casing. Will have to rotate OS over 09:45 - 11 :00 1.25 RUNCm p RUNCMP PJSM on RD slickline. RD same. Start to bleed OA for changing packoff 11:00 - 15:45 4.75 RUNCm p RUNCMP Loading pipe shed and allowing OA to bleed down 15:45 - 16:45 1.00 RUNCm p RUNCMP Changing FMC' packoff and still loading pipe shed Tested packoff seal to 5000 psi 15min and wittnessed. 16:45 - 18:30 1.75 RUNCm p RUNCMP Finished loading pipe shed. 18:30 - 20:00 1.50 RUNCm p RUNCMP Rig up floor to run completion. Bring on Halliburton, Doyon, and Baker equipment. Rig up equipment. 20:00 - 20:30 0.50 RUNCm p RUNCMP Hold PJSM with all hands. Review procedures. Discuss hazards. Assign duties and responsibilities to hands. 20:30 - 00:00 3.50 RUNCm p RUNCMP Torque turn chrome tail pipe assembly, packer, and Halliburton downhole tool. Install I-cable. Test same. Continue to run L-80 tubing and jewelry. 4/29/2006 00:00 - 09:30 9.50 RUNCm p RUNCMP Continue to run 4-1/2 x 3-1/2 completion. Making up I-wire clamps on each joint. Depth = 4,825 ft 09:30 - 10:15 0.75 RUNCm p RUNCMP Change over to 4-1/2" slips and elevators. Remove 39 extra jts 3-1/2" from pipe shed. 10:15-17:00 6.75 RUNCm p RUNCMP Continue to run 4-1/2" completion. Making up I-wire clamps on each joint. 17:00 - 19:00 2.00 RUNCor P RUNCMP RIH and tagged top of stub at 9,391 ft.w/ 9.33 ft in on Jt 293 (Old numbering system) Slacked off to 9393 ft and tagged NO/Go PU 2 ft and measured for space out. 19:00 - 21 :00 2.00 RUNCor P RUNCMP LD 3 jts 4-112" tubing and PU 2-10 ft and 14ft PJ. Make up 1 jt of 4-1/2" on top of space out pups. MU hanger and attach HES I-Wire cable MU landing joint with 3-1/2IF x TCII crossover. Drain BOPS. Land hanger. Visually verify landed in cellar. 21 :00 - 00:00 3.00 RUNCor P RUNCMP PU out of tbg spool. Displace well down the back side. Pump 190 bbls 140F seawater. Follow with 210 bbls 140 deg F inhibited seawater. 4/30/2006 00:00 - 00:30 0.50 RUNCO! P RUNCMP Finished reverse cir inhibitor fluid down IA. Landed tubing, verify on depth RILDS 00:30 - 03:00 2.50 RUNCO! P RUNCMP Dropped Rod/Ball and allowed 20 min to fall. Pressured up and set packer 03:00 - 06:00 3.00 RUNCO! P RUNCMP Lined out to pump down IA PT tubing to 3500 psi for 30 min. Charted and bleed down to 1500 psi 06:00 - 07:45 1.75 RUNCor P RUNCMP Put 1500 psi on tubing. SI tubing Pressure holding at 1500 psi. PT IA to 3500 psi for 30 min (OK). Bleed pressure down on tubing with Baker choke and at 300 psi the DCK valved at 4600 ft sheared. Circulated down IA at 2 bpm for conformation. SO 07:45 - 09:30 1.75 RUNCor P RUNCMP Monitored well, backed off landing joint and PUH and removed XO. Dry rod in BPV PT below BPV to 500 psi (OK). NO landing jt 09:30 - 09:45 0.25 RUNCO! IP RUNCMP PJSM on NO BOP's and hazards associated with NO and Printed: 5/1/2006 1:31:41 PM · BP EXPLORATION Page40f 4 Operations Summary Report ~ Legal Well Name: S-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: WORKOVER Start: 4/24/2006 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From- To Hours Task Code NPT Phase Description of Operations 4/30/2006 09:30 - 09:45 0.25 RUNCor fp RUNCMP replacing lower boots on riser and stored clamps. 09:45 - 15:00 5.25 WHSUR P POST NO BOPs and replace boots in riser 15:00-17:15 2.25 WHSUR P POST Installed 11" 5k X 4-1/16" adaptor. Wire in the Symphony I-Wire and PT adaptor seal. 17:15-19:30 2.25 WHSUR P POST Following PJSM, installed 4-1/16" 5k tree 19:30 - 20:45 1.25 WHSUR P POST RU DSM lubricator. Pull BPV. Set two way check valve in hanger. 20:45 - 21 :00 0.25 WHSUR P POST Pressure test tree to 5000 psi for 10 min. Test good. 21 :00 - 22:00 1.00 WHSUR P POST RU DSM lubricator. Pull TWC from hanger. 22:00 - 22:15 0.25 WHSUR P POST Hold PJSM with LRS and rig crew to discuss freeze protection procedure. 22:15 - 23:30 1.25 WHSUR P POST Rig up flow lines in cellar from tree and to IA casing valve. 23:30 - 00:00 0.50 WHSUR P POST Pressure test lines in cellar. Small leak from manifold. Trouble shoot same. 5/1/2006 00:00 - 01 :00 1.00 WHSUR P POST Pump 75 bbls diesel down IA. 2.0 bpm at 500 psi. 01 :00 - 02:00 1.00 WHSUR P POST U-tube diesel back into tbg from IA. 02:00 - 03:00 1.00 WHSUR P POST Set BPA. Test same to 1000 psi. Finish cleaning pits. Secure tree and well. 03:00 - 04:00 1.00 RIGD P POST Release rig at 0300. Jack up rig and warm up moving system. Hold PJSM to review moving do's and dont's. Shut in adjacent injection well with DSO. 04:00 - 06:00 2.00 RIGD P POST BAck off well. Clean up around well head. Pick up rig mats. e tit , .. Printed: 5/1/2006 1:31:41 PM ,~'~I'~-.. MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2986 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/8/2003 Field: Aurora Midnight Sun Well Job # Log Description Date BL Color CD E-102 ~l.L--~ { '- \ ~Z~(~2 STATIC TEMPIPRESSURE 04102/03 1 S-103 ~--~ (~ PSP PRODUCTION PROFILE 0910S/03 S-106 ~),('~ ~ ~)\ ~ GAS LIFT SURVEY 08121103 S-108 ~ [ ~ ~ ~ LEAK DETECTION LOG 09108103 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1;,.~.~ ~; 900 E Benson Blvd. s=c' .~. :,.~.,,,,,, ',~,,=,..,~ ~,~ ~ '~ ~ ~-' Anchorage AK 99508-4254 OCT 0 8 Date Delivered: ......... Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Permit to Drill 2001680 MD 10079 J' 'rVD DATA SUBMITTAL COMPLIANCE REPORT 411612003 Well Name/No. PRUDHOE BAY UN AURO S-103 Operator BP EXPLORATION (ALASKA) INC 7009 --- Completion Dat 3/26/2001 ~ Completion Statu 1-OIL Current Status l-OIL APl No. 50-029-22981-00-00 UIC N REQUIRED INFORMATION Mud Log N_~o Sample N_go Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Run Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Numb. pr Comments 5/8/2001 /Je032 9473-9908 Ver LIS Verification Ver LIS Verification ~DD Gurvey Report PJ RES 2/5 ~.>~ GPJ NEU/DEN 1,2,5 /MI~GPJ NEU! DEN 2/5 IIFR Survey Report .-MW0"S urvey Report MWD Survey Report Slim Cement Mapping 5 and Jewelr ~EU Sigma RST-A 5 "1170?-9 .~ROP/RES 2/5 FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL 1 1 9473 9908 Case 9473 9913 Case 225 1OO78 OH 225 10078 OH 225 10078 OH 9473 9913 ch 9473 9908 ch 9473 9908 ch 9473 9913 ch 225 10078 OH 166 10048 Case 166 10048 Case 5/17/2001 119/2001 712/2001 7/2/2001 712/2001 1/9/2001 119/2001 119/2001 5/15~2001 5/15/2001 5/15/2001 5/18/2001 7/2/2001 6/1/2001 6/1/2001 ~79 /.~032 079 9473-9913 Survey Report Digital Data 225-10078 BL, Sepia 225-10078 BL, Sepia 225-10078 BL, Sepia Survey Report Paper Copy Survey Report Digital Data Survey Report Paper Copy 9473-9913 2 Copies Color Print 9473-9908 BL, Sepia 9473-9908 Digital Data 9473-9913 Digital Data 225-10078 BL, Sepia · - . Well Cores/Samples Information: Name Start Interval stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2001680 DATA SUBMITTAL COMPLIANCE REPORT 4116/2003 Well Name/No. PRUDHOE BAY UN AURO S-103 Operator BP EXPLORATION (ALASKA) INC MD 10079 TVD 7009 Well Cored? Y I(~ Chips Received?---'Y'7'R'-'-- Analysis ~ Receive. d? Completion Dat 3/26/2001 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ~1 N Formation Tops ~ N APl No. 50-029-22981-00-00 UIC N Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ FRAe Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorac, le, AK 99519-6612 5. Type of Well: Development _X Exploratory__ Stratigraphic_ ServicL 4. Location of well at surface 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 932' FNL, 2421' FEL, Sec. 27, T12N, R12E, UM At effective depth 650' FNL, 2620' FEL, Sec. 27, T12N, R12E, UM At total depth 585' FNL, 2666' FEL, Sec. 27, T12N, R12E, UM (asp's 618930, 5980775) (asp's 615639, 5985779) (asp's 615435, 5986059) (asp's 615388, 5986123) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 109' Surface 3022' Production 9992' 10079 feet Plugs (measured) 7009 feet 9975 feet Junk (measured) 6942 feet 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-103 9. Permit number / approval number 200-168 / 302-087 10. APl number 50-029-22981-00 11. Field / Pool Prudhoe Bay Field/Aurora Pool Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arctic Set 174' 174' 9-5/8" 562 sx AS Lite 3, 260 sx Class 'G' 3087' 2830' 7" 582 sx Class 'G' 10057' 6994' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure measured Open Perfs 9551' - 9572', 9578'- 9598', 9608'- 9620', 9632'- 9642', 9652'- 9660', 9762' - 9787', 9708'- 9814', 9822'- 9832' true vertical Open Perfs 6670' - 6684', 6688' - 6700', 6681' - 6720', 6723' - 6729', 6735' - 6740', 6806'- 6818', 6828'- 6839', 6844'- 6850' l~',~ ~"' 1;~ ~1,. 3-1/2" 9.3~, L-80 TBG ~ 9432'. 3-1/2" 9.3~ Tubing Tail to 9489'. 7" x 3-1/2" Baker S-3 Packer ~ 9432' MD. 3-1/2" HES 'X' Nipple ~=27~'. ~ ..... '~" Anchoraae 14. Prior to well operation 03/02/2002 Subsequent to operation 04/23/2002 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 898 615 1380 302 3465 3200 936 347 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _X Gas _ Suspended ~ Service 17. I hereby certify that the foregoing i..s,true/~nd correct to the best of my knowledge. , DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · ORIGINAL Date June 101 2002 Prepared by DeWayne R. Schnorr 564-51 SUBMIT IN DUPLICATE ~ 03/05/2002 03/06/2002 03/07/2002 03/08/2002 03/08/2002 03/09/2002 03/09/2002 03/12/2002 03/13/2002 03/14/2002 03/20/2002 03/21/2002 04/19/2002 04/20/2002 S-103 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FRACTURING: SAND PLUG FRACTURING: SAND PLUG FRACTURING: AC-MITIA; DRIFT/TAG; GAS LIFT--TO DUMMY VALVES FRACTURING: AC-MITIA; GAS LIFT--TO DUMMY VALVES FRACTURING: MIT-IA FRACTURING: FRACTURING FRACTURING: FRACTURING FRACTURING: FILL CLEAN OUT FRACTURING: GAS LIFT--FOR RATE FRACTURING: GAS LIFT--FOR RATE FRACTURING: DRIFT/TAG; GAS LIFT--FOR RATE FRACTURING: GAS LIFT--FOR RATE FILL CLEAN OUT: FILL CLEAN OUT FILL CLEAN OUT: FILL CLEAN OUT EVENT SUMMARY O3/05~O2 MIRU DS CTU#3. DRIFT NEW COIL. MU TS 3" BALL DROP NOZZLE. LOAD AND KILL WELL W/2% FILTERED KCL. RIH, TAG BTTM AT 9916' - CORRECT TO 9904' ELMD, FLAG PIPE. RIG UP CEMENTERS 03/06/02 PUMP 25 BBLS 40# HEC SLURRY W/8 PPG 20/40 RIVER SAND. WAIT 1 HR FOR SAND TO SETTLE, TAG AT 9661'. PUMP 2ND 8 BBL SLURRY PILL. TAG 9638', WASH SAND OFF WALLS, WAIT TO SETTLE. TAG 9547'. REV CLEANOUT TO 9571'. CONFIRM TAG @ 9576'. POOH. FP TOP 3000' WITH METH. RDMO. <<<WELL LEFT SI & FP, NOTIFY PAD OPR>>> 03/07/02 RAN 2.25" SWAGE W/TEL & SAMPLE BAILER & TAG EOT @ 9456' SLM (ELMD=9473' FOR A +17' CORRECTION) CONT' IN HOLE & TAG TD @ 9578' CORRECTED DEPTH. VERY STICKY. DUMP BAIL 5 GALLONS OF LATEX, SBHPS ( PETREDAT ), PULLED DGLV FROM GLM #1 & OGLV FROM GLM # 2 & LGLV FORM GLM #3. <<<WELL SHUT-IN>>> 03/08/02 CONT. W/JOB SET DGLV'S RK LATCH STA 3 - 2 SET SPMG RK LATCH STA 1 MITIA GOOD PULL CS HB&R DO INJECTIVITY TEST FREEZE PROTECT FLOW LINE SET FRAC SLEEVE RDMO. 03/08/02 FILL IA 240 BBLS CRUDE PT. WITH DSL TO 3500 PSI FOR MIT GOOD TEST DROPPED 40 PSI IN 30 MINS ESTABLISH INJECTIVITY RATE ON TBG 4.5 BPM AT 2350 PSI 25 BBLS MEOH FREEZE PROTECT FLOWLINE 5 BBLS MECH. 03/09/02 TRANSPORT DIESEL, HEAT TO 100' F, TRANSFER INTO' DOWEL TRANSPORT. HOLD IA PRESSURE FOR FRAC. 03/09/02 FRAC'D C4 SD WITH YF125LG SYSTEM 118.5K# OF CARBOLITE PROP. Page 1 S-103 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/09/O2 (continued) SCREENED OUT AT 91 BBLS OF 10 PPGA 12/18 PUMPED, 35 BBLS OF 9 PPGA 12/18 IN PERFS. 91.7K# 16/20 AND 12/18 PROP PLACED IN FORMATION, 26.7K# PROP LEFT IN CSG, (SAND TO SURFACE). AVG TREAT PRESS = 4620 PSI. LOAD TO RECOVER IS 864 BBLS. TREESAVER CUPS RECOVERED. WELL NOT FREEZE PROTECTED, HEATERS PLACED ON WELLHEAD. 03/12/02 MIRU UNIT #8. RIH WITH JSN AND CLEANOUT CARBOLITE TO 9550' CTM. MAINTAINED 1:1 RETURNS THROUGHOUT JOB. LEFT WELL FREEZE PROTECTED TO 2000' WITH METHANOL WATER AND SECURED FOR SLICKLINE TO RUN GLV'S. FRAC SLEEVE STILL IN HOLE. 03/13/02 PULL FRAC SLEEVE. DRIFT TBG W/2.44" SWAGE W/TEL & SB. TAGGED FRAC SAND & FILL @ 9392' SLM. CONTINUE W/GASLIFTING.PULLED DGLV'S FROM GLM'S #3 AND #2.SET 16/64"- 1743# TRO (RK) IN GLM#3. 03/14/02 SET 20/64" OGLV (RK) IN GLM#2. NOTE:SIDE POCKET MANDREL GAUGE IS STILL IN GLM #1. 03/20/02 TAG TD W/2.35" CENT @ 9646' MD(RKB) -- SET 2.75" X-LOCK C-SUB -- PULL STA#1 SPMG & STA# 2 S/O -- 03/21/02 SET STA# 2 LGLV RK-1764#, 1/4" PORT - SET 20/64" S/O IN STA# 1 - PULL C- SUB, 04/19/02 FCO- MIRU DS CTU #5, RIH TO CLEAN OUT TO 9970'. O4/2O/O2 FOO-CONT'D FROM 4/19/02 WSR, RIH, DRY TAG AT 9804' OTMD. CLEANED OUT TO 9975' CTMD. LEFT WELL FLOWING TO APC. PUT ON 4 HR TEST. FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, I1 TEST) 10 METHANOL 125 60/40 METHANOL WATER 30 50/50 METHANOL WATER 480 DEAD CRUDE 310 DIESEL 870 EXTRA SLICK KCL WATER 510 SLICK KCL WATER 245 1% EXTRA SLICK KCL WATER 1550 FRESH WATER 32 30 PPT HEC GEL 100 BIO 70 1.5# BIO 8200# 20/40 RIVER SAND 4333 TOTAL Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X FRAC Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development IX Exploratory i Stratigraphic I Servicel 4. Location of well at surface 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 932' FNL, 2421' FEL, SEC 27, T12N, R12E, UM At effective depth 691' FNL, 1558' FEL, Sec. 27, T12N, R12E, UM At total depth 585' FNL, 2666' FEL, Sec 27 T12N, R12E, UM (asp's 618930, 5980775) (asp's 615639, 5985779) (asp's 596094, 5964625) (asp's 615388,5986123) 6. Datum elevation (DF or KB feet) RKB 64.6 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-103 9. Permit numar / approval number 200-168 / 302-024 10. APl number v~ 50-029-22981 11. Field / Pool Prudhoe Bay Field / Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 109' Surface 3022' Production ' RECEIV 10079 feet v~ Plugs (measured) Tagged PBTD @ 9330' (04/25/2001). 7009 feet 9930 feet Junk (measured) 6913 feet Size Cemented Measured Depth True vertical Depth 20" 260 sx AS 174' 174' 9-5/8" 562 sx AS Lite III, 260 sx 3087' 2830' Class 'G' 7" 582 sx Class 'G' 10057' 6994' MAR 0 ? 2007. Per~or~e~C00s. C0fllll~iSl~sured Open Perf 9551'-9572', (~578'- 9598', 9608'- 9620', 9632'- 9642', 9652'- 9660', AllCl10f'age 9762'- 9787', 9798'- 9814', 9822'- 9832"~ %,-u~'~ ~c..~ true vertical Open Perf 6670' - 6684', 6688' - 6700', 6681' - 6720', 6723' - 6729', 6735' - 6740', 6806'- 6818', 6828'- 6839', 6844'- 6850' Fubing (size, grade, and measured depth 3-1/2" 9.2#, L-80 TBG @ 9432'. 3-1/2" 9.2# Tubing Tail to 9489'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 9432' MD. 3-1/2" HES 'X' Nipple @ 2110'. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch _ 15. Status of well 'classification as: 14. Estimated date for commencing operation 03/1 1/2002 16. If proposal was verbally approved 'Name of approver Date approved Oil _ X 'Gas I Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ '~~-,~~~ Title:AuroraSurveillanceEngineer Jim Youn~ FOR COMMISSION USE ONLY Questions? Call Bruce W. Smith @ 564-5093. Date March 01,2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Plug integrity i BOP Test I Location clearance Mechanical Integrity Test I Approved by order of the Commission Form 10-403 Rev 06/15/88 · i Subsequent form required 10- I_~ Original Sig.ed By ORIGINAL Commissioner SUBMIT IN TRIPLICATE bp (' BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-Sl 11 March 04, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for S-103 to Frac BP Exploration Alaska, Inc. proposes to frac development well S-103. The project has an un-risked IOR of 2500 BOPD (1500 annualized IOR risked). The frac operation will consist of a MiniFRAC to determine fluid efficiency, a SRT to determine parting pressure and the main frac. The frac will consist of pumping _+80,000 and _+30,000 pounds of 16/20 and 12/18 Carbo-lite proppant resp, resulting in a 100 foot propped length with an average prop concentration of _+ 4 Ib/ft2. The procedure includes the following major steps: Step Description CTU sandback to 9575' ELMD for frac prep Tag sand-top, SBHP, set DGLVs, SPMG MITIA 3500psi PUMP DATAFRAC & FRAC FCO (underbalance) C/O DGLVs TO LGLVs (deep design) APC FRAC FLOWBACK Please call (~im Young 564-5754, hm: 248-0133, cell: 440-8007; Mike Coker Ce11:223-0582 or Steve Deckert ~0~:564-4128, H:338-1476) if there are any questions. Pre-Frac 1. CTU sandback to 9575' ELMD (window = 9570'-9590') i) The objective is to provide adequate plug-back to isolate existing perfs below 9572' MD and prevent downflow during upcoming frac. Adequate room must be left to frac into all 20' of perfs 9550'-9570'MD. 2. Tag sand-top, Set DGLVs in sta's 1,2, replace OGLV in sta. 3 with SPMG, and obtain pre-frac static: 15-min stops at 9550' and 9350'. Dump bail mixed grade carbonate & 100 mesh sand on sand-back plug, adequate to prevent down-flow. i) Perfr., pump-in jug test. Bail-in carbonate & . plug until pump-in test is jug tight. Gauge sampling: Event Time Sample Rate All 12 Days 15 seconds J mesh sand on sand-back Sample _~ 6100 3. Load annulus, pressure test IA to 3500 psi. Fracture Treatment 1) Water requirements, heat water to - 100 F. A total of -1200 bbls filtered KCL water are required (excluding tank bottoms). 2) RU the treesaver/isolation tool for 3 Y2 "- 9.2#/ft. tubing (see attached schematic), Set pop-off at 8500 psi. 3) PT backside and maintain 3500 psi throughout treatment (set IA pop-off at 4000 psi). Pressure test lines to 10000 psi. Set pump trips afterwards to 7500 psi. It is recommended that 5 pumps be on location. The maximum allowable surface treating pressure is 9200 psig. The well should treat at 4000 psig, allowing for 3500 psig of excess treating'pressure. If the data frac indicates that the well cannot be treated below 8000 psig, then consult with town or onsite engineer before raising pump trips to max 9000 psig. 4) Pump Data Frac/SD per attached schedule; initial rate will be 10 bpm while displacing wellbore fluid, after spotting Data Frac fluid a few feet above top perf increase rate design for data frac. Shut down, monitor for closure time, calculate efficiency and re-design frac schedule as necessary (Pad size, fluid loss additive, Shut down for ISIP, strap tanks, calibrate flow meters and calculate excess perforation pressure, etc). 5) Re-establish injection, when add rates are lined out start counting PAD. Pump the proppant schedule as detailed in the attached pump schedule. Flush with linear fluid containing 50% methanol for freeze protection. 6) Bleed off excess annulus pressure. Rig down Service Company. Post Fracture Treatment (within 48 hours) 1) Perform CTU fill cleanout to PBTD. i) Perform clean-out slightly under-balanced (to minimize damage to frac & perfs) to tank. ii) Formation pressure will support equivalent ECD of 8.8ppg, if this limit is much be exceeded, use only gelled diesel, have lab verify that breaker loading is adequate to break polymer & mix water at 140° F. iii) It is important to slow down FCO rate when the top of the interval is reached. Excess proppant production can 'be caused by circulating too fast or kicking the well off too quickly. 4. Retrieve sidepocket gauge changeout DGLV's to LGLV's (deep design). . FLOWBACK: Drop 5bbls MeOH into IA, open production choke slowly to 100% and POP well with minimum lift gas (<500 MSCFD) to flow through portable clean-up separator (expect proppant to be flowed back while well is cleaning up). If WHT remains below 50 F, Pump 20 gal/hour MeOH down IA continuously (or 1 bbl at minimum rate possible every 2-hours). i) The is to have the fmc flowed back 5-10 days of pumping the frac ii) Do not allow rates to exceed 20 bbl/hr for first 6-hours and gradually open choke during the remaining flowback period. The objective is to limit flowrate increases to a maximum of 750 BLPD in any 12 hour period. iii) Once the flowback has initiated, do not shut-in the well until majority of proppant has been cleared from the tubing. iv) Continue producing through clean-up separator until solids are down to trace (<0.2%) with the well at maximum drawdown (1200 GLR, wide-open choke). Obtain liquid sample and send to PBU lab. Return to GC2 and obtain well- test from S-pad separator as soon as possible (default NOC=0.865). Sincerely, Jim Young Greater Prudhoe Bay Aurora Development Engineer '[P, EE = 5M CIW CHROIVE WELLHEAD = FMC GEN 5 ACTUATOR = ? KB. B. EV = 64.61 BF. B. EV = 36' _.. KOP= 1636' Max Angle = 56 @ 6294' Datum IVD = 10079' Datum TVD= 6944' S-103 2110' 9-5/8" CSG, 40#, L-80, BTC, ID = 8.750" ~ 3087' IMinimum ID = 2.75" @ 2110' 3-112" HES X NIPPLE 3-112"TBG, 9.2#, L-80-NSCT, .0087 bpf, D = 2.992" H 9489' PI~FORATION SUMMA RY REF LOG: MWD I GR ON 11/07/00 ANGLEATTOP PERF.' 49 @ 9551' SIZE SPF INTERVAL Opn/Sqz DATE 2-112' 4 9551 - 9571 O 02121/02 2-112' 4 9552 - 9572 O 02/21/02 2-112' 6 9578 - 9598 O 12/24101 2.' 6 9608 - 9620 O 06117/01 2" 6 9632 - 9642 O 06/17/01 Z' 6 9652 - 9660 O 06117/01 2-112' 6 9762 - 9782 O 03126101 2'' 6 9798 - 9814 0 04126101 2'' 6 9822 - 9832 0 04126101 9972' [7" CSG, 26#, L-80-BTC-M, ID: 6276" H 10857' 9489' DATE REV BY COMV~NTS DATE REV BY COMIVENTS 11110/00 ORIGINAL COIVPLETION 05/21/01 I'IP ADD PERFS 01/26/01 SIS-MD RNAL 12/06/01 DAV/tlh I-ES NII:::PLEIDCORRECTIE) 03/18/01 RN/TP COf:~,ECI'IONS 12/24/01 CWS/tlh ADDPI~FS 03126/01 GN/I'LH INITIAL PERFS 02/21/02 CWS/KK ADDPERFS 05/07/01 JJ/KAK ADPERFS SAFETY NOT ES 3-1/2" I-ES X NIPR. E, ID = 2.750" GAS LIFT MANDRELS H3-112" I-ES X NIP, ID = 2.75" 3-112" X4-112'' NSCTXO I 7" x 3-1/2" BAKERS-3 PKR I 4-1/2" X 3-1/2" NSCT XO I I---t 3'1/2" "---s x NI"' = 2'75" I -~ 3-112" I-ES, X NIP, ID [] 2.75" ~bT LOGGEDI PRUDHOEBAY UNIT WELL: S-103 PERMIT No: 200-186 AR No: 50-029-22981-00 SEC 35, T12, R12E, UM4571' NSL, 4409'WEL BP Exploratbn (Alaska) STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X ExploratoL Stratigraphic_ Service._ 4. Location of well at surface 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 932' FNL, 2421' FEL, Sec. 27, T12N, R12E, UM At effective depth 684' FNL, 2594' FEL, Sec. 27, T12N, R12E, UM At total depth 585' FNL, 2666' FEL, Sec. 27, T12N, R12E, UM (asp's 618930, 5980775) (asp's 615639, 5985779) (asp's 615461, 5986025) (asp's 615388, 5986123) 12. Present well condition summary Total depth: measured true vertical 10079 feet Plugs (measured) 7009 feet Effective depth: measured true vertical 9919 feet Junk (measured) 6906 feet Casing Length Conductor 109' Surface 3022' Production 9992' 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-103 9. Permit number / approval number 200-1680 10. APl number 50-029-22981-00 11. Field / Pool Prudhoe Bay Field / Aurora Pool Tagged PBTD @ 9919' (12/24/2001). Size Cemented Measured Depth True Vertical Depth 20" 260 sx AS 174' 174' 9-5/8" 562 sx AS Lite III, 260 sx 3087' 2830' Class 'G' 7" 582 sx Class 'G' 10057' 6994' Perforation depth: measured Open Peds 9578'-9598', 9608'-9620', 9632'-9642', 9652'-9660', 9762'-9787' 9798'-9814', 9822'-9832' truevertical Open Peds 6688'-6700', 6708'-6715', 6722'-6729', 6735'-6740', 6806'-6821', Tubing (size, grade, and measured depth) 6828'- 6839', 6844'- 6850' 3-1/2", 9.2#, L-80 TBG @ 9432'. 3-1/2" 9.2# Tubing Tail to 9489'. 7" x 3-1/2" Baker S-3 Packer @ 9432'. 3-1/2" HES 'X' Nipple @ 2110'. Packers & SSSV (type & measured depth) RECEIVED JAN 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Naska Oil & Gas Cons. Commission Anchor'dDe 14. Prior to well operation 12/20/2001 Subsequent to operation 12/26/2001 OiI-Bbl 324 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 282 1119 367 271 1171 Casing Pressure Tubing Pressure Gas Lift 301 Gas Lift 307 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~~.~J~.,...._ Title: Technical Assistant DeWal/ne R. Schnorr Form 10-404 Rev 06/15/88 · Date January 14, 2002 Prepared by DeWar/ne R, Schnorr 564.5174 SUBMIT IN DUPLICATE S-103 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/20/2001 GLV C/O- RATE: DRIFT/TAG (PRE-PERF) 12/24/2001 DRILL-POST WORK: PERF 2.5" HSD POWER JET 6 SPF EVENT SUMMARY 11/20/01 TAGGED PBTD AT 9919' CORECTED TO MD W/2.55" DUMMY GUN (RATHOLE= -87'). WELL POP AT 40 BEAN, DSO TO OPEN FULL AFTER CHANGE OUT. 12/24/01 PERFORATED 20' INTERVAL (9578'-9598') WITH 2-1/2" PJ 2506, 6 SPF, RANDOM ORIENTED, 60 DEGREE PHASED GUN. SHOT UNDER BALANCED, BLED WH PRESSURE FROM 1100# TO 400# PRIOR TO SHOOTING. **** WELL BACK ON PRODUCTION **** FLUIDS PUMPED BBLS 2 PRESSURE TEST LUBRICATOR W/2 BBL OF DIESEL, (1 TEST) 2 TOTAL ADD PERFS 1 2/24/2001 THE FOLLOWING INTERVAL WAS PERFORATED WITH THE 2-1/2" PJ 2506, 6 SPF, 60 DEGREE PHASED GUN, RANDOM ORIENTATION. 9578' - 9598' Page 1 . STATE OF ALASKA A~S~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n nr'lrln~- w iii1~ 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well_ "~'"' Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Add Pelfs Change approved program _ Pull tubing _ Variance _ Perforate _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 64.6 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchora~le, AK 99519-6612 Se~vice~ Prudhoe Bay Unit 4. Location of well at surface ~ ~' ,,/ 8. Well number 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM (asp's 618930, 598O775) S-103 At top of productive interval 9. Permit number./~approval number 932' FNL, 2421' FEL, SEC 27, T12N, R12E, UM (asp's 615639, 5985779) 200-1680 At effective depth 10. APl number 684' FNL, 2594' FEL, Sec. 27, T12N, R12E, UM (asp's 615461, 5986025) 50-029-22981 At total depth 11. Field / Pool 585' FNL, 2666' FEL, Sec 27 T12N, R12E, UM (asp's 615388, 5986123) Prudhoe Ba~/Field / Aurora Pool (undefined) 12. Present well condition summary Total depth: measured 10079 feet Plugs (measured) Tagged PBTD @ 9919' (12/24/2001). true vertical 7009 feet Effective depth: measured 9930 feet Junk (measured) true vertical 6906 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 109' 20" 260 sx AS 174' 174' Surface 3022' 9-5/8" 562 sx AS Lite III, 260 sx 3087' 2830' Class 'G' Production 9992' 7" 582 sx Class 'G' 10057' 6994' Perforation depth: measured Open Perf 9578' - 9598', 9608' - 9620', 9632' - 9642', 9652' - 9660', 9762' - 9787', 9798'- 9814', 9822'- 9832' true vertical Open Perf 6688' - 6700', 6708' - 6715', 6722' - 6729', 6735' - 6740', 6806' - 6821', 6828'- 6839', 6844' - 6850' Tubing (size, grade, and measured depth 3-1/2" 9.2#, L-80 TBG @ 9432'. 3-1/2" 9.2#.Tubing Tail to 9489'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 9432' MD. 3-1/2" HES 'X' Nipple @ 2110'. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 11 January 16, 2002 16. If proposal was verbally approved Oil ~ X Gas _ Suspended _ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jim Young @ 564-5754, Signed (~'~';~ ~~~ Title: Aurera Sun/eillance Engineer Date January 11,2002 Jim Young Prepared by DeWa~e R. Schnorr 564.5174 ,, FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Appro_vpl...~,..,,., ,.,~, ,n°' Plug integrity_ BOP Test_ Location clearance_I r~,.,~_~'_(..~(.~ Mechanical Integrity Test_ Subsequent form required 10- Original Signed By . .Approved by order of the Commission rummy 0ech$li commissioner Date ~i~ ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 11/1/2001 Schimberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1590 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Well Job # Log Description Date Color Sepia BL CD S.110 <~O):'; Ic~- 21419 USlT 08/20/01 ~ S-103 <~ D~-/~ PROD PROFILE/DEFT 10/20/01 1 /r L-115 mol- Iqo TEMPERATURE LOG 10122/01 · 1 ,t- L-110 21381 D/N & IMP (PDC) 07127101 1 L-110 <~D)- I o~ .~ 21381 VID VISION RESISTIVITY 07/27/01 o 1 ~ L-110 21381 iTVD VISION RESISTIVITY 07127/01 · 1 ~ L-110 21381 :MD VISIO'N DEN/NEUTRON 07127/01 · 1 ,~' L-110 21381 TVD VISION DEN/NEUTRON 07127101 1 .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 99508-4284 Date Delivered: RECEIVED l OV 0-2 2_.. 01 I3glTCI VIi G WO Wilt/. V¥IIIIIIilINIVa I Ancl-.-orage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrle Receiv~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Add Perfs Change approved program _ Pull tubing _ Variance _ Perforate _X Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Sewice_ 4. Location of well at surface 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 932' FNL, 2421' FEL, SEC 27, T12N, R12E, UM At effective depth 691' FNL, 1558' FEL, Sec. 27, T12N, R12E, UM At total depth 585' FNL, 2666' FEL, Sec 27 T12N, R12E, UM (asp's 618930, 5980775) (asp's 615639, 5985779) (asp's 596094, 5964625) (asp's 615388, 5986123) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 109' Surface 3022' Production 9992' 10079 feet Plugs (measured) 7009 feet 6. Datum elevation (DF or KB feet) RKB 64.6 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-103 9. Permit number / approval number 200-168 10. APl number 50-029-22981 11. Field / Pool Prudhoe Bay Field / Aurora Pool (undefined) Tagged PBTD @ 9330' (04/25/2001). 9930 feet Junk (measured) 6913 feet Size Cemented Measured Depth True vertical Depth 20" 260 sx AS 174' 174' 9-5/8" 562 sx AS Lite III, 260 sx 3087' 2830' Class 'G' 7" 582 sx Class 'G' 10057' 6994' Perforation depth: measured Open Perf 9608'-9620', 9632'-9642', 9652'- 9660', 9762'-9787', 9798'-9814', 9822'-9832' true vertical Open Peal 6681' - 6720', 6723' - 6729', 6735' - 6740', 6806' - 6818', 6828' - 6839', 6844' - 6850' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3-1/2" 9.2#, L-80 TBG @ 9432'. 3-1/2" 9.2# Tubing Tail to 9489'. 7" x 3-1/2" Baker S-3 Packer @ 9432' MD. 3-1/2" HES 'X' Nipple @ 2110'. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation 11/10/2001 16. If proposal was verbally approved Name of approver Date approved Oil _ X Gas ~ Suspended B ~.' Service . 17. I hereby certify that ~e/~going... ' ~ .....is~e and correct to the best of my knowledge. Signed t /-f-4'~ ~"'/~4~0 Title: Aurora Sun/eillance Engineer Jim Young FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Questions? Call Bruce W. Smith @ 564-5093. Date October 31, 2001 Prepared by DeWayne R. Schnorr 564-5174 1 Approv~ .. ~(~ ~ Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test __ . Subsequent form required lO- .".Original Signed By Approved by order of the Commission Cl~.m..m__,v rt..~.hsli Commissioner Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 31,2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for S-103 to Add Peris (Kuparuk C-3 Sands) BP Exploration Alaska, Inc. proposes underbalanced perforating the Kuparuk C-3 Sands in Aurora development well S-103. Underbalance should be achieved by gas- lifting with the well open to LPS. The proposed perfs are in a Iow quality reservoir, so long clean perf tunnels are necessary to enhance flow since fracturing will not be possible due to a prognosed GOC at approximately 9580'. The procedure includes the following major steps: Category IOR Step Description E 300 I Perforate 20' of C3, lowest shot 9596 MD Last Test: FBHP: Max. Deviation: Peris: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: Tie in Log: BHP: 10-21-01, 1700 BOPD, 65% WC, 2MMscfd ALG 1900 psi 56° @ 6294' md Deviation at peris: 50° Present Peris 9608' through 9832' MD Three .... 2.75" at X nipples, see schematic 9915' MD (09/20/2001) PROF w/DEFT & GLS, 10/20/01 < 10 ppm Sperry CNPGR Schlumberger CMTGR (03/25/2001). 3087 psia @ 9543' MD @ 6600' TVDSS 1. Obtain Well test no less than 2-days prior to, and ASAP after perforating. 2. Open CK 100% with ~0.5MMcfd ALG --> 1000 psi underbalance. E-Line . Perforate well, Zone C3 from 9578'- 9598' MD, ( . TVDss). Perforate using Schlumberger 2-1/2" HSD PJ, 2506 UP, 6SPF, 60 degree phasing, no orientation. Tie-into SWS CMTGR (25/Mar/2001). 4. POOH to sar and then increase gas lift to 2.0MMcfd, 5. Obtain Well test ASAP after perforating. post-perf test. Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007) if there are any questions. ~,~Sinc,~r~ly. Jim Young Greater Prudhoe Bay Aurora Development Engineer PERFORATING PROCEDURE Ver 4.0 06/04/01 Well: S-103 APl if: 50-029-22981-00 .... H2S Lev'li 11 Date: ...................... .1..,0..,/.,2...5,./.,0,..1. ....................... Prod Engr.,J,,!,.,m..,..Y...o..,u,,.n..,g,, .................... HomeOffice Ph:Ph: ........................... ............................................................................. 248-0133 '5"6"'4':5"7"5"'4' ................................................... <m oppm"'"'"'"'"'"'"'ll Cell/Pager: ........................... ,,,,4~,..0.:,B.~,0.,7. ........................... cc or AFC: 5M0005 Detail Code: 9335-070-770 Description: DRLG / COMPLETION / PERF WBL Entries IOR Type Work Desciption 300 E Perforate 20' underbalanced Well Obiectives and Lo,clqinq Notes: Obtain Well test no less than 2-days prior to, and ASAP after perforating Well makes -1700bopd, 65%wc, 2mmcfd ALG (1900psi FBHP on 10-21-01) Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: CNPGR CMTGR Date: 11/7/2000 3/25/2001 Company: ,.,S,p,.,e,,r,,~ ............. Schlum Depths (from-to) Depths (from-to) Feet SPF Orient. ......... ,,9..,.,,5,,,,7.,~: ............... ..9.,...5...9..~,. .............. ..9..:...5..7...,8,.'. ....... - ....... ,9,.,.,,5.,,9.,,e.,'. ............ ,,2,...o. ............. .~ ................... .n..~ .......... . . . "a'~'~':~'~i'~'~"~=x ~'~'~'~':~ ......................................... ::::::::::::::::::::::::::::: ................. Ai"~i"~ept~' .................... Requested Gun Size: ........... .2..:..5.:: ............ Charge: ............. p.j..2...5...0...6.. ............ Desired Penetration: >20" Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe be/ow how to ach/eve drawdown [check wi Pad Operator to see if necessary p/ping Is instal/ed) (e.g. N2 Lift, Hardllne Lift Gas, Gas Lift, Flow Well, Bacldlow Through Drain or Harclline) Tie in to Jewelry @ 9490 MD Tie in using: Minimum ID: jii?;~i~.~i~i~l~i~n Min ID Type: Tail Depth: .......... ,.9...4...9,.,0. .......... ff MD Casing Size: Est Res. Pres. @ Last Tag: >9900 ft MD on 10/21/2001 Perforation Summary Well: S-103 Date: APl if: 50-029-22981-00 General Comments: Add 2 to the tie-in log to be on depth with the reference log. feet Phasing Zone Ad/Re/Iperf ...... ,.c..,~ ....................... !,p...e..~ .................. N/A Entry Hole Diam: >0.3" FOR FRAC ,..°.P.,e,..n.,..c,.k.,!,,0.0.% ..,,W,,/,,-,,,0.:,5.,,m,.,m,,,~d,,,.,A,.,,L..,e,.::~.~.L~.~.~!~,~ .............................. ,....P..,.O....O..H,.t.o,, s..af.e.'.~.`.&...~'a..s..~!!..ff...~2..m....m....c..f`~*~.~[.P9~!:P~.~.[~.~!: ......................................... 7 in ....... ..9.,..8.0.~ ...... MD is ................ ..3...0...0...0.. psi J ~.ummary Dist II,OWn: Prod Engr: II^nch Prod Engr .............................................................................. [IP.D. Center PBTD Depths Balance ReferencedtoBHCS Gun Dia. Orient. SPF Phasing O/B/U - , ............................................................................................... O/B/U - , ............................................................................................... O/B/U ' ' ............................................................................................... O/B/U - , ............................................................................................... O/B/U - , ............................................................................................... ©.-. Zone Aperf/Reperf TREE= 5M QW CHROIVE WELLHEAD = FMC GEN 5 ACTUATOR = ? KB. REV = 64.61' BF. B. EV = 36' KOP= 1636' .Max Angle = 56 @ 6294' Datum IVD = 10079' Datum TVD= 6944' S-103 2119- SAFETY NOTES 3-1/2" I-ES 'X' NIPR. E ID = 2.992" ~ 19-5/8" CSG, 40#, L-80, BTC, ID = 8.750" H 3087' GAS LIFT M~NDRB. S IMinimum ID = 2.75" @ 2110' I 3-1/2" HES 'X' Nipple I 3-1/2" TBG, 9.2#, L-80-NSCr, .0087 bpf, ID = 2.992" H 9489' 9489' 3-112" I-ES 'X' NIP, ID = 2.75" 3-112" X4-1/Z' NSCT'XO' I 7" x 3-1/2" BAKERS-3 PKR I 4-11Z' X 3-112" NSCT 'XO' I 3-1/2" I-ES 'X' NIP, ID = 2.75" ~OT LOGGED I PEI~ORA TIO N SUMM~ RY REF LOG: MWD I GR ON 11/07/00 ANGLE AT TOP PEI~:: SIZE SPF INTERVAL OpnlSqz DATE 2" 6 9608'- 9620' O 06/17/01 Z' 6 963Z- 9642' O 06/17/01 Z' 6 9652'- 9660' O 06/17101 2-1/2" 6 976Z- 9782' O 03/26/01 2" 6 9798'- 9814' O 04/26/01 2" 6 9822'- 9832' O 04/26101 DATE REV BY COMk/~NTS DATE REV BY COMMENTS 11/10/00 ORIGINAL COIVPL~ION 05/07/01 JJ/KAK ADPERFS 11115/00 SIS-SLT CONVERTEDTOCANVAS 06/21/01 /TP ADDPERFS 01/26/01 SIS-MD RNAL 03118101 RN/TP OOF~ECTIONS 03126101 GN/TLH INITIAL PERFS PRUDHOE BAY uNrr WB.L: S-103 PERMIT No: 200-186 AP! No: 50-029-22981-00 SEC 35, T12, R12E, UM4571' NSL, 4409'WB. BP Exploratbn (Alaska) To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs" S-103 AURORA, July 02, 2001 AK-MM-00250 S-103 AURORA: 2"x 5" MD Resistivity & Gamma Ray Logs' . 50-029-22981-00 2"x 5" TVD Resistivity & Gamma Ray Logs' · 50-029-22981-00 2"x 5" MD Neutron & Density LOgs.: 50-029-22981-00 2"x 5" TvD Neutron & DensitY Logs: 50-029-22981-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL' LETTER TO THE ATTENTION OF: . Sperry-Sun Drilling Services Atto: Jim Galvin. 6900 Arctic Blvd. .'. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. . Petro-technical Data Center LR2,1 900 E. Benson Blvd. ' Anchorage, Alaska' 99508 Date: JUL 0 2 2,.t)1 ~llm C~l & Ga~ Gores. Cemmi~m REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development._X RKB 64.6 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 service_ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM (asp's 618930, 5980775) S-103 At top of productive interval 9. Permit number / approval number 932' FNL, 2421' FEL, SEC 27, T12N, R12E, UM (asp's 615639, 5985779) 200-168 / (301-146 signed 6/11/2001) At effective depth 10. APl number 50-029-22981 At total depth 11. Field / Pool 585' FNL, 2666' FEL, SEC 27, T12N, R12E, UM (asp's 615388, 5986123) Prudhoe Bay Oil Pool / Aurora Pool (undefined) 12. Present well condition summary Total depth: measured 10079 feet Plugs (measured) Tagged PBTD @ 9930' MD on 4/25/2001. true vertical 7009 feet Effective depth: measured 9930 feet Junk (measured) true vertical 6913 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 109' 20" 260 sx AS 109' 109' Surface 3022' 9-5/8" 562 Sx AS Lite III & 260 Sx Class 3087' 2830' Production 9992' 7" 582 Sx C~ass G 10057' 6994' Perforation depth: measured 9608' - 9620'; 9632' - 9642'; 9652' - 9660'; 9762' - 9787'; 9798' - 9814'; 9822' - 9832'. true vertical 6707' - 6715'; 6723' - 6729'; 6735' - 6740'; 6806' - 6818'; 6828' - 6839'; 6844' - 6850'. Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80-NSCT Tbg O 9489' MD. RE C E iV E D Packers & SSSV (type & measured depth) 7"X 3-1/2" Baker S-3 Packer O 9432' MD.JUN 2,5 '" ?nnl 4-1/2" X Landing Nipple @ 2110' MD. 13. Stimulation or cement squeeze summary Naska Oil & Gas Cons, Commission Intervals treated (measured) (see attached) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 736 1200 469 - 258 Subsequent to operation 770 4465 1890 - 303 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Aurora Surveillance Engineer Date June 20, 2001 Jim Youngv -- ~ Prepared by Paul Rauf ,564-5799 ORIGINAL Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE S-103 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 6111/2001: 611712001: 6/18/2001: Sundry Application approved for add perfs. Approval number 301-146. MIRU ELU. Safety meeting. PT'd equip. RIH & did correlation. Shot 30' of add perforations in 3 separate runs as follows: 9608' - 9620' MD (Kuparuk Zone) Reference Log: Sperry CNPGR 11/07/2001. 9632'- 9642' MD (Kuparuk Zone) 9652'- 9660' MD (Kuparuk Zone) Used 2" carriers & all shots @ 6 SPF, random orientation, 60° phasing, & underbalanced press. POOH w/guns - ASF. RD ELU. Well left on production. Obtained representative production test. Page I WELL LOG TRANSMITTAL To: State of Alaska May 30, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs S- 103, 1 LDWG formatted Disc with verification listing. API#: 50-029-22981-00 AK-MM-00250 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED JUN 0,1 2001 Ala~ Oil & 6~ Cons. ~ T' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _X Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P, O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface ~' ~' ~ 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 932' FNL, 2421' FEL, SEC 27, T12N, R12E, UM At effective depth At total depth 585' FNL, 2666' FEL, SEC 27, T12N, R12E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic __ Service_ (asp's 618930, 5980775) (asp's 615639, 5985779) (asp's 615388, 5986123) 6. Datum elevation (DF or KB feet) RKB 64.6 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-103 9. Permit number / a~proval number 200-168 '" 10. APl number 50-029-22981 V~ 11. Field / Pool Prudhoe Bay Field/Aurora Pool (undefined) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 109' Surface 3022' Production 9992' Size 20" 9-5/8" 7" 10079 7009 9972 6940 feet Plugs (measured) feet feet Junk (measured) feet Cemented 260 Sx AS 562 Sx AS Lite III & 260 Sx Class G 582 Sx Class G Measured Depth True verticalDepth 109' 109' 3087' 2830' 10057' 6994' Perforation depth: measured 9762' - 9787'; 9798' - 9814'; 9822' - 9832'. true vertical 6806' - 6818'; 6828' - 6839'; 6844' - 6850'. Tubing (size, grade, and measured depth 3-1/2", 9.2#, L-80-NSCT Tbg @ 9489' MD. Packers & SSSV (type & measured depth) 7" X 3-1/2" Baker S-3 Packer @ 9432' MD. 4-1/2" X Landing Nipple @ 2110' MD, 13. Attachments Description summary of proposal _~ Detailed operations program__ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation June 10, 2001 16. If proposal was verbally approved Name of approver Date approved Oil _ X Service Gas __ Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedjimYoun~l ~/~~~~2.) Title: Aurora Petroleum Engineer FOR COMMISSION USE ONLY Questions? Call Jim Young O 564-5754. Date June 1,2001 Prepared by Paul Rauf 564-5799 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance _ ,I._t~ Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commission .Original S~ed 6y Commissioner Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE bp June 1, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: 'i:' ECEIVE ,.:,Jf,.j ,",, EO01 Oil & Gas C, ons. Oommissios Anc, RE: Sundry Notice for S- 103 Add Perforations (permit #200-168). Underbalanced perforating is proposed for Aurora development well S-10B. Underbalance should be achieved by gas-lifting with the well open to LPS. The proposed perfs are lower quality reservoir, so long clean perf tunnels are necessary to enhance flow since fracturing will not be possible due to a prognosed GOC at -9580' MD. S-103 E UB Perforate 9608'-9660' After rig moves off S-106 Ref Log Log: CNPGR Date: 11/7/2000 Company: ,..S.,,p...,.e.,,.,r..~ ............................. Depths (from-to) ................... 9,,,,,,6,,,0,,,8,,,'. ................................... .9,.,,,,6,,,,2,,,.0,.', ................ ................... 9....,.6..3....2..'. ................................... 9..:6....4...2.'. ................ ................... .9.. ..'. ~r5..2..'. ................................... .9.:6...6..9..'. ................ Gas Jetting Expected? Min. Accept. Penetration: Tie-in = :Ref Log+ 3 ft CMTGR 3/25/01 Schlum Feet SPF Ubalance Phasing Zone Ad/Re/Iperf ............. ,!,,,,2..: ...................................... ,,,6,.. .......................................... ,~,,,.o,,,,.,O..,,,o,,,p,..,,s.,,!. ................................... ,,,6,.,,,02 ....................... ,,,C.,,,,3,,,,,A,,,, .................................................. !.p,,,.,e.,,.~ ........................................ ............. .!.,,,o,,,,', ...................................... ,,,6,,, ............................................ ,!,,,O,,,,,O,,,,,o,,,p,,,,,s,,i ................................ ,,,6,,,9.,°,, ....................... ,,.,C,..,3,.,,...A,, .................................................. !,,p.,.,.e,,,..rf.,,. ....................................... ............... ,,.8,.,', ......................................... ,,,6,., .......................................... ,!.,,,O...,,O.,,.,o,..p,,...s,.i ................................... ,,.6...9.,°.. ....................... 9.....3.......A,. .................................................. !.p.....e....d. ....................................... NO Rate: 900 bopd, 40%wc 800 FGOR 20" ........ ...P,..,o..,~9..rj.9.t. ........ Min. Accept. Hole Size: ............. ..N......A... ............ Is Drawdown Necessary/Desired/Unnecessary During Perforating Schematic 7 in 9600 MD 3200 ................................................................................ Gas-lift off to >5600' TVD, flow well to LPS to achieve >1500psi underbalance (seawater below) Multiple-See Minimum ID: 2.75 in Min ID Type: Tail Depth: ................. ..9..4...9..0. ................ ft MD Casing Size: H2S Level: ........................................................ ppm Est Res. Pres. @ Last Tag: ft MD on Attachment: Reference log with proposed perfs annotated, 5"/100' scale S-103 Max. Deviation: 56° @ 8160' md Perf Deviation: 50° Latest H2S value: None taken (offset S-100=8ppm) P~ Page 1 Last Tag TD: 9930' on 3/3/01 If you have any questions, please contact Jim Young, Aurora Petroleum Engineer, at 564-5754 or by email at Youngj3@bp.com. Sin~5~ely,, Jim Young Aurora Petroleum Engineer Page 2 TREE = 5M ClW CHROIVE LHEA D= FMC GEN 5 ACTUATOR=- ? B. EV = 64.61 BF. ELEV = 36' KOP= 1636' Max Angle = 56 @ 6294' Datum IVD = 10079' Datum TVD= 6944' S-103 F-~AFETY NOT ES 2110' ~ 3-1/2" I-ES'X'NIPPLE ID= 2.992"I 19-5/8" CSG, 40~, L-80, BTC, ID = 8.750" ~ 3087' GAS LIFT M~I~RB_S IMinimum ID = 2.75" (~ 2110' I 3-112" HES 3(' Nipple I 3-1/2"TBG, 9.2#,L-80-NSCr, .0087 bpf, ID=2.992" H 9489' PE~=ORA'RON SUMMARY REF LOG: MVVD / GR 11/7/2000. ANGLE AT TOP PERF: SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 6 9762'- 9782' O 3/26/2001 Z' 6 9798'- 9814' O 4/26/2001 Z' 6 9822'- 9832' O 4/26/2001 ~ 9972' 17" CSG, 26#, L-80-BTC-tvt ID= 6.276" I--I I 9429' ~ 3-1/2"X4-1/2"NSCT'XO'I 9432' 7" x 3-112" BAKER S-3 PKR J 9435' 4-1/2" X 3-1/2" NSCT 'XO' J ~6' J~ 3-112" I-ES'X'NIP, ID= 2.75" J 9477' ~ 3-1/2" HES, 'X' NIP, ID= 2.79' J WLEG I IELMD NOT LOGGED I DATE REV BY COMIVENTS DATE REV BY COMIVENTS 11/10/00 ORIGINAL COIVPL~I~ 05/07/01 JJ/KAK ADPERFS 11/15/00 SIS-SLT CONVERTEDTO CANVAS 01/26/01 SIS-MD RNAL 03/18/01 RN/TP COI~,ECTIONS 03/26/01 GN/TLH INITIAL PERFS PRUDHOE BAY UNIT WB.L: S-103 PERMIT No: 200-186 APl No: 50-029-22981-00 SEC 35, T12, R12E, UM 4571' NSL, 4409' WEL BP Exploratbn (Alaska) 5/17/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57tl ATTN: Sherrie NO. 1150 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-103 '~.OO-I-G~ 21211 SCMT(PDC) '- 03123101 -. 1 . . . . _ r' . 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 HAY 1 8 2001 . Schlumberger DCS 3940 Amtic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Recei 5/10/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: sherrie NO. tt30 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-103 . ~ 13 b" ~ I~ 21174 SCMT 03123/01 2 S-103 2t2t0 RST 0412610t 1 1 S-105 ~-~bO~ ~_~ PRODUCTION PROFILE/DEFTIGLS 04123101 1 t -. 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 HAY 1 5 2001 .- . Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie " 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 r~ GAS [~] SUSPENDED F'~ ABANDONED D SERVICE D 2. NameExplorationOf Operator(Alaska), t.~;~.~'l~l~l~ i 7. Permit Number BP Inc. V~ 200-168 3. Address ,%lt, C~a~,,~ 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 ~ i'~.~ 50-029-22981-00 4. Location of well at surface ~'"'~ 9. Unit or Lease Name , 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM (asp's 618930, 5980775) :' ''''-~ .... ~"'"; t Prudhoe Bay Unit At Top Producing Interval ~ 10. Well Number 932' FNL, 2421' FEL, SEC 27, T12N, R12E, UM (asp's 615639, 5985779) . -~: .2....~,_. ~...; S-103 At Total Depth ......./---"-- "~-" ¢ 11. Field and Pool 585' FNL, 2666' FEL, SEC 27, T12N, R12E, UM (asp's 615388, 5986123) .............. -- .......... ..... .'- Prudhoe Bay Field / Aurora 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 64.61 feetI ADL 28258 Pool (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date. Corpp., Susp. Or Aband. 115. Water Depth, if offshore '16. No. of Completions November 6, 2000 November 18, 2000 ~,t~.Ir26, 2001/~ I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10079' MD / 7009' TVD 9972' MD / 6940' TVD YES [~] No r~'1 2110, (nipple) feet MD 1798' 22. Type Electric or Other Logs Run MWD GR; MWD GR/Resistivity/Neutron/PWD; SCMT/Jewerly; RST Sigma 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WI'. PER FT. GRADE TOP Bo'n'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 109' 30" 260 Sx AS 9-5/8" 40# L-80 Surface 3087' 12-1/4" 562 Sx AS Lite III & 260 Sx Class G 7" 26# L-80 Surface 10057' 8-3/4" 582 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) (with 2-1/2" HSD P J, 6 SPF, 60°phasing & underbalanced) 3-1/2" 9.2# L-80 9489' 9432' 9762' - 9782' MD; 6806' - 8818' TVD (with 2" HSD PJ, 6 SPF, 60° phasing & underbalanced) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9798' - 9814' MD; 6828' - 6839' 'I'VD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9822' - 9832' MD; 6844' - 6850' TVD FP w/75 bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 26, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 4/29/2001 4.0 Test Pedod > I 601 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -288 psi 24-Hour Rate > 850 511 641 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved November 3, 2000 (Permit ~Y200-168) RECEIVED ,, MAY 0 3 Z001 Form 10-407. Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Alaska 0il & Gas Cons. Commission 0 ~..~.. I G! I [~/~_~ L Anchorage " GEOLOGIC MARKEI~ FORMATION TESTS NAME Include inten/al tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top Shrader Bluff / Base Ugnu 6253' 4712' Base Shrader Bluff/Top Colville 7339' 5337' Top of Kupamk C Sand 9524' 6652' Top of Kuparuk B Sand 9769' 6810' Kuparuk A6 9926' 6910' Kuparuk A5 9940' 6919' Kuparuk A4 9974' 6941' Base Kuparuk / Top Miluveach 10034' 6980' 31. LIST OF ATTACHMENTS Summary of S-103 Rig Drilling Operations + End of Well Survey + FIT. Signec[ /~~_ _ ~/', I Title AD&W Drillin,q En,qineer Date May 1, 2001 Allen ShernW V Prepared by Paul Rauf 564-5799. 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 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". RECEIVED Fo.. 0 07 MAY 0'3 ZOO1 ORIGINAL Alaska 0il & Gas Cons. Commission Anchorage '" S-103 DESCRIPTION OF WORK COMPLETED POST RIG DRILLING OPERATIONS SUMMARY Date Event Summary 3102/2001: 3/0312001: 3/23/2001: 312412001: 3/25/2001: 3/2612001: 312712001: 3/3012001: 4/25/2001: 4/26/2001: 4/29/2001: RIH & pulled ball / rod @ 9470' SLM. Installed generic GLV design. RIH & pulled RHC Plug f/3-1/2" tubing @ 9475'. Tagged PBTD @ 9930' SLM. Pulled Station #1 CA/RD/RK DGLV. Set RK/SP Mem Gauge. RIH w/logging tools. Ran SCMT & jewerly log f/9473' to 9913' MD. Pumped Methanol down IA. Underbalanced tubing in prop for IPERF's. FP'd well. MIRU wireline unit. PT'd equip to 3000 psi. RIH w/perf guns & shot 20' of Initial Perfs f/: 9762' - 9782' MD (Kuparuk C/B Zone) Used 2-1/2" HSD PJ carriem & all shots @ 6 SPF, 60° phasing, random orientation, & 1600 psi unerbalanced. POOH w/guns - ASF. RD wimline unit. Placed well initially on production w/AL. Performed 1st well test as follows: Oil = 3437 bopd, Water = 0 bwpd, FM Gas = 2073 MSCFD, FM GOR = 603, FTP = 270 psi, duration = 4 hrs. Pulled Station #1 RK/SP Mem Gauge. Set CA/RD/RK DGLV. Performed RST Sigma Log. MIRU wimline unit. PT'd equip to 3000 psi. RIH w/perf guns & shot (in 2 separate runs) the remaining 26' of Initial Perforations f/: 9798' - 9814' MD (Kuparuk B3 Zone) Reference Log: Sperry MWD/GR 11/7/2000. 9822' - 9832' MD (Kuparuk B3 Zone) Perforated while well was flowing. Used 2" HSD PJ carriers & all shots @ 6 SPF, 60° phasing, underbalanced press, & random orientation. POOH w/guns - ASF. RD wireline unit. Left well on production. Performed well test. BP EXPLORATION Page I of 1 Final Well ! Event Summary Legal Well Name: S-103 Common Well Name: S-103 Event Name: DRILL+COMPLETE Start Date: 11/6/2000 End Date: 11/21/2000 DATE TMD 24 HOUR SUMMARY 11/6/2000 225.0 (fi) MIRU Nabors 9ES on Well #S-103. Spud well. 11/7/2000 956.0 (ft) Drill 12 1/4" surface hole. 11/812000 2,202.0 (fi) Drill 12 1/4" Directional hole F/956'-2202'. 11/9/2000 3,102.0 (ft) Drilled to 9 5~8" csg point. Short trip to 1798'. C & C mud. 11/10/2000 3,102.0 (ft) Run, Land & Cement 9 5~8" CSG. 11111/2000 3,102.0 (ft) Perform 2nd stage cmt. N/U & test BOP. M/U 8.750" BHA. 11/12/2000 4,030.0 (fi) TIH with 8.75" drlg assy. Drlg out & FIT. Drlg ahead. 11/13/2000 5,895.0 (ft) Drlg to 5895'. MWD tool Failure. POOH to change MWD. 11114/2000 7,016.0 (ft) POH, c/o MWD, RIH - no fill, Drill Dir. Hole Fr. 5895' to 7016'. 11/1512000 7,949.0 (fi) Drill to 7949, POH to shoe,c/o liners to 5" RIH 11/1612000 9,068.0 (ft) RIH to 7949', Dir. Drill to 9068. POH to 9 5/8' shoe, prep for mud c/o 11117/2000 10,000.0 (fi) Displace to GEM. Drill to 10,079'. ST to 8,920. RIH and MADD. 11/18/2000 10,079.0 (ft) Drill to TD @ 10,079'. Check Trip. POH. PJU and run 7" Casing. 11/19/2000 10,079.0 (fi) Run 7" casing to 10,057'. Work tight Hole. Cement. FP. RIH with DP 11/20/2000 10,079.0 (ft) Chg. rams & test, I_/D excess 4" DP, Rig & Run 3 1/2" comp. string. 11/21/2000 10,079.0 (fi) Run prod tbg,N/D BOPE, N/U Tree Set Pkr Frz. prot. secure well ReI.Rig Printed: 511/2001 10:21:38 AM BP EXPLORATION Page 1 of 6 Operations Summar Report Legal Well Name: $-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: DRILL+COMPLETE Start: 11/6/2000 End: 11/21/2000 Contractor Name: NABORS Rig Release: 11/21/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date. .'From 'To Hours Task. Sub phase. ' ' Description of Operations Code . 11/6/2000 00:00 - 03:00 3.00 MOB PRE Prepare to move rig. Blow down steam lines. Secure pipe in derrick and Disconnect Pit module. Move pit module to S-103. Move Sub module off S-105. 03:00 - 07:00 4.00 RIGU PRE Move mats and herculite. Move sub base and spoy rig. Spot and connect pit Module Accept rig at 07:00 11/06/2000. 07:00 - 14:00 7.00 DRILL SURF NU flow nipple on pre installed diverter. NU koomey lines. Function test diverter. Clear floor and pu BHA tools to floor. Take on water and mix spud mud. 14:00 - 16:30 2.50 DRILL SURF Topdrive repair. 16:30 - 19:00 2.50 DRILL SURF MIU 12 1/4" Drilling assembly. 12 1/4" bit, mud-motor, NM Flex pony collar, 12" NM Stabilizer, 7 7/8" Drilling jar, xo. Adjust mud-motor to 1.5 deg bend. 19:00 - 20:00 1.00 DRILL SURF Held Pre-Spud meeting with rig crews. Function test 21 1/4" Diverter system ( 18 seconds to close element ). ** Chuck Scheve with the ^OGCC wavied witnessing the 21 1/4" Diverter Function test ** 20:00 - 21:00 1.00 DRILL 'SURF Fill up hole with spud mud & check mud system for leaks. Found Bell-nipple dresser sleeve leaking. Adjust & tighten same. 21:00 - 23:30 2.50 DRILL SURF Spud well @ 21:00 hrs. Clean out 20" conductor pipe to 109'. Drill 12 1/4" hole from 109' to 225'. 23:30 - 00:00 0.50 DRILL SURF Circulate hole clean from 225' with 586 gpm. Lots of gravel coming over shale shakers. Held D3 Diverter drill. 11/7/2000 00:00 - 00:30 0.50 DRILL SURF POOH from 225'. 00:30 - 02:30 2.00 DRILL SURF Check bit. M/U 12 1/4" Steerable drilling assembly. Orient mud-motor & MWD. Break Circulation. 02:30 - 12:30 10.00 DRILL SURF Drill 12 114" hole from 225' to 648'. 12:30 - 13:30 1.00 DRILL SURF Rigs Top-Drive developed a oil leak on the Iow pressure oil return line. Repair leak. Change oil & filter on Top-Drive. 13:30 - 17:30 4.00 DRILL SURF Drill 12 1/4" hole from 648' to 871'. WOB = 2-18K, RPM = 55, GPM - 483 with 1300 psi. PU = 87K, SO = 80K, ROT WT -- 85K. 17:30 - 18:30 1.00 DRILL SURF Circulate hole clean from 871'. 18:30 - 20:00 1.50 DRILL SURF POOH for bit change. No hole problems encountered. 20:00 - 21:30 1.50 DRILL SURF MIU Bit #2. TIH with BHA to bottom with no problems. 21:30 - 00:00 2.50 DRILL SURF Kick-off well from 871'. Drill 12 1/4" directional hole from 871' to 956'. ART = 6.75 AST = 5.5 1118/2000 00:00 - 00:00 24.00 DRILL SURF Drill 12 1/4" directional hole from 956' to 2202'. PU -- 103K, SO -- 98K, ROTWT -- 101K. WOB -- 5-20K, RPM = 60, GPM -- 542 ~ 1900 psi. ** Mud-motor factor = .15 RPM/GAL** ART -- 4, AST -- 14.25. No drag, No losses. 11/9/2000 00:00 - 16:30 16.50 DRILL SURF Drill 12 1/4" directional hole from 2202' to 3102' MD/2839' TVD which is TD for 9 5~8" surface casing. PU = 11 OK, SO = 99K, ROT WT = 108K. WOB 5-30K, RPM = 60, GPM = 550 @ 2350 PSI. ART = 5.75 hrs, AST = 7.25 hrs. No losses. 16:30 - 18:00 1.50 DRILL SURF Pump 50 bbl Hi-vis sweep. Circulate hole clean from 3102'. 18:00 - 19:00 1.00 DRILL SURF POOH for wiper trip up to 2732'. Encountered tight hole from 2870'-2732' with 25-35k drag over normal PU wt. Note: Trip tank pump not working due to suction line being frooze up. 19:00 - 20:30 1.50 DRILL NDC SURF Circulate & work pipe @ 2732' while attempting to un-thaw Trip Tank suction line. 20:30 - 21:30 1.00 DRILL SURF Continue POOH to 1798' ( Base of permafrost ). Encountered tight hole from 2390'-2266' & 2177'- 1820' with 10-30k drag over normal PU wt. 21:30 - 23:00 1.50 DRILL SURF RIH to 3102'. Hit obstruction @ 1969' & 2090'. Both times circulation Printed: 11/28/2000 8:50:03 AM BP EXPLORATION Page 2 of 6 Operations Summa Report Legal Well Name: 8-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: DRILL+COMPLETE Start: 11/6/2000 End: 11/21/2000 Contractor Name: NABORS Rig Release: 11/21/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es ...... Sub" · ' ........... .Date From - To Hours Task Code Phase : :. DescriptiOn of operations· ... 11/9/2000 21:30 - 23:00 1.50 DRILL SURF was established, the bit was oriented to HS & worked past tight spot with no problems. Washed 87' to bottom with no fill. 23:00 - 00:00 1.00 DRILL SURF Pump 50 bbl Hi-vis sweep. Circulate hole clean from 3102' with 542 gpm @ 2250 psi. 11/10/2000 00:00 - 00:30 0.50 DRILL SURF Spot Casing pill with 5% Lubetex concentration below Permafrost. Drop ESS. 00:30 - 02:00 1.50 DRILL ~SURF POOH taking check shots. Average drag 10-15 kibe, 30 kibe ~ 3,000 ft '( Chert bed). 02:00 - 05:00 3.00 DRILL SURF i Lay down HWDP and BHA. Inspect bit- In good shape. 105:00 - 08:00 3.00 CASE SURF R/U to run 9.5/8" Surface casing. Power tongs, Spider, 15 ff bails and elevators. Make Dummy run with hanger. MIU Franks Fill-Up Tool. 08:00 - 08:30 0.50 CASE SURF Hold PJSM for casing running and discussion of Phase 2 weather Implications. Dowell and Peak Contractors on location and rigged up. 08:30 - 13:00 4.50 CASE SURF Check floats. Bakerlock shoetrack and run 9.5~8" casing - No Drag. Hit obstruction @ 2,670 ft. 13:00 - 14:45 1.75 CASE SURF Work 9.5/8" casing down from 2,670 tt to 3,086 ft. Taking 40-60 kibe weight to get casing down. Land casing ~ 14.40 hrs. Up weight 170 kibe, Down weight 90 kibe. Shoe {~ 3,086 ft MD, Port Collar (~ 1,008 ft MD. 75 joints 40 lb/fi, L-80 Casing. 14:45 - 15:30 0.75 CASE SURF Rig Down Franks Tool and R/U Cement Head. Clear rigfloor. 15:30 - 17:00 1.50 CASE SURF Circulate & condition mud/hole (~ 6 bpm with 300 psi. Reciprocate pipe 10' up/down while circulating. PU = 155K, SO = 120K. Held PJSM with rig crew while circulating. 17:00 - 20:00 3.00 CASE SURF Dowell test cement lines to 3500 psi. Cement 9 5/8" csg ~ 3087'. Pump 75 bbl of 10.4 ppg Mud-push spacer. Drop Btm plug. Mix & pump 257 bbl of 10.5 ppg ASL III lead slurry + 53 bbl of 15.8 ppg Class G tail slurry. Release Top plug. Dowell pump 10 bbl of water. Switch over to Rig pump & displace cement with 217 bbl of 9.5 ppg mud ~ 8.2 bpm with 565 psi. Bump plug with 3000 psi. Cement in place @ 19:50 hrs. Release pressure. Floats held. Had full returns throughout the entire job. No cement observed @ surface. Pumped 100% excess. 20:00 - 22:30 2.50 CASE SURF PJD Dowell cement head & lines. Back-out landing jt. & L/D same. PJD csg running tools. 22:30 - 23:30 1.00 CASE SURF M/U Tam Combo tool on 4" drill pipe. TIH to Tam collar ~ 1008'. Dropp 1 1/8" setting ball down drill pipe 2 etd prior to reaching Tam collar. 23:30 - 00:00 0.50 CASE SURF Engage Tam Port collar with Combo tool. Test Combo tool to 1000 psi. Open Port collar with 12K SO Wt. Establish circulation. Circulate through Tam Port collar {~ 8 bpm with 620 psi. Had cement contaminated mud to surface after pumping 72 bbl. 11111/2000 00:00 - 00:30 0.50 CASE SURF Continue Circulating thru Port Collar (~ 1,008 ft while preparing for second stage job ~ 8 BPM! 620 psi. 00:30 - 02:00 1.50 CASE SURF Pump 20 bbls water. Mix and Pump 192 bbls 10.7 ppg ASL II cement ~ 3 BPM! 200 psi. Observe contiaminated cement returns after 125 bbls. Pump further 67 bbls ( Total 249% excess). Water supply Iow. Shut down with High pH and weight of 9.7 ppg. Displace cement from pipe. 02:00 - 03:30 1.50 CASE SURF Close Port Collar. Test to 1200 psi. No Backflow. Relese tool. Circulate drillpipe annulus @ 8 BPM1565 psi. POOH with TAM Tool and L/D same. 03:30 - 06:00 2.50 BOPSUI; SURF Flush Diverter. N/D Diverter and riser. PJSM to mitigate hazards of opening Cellar doors in High Winds and other hazards of Phase 2 conditions for next phase operations 06:00 - 09:00 3.00 BOPSUi; SURF Install FMC Lower & Upper Unihead on 9 5/8" casing hanger mandrel. Printed: 11/28/2000 8:50:03 AM BP EXPLORATION Page 3 of 6 Operations Summa Report Legal Well Name: $-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: DRILL+COMPLETE Start: 11/6/2000 End: 11/21/2000 Contractor Name: NABORS Rig Release: 11/21/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es · . .Sub: .. Date From-T° Hours .Task Code Phase... Description of OPerations 11111/2000 06:00 - 09:00 3.00 BOPSUI~ SURF Test casing hanger/head connection to 1000 psi for 10 minutes. Test was APl. 09:00 - 16:00 7.00 BOPSUI; SURF N/U 13 5/8" 10M BOP'S & Bell-nipple. Test C/K Manifold to 250/3500 psi & change out Die blocks on Top-Drive. 16:00 - 21:00 5.00 BOPSUlq SURF Test BOP'S. Test all rams, Hydril, ClK lines & valves to 250~3500 psi. Test Top-Drive & all surface related equipment to 250/3500 psi. Had to change out leaking Lower IBOP on Top-Drive. Install Wearbushing. ** Note: John Crisp with the AOGCC wavied witnessing the 13 5~8" BOP Test. 21:00 - 00:00 3.00 DRILL PROD1 Test 9 5/8" casing for 10 minutes. M/U 8 314" Steerable drilling I assembly. Held PJSM prior to Sperry-Sun installing Nuclear source in LWD. 11/12/2000 00:00 - 01:00 1.00 DRILL PROD1 Continue to M/U 8 3~4" Performance BHA. Surface test same. 01:00 - 02:30 1.50 DRILL PROD1 Slip and Cut 78 ff Drill line. Servive Top Drive. 02:30 - 07:30 5.00 DRILL PROD1 RIH Picking up 33 jts 4" HWDP. P/U 51 joints 4" DP and rack back. RIH picking up further 51 joints 4" DP. No problem going through TAM collar. 07:30 - 08:00 0.50 DRILL PROD1 Wash down last two stands as a precaution and observe cement @ 2,962 ff ( 38 ft high). 08:00 - 09:00 1.00 DRILL PROD1 Drill Hard cement f/2,962 fi to 3,001 fi ( Landing Collar) 09:00 - 09:30 0.50 DRILL PROD1 CBU ~ 420 GPM/1300 psi. 09:30 - 10:30 1.00 DRILL PROD1 Test Casing to 500~3500 psi for 30 minutes. 3.3 bbls pumped/returned. Held Reservoir Meeting while testing casing. 10:30 - 12:30 2.00 DRILL PROD1 Drill Good cement ~ 70-150 fi/hr wi 5 klbs WOB to 3102 fi and Drill 20 fi new formation to 3,122 fi. 12:30 - 13:30 1.00 DRILL PROD1 Displace well to 10.5 ppg New LSND mud. 13:30 - 14:30 1.00 DRILL PROD1 Conduct FIT to 12.6 ppg EMW ( 310 psi surface pressure). Shoe ~ 3087 ft MD/2837' fi TVD. 0.8 bbls pumped, 0.5 bbls Returned. 14:30 - 00:00 9.50 DRILL PROD1 Drill 8 3/4" directional hole from 3122 fi to 4030 fi. WOB -- 2-10K, RPM . -- 80, GPM -- 520 wi 2450 psi. PU = 103K, SO = 86K, ROT WT -- 96K. ART = 4.25 hr. ^ST = 1.25 hr. 11113/2000 00:00 - 19:30 19.50 DRILL PROD1 Drill 8 3~4" Directional hole from 4030 fi to 5895 ft. WOB = 5-151(, RPM 60-80 + MM, 520 GPM WITH 3150 PSI.** Note: Had MWD Tool failure prior to reaching 5895'. MWD not transmitting the correct azimuth. 19:30 - 20:30 1.00 DRILL PROD1 Pump Hi-vis pill & circulate hole clean from 5895'. 20:30 - 23:30 3.00 DRILL PROD1 POOH. Encountered excessive tight spot at 3557'. Hole was tight from TD all the way up the hole. Had 15-50K drag from TD up. Worked pipe down on each std & then pulled back up through same interval. The drag was significantly reduced while performing this procedure. 23:30 - 00:00 0.50 DRILL PROD1 Backream hole from 3557' to 3277'. 450 gpm with 2100 psi, 60 RPM with 3-1 OK torque. 11/14/2000 00:00 - 01:00 1.00 DRILL PROD1 Backream tight hole to 9.5~8" shoe @ 3,087 ft.450 GPM/2100 psi. 60 RPM, 3-10 kffibs. (Soft clays underneath above SV-1) 01:00 - 01:30 0.50 DRILL LMWD PROD1 CBU- no excessive cuttings from hole. Flowcheck. Pump Slug. 01:30 - 04:30 3.00 DRILL LMWD PROD1 POOH. Inspect Bit. L/D PWD/NEUI PUL/DIR. Clear rigfloor 04:30 - 07:30 3.00 DRILL LMWD PROD1 M/U new module. Surface test same. RIH to 9.5/8" shoe ~ 3,087ft. 07:30 - 09:00 1.50 DRILL PROD1 Service Top Drive. Slip and Cut Drilline. ( 42 ft) 09:00 - 11:00 2.00 DRILL PROD1 RIH. Wash down last two stands from 5,709 ff taking two checkshots. No fill. Hole in good shape. 11:00 - 00:00 13.00 DRILL PROD1 Drill 8 3~4" Diectional hole from 5898' to 7016'. WOB: 5 - 20 K, RPM - 60 - 80 + MM, 500 GPM w/3100 psi. AST = 1.5 hrs, APT = 7.5 hrs. Printed: 11/28/2000 8:50:03 AM BP EXPLORATION Page 4 of 6 Operations Summa Report Legal Well Name: 8-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: DRILL+COMPLETE Start: 11/6/2000 End: 11/21/2000 Contractor Name: NABORS Rig Release: 11/21/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date From-To Hours Task ~nu~ Phase Description of Operations , · . 11114/2000 11:00 - 00:00 13.00 DRILL PROD1 Note: Experienced hard interval 6700' to 6713. Also bit and stabilizer bailing @ 6713' and 6950'. Hi Vis sweeps alleviated the problem and also reduced torque, circ. pres.and ECD. 11/15/2000 00:00 - 05:30 5.50 DRILL PROD1 Directionally Drill 8.75" hole fl 7,016 fi to 7,485 ft. No Drag, No Losses. Parameters steady. 05:30 - 06:30 1.00 DRILL PROD1 Ciroulate Hole clean @ 490 GPM while rotating @ 85 RPM/7,000 ftlbs. 06:30 - 09:30 3.00 DRILL PROD1 Make Check trip to old hole @ 5,800 fi. Drag- 20-45 klbs. Acting like Filter Cake. Double wipe each stand. Tight spot @ 6,600 fi-work thru same- acting like "debris" caught @ bit. Old hole in good shape. 09:30 - 15:30 6.00 DRILL PROD1 Directionally Drill 8.3/4" Hole from 7,485 ft to 7,949 ft. ECD staying steady @ 11.1-11.2 ppg. Sweeps less effective with footage drilled but all other parameters steady ( Flowrate @ 470 GPM/3350 psi). Some drag on connection ~ 7,857'. 15:30 - 16:00 0.50 DRILL TGHT PROD1 Work tight hole @ 7,949' on a connection. Slump pipe with high RH torque to free same. Work pipe and clean up stand reaming down @ 85 RPM/high torque, pumping up @ 480 GPM/3400 psi. All indications suggest inadequate hole cleaning. Prepare to POOH to shoe to change to 5" liners. 16:00 - 17:00 1.00 DRILL PROD1 Sweep hole clean while working pipe. 17:00 - 20:00 3.00 DRILL PROD1 POH to 9.5/8" shoe ~ 3,087 fi. Hole in good shape - normal drag {~ 10-15 klbs. 20:00 - 22:30 2.50 DRILL PROD1 C/O Liners and swabs on both pumps to 5". Service Top Drive. 22:30 - 00:00 1.50 DRILL PROD1 RIH to 3150', Flow test mud pumps - 210 spm -'- 520 gpm. @ 2285 psi. Check MWD -OK. Cont. RIH. 11/16/2000 00:00 - 01:30 1.50 DRILL PROD1 Continue RIH to 7770', wash to 7949' No Fill. 01:30 - 16:30 15.00 DRILL PROD1 Drill directional hole from 7949' to 9068' pumping sweeps every 100 fi.. Torque up to 12 K. Increased rotary to 100 rpm. in effort to improve hole cleaning, control drilled at < 100 fi/hr. 16:30 - 18:00 1.50 DRILL PROD1 Circulate hole clean with Hi Vis sweep. 18:00 - 23:00 5.00 DRILL PROD1 POOH to 9 5/8" Casing shoe at 3087. Pulled max of 230 K through new hole up to 7950'. Pulled rest of the way to shoe with no excessive drag. 23:00 - 00:00 1.00 DRILL PROD1. Service Top Drive while cleaning pits for KCL I Gem mud change over. 11/17/2000 00:00 - 03:30 3.50 DRILL PROD1 RIH to 9068 washing down last stand. Hole in good shape- no fill. 03:30 - 06:00 2.50 DRILL PROD1 Stage Pumps up to 500 GPM while working pipe and observe considerable cuttings on bottoms up and 1500 units of gas.( 9.5 ppg gas cut mud). Circulate shakers clean. 06:00 - 08:00 2.00 DRILL PROD1 Pump 70 bbls 10.8 ppg Spacer and displace to KCL/GEM mud system. Due to hole cleaning issues did not drill and displace. Clean out Possum Belly and shaker trays. 08:00 - 00:00 16.00 DRILL PROD1 Drill Directional 8.3/4" hole from 9,068' to 10,001'. No Losses. With New Mud in hole connections smoother but still some drag. Backreaming each stand (~ 80 RPM1500 GPM. Reaming down ~ 480 GPM. Drilling with 100 RPM. Good ECD hole cleaning "signatures"- 11.2-11.5 ppg. Once in Sandstone- connections incident free 11118/2000 00:00 - 02:30 2.50 DRILL PROD1 Drill 8.75" hole to TD @ 10,079 ft. Top Mileuveach ~ 9,911 ft. Top Kuparuk @ 9,524 ft MD. No Drag, No Losses. 02:30 - 04:00 1.50 DRILL PROD1 Circulate Bottoms Up ~ 500 GPM/3100 psi while working / rciprocating pipe @ 85 RPM/8,000 ftlbs. 04:00 - 05:00 1.00 DRILL PROD1 Make wiper trip to old hole- tight through lower shales ( 35 klbs drag). Rest OK. 05:00 - 08:30 3.50 DRILL PROD1 RIH and conduct MADD pass from 9,480' to bottom of sand @ 300 fph. 08:30 - 11:00 2.50 DRILL PROD1 Sweep Hole clean 520 GPM/3300 psi working/reciprocating pipe. Spot 60 bbls Casing Pill and pump dry job. Flowcheck. Printed: 11/28/2000 8:50:03 AM BP EXPLORATION Page 5 of 6 Operations Summa Report Legal Well Name: 8-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: DRILL+COMPLETE Start: 11/6/2000 End: 11/21/2000 Contractor Name: NABORS Rig Release: 11/21/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Task 'Sub" PhaSe .Description of Operations Code 11/18~2000 11:00 - 16:00 5.00 DRILL PROD1 POOH. Some drag across lower shales & 8,500 ft. Rest of Hole in Good Shape. SLM. FC @ Shoe. SIB HWDP. Take P/U and S/O every 10 stands in OH. 16:00 - 18:30 2.50 DRILL PROD1 Download LWD data. PJM. Remove Nuclear Sources. L/D BHA and inspect bit 18:30 - 21:30 3.00 CASE = COMP Pull Wear Bushing. Change out UVBR to 7" Casing Rams. Test BOP bonnets to 3500 psi. Make dummy run with hanger. 21:30 - 23:00 1.50 CASE COMP :R/U 7" casing running equipment. PJSM. 23:00 - 00:00 1.00 CASE COMP ~Check Floats. Bakerlock Shoetrack. Run 7", 26 Ib/ft, L-80 casing. 11119/2000 00:00 - 03:00 3.00 CASE COMP Run 7" casing to 9.5~8" Shoe (~ 3,087 ft. 03:00 - 04:00 1.00 CASE COMP Circulate casing contents ( 120 bbls ) ~ 4 BPM/350 psi. Full returns. 04:00 - 13:30 9.50 CASE COMP Run 246 Joints 7", L-80, 26 lb Ift casing. M/U mandrel hanger and RIH. Stacked out at 10,050 ft. Losses while running pipe= 42 bbls. Running rate adjusted accordingly once losses noted. ( Suspect loss zone is SV1 with cold mud: YP=36, PV=25. 13:30 - 16:00 2.50 CASE COMP Work Pipe. P/U 300 klbs, S/O 80 klbs. Unable to circulate or work pipe down-Packed Off. Reciprocate pipe and gradually gain circulation. Stage pump up to 6 BPM1900 psi while working pipe. Finally land casing ~ 1530 hrs with Shoe ~ 10,057 ft. Losses while circulating = 44 bbls. 16:00 - 16:30 0.50 CEMT COMP R/D Franks circulating tool and PJU Cement head and lines. 16:30 - 17:00 0.50 CEMT COMP Circulate to ensure stable rate and pressure prior to Cementing. 7 BPMI 900 psi wi full returns. 17:00 - 19:30 2.50 CEMT COMP Test lines to 3500 psi. Pump 50 bbls 11.5 ppg Spacer. Drop bottom plug, Mix and pump 161 bbls 11.5 ppg Lead, and 57 bbls 15.8 ppg Tail at 6 BPM/600 psi. Drop Top Plug and displace with 374 bls Seawater. Bump plug with 3500 psi. ClP ~ 1930 hrs. Floats held PBTD ~ 9,972 ft. Full Returns. 19:30 - 21:30 2.00 CASE COMP R/D Landing it. MIU 7" packoff, RIH, set packoff, RILDS, Test Packoff to 5000 psi. - 15 min, OK 21:30 - 23:30 2.00 CASE COMP FUU Rig pump & Hot oiler on 9 5/8 X 7' annulus. test all lines to 3500 psi. With Rig pump; bullhead 93 bbls. 10.8 mud down annulus Start at 1 bbl/min @ 600 psi. - complete at 4 bbl./min ~ 500psi. Switch to hot oiler and pump 56 bbls dead crude down annulus. Max rate 2.3 bbl/min, max pressure 850 psi S/I with 750 psi. R/D hot oiler, switch rig lines to test casing. 23:30 - 00:00 0.50 CASE COMP Pressure test 7" casing to 3500 psi for 30 minutes. OK. 11120/2000 00:00 - 00:30 0.50 CASE COMP Complete 7" pressure test - 3500 psi, R/D. 00:30 - 01:30 1.00 BOPSUF~ COMP Change top rams to 3 1/2" X 6" Variables. 01:30 - 02:30 1.00 BOPSUF~ COMP Install test plug, PJU test equip., test rams to 250/3500 psi., install wear bushing. NOTE: Lou Grimaldi,AOGCC, waived BOP complete test. 02:30 - 05:00 2.50 RUNCOI~! COMP Rig up & RIH 57 stands - 4" DP and 11 stands 4"HW. 05:00 - 06:00 1.00 RUNCOI~ COMP Slip and Cut Drilling Line 06:00 - 07:30 1.50 RUNCOI~! COMP Full circ. clean mud. clean out under shakers 07:30- 11:30 4.00 RUNCOI~ COMP POH lay down 171 its. DP std bk 11 stds. HWDP. 11:30 - 13:00 1.50 RUNCOI~ COMP Pull wear bushing, rig up to run 3 112" tubing. 13:00 - 13:30 0.50 RUNCOI~i COMP Hold Pre Job Safety Meeting with Rig crew and svc co. personnel. 13:30 - 00:00 10.50 RUNCOI~! COMP Make Up Baker S-3 Packer assy. RIH w/3 1/2', 9.2 lb., L-80, 8 RD. Tbg. as per program 11/2112000 00:00 - 00:30 0.50 RUNCOI~ COMP RIH Total 296 its. 3.5" & 1 Jt. 4.5" tbg. with all accesories as per program. Printed: 11128/2000 8:50:03 AM 'BP EXPLORATION Page 6 of 6 Operations Summa Report Legal Well Name: $-103 Common Well Name: S-103 Spud Date: 11/6/2000 Event Name: DRILL+COMPLETE Start: 11/6/2000 End: 11/21/2000 Contractor Name: NABORS Rig Release: 11/2112000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es .. . 'Sub' PhaSe. · · Description of Operations Date From - To Hours Task Code . . · 11112112000 00:00 - 00:30 0.50 RUNCOI~I COMP 00:30 - 01:30 1.00 RUNCOI~! COMP M/U Tubing Hanger, Land tubing, RILDS .01:30 - 04:30 3.00 RUNCOI~! COMP PJU and Reverse Circ Clean Sea Water Spotting Corexit ~ 2.5 bpm - 200psi. I 104:30 - 05:30 1.00 RUNCOI~! COMP PJU lines, Set TWC, Test 500 psi from above; 1000psi.from below. 05:30 - 08:00 2.50 WHSUR COMP N/D BOPE. 08:00 - 11:30 3.50 WHSUR COMP NIU Adaptor Flange - test to 5000 psi. NIU Tree. 11:30 - 13:30 2.00 WHSUR COMP Test Tree to 50015000, Pull TWC, Drop Ball Rod for RHC Plug, R/U Hot Oiler & test lines to 4000psi. 13:30 - 15:30 2.00 RUNCOI~! COMP Set Baker S-3 Pkr. wi 3500 psi. Hold for 30 min.,Bleed Tbg. to 1500 psi. & Pressure annulus to 3500 psi. Bleed Tbg to 1000 psi to shear RP. Bleed off. 15:30 - 16:30 1.00 RUNCOI~ ~ COMP Reverse circ 75 Bbls. Diesel for Freeze Protection. 16:30 - 19:00 2.50 RUNCOI~ COMP R/U DSM Lubricator, Set BPV, PJD DSM, PJD lines and Valves, Secure Tree. RIG RELEASED AT 1900 HRS - 11/21/2000 Printed: 11/28/2000 8:50:03 AM " , . ' ... . . .... I ...... , ~ .~,,, ...... · ,~ ........ , ~ ........ ., ~ · .~ ~..., . . . . . . ' '. .... : .......... :;:.' ,"' ,..~ . .. "': ' ~:' ~,'", ', ..... , ~.~':'..i~ .... ".'.'"' ~ ~",~," 'lt~ g-.4~ l'lv.l~., . ' .... . .. ........................................... . .............................. ..................... !~...~ ....... ,'~? ... ....... ..... . ..... : ....... , ....... , ..' ,: ..', ............. ,., ': ,.'... ;,,,'L:,:,!..,,~,,;;,:i.:.,'.,...,~, .....' :.~ ',.'::,:,i ..... ',l,.,,,", ............... ~::':.'.~' .,:"~.~ .... ,,' "~'":":'I ....... '~'~i'": ...... '~'""'!" '"'"""" .... · .... ' , . . ...., ,..,..,., ..... , ,,,. ;, ,,,.. ,~.. ,. ..... ,,,,,...~..,,,.,.,....,...., ..... ~ .... ,, , ,,, ....... ,.., ~,,, ~, ..... ,, ....... , . , . '.. . .... . ..,~ ....... '.'.:,. :2 ........... .i" .'.:'' .~.i;'..'..'? ............... {l"i:"l" :' ;' '"' ':'"~""i ';.:' '":'::;~g" ;11'1'?"111'! ........... :i1:,':{::"1.':{,:.:" ?,;.: ...... "'m' i'~W~,,"':l~l~,~l~12~,~'~"'~'~'~:~~"~:'''' ...... ' ' ' ...................................... ~.kl · ~l'l/, l~l , ~ ..... ....................... .. ...... ,y ........ Legal Name: S-103 Common Name: S-103 '. '~,i',, "i" :'"'" .'hi,,,: i '.']:Ii ];'.? ,,.r,,.,,. ,:. ,,... % ' .' ""~":.., ? ,.'"?]~li,;i!' :J'i,. ~]illl~.~:l:l,illill;.il,~,~ :¥' .,:, :,,: . :',.. ,, ....;7., . r,!. !,, '~ ,' ,,i,, ,: ,..:,,,, ..,, ..,i;,. .. ,,,i,.. ,, ,, ,... , . .......... ,,,~e~t':~ate '::"' i .... '! ii!i,:''' :!, !,', ?",,T~--t=Tvn'e?,:, :'"',':,: '," ,: ::,:::i, ,,::!,,, ,,, '",,':, Test',~Pth' '{,.TJglO),",';,',i"i,' ...... ' .... "'" ..... :':'"' ',: ;' , ............ :,, ....... ,=,,, ,, ",,,,Te,~,,~l~th,,,~),,,;:,,, ,,,,,, ......:?::!'?.:?,,':.,:i~.:..,~MW'.,.....i, ?,.'.!i '.'?.:':: :i, ,,, :.!So'Ce Pressure Leak Off Pressure (BHP) EMW "=',',i'!,l'["~'~PILh"[[Ih[]:#~ ,,,[: ~ ' ,"' ',"'Jl I", ,'=i=IIHI' h IIIIiI1.111111]~,11'~1 'iduI'. ,".",~ I,~,,'!I, iI I, i' I Il ' i~ ..... 11/12/2000 FIT 3,087.0 (ft) 2,837.0 (ti) 10.50 (ppg) 310 (psi) 1,857 (psi) 12.60 (ppg) Printed: 4/2412001 4:41:36 PM TREE = . 5M ClW CHROME WELLHEAD= FMC GEN 5 ACTUATOR= ? "Ri~"~'~' '; ...................................................................................................... 64.61' ~'IEi"~"~'~: .......................................................... 36' ...............KOP-~'- ............................................................. ............................................. ................................ ~tum MB = ~ 0070' ..................................................................................................................................tatum W~ S-103 2110' ~FETY NOTES 3-1/2" HES 'X' NIPPLE ID= 2.992"I 19-5/8" CSG, 40#, L-80, BTC, ID = 8.750" I~ 3087' IMinimum ID =2.75" @ 2110' 3-112" HES 'X' Nipple 13-1/2" TBG, 9.2#, L-80-NSCT, .0087 bpf, ID = 2.992" I~ 9489' PERFORATION SUMMARY REF LOG: MVVD / GR 11/7/2000. ANGLE AT TOP PEP, F: SIZE SPF INT-u. RVA L Opn/Sqz DATE 2.5 6 9762' - 9782' O 3/26/2001 2 6 9798' - 9814' O 412612001 2 6 9822' - 9832' O 4/26/2001 17" CSG, 26#, L-80-BTC-M, ID= 6.276" J'~ 9972' 10057' 9418' 9429' 9432' 9435' 9456' 9477' 9489' GAS LIFT MANDRELS MMM MMM I~-~ 3-1/2" HES 'X' NIP, ID= 2.75" I~-'~ 3-1/2"X 4-1/2" NSCT'XO'I I-----~ 7"x 3-1/2" BAKER S-3 PKR I I~ 4-1/2" X 3-1/2" NSCT'XO'I I----~ 3'112" HES 'X' NIP' ID = 2'75" I I--~ 3-1/2" HES, 'X' NIP, ID = 2.75" I I ELMD NOT LOGGED I DATE REV BY COMMENTS 11/10/00 ORIGINAL COMPLETION 11/15/00 SIS-SLT CONVERTED TO CANVAS 01/26/01 SIS-MD FINAL 03/18/01 RN/TP CORRECTIONS 03/26/01 GN/TLH INITIAL PERFS AURORA UNIT WELL: S-103 PERMIT No: 200-168 APl No: 50-029-22981-00 Sec 35, T12, R12E UM 4571' NSL, 4409' WEL BP Exploration (Alaska) 27-Nov-O0 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well S-103 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,078.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-~03 S-103 Surveyed: 18 November, 2000 S UR VEY REPORT December, 2000 Your Ref: API50029228f O0 Surface Coordinates: 5980774.79 N, 618929.79 E (70° 2'/' 22.0612' N, f49° 02' 02.8599" W) Kelly Bushing: 64.6fft above Mean Sea Level 0 FI I L.'I_ I N(; ~ I;;; RVI I~ ~ ~ Survey Ref: svy10611 A Halliburton Company Sperry-Sun Drilling Services Survey Report for S-103 Your Reft APiSOO29228f O0 Surveyed: f8 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub.Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -64.61 0.00 151.02 0.480 45.719 86.41 151.02 238.40 0.190 60.763 173.79 238.40 332.52 0.480 93.631 267.91 332.52 426.76 0.600 82.149 362.14 426.75 522.39 0.760 69.587 457.76 614.35 0.640 28.162 549.72 706.79 0.970 356.025 642.15 800.53 1.180 349.597 735.87 886.97 1.820 331.497 822.28 0.00 N 0.00 E 5980774.79 N 618929.79 E 0.44 N 0.45 E 5980775.24 N 618930.24 E 0.77 N 0.84 E 5980775.57 N 618930.62 E 0.82 N 1.37 E 5980775.63 N 618931.15 E 0.86 N 2.25 E 5980775.69 N 618932.03 E 522.37 1.15 N 3.34 E 614.33 1.82 N 4.16 E 706.76 3.05 N 4.35 E 800.48 4.79 N 4.12 E 886.89 6.88 N 3.30 E 980.15 1.670 329.617 915.42 980.03 1076.54 2.110 324.400 1011.76 1076.37 1169.31 2.690 312.167 1104.45 1169.06 1262.49 3.410 312.825 1197.49 1262.10 1355.67 3.850 314.150 1290.49 1355.10 1449.75 7.060 317.618 1384.13 1448.74 1542.42 8.650 320.871 1475.93 1540.54 1635.82 9.510 323.969 1568.16 1632.77 1728.51 12.900 327.510 1659.07 1723.68 1822.58 16.840 328.235 1749.97 1814.58 1916.05 19.470 329.551 1838.78 1903.39 2009.01 22.540 330.341 1925.55 1990.16 2101.01 23.420 330.399 2010.25 2074.86 2195.33 25.930 327.934 2095.95 2160.56 2290.04 29.070 325.991 2179.95 2244.56 Dogleg Rate (°/100ft) 0.32 0.34 0,36 0.17 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment o.oo o.13 0.20 -0.04 -0.47 5980775.99 N 618933.12 E 0.23 -0.81 5980776.67 N 618933.92 E 0.55 -0.68 5980777.91N 618934.09 E 0.59 0.26 5980779.65 N 618933.83 E 0.26 1.86 5980781.72 N 618932.98 E 0.91 4.05 0.17 0.49 0.83 0.77 0.48 3.43 1.78 1.06 3.73 4.19 2.85 3.32 0.96 2.88 3.45 9.35 N 1.91E 5980784.17 N 618931.55 E 12.00 N 0.17 E 5980786.79 N 618929.77 E 14.85 N 2.44W 5980789.60 N 618927.11 E 18.20 N 6.09W 5980792.89 N 618923.41E 22.27 N 10.37W 5980796.89 N 618919.07 E 28.74 N 16.54W 5980803.26 N 618912.80 E 38.35 N 24.77W 5980812.74 N 618904.41E 50.04 N 33.75W 5980824.29 N 618895.25 E 64.96 N 43.81W 5980839.05 N 618884.95 E 85.41N -56.63W 5980859.29 N 618871.81E 110.36 N 71.65W 5980884.00 N 618856.39 E 139.20 N 88.32W 5980912.57 N 618839.27 E 170.42 N 106.08W 5980943.51N 618821.02 E 204.20 N 126.29W 5980976.90 N 618800.27 E 240.84N 150.16W 5981013.21 N 618775.82 E 6.89 10.06 13.86 18.65 24.37 33.13 45.65 60.33 78.32 102.45 131.57 164.86 200.74 240.09 283.81 AK-6 BP_IFR-AK Continued.,. December, 2000- 11:27 -2- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-f03 Your Ref: APi50029228fO0 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2382.56 32.420 325.821 2259.46 2324.07 2476.62 35.590 326.788 2337.42 2402.03 2569.73 38.550 327.843 2411.71 2476.32 2662.39 42.160 329.068 2482.31 2546.92 2755.72 45.630 328.931 2549.55 2614.16 2847.42 48.020 328.769 2612.29 2676,90 2942.30 50.570 329.624 2674.16 2738.77 3033.75 51.110 329.024 2731.91 2796.52 3118.76 50.310 329.734 2785.75 2850.36 3214.06 53.890 328.947 2844.28 2908.89 3306.31 53.580 329.364 2898.85 2963.46 3399.24 53.070 328.956 2954.35 3018.96 3494.34 54.450 326.224 3010.58 3075.19 3587.06 55.210 324.698 3063.99 3128,60 3681.33 53.980 324.704 3118.60 3183,21 3773.87 52.730 324.523 3173.83 3238.44 3866.99 52.210 324.267 3230.56 3295.17 3961.30 53.070 325.774 3287.79 3352.40 4053.15 54.530 328.249 3342.04 3406.65 4146.11 54.030 327.785 3396.31 3460.92 4239.05 53.380 327.727 3451.33 3515.94 4332.86 52.540 327.428 3507.84 3572.45 4426.17 51.090 328.253 3565.52 3630.13 4518.50 50.750 329.718 3623.73 3688.34 4612.27 51.770 330.480 3682.41 3747.02 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 280.00 N 176.67W 5981051.95 N 618748.69 E 323.77 N 205.84W 5981095.25N 618718.84E 371.01N 236.13W 5981142.00 N 618687.80 E 422.14 N 267.49W 5981192.63 N 618655.63 E 477.60 N 300.82W 5981247.55 N 618621.43 E 534.83 N 335.41W 5981304.22 N 618585.93 E 596.61N 372.23W 5981365.41N 618548.14 E 657.59N 408.40W 5981425.81N 618511.00 E 714.21N 441.92W 5981481.89 N 618476.59 E 778.88 N 480.27W 5981545.94 N 618437.22 E 842.74N 518.40W 5981609.19 N 618398.07 E 906.73 N 556.61W 5981672.57 N 618358.85 E 971.47 N 597.73W 5981736.64N 618316.71 E 1033.89 N 640.70W 5981798.38 N 618272.75 E 1096.60 N 685.10W 5981860.38 N 618227.37 E 1157.14 N 728.10W 5981920.22 N 618183.41E 1217.18 N 771.09W 5981979.57 N 618139.47 E 1278.60 N 814.06W 5982040.30 N 618095.54E 1340.77 N 854.39W 5982101.82 N 618054.22 E 1404.78 N 894.37W 5982165.20 N 618013.23 E 1468.14 N 934.33W 5982227.91N 617972.27 E 1531.35 N 974.48W 5982290.47 N 617931.12 E 1593.43 N 1013.52W 5982351.93 N 617891.10 E 1654.85 N 1050.45W 5982412.76 N 617853.20 E 1718.26 N 1086.91W 5982475.57 N 617815.74 E Dogleg Rate ('/lOOft) 3.62 3.42 3.25 3.99 3.72 2.61 2.77 0.78 1.14 3.81 0.50 0.65 2.73 1.58 1.30 1.36 0.60 1.56 2.69 0.67 0.70 0.93 1.70 1.29 1.26 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 331.08 383.66 439.77 499.75 564.44 631.30 703.19 774.07 839.84 915.00 989.36 1063.87 114o.56 1216.28 1293.01 1367.15 1440.86 1515.74 1589.84 1665.31 1740.21 1815.09 1888.43 1960.09 2o33.16 Continued... 1 December, 2000 - 11:27 - 3 - DrlllQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-103 Your Ref: API50029228100 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4705.36 52.440 329.800 3739.58 3804.19 4799.46 53.370 328.265 3796.34 3860.95 4892.35 52.200 328.788 3852.52 3917.13 4986.42 53.640 327.904 3909.24 3973.85 5078.08 54.510 328.214 3963.02 4027.63 5174.62 53.700 327.507 4019.62 4084.23 5268.92 53.350 327.487 4075.68 4140.29 5360.26 52.810 327.357 4130.54 4195.15 5452.84 52.300 327.092 4186.83 4251.44 5546.80 53.490 326.205 4243.52 4308.13 5642.83 54.420 328.217 4300.03 4354.64 5733.02 54.020 327.915 4352.76 4417.37 5825.43 53.860 329.684 4407.16 4471.77 5919.39 55.560 328.111 4461.44 4526.05 6013.44 56.220 326.892 4514.18 4578.79 6106.69 56.260 327.165 4566.00 4630.61 6199.63 56.420 327.375 4617.51 4682.12 6293.67 56.680 328.342 4669.35 4733.96 6387.18 56.360 327.140 4720.94 4785.55 6479.95 54.540 325.460 4773.55 4838.16 6573.43 54.880 325.353 4827.55 4892.16 6666.69 54.840 325.685 4881.23 4945.84 6760.05 54.800 324.776 4935.02 4999.63 6853.20 54.890 326.099 4988.66 5053.27 6946.39 54.560 324.741 5042.48 5107.09 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 1781.96 N 1123.48W 5982538.69 N 617778.16 E 1846.31N 1162.11W 5982602.42 N 617738.52 E 1909.40 N 1200.73W 5982664.89 N 617698.90 E 1973.28 N 1240.12W 5982728.13 N 617658.50 E 2036.27N 1279.38W 5982790.49 N 617618.24 E 2102.49 N 1320.99W 5982856.04 N 617575.59 E 2166.44N 1361.73W 5982919.34N 617533.84E 2227.98 N 1401.05W 5982980.24N 617493.55 E 2289.78N 1440.84W 5983041.40 N 617452.78 E 2352.37 N 1482.04W 5983103.33 N 617410.59 E 2417.64N 1524.08W 5983167.93 N 617367.52 E 2479.73 N 1562.78W 5983229.40 N 617327.84E 2543.63 N 1601.48W 5983292.67 N 617288.13 E 2609.28 N 1641.10W 5983357.69 N 617247.47 E 2674.96 N 1682.94W 5983422.69 N 617204.59 E 2740.00 N 1725.13W 5983487.05 N 617161.38 E 2805.07 N 1766.96W 5983551.46 N 617118.52 E 2871.51N 1808.70W 5983617.22 N 617075.73 E 2937.46 N 1850.33W 5983682.51N 617033.06 E 3001.03 N 1892.71W 5983745.39 N 616989.68 E 3063.84N 1936.03W 5983807.51N 616945.37 E 3126.71N · 1979.20W 5983869.68 N 616901.20 E 3189.39 N 2022.72W 5983931.66 N 616856.69 E 3252.11N 2065.92W 5983993.69 N 616812.50 E 3314.74 N 2109.10W 5984055.63 N 616768.33 E Dogleg Rate (°/'lOOft) 0.92 1.63 1.34 1.70 0.99 1.03 0.37 0.60 0.60 1.47 1.95 0.52 1.56 2.27 1.28 0,25 0.25 0.90 1.13 2.46 0.38 0.29 0.80 1.16 1.24 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 2106.56 2181.60 2255.56 2330.60 2404.83 2483.03 2558.86 2631.88 2705.38 2780.30 2857.93 2931.10 3005.79 3082.46 3160.33 3237.85 3315.20 3393.66 3471.66 3548.03 3624.27 3700.47 3776.70 3852.8o 3928.81 Continued... 1 December, 2000- 11:27 -4- DrillQuest 2.00.05 Sperry. Sun Drilling Services Survey Report for S-103 Your Ref: API50029228100 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings N°rthings Eastings (~t) (ft) (ft) (ft) (~t) 7040.28 54,140 323.617 5097,20 5161.81 7133.19 54.230 325.685 5151,57 5216.18 7227,32 54,280 329,461 5206,57 5271,18 7321.25 54.160 329.266 5261,49 5326,10 7413.38 53.430 329.503 5315.91 5380,52 7507.08 53.130 327,672 5371,94 5436.55 7600.53 52,740 328.440 5428.26 5492,87 7694.30 52.190 327.604 5485.39 5550.00 7787.21 54,000 328.138 5541.18 5605.79 7880.63 54.350 327.237 5595.86 5660,47 7973.03 53.770 325.359 5650,10 5714.71 8064.98 54.510 328.679 5703.97 5768,58 8158.85 55.540 331,242 5757,79 5822.40 . 8252.10 55.370 329.672 5810.67 5875,28 8345.30 54.670 329.646 5854,10 5928.71 8438.94 54.080 328.353 5918.64 5983.25 8532.67 53.780 329.222 5973,83 6038,44 8625.01 53.080 328.177 6028.85 6093,46 8718.53 . 52.700 328.161 6085.27 6149,88 8811.99 53.510 328.604 6141.38 6205,99 8905.49 53.020 327.173 6197,30 6261.91 8998.46 52.340 327.792 6253.67 6318.28 9092.39 51.490 326.381 6311,61 6376,22 9185.70 51,000 325.680 6370.02 6434,63 9279.34 50,320 325.926 6429.38 6493,99 3376,61N 2153,75W 5964116,78 N 616722,71E 3438,05 N 2197,33W 5964177,52 N 616678,15 E 3502,52 N 2238.28W 5984241,33 N 616636,18 E 3568.08 N 2277,11W 5984306,27 N 616596,31E 3632,06 N 2314,97W 5984369,64N 616557,44 E 3696,16 N 2354,12W 5984433,11N 616517.29 E 3759,43 N 2393,57W 5984495,75 N 616476,84E 3822,51N 2432,95W 5984558.19 N 616436,46 E 3885,42 N 2472,45W 5984620,47N 616395,96 E 3949,43 N 2512,94W 5984683,83 N 616354.46 E 4011,67 N 2554,45W 5964745,40 N 616311,98 E 4074,17 N 2594,99W 5984807,25 N 616270.44 E 4140,75 N 2633,48W 5984873,21N 616230,90 E 4207,57 N 2671,35W 5984939,42 N 616191,97 E 4273,54N 2709,81W 5985004,77 N 616152,47 E 4338,85 N 2748,90W 5985069,45 N 616112.36 E 4403,65 N 2788,16W 5985133,62 N 616072,07 E 4467,01N 2826,68W 5985196,36 N 616032,54E 4530,38 N 2866.02W 5985259,09 N 615992.21E 4594,02 N 2905,20W 5985322,11N 615952,02 E 4657.49 N 2945,03W 5985384,94 N 615911,19 E 4719,83 N 2984,77W 5985446,64N 615870,46 E 4781.90 N 3024,94W 5985508,06 N 615829,31E 4642,25 N 3065,60W 5985567,76 N 615787,71 E 4902,15 N 3106,30W 5985627,00 N 615746,06 E Dogleg Rate (°/'lOOft) 1.07 1.81 3.26 0.21 0.82 1,60 0.78 0.92 2.00 0.87 1.76 3,03 2,49 1,40 0.77 1,44 0,82 1,18 0,41 0,95 1,33 0.90 1,49 0.79 0.75 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 4004,95 4080.17 4156,55 4232.72 4307,03 4382,13 4456.69 4531,05 46O5,34 4681,08 4755,86 4830,36 4907,21 4983.93 5060,25 5136,34 5212,08 5286,23 5360.81 5435.55 5510,48 5584.41 5658,33 5731.o7 5803,44 Con#nued,,, I December, 2000.11:27 - 5. DrillQuest 2.00.05 Sperry. Sun Drilling Services Survey Report for S-103 Your Reft API50029228100 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings fit) (ft) (ft) fit) (ft) (ft) 9371.63 49.690 325.132 6488.70 6553.31 4960.43 N 3146.31 W 5985684.65 N 615705.12 E 9465.38 49.320 326.186 6549.58 6614.19 5019.30 N 3186.53 W 5985742.87 N 615663.97 E 9559.67 49.270 325.532 6611.07 6675.68 5078.46 N 3226.65 W 5985801.38 N 615622.92 E 9652.46 50.230 325.032 6671.02 6735.63 5136.67 N 3266.98 W 5985858.94 N 615581.67 E 9746.40 50.470 324.737 6730.97 6795.58 5195.83 N 3308.59 W 5985917.44 N 615539.13 E 9839.16 50.380 325.019 6790.06 6854.67 5254.31 N 3349.72 W 5985975.26 N 615497.07 E 9933.17 49.880 323.720 6850.33 6914.94 5312.96 N 3391.75 W 5986033.23 N 615454.12 E 9998.24 50.120 324.450 6892.16 6956.77 5353.33 N 3420.99 W 5986073.13 N 615424.24 E 10078.00 50.120 324.450 6943.30 7007.91 5403.13 N 3456.58 W 5986122.36 N 615387.87 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vedical depths are relative to S-103 (Slot18,EX-8). Northings and Eastings are relative to S-103 (Slot18, EX-8). Magnetic Declination at Surface is 26.6~5° (06-Nov-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from S-103 and calculated along an Azimuth of 327.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10078.00ft., The Bottom Hole Displacement is 6414.18ft., in the Direction of 327.391° (True). Dogleg Rate (°llOOft) 0.95 0.94 0.53 1.11 0.35 0.25 1.19 0.94 0.00 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 5874.09 5945.33 6016.77 6087.52 6159.76 6231.17 6303.19 6352.94 6414.04 MWD Magnetic Projected Survey Continued... 1 December, 2000 - 11:27 - 6- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S.103 Your Ref: API50029228f O0 Surveyed: f8 November, 2000 .. North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Comments 'Measured Depth fit) 10078.00 Station Coordinates TVD Northings . Eastings (ft) (ft) (ft) 7007.91 5403.13 N 3456.58 W Comment Projected Survey Survey fool program for S-103 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (fi) (f~) (ft) (ft) 0.00 0.00 9998.24 6956.77 9998.24 6956.77 10078.00 7007.91 ~urvey Tool Description AK-6 BP_IFR-AK MWD Magnetic December, 2000.1f:27 - 7- DrillOuest 2.00.05 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-~03 S-~03 MWD Surveyed: 18 November, 2000 SURVEY REPORT December, 2000 Your Ref: API50029228fO Surface Coordinates: 5980774.79 N, 6f8929.79 E (70° 2f' 22.06f2" N, 149° 02' 02.8599" W) Kelly Bushing: 64.6fft above Mean Sea Level DRILLING 5 E RVI C I::: S Survey Reft svyl0609 A Halliburton Company Sperry-Sun Drilling Services Survey Report for S-f03 MWD Your Ref: API5002922810 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth {ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -64.61 0.00 151.02 0.480 45.530 86.41 151.02 238.40 0,190 59.860 173.79 238.40 332,52 0.480 92.730 267.91 332.52 426.76 0.600 81.770 362.14 426.75 522.39 0.760 68.650 457.76 614.35 0.640 27.830 549.72 706.79 0.970 355,760 642.15 800.53 1.180 349.240 735,87 886.97 1.820 331.300 822.28 522.37 614.33 706.76 800.48 886.89 980.15 1.670 329.340 915.42 980.03 1076.54 2.110 324.350 1011.76 1076.37 1169.31 2.690 311.760 1104.45 1169.06 1262.49 3.410 312.270 1197.49 1262.10 1355.67 3.850 313.480 1290.49 1355.10 1449.75 7.060 317.050 1384.13 1448.74 1542.42 8.650 320.160 1475.93 1540.54 1635.82 9.510 323.580 1568.16 1632.77 1728.51 12.900 326.960 1659.07 1723.68 1822.58 16.840 327.770 1749.97 1814.58 1916.05 19.470 329.180 1838.78 1903.39 2009.01 22.540 330.100 1925.55 1990.16 2101.01 23.420 330.210 2010.25 2074.86 2195.33 25.930 328.600 2095.95 2160.56 2290.04 29.070 326.600 2179.95 2244.56 0.00 N 0.00 E 0.44 N 0.45 E 0.77 N 0.84 E 0.83 N 1.37 E 0.88 N 2.25 E 1.19 N 3.34 E 1.86 N 4.14 E 3.10 N 4.33 E 4.84 N 4.09 E 6.92 N 3.26 E 9.38 N 1.86 E 12.03 N 0.11 E 14.87 N 2.51 W 18.19 N 6.19 W 22.21 N 10.51 W 28.61 N 16.75 W 38.13 N 25.09 W 49.74 N 34.17 W 64.58 N 44.36 -W 64.91 N 57.36 W 5980774.79 N 618929.79 5980775.24 N 618930.23 5980775.58 N 618930.62 5980775.64N 618931.14 5980775.71 N 618932.03 5980776.03 N 618933.11 5980776.72 N 618933.90 5980777.96 N 618934.07 5980779.69 N 618933.80 5980781.76 N 618932.94 5980784.20 N 618931.50 5980786.82 N 618929.71 5980789.62 N 618927.04 5980792.88 N 618923.31 5980796.83 N 618918.93 5980803.14 N 618912.59 5980812.52 N 618904.10 5980823.98 N 618894.83 5980838.65 N 618884.41 5980858.78 N 618871.09 109.75 N 72.56W 5980883.37 N 618855.49 138.51N 89.39W 5980911.86 N 618838.22 169.66 N 107.26W 5980942.73 N 618819.85 203.53 N 127.32W 5980976.28 N 618799.25 240.43 N 150.78W 5981012.79 N 618775.21 Dogleg Rate (°/'tOOft) Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment E 0.00 E 0.32 0.13 E 0.34 0.21 E 0.36 -0.03 E 0.17 -0.45 E 0.23 -0.78 E 0.54 - -0.63 E 0.59 0.31 E 0.26 1.91 E 0.91 4.11 E 0.17 6.95 E 0.49 10.12 E 0.84 13.92 E 0.77 18.69 E 0.48 24.39 E 3.43 33.14 E 1.78 45.64 E 1.09 60.30 E 3.72 78.28 E 4.19 102.42 E 2.85 131.54 E 3.32 164.84 E 0.96 200.72 E 2.75 240.08 E 3.46 283.80 MWD Magnetic Continued... December, 2000 - 10:05 - 2 - DrillQuest ZOO.05 Sperry-Sun Drilling Services Survey Report for S-f03 MWD Your Reft API5002922810 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2382.56 32.420 326.090 2259.46 2324.07 2476.62 35.590 326.170 2337.42 2402.03 2569.73 38.550 327.530 2411.71 2476.32 2662.39 42.160 329.110 2482.31 2546.92 2755.72 45.630 328.610 2549.55 2614.16 2847.42 48.020 329.110 2612.29 2676.90 2942.30 50.570 329.110 2674.16 2738.77 3033.75 51.110 328.500 2731.91 2796.52 3118.76 50.310 329.970 2785.75 2850.36 3214.06 53.890 329.200 2844.28 2908.89 3306.31 53.580 329.400 2898.85 2963.46 3399.24 53.070 329.160 2954.35 3018.96 3494.34 54.450 326.450 3010.58 3075.19 3587.06 55.210 324.900 3063.99 3128.60 3681.33 53.980 324.870 3118.60 3183.21 3773.87 52.730 324.770 3173.83 3238.44 3866.99 52.210 324.540 3230.56 3295.17 3961.30 53.070 326.050 3287.79 3352.40 4053.15 54.530 328.500 3342.04 3406.65 4146.11 54.030 327.970 3396.31 3460.92 4239.05 53.380 328.160 3451.33 3515.94 4332.86 52.540 327.520 3507.84 3572.45 4426.17 51.090 328.100 3565.52 3630.13 4518.50 50.750 329.330 3623.73 3688.34 4612.27 51.770 330.200 3682.41 3747.02 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 279.79 N 177.00W 5981051.73 N 618748.37 E 323.46 N 206.31W 5981094.93 N 618718.37 E 370.46 N 236.98W 5981141.44 N 618686.96 E 421.52 N 268.45W 5981191.99 N 618654.68 E 476.89 N 301.92W 5981246.83 N 618620.34 E 534.13 N 336.49W 5981303.51N 618584.86 E 595.85 N 373.42W 5981364.63 N 618546.96 E 656.50 N 410.15W 5981424.70 N 618509.27 E 713.03 N 443.80W 5981480.68 N 618474.72 E 777.86 N 481.88W 5981544.90 N 618435.62 E 841.82 N 519.85W 5981608.25 N 618396.64E 905.89 N 557.93W 5981671.71N 618357.55 E 970.78 N 598.80W 5981735.94 N 618315.65 E 1033.37 N 641.54W 5981797.84 N 618271.92 E 1096.22 N 685.74W 5981859.99 N 618226.74E 1156.91N 728.52W 5981919.98 N 618183.00 E 1217.14 N 771.23W 5981979.54 N 618139.33 E 1278.77 N 813.91W 5982040.47 N 618095.68 E 1341.12 N 853.96W 5982102.18 N 618054.65 E 1405.29 N 893.69W 5982165.71 N 618013.90 E 1468.86 N 933.31W 5982228.65 N 617973.28 E 1532.25 N 973.17W 5982291.40 N 617932.42 E 1594.31 N 1012.24W 5982352.83 N 617892.37 E 1655.56 N 1049.46W 5982413.48 N 617854.18 E 1718.75 N 1086.28W 5982476.08 N 617816.36 E Dogleg Rate (°/lO0~t) 3.63 3.37 3.30 4.05 3.74 2.64 2.69 O.78 1.64 3.81 0.38 0.59 2.72 1.59 1.31 1.35 O.59 1.57 2.68 0.71 0.72 1.05 1.63 1.10 1.31 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 331.07 383.65 439.76 499.74 564.43 631.28 703.18 774.08 839.85 915.00 989.35 1063.86 1140.55 1216.29 1293.03 1367.17 1440.91 1515.80 1589.90 1665.37 1740.28 1815.16 1888.50 1960.16 2033.25 Continued... 1 December, 2000 - 10:05 - 3. DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-f03 MWD Your Reft API5002922810 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4705.36 52.440 329.700 3739.58 3804.19 4799.46 53.370 328.550 3796.34 3860.95 4892.35 52.200 329.030 3852.52 3917.13 4986.42 53.640 328.360 3909.24 3973.85 5078.08 54.510 328.600 3963.01 4027.62 5174.62 53.700 327.880 4019.62 4084.23 5268.92 53.350 328.050 4075.67 4140.28 5360.26 52.810 328.040 4130.64 4195.15 5452.84 52.300 327.590 4186.83 4251.44 5546.80 53.490 326.390 4243.52 4308.13 5642.83 54.420 328.550 4300.03 4364.64 5733.02 54.020 328.210 4352.76 4417.37 5825.43 53.860 330.010 4407.16 4471.77 5919.39 55.560 328.500 4461.44 4526.05 6013.44 56.220 327.440 4514.18 4578.79 1782.34N 1123.07W 1846.75 N 1161.59W 1910.02 N 1199.92W 1974.14 N 1238.92W 2037.41N 1277.72W 6106.69 56.260 327.790 6199.63 56.420 327.930 6293.67 56.680 328.700 6387.18 56.360 327.310 6479.95 54.540 325.770 2103.91N 1318.89W 2168.19 N 1359.11W 2230.15 N 1397.76W 2292.36 N 1436.91W 2355.19 N 1477.73W 2420.65 N 1519.48W 2482.96 N 1557.84W 2547.06 N 1596.19W 2612.96 N 1635.40W 2678.97 N 1676.70W 4566.00 4630.61 2744.44 N 1718.22W 4617.51 4682.12 2809.94 N 1759.38W 4669.35 4733.96 2876.71 N 1800.59W 4720.94 4785.55 2942.86 N 1841.91W 4773.55 4838.16 3006.60 N 1884.03W 6573.43 54.880 325.680 4827.55 4892.16 6666.69 54.840 325.960 4881.23 4945.84 6760.05 54.800 325.040 4935.02 4999.63 6853.20 54.890 326.490 4988.66 5053.27 6946.39 54.560 326.380 5042.48 5107.09 3069.65 N 1927.00W 3132.75 N 1969.84W 3195.63 N 2013.06W 3258.59 N 2055.90W 3321.99 N 2097.97W 5982539.07 N 617778.56 E 5982602.87 N 617739.03 E 5982665.52 N 617699.69 E 5982729.01N 617659.68 E 5982791.66 N 617619.88 E 5982857.49 N 617577.67 E 5982921.13 N 617536.43 E 5982982.47 N 617496.80 E 5983044.04 N 617456.67 E 5983106.22 N 617414.85 E 5983171.01 N 617372.08 E 5983232.70 N 617332.73 E 5983296.19 N 617293.37 E 5983361.46 N 617253.11E 5983426.81N 617210.77 E 5983491.61N 617168.21E 5983556.45 N 617126.02 E 5983622.55 N 617083.76 E 5983688.03 N 617041.39 E 5983751.10 N 616998.27 E 5983813.46 N 616954.30 E 5983875.87 N 616910.46 E 5983938.06 N 616866.25 E 5984000.33 N 616822.41E 5984063.05 N 616779.35 E Dogleg Rate (°/lOOff) 0.84 1.39 1.33 1.63 0.97 1.03 0.40 0.59 0.67 1.63 2.06 0.54 1.58 2.23 1.17 0.31 0.21 0.74 1.29 2.39 0.37 0.25 0.81 1.28 0.37 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 2106.66 2181.69 2255.66 2330.69 2404.91 2483.11 2558.94 2631.96 2705.47 2780.39 2858.03 2931.19 3005.87 3082.53 3160.40 3237.92 3315.28 3393.74 3471.73 3548.11 3624.37 3700.59 3776.83 3852.94 3929.00 Continued... December, 2000- 10:05 -4- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-f03 MWD Your Ref: API5002922810 Surveyed: 18 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. 7040.28 54.140 324.340 7133.19 54.230 326.100 7227.32 54.280 329.840 7321.25 54.160 329.470 7413.38 53.430 329.800 Sub-Sea Depth (ft) 5097.20 5151.57 5206.57 5261.49 5315.91 Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°llOOft) 5161.81 3384.75 N 2141.33W 5984125.12 N 616735.00 E 5216.18 3446.63 N 2184.30W 5984186.31N 616691.05 E 5271.18 3511.38 N 2224.81W 5984250.41N 616649.52E 5326.10 3577.14 N 2263.30W 5984315.55 N 616609.98 E 5380.52 3641.28 N 2300.88W 5984-379.09 N 616571.39 E 7507.08 53.130 328.140 5371.94 5436.55 7600.53 52.740 328.930 5428.26 5492.87 7694.30 52.190 328.040 5485.39 5550.00 7787.21 54.000 328.580 5541.18 5605.79 7880.63 54.350 327.700 5595.86 5660.47 7973.03 53.770 325.860 5650.10 5714.71 8064.98 54.510 329.050 5703.97 5768.58 8158.85 55.540 331.600 5757.78 5822.39 8252.10 55.370 329.950 5810.66 5875.27 8345.30 54.670 330.130 5864.09 5928.70 3705.64 N 2339.60W 5984442.82 N 616531.66 E 3769.24 N 2378.52W 5984505.80 N 616491.73 E 3832.63 N 2417.39W 5984568.56 N 616451.86 E 3895.85 N 2456.41W 5984631.15 N 616411.84 E 3960.18 N 2496.39W 5984694.84 N 616370.84 E 8438.94 54.080 328.630 5918.64 5983.25 8532.67 53.780 329.440 5973.83 6038.44 8625.01 53.080 328.360 6028.84 6093.45 8718.53 52.700 328.450 6085.27 6149.88 8811.99 53.510 328.980 6141.38 6205.99 4022.76 N 2537.37W 5984756.76 N 616328.87 E 4085.57 N 2577.44W 5984818.93 N 616287.81E 4152.40 N 2615.51W 5984885.14 N 616248.69 E 4219.43 N 2653.01W 5984951.56 N 616210.13 E 4285.58 N 2691.14W 5985017.11N 616170.95 E 4351.08 N 2729.90W 5985081.99 N 616131.15 E 4416.05 N 2768.89W 5985146.32 N 616091.14 E 4479.55 N 2807.19W 5985209.21N 616051.64E 4543.07 N 2846.26W 5985272.10 N 616011.76 E 4606.95 N 2885.07W 5985335.35 N 615971.94 E 6261.91 4670.54N 2924.54W 5985398.41N 615931.46 E 6318.28 4733.20 N 2963.94W 5985460.34 N 615891.08 E 6376.22 4795.51 N 3003.73W 5985522.01N 615850.31E 6434.63 4856.07 N 3044.06W 5985581.92 N 615809.01 E 6493.99 4916.19 N 3084.44W 5985641.39 N 615767.69 E 8905.49 53.020 327.440 6197.30 8998.46 52.340 328.160 6253.67 9092.39 51.490 326.710 6311.61 9185.70 51.000 325.960 6370.02 9279.34 50.320 326.280 6429.38 1.82 1.54 3.23 0.34 0.84 1.46 0.79 0.95 2.00 0.85 1.73 2.92 2.48 1.47 0.77 1.45 0.77 1.21 0.41 0.98 1.42 0.96 1.51 0.82 0.77 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 4005.22 4080.48 4156.86 4233.02 4307.32 4382.41 4456.97 4531.32 4605.60 4681.35 4756.14 4830.64 4907.47 4984.17 5060.47 5136.55 5212.30 5286.44 5361.02 5435.75 5510.67 5584.61 5658.53 5731.28 5803.67 Continued... f December, 2000 - 10:05 - 5 - DrillQuest ZOO.05 Sperry-Sun Drilling Services Survey Report for S.'103 MWD Your Ref: API50029228'10 Surveyed: '18 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical ' Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 9371.63 49.690 325.560 6488.70 6553.31 4974.75 N 3124.05 W 5985699.32 N 615727.15 E 9465.38 49.320 326.500 6549.58 6614.19 5033.88 N 3163.89 W 5985757.80 N 615686.38 E 9559.67 49.270 325.800 6611.07 6675.68 5093.24 N 3203.70 W 5985816.53 N 615645.63 E 9652.46 50.230 325.230 6671.02 6735.63 5151.61 N 3243.80 W 5985874.25 N 615604.61 E 9746.40 50.470 324.950 6730.97 6795.58 5210.93 N 3285.20 W 5985932.90 N 615562.28 E 9839.16 50.380 325.100 6790.06 6854.67 5269.51 N 3326.18 W 5985990.83 N 615520.37 E 9933.17 49.880 323.820 6850.33 6914.94 5328.22 N 3368.12 W 5986048.87 N 615477.51 E 9998.24 50.120 324.450 6892.15 6956.76 5368.62 N 3397.32 W 5986088.80 N 615447.67 E 10078.00 50.120 324.450 6943.29 7007.90 5418.42 N 3432.91 W 5986138.02 N 615411.29 E- All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-103 (Slot18,EX-8). Northings and Eastings are relative .to S-103 (Slot18, EX-8). Magnetic Declination at Surface is 26.685° (06-Nov-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from S-103 and calculated along an Azimuth of 327.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10078.00ff., The Bottom Hole Displacement is 6414.37ft., in the Direction of 327.643° (True). Dogleg Rate (o/looft) 0.91 0.86 0.57 1.14 0.34 0.16 1.17 0.83 0.00 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 5874.33 5945.59 6017.04 6087.80 6160.05 6231.47 6303.50 6353.25 6414.35 Projected Survey Continued... December, 2000 - fO:05 - 6 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-103 MWD Your Ref: AP!5002922810 Surveyed: 18 November, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA $ Pad Comments Measured Depth (ft) 10078.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7007.90 5418.42 N 3432.91 W Comment Projected Survey Survey tool program for S-'/03 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 10078.00 7007.90 Survey Tool Description MWD Magnetic 1 December, 2000.10:05 - 7. DrillQuest 2.00.05 U~/ZZ/ZUU.L lO:~16 FAX 907 564 4284 BP EXPLORATION ( bp March 21,2001 I~00! BP Exploration (Alaska) Inc. 900 Bast Benson Boulevard P.O. Box 196612 Anchorage,, Alnska 99519-66 (9O7) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: RECEIVED MAR 2 3 2001 Alaska Oil & Gas Cons. CommOn An~orage Re: Pmdhoc-BOA, Pt. Mac, &.Lisbume Well Work This listing is provided as required under the terms o,f Cons, ervation Order No. 341C (Rule 14) & Order No. 342. This is a list ~f well work tentatively sch6dulcd for March 19 - 26, 2001: ' 05-01C Work Planned ' CTE PERFORATION 05-18A 06-24A 12-15 13-27A CTE ADD PERFORATION CT ACID STIMULATION W/DIVERTER SAG HYDRAULIC FRACTURE TREATMENT CT ADD PERFORATION W/WORK PLATFORM 16-23Ai. NK-65i CHE~CAL CUT TUBING (PRE RIG ST) CTE ADD PERFORATION S-101 'ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. Sincerely, ./~ ,~'.,, .~ Paul C. Rauf ~ Technical Assistant, BPXA Alaska Drilling & Wells 0;t/14/Z001 18:41 I,'AA. 907 564 41164 BP EXPLORATION £ bp I~J 00l. BP Exploration (Alaska) Inc. 900 F.~t Benson Boulevard P.O. Box 196612 Anchorage, Alaslm 99519-6612 (907) 561-511! March 14, 2001 lulie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. Wel--! 03-27 03-28 05-18A 12-15 13-27A 16-21 NK-65i S.-101 This is a list of well work tentatively scheduled for March 12.- 19, 2001: Work Planned REPERFORATION / HYDRAULIC FRACTURE TREATMENT REPERFORATION CTE ADD PERFORATION SAG HYDRAULIC FRACTURE TREATMENT CT ADD PERFORATION W/WORK PLATFORM REPERFORATION ' .CTE ADD PERFORATION ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed,, please call me a! 564-5799 orE-mail me at raufpc @bp.com. Sincerely, Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells R. :c. tVED ' l aR 1,5 001 0~/08/2001 ~5:43 FAX 90'7' 564 4264 BP EXPLORATION ( BP Bxplocation (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 56~-51 ! 1 I(6J uu/ 0 March 7, 2001 Julie Hensser, Dan Seamount, & Cammy Occhsli Taylor Alaska Oil & Gas Conservation Commission 333 West 70~ Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re_: Pmdhoc-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & ' Order No. 342. This is a list of well work tentatively scheduled for March 5 - 12, 2001: Wel__..! 03-08 Work Planned REPERFORATION 03-25A 03-27 REPER~ORATION REPERFORATION ! HYD~~C FRACTUR~ TREA~ 03-28 06-18 13-27A 16-05Ai ' 16-21 NK-22 REPtS~ORATION CT ACID WASH = GEL CE~ SQUEEZE OSO CT ADD PERFORATION W/WORK PLATFORM CTD SIDETRACK (NABORS 3S) REPERPORATION ADD pERFORATION S-lOl S-105 ADD PERFORATION INITIAL PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at RECEIV O M,qR 0 8 2001 Alaska Oil & Gas Cons. Commission Anchorage bp I" BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 11,2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for S-103 to Add Perfs (Kuparuk C-4 Sands) BP Exploration Alaska, Inc. proposes underbalanced perforating the Kuparuk C-4 Sands in Aurora development well $-103. Underbalance should be achieved by gas- lifting with the well open to LPS. The proposed perfs are in a Iow quality reservoir, so long clean perf tunnels are necessary to enhance flow. The procedure includes the following major steps: Category IOR Step Description E 600 1 Perforate 20' of 04, lowest shot 9572 MD Last Test: FBHP: Max. Deviation: Perfs: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: Tie in Log: BHP: 10-21-01, 1700 BOPD, 65% WC, 2MMscfd ALG 1900 psi 56° @ 6294' md Deviation at perfs: 50° Present Perfs 9578' through 9832' MD Three .... 2.75" at X nipples, see schematic 9919' MD (11/20/2001) Add Perfs, 12/24/2001 < 10 ppm Sperry CNPGR Schlumberger CMTGR (03/25/2001). 3087 psia @ 9543' MD @ 6600' TVDSS 1. Obtain Well test no less than 2-days prior to, and ASAP after perforating. 2. Open CK 100% with ~0.5MMcfd ALG --> 1000 psi underbalance. E-Line . Perforate well, Zone C4 from 9552'-9572' MD, (6671'-6684' TVDss). Perforate using Schlumberger 2-1/2" HSD PJ, 2506 UP, 4SPF, 180 degree phasing, 40 degree CW from Iowside orientation. Tie-into SWS CMTGR (25/Mar/2001). 4. POOH to ,sty and then increase gas lift to 2.0 ,,vlcfd 5. Obtain Well test ASAP after perforating. , for post-perf test. Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007) if there are any questions. Sincerely, Jim Young Greater Prudhoe Bay Aurora Development Engineer PERFORATING PROCEDURE Ver 4.0 06/04/01 Well: S-103 APl #: 50-029-22981-00 Date: 1/11/02 Prod Engr Jim Young Office Ph: ........................... ,5.,,6.,,4.,-.,,5.,,7.,,5.,,4. II .2S Level: ................................................................................................................ Home Ph: ,~;2~.~ ...................................................... ............................ "11 ......................... '~'~'~11 Cell/Pager: ........................... ..,.4~,_ .0..-..8.,.0..0...7,. .......................... CC or AFC: ................................. 5M0005, ............................... Detail Code: ........................................................... ~,,,,33.,.,,5.:0.,,7..0.:.,,,7~.,.,0.. .......................................................... Description: DRLG / COMPLETION / PERF WBL Entries IOR Type Work Desciption 600 E Perforate 20' underbalanced Well Obiectives and Lo,qqinq Notes: Obtain Well test no less than 2-days prior to, and ASAP after perforating Well makes -1700bopd. 65%wc, 2mmcfd ALG (1900psi FBHP on 10-21-01) Attachment: Reference Io ! with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Subtract 2 Log: .,.C....N..,.P...G....R. .......... CMTGR from the tie-in log to be on Date: ...... ,1,.,1,,~,/,,2,.,0,..,,0~,,, 3/25/2001 depth with the reference log. Company: ,,,S,p,,e,,r,~ ............. Schlum Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing ......... .,9.,.,,s,,,5,,,0,. ............... ,.9..,...s.Z,.o.. .............. ~:5.,~,,2,'. ....... - ....... ,~,..,5..7,.,,2.,'. ............ ,.2.,0,. ............ ~ .............. r~,.0..~,?g. ......................... .!.,.,e.,,0,. .................... - -, .................................................................. ..CW,.f.r.q,m,,..!,0,.~side ................................................... Gas Jetting E]~pected? ............................................ ~'~' ............................. Ai"~"~ept~' ....... [~j.~ .............................................. Requested Gun Size: ........... 2..:5.:: ............ Charge: ,p.i,2...5..,0,,,6,,...H,,..M....X...,...,m...~ MAX Swe11=2.72" in GAS Desired Penetration: >20" Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to ach/eve drawdown (check w~ Pad Operator to see If necessary p/ping/s installed) (e.g. N2 Lift, Hardllne Uft Gas, Gas Lift, Flow Well, Bad(flow Through Drain or Hardline) Tie in to Jewelry ~ 9490 MD Tie in using: Minimum ID: ~iii~i~:~'~i~ii~:~;~in Min ID Type: Tail Depth: .......... ..9.4.9.0. .......... ft MD Casing Size: Est Res. Pres. Last Tag: ........ ,,>,,,9,,,9,,,0,,,0, ........ ft MD on .,,!,,,0/,,,2,,1,,,/,.2.,.0,,,0,,,1,,,. feet Zone Ad/ReJIperf ...... .9...4.. ....................... ,!~,.e..~ .................. :7: ................................................................ N/A Entry Hole D/am: >0.3" FOR FRAC , °,P,,e., ,n.,,c,,k,,,~,~,/,;.,.W, ,/,,-,., ,0.;,5., ,m,.,,m.,~,d...,A,.,,L.,,G,,::,>,.~..0...0....0..P.~.L,.u..."..,d, .e.~a.!a. n.c.e. .............................. ,..P., .~..~....H.~.t..~.~s...a..f..e.~t.y.~.&..~;~a.~.s..~!!~;~..2...m.~.m....c1..~[~!:P~!~ ......................................... .................... ,.M.,U, .,,L,,T.,[,,P.,.L..,,E..,X..:.,.N.!.,P...,P.,.L,...E.,S.' ................... @ ................... 'MD 7 in ,..i,...,,9,,:,8,,0.,,0. ...... MD is ................ ..3,..0.0.0.. psi Well: S-103 Date: General Comments: Perforation Summary IIsummary Dist II APl #: 50-029-22981-00 Prod Engr: IIAnch Prod Engr II ........................................................................................................................................ IIP.D. Center II PBTD Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing O/B/U - , ............................................................................................... ~ O/B/U ............................... - ................................................................................................ O/B/U ............................... : ............................................................................................................................... 0 O/B/U - . ............................................................................................... ('~ O/B/U - , ............................................................................................... Zone Aperf/Reperf TREE-- 5M CIW CHROIVE ~- WELLHEAD= FMC GEN5 FSAFETY NOTES ACTUATOR = ? S-103 BF. B. EV = 36' KOP 1636' Max Angle = 56 @ 6294' a 12110' I~ 3'll2"l~SXbll~Jt-fi'lD=2'7§O" l ~tum ~ = 10079' I · Batum IVD= 6944' ! GAS LIFT MANDRELS WV ATE L 1 9329 6461 IVlVlM RK Minimum ID = 2.75" @ 2110' 3-112" HES X NIPPLE I i ' I 9418' I~ 3'1/2" I'~S X NIP' ID = 2'7fi" I ~ ~ ?'xa-v2" AKE S-aPm_ I ~ ~ .112, x 3-112,, Ns.r xo I I,' ~' 94r~' I~-l 3-112"~SX~',~D~2.7s"I I " II 9477' ~ 3-1/2"I-ES, XNIP, ID=2.75"I 13-1/2"TBG, 9.2#, L-80-NSCT, .0087 bpf, D =2.992" H 9489' . , PERFORATION S UMIV~ RY REFLOG: MWD/GRON 11/07100 ANGLE AT TOP PERF: SIZE SPF INTERVAL ' Opn/Sqz DATE 2" 6 9608 - 9620 , O 06/17/01 2" 6 9632 - 9642 O 06/17/01 2" 6 9652 - 9660 O 06/17101 2-112" 6 9762- 9782 O 03/26/01 2" 6 9798- 9814 O 04126/01 2" 6 9822- 9832 O 04126/01 . I?' cra, 26#, .-~0-~*~ ~D-- 6.27.' I-'t ~00rt' ~ DATE REV BY COMIVENTS DATE REV BY COMIVENTS PRLDHOEBAY UNIT 11110100 ORIGINAL COIVPLErlON 05/07/01 JJIKAK ADPERFS WB.L: S-103 11/15100 SIS-SLT CONVERTEDTO CANVAS 06/21/01 /TP ADD PERFS PERVlIT No: 200-186 01/26/01 SIS-MD RNAL 12/06/01 DAV/tlh I-ES NIPPLE ID CORRECTED APl No: 50-029-22981-00 03118101 RN/TP COI~RECTIONS SEC 35, T12, R12E, UM4571' NSL, 4409'WB_ 03/26101 GN/rLH II~'I'IAL PERFS BP Exploratbn (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9808 - 9820 O 06/17/01 2" 6 9832 - 9842 O 06/17/01 2" 6 9852 - 9860 O 06/17101 2-112" 6 9762- 9782 O 03/26/01 2" 6 9798- 9814 O 04126/01 2" 6 9822- 9832 O 04126/01 DATE REV BY COMIVENTS DATE REV BY COMIVENTS 11110100 ORIGINAL COIVPLErlON 05/07/01 JJIKAK ADPERFS 11/15100 SIS-SLT CONVERTEDTO CANVAS 06/21/01 /TP ADDPERFS 01/26/01 SIS-MD RNAL 12/06/01 DAV/tlh I-ES NIPPLE ID CORRECTED 03118101 RN/TP COI~RECTIONS 03/26101 GN/rLH II~'I'IAL PERFS ALASILA OIL AND GAS CONSERVATION CO]~PlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S- 103 BP Exploration (Alaska) Inc. Permit No: 200-168 Sur Loc: 4571'NSL, 4496'WEL, Sec. 35, TI2N, RI2E, UM Btmhole Loc. 4603'NSL, 2555'WEL, Sec. 27, 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. 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 BOPE 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. Sincerely, Commissioner BY ORDER OF THE COMMISSI.ON DATED this ~/-o/ day of November, 2000 dlf/Enclosures ' CC: Department of Fish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. S- 103 - Status of Drilling Permit Subject: S-103 - Status of Drilling Permit Date: Thu, 2 Nov 2000 13:16:54 -0600 From: "Sherritt, Allen" <SherriJA~BP.com> To: "Tom Maunder (E-mail)" <Tom_Maunder~admin.state.ak.us>, "Blair Wondzell (E-mail)" <blair_wondzell~admin. state.ak.us> Tom/Blair, I am just checking on the status of the S-103 drilling permit submitted on 10-16-00. The estimated spud date on the permit application is 11-08-00. Do to better-then-planned operations on S-105, the actual spud date has moved forward to 11-05-00, (this coming Sunday.) Hopefully, this will not be a problem. Additionally, I have forwarded the S-105 surface gas logs to Bob Crandall for review. Is there a possibility of obtaining the diverter dispensation for S-103 or will we be shooting for the next well? Thanks for you time. If you have any questions give me a shout. Allen Sherritt BP Alaska Drilling and Wells * (.907) 564-5204 (Direct) * (907) 240-8070 (Mobile) * sherrij a@bp. corn * (907) 564-4040 (Fax) * MB 6-3 / 681B 1 of I 1 l/2/00 3:09 PM STATE OF ALASKA ALASI~" JIL AND GAS CONSERVATION COJ., ,SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Drill [] Redrill 1 lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen [] Exploratory [] Stratigraphic Test [] Development Oil 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.3' Prudhoe Bay Field /Aurora 3. Address 6. Property Designation Pool (Undefined) P.O. Box 196612, Anchorage, Alaska 99519-6612 c'.-~.~~D~.~028258 4. Location of well at surface 7. Unit or Pro~'rty Name 11. Type Bond (See 20 AAC 25.025) 4571' NSL, 4496' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 4421' NSL, 2444' WEL, SEC. 27, T12N, R12E, UM S-103 Number 2S100302630-277 At total depth 9. Approximate spud date 4603' NSL, 2555' WEL, SEC. 27, T12N, R12E, UM 11/08/00 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 028256, 676' MDI S-105 is 60' away at surface 2560 10184' MD / 7159' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 1000' MD Maximum Hole Angle 58 ° Maximum surface 2772 psig, At total depth (TVD) 6634' / 3435 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casinq 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 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-M 3000' Surface Surface 3000' 2785' 3_P9 sx AS Lite 3~ 261 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 10184' Surface Surface 10184' 7159' 595 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 Production Liner Perforation depth: measured ORIGINAL Ataska. Oil & G~s {:.~,~gs. Co,:fi,",dssio~ true vertical ,,,. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25,050 Requirements Contact Engineer Name/Number: Allen Sherritt, 564-5204 Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed DanStone ~----------'~_ ...~,~.~o .~~ Title Senior Drilling Engineer Date I~(1~.~ Permit Number APl Number Approval D. at~/.) See cover letter 50-~'OZ-~'-- ~ ~--~? / - ~) //.~ ~'~-~... for other requirements Conditions of Approval: Samples Required [] Yes j~ No Mud Log Required [] Yes [~rNo Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required !~[ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~1~3.5K-~ Other: ORIGINAL SIGNED BY by order of Approved By D Taylor R~.~mn,,qt Commissioner the commission Date J/"" Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I S-103 Drill and Complete Plan Summary I Type of Well (service / producer I injector): I Producer Surface Location: Target Location: Kuparuk Bottom Hole Location: X = 618,930.00 Y = 5,980,775.00 4571' FSL, 4496' FEL, SEC. 35, T12N, R12E Umiat X = 615,614.00 Y = 5,985,854.00 4421' FSL, 2444' FEL, SEC. 27, T12N, R12E Umiat X = 615,500.00 Y = 5,986,034.00 4603' FSL, 2555' FEL, SEC. 27, T12N, R12E Umiat I AFE Number: 15M0005 Estimated Start Date: I 11/8/2000 I MD: 110,184' I I Rig: I Nabors 9ES I Operating days to complete: 116.9 IT VD: 17,159' I I BF/MS' 135.8' I I RKB: 164.3' I Well Design (conventional, slimhole, etc.): I Ultra Slimhole Longstring I Objective: I Kuparuk Formation Mud Program: 12-1/4" Surface Hole (0-3000'): Fresh Water Surface Hole Mud Interval Density Viscosity YP PV Gel-10 Fluid (ppg) (seconds) sec Loss Initial 8.5-9.1 300 75 12 12/25 NC Interval TD 9.1-9.6 65 20-25 22-25 19/55 NC 8-3/4" Upper Intermediate Hole (3000' - 9682'): Freshwater LSND Interval' Density Viscosit~ YP 'PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.5 42-52 15-25 10-19 9.0-9.5 6cc <14 shoe to to by HRZ HRZ <5 8-3/4" Production Zone (9682' - 10,184') GEM + 6% KCI Interval Density ~iscosity YP' PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Production 10.5 40-50 18-25 12-18 9.0-9.5 <5 <9 Hole S-105 Permit to Drill Page 1 Directional: KOP: 11000' Maximum Hole Angle: Close Approach Wells: 58° at 3263' MD - Intermediate hole S-105 is located 60' North of surface location. Logging Program: Surface Intermediate I Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den / PWD All Realtime + MAD pass Kuparuk & Cuttings Gas & Samples Open Hole: None Cased Hole: None Formation Markers: Formation Tops MD TVDss Comments Base Permafrost 1882 1800 SV3 / T5 2883 2642 SV1 3766 3139 Ugnu top (UG4A) 4501 3527 Unknown, 10.5 ppg MW required on SB-01 S-102 reduced hydrostatic to 9.0 ppg EMW with no indication of problems. Schrader (Mb1 Sand) 6782 4732 9.06 ppg EMW (pore pressure = 2230) Schrader (Na Sand) 7059 4878 9.51 ppg EMW (pore pressure = 2412) Schrader (Oa Sand) 7294 5002 9.27 ppg EMW (pore pressure = 2410) Base Schrader (Obf) 7903 5324 HRZ top 9498 6533 HRZ Base 9672 6634 Kuparuk C4B 9682 6634 Top Target 9.96 EMW (pore pressure = 3435) Kuparuk C4A 9691 6642 Kuparuk C3B 9709 6659 Kuparuk C3A 9748 6694 Base Target Interval Kuparuk C2 9795 6737 Kuparuk Cl 9813 6754 Kuparuk B, LCU 9832 6771 Kuparuk A 9913 6845 Miluveach 9984 6910 TD 10184 7093 TD S-105 Permit to Drill Page 2 Casinc rrubinq Proqram: Hole Csg! Wt/Ft Grade Conn Length Top Btm Size Tb9 O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 109/109 12-1/4" 9-5/8" 40# L-80 BTC-M 3000' GL 3000'/2785' 8-3/4" 7" 26# L-80 BTC-M 10184' GL 10184'/7159' Tubing 3-1/2" 9.3# 13-Cr Fox -9672' GL 9672'/6691' 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. Casim, Basis: Size 1 9-5/8" Surface Lead: Based on 1882' of annulus in the permafrost @ 100% excess and 459' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Total Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2341' MD (2285' TVDbkb). Lead 1 260 bbl / 1460 f¢ / 329 sks of Dowell ARTICSET Lite 3 at 1 10.7 ppg and 4.44 cf/sk. Tail 54 bbl / 303 f¢ / 261 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casino_ Size 17" Intermediate I Basis: Lead: to 500' MD above the Ugnu 4A Formation and 30% excess Lead TOC: 4001' MD Tail: Based on TOC 1000' above top of Kuparuk R. formation and 30% excess + shoe Tail TOC: 8682' MD, 5873' TVDbkb ITotal Cement Volume: I Lead 163 bbls / 915 f¢/328 sks of Dowell Extended blend at I11.5 ppg and 2.79 cf/sk. I Tail 1 55 bbls / 309 f¢/267 sks of Dowell Premium 'G' at 15.8 I ppg and 1.16 cf/sk. S-105 Permit to Drill Page 3 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. 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 @ 6634' TVDss - Kuparuk Target Top 2772 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: 8.6 ppg KCI / seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · S-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad has been 60 ppm (S-37, 12/2/98) DRILLING CLOSE APPROACH: Close approach issues are not expected at this time or will be mitigated in the final well plan. SURFACE HOLE SECTION: · Directional control was an issue in the S-100 and S-102 surface holes. Response to sliding in the permafrost was hampered through the gravel intervals, presumably the washed-out sections. Doglegs should be kept below 12.5° for casing running. · The surface hole interval on S-Pad has been relatively problem free on most wells to date. Only one well (S-22, 1990) is recorded with lost circulation problems. S-22 experienced lost circulation while drilling and cementing both. · Some tight hole has been noted while running casing, in particular with 13-3/8" casing in 16" hole. All three Aurora wells on S-pad have experienced some degree of tight hole while drilling and casing the surface hole. Conditions have improved each well as mud and drilling parameters become fine-tuned. · No faults are mapped in the direction of the well plan · Heavy clays are reported in the 2000-3000' TVD area of S-pad. · Produced water injection has over-pressured the SV3/Cretaceous zone. Recent well S- 40 required 9.3 ppg mud to drill this interval. S-105 Permit to Drill Page 4 INTERMEDIATE/PRODUCTION HOLE SECTION: · The surface casing point is chosen just below the SV3 sands, leaving the SV1 exposed for the 8-3/4" hole. The first three Aurora wells covered the SV1 sand with the surface casing to mitigate differential sticking hazards across the sand. Due to the Iow hole angle through the HRZ, a lower mud weight will be required to provide well bore stability, thus minimizing the risk of differential sticking. · The kick tolerance for the 8 3,4" open hole section would be 52 bbls assuming an influx from the Kuparuk interval at -9,682' MD. This is a worst case scenario based on a 9.96 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.5 ppg mud in the hole. Rig will perform LOT after drilling 20ft of new formation. · The closest mapped fault is approximately 550' away from the planned target coordinate at the top of Kuparuk, converging to 400' from the plan at TD. Adequate standoff will be maintained to avoid fault-related lost circulation problems and seismic uncertainty (_+100'). · Gas cut mud occurred in a relatively nearby well (S-031) at 5713' TVD. Mud weight was increased from 10.1 ppg to 10.3 ppg to handle the pro, em. S-100 experienced traces of oil at the top of the Ugnu. For this reason the 7" casing wiE'be.~emented to 500' above the UG4A. -"---,~ \~\ - \~ Disposal: · No annular injection in this well. · Cuffings 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. DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor was set Sept 2~h, 2000. 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 Operations: 1. MIRU Nabors 9ES. 2. Nipple up and function test 16" diverter system. PU 4" DP as required and stand back in derrick. 3. MU 12 lA,, drilling assembly and drill surface hole to approximately 3000' MD / 2785' TVD. The actual surface hole TD will be +/-125' TVD below the SV3 sand top (30' below the sand base). 4. Run and cement the 9 5/8", 40# surface casing back to surface. A TAM port collar will be p.ositioned at _+1000' as contingency in the event cement does no fully circulate to surface. 5. ND diverter system and NU casing / tubing head. NU BOPE and test to 3500 psi. S-105 Permit to Drill Page 5 6. MU 8 3/4" 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 displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a LOT. 8. Drill per directional plan to top of Kuparuk and change mud system to 6% KCI GEM. Continue drilling 8 3,~,, hole to 150' below the base of Kuparuk A sands. TD: 10,184' MD / 7159' TVDbkb. POOH, lay down 4" DP. 9. Run 7" 26#/ft long string casing to TD and cement to 500' above the Ugnu UG4A formation , set on mandrel hanger. Displace cement with clean Seawater. Bump plug to 3500 psi, check floats. 10. Freeze protect 7" x 9-5/8" annulus with dead crude to 2000' TVD by bullhead method. 11. Run 3-1/2", 9.3# 13-Cr completion string. See attached completion schematic for details. 12. Freeze protect tubing and annulus with 2000' diesel. 13. set production packer and test tubing and annulus to 3500 psi. 14. Install two-way check and test to 3500 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 15. Pull two-way check and Install BPV. Secure the well and rig down / move off 9ES. Estimated Spud Date: 11/8/2000 Allen Sherritt Alaska Drilling and Wells 564-5204 sherrija@ BP.com S-105 Permit to Drill Page 6 TREE: 4-1/16 "- 5M ClW Chrome WELLHEAD: 11" - 5M FMC Ultra SH Gert 5 S-103 Proposed Completion 4-1/2" 12.6# 13Cr-80, single joint Cellar Elevation = 35.8' Nabors 9ES Floor = 64.3' 3-1/2" 'X' Landing Nipple with 2.75" seal bore. I 2100' I 9-5/8"", 40 #/ft, L-80, M-BTC 3-1/2" Camco Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS ....... -#' TVDss ...... ~i~' ............ Valve Type 1 1 / 3700 1 1/2" RP Shear 2 / 5800 1 1/2" DV 3 / 2 jts above 1 1/2" DV 3-1/2" 9.2# 13Cr-80, Fox Tubing 7", 26 #/ft, L80, BTC-Mod 11°1s4' I ~ 3-1/2" 'X' Landing Nipple with 2.75" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer with crossover pups to 3-1/2" 3-1/2" 'X' Landing Nipple with 2.75" seal bom. 3-1/2" WimLine Entry Guide Date 10/11/2000 Rev By Comments JAS Proposed Completion AURORA WELL: S-103 APl NO: 50-029-22### BP Alaska Drilling & Wells S-103 Ri.qsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE High formation pressures are present both in and sometimes above the Kuparuk reservoir zone. Expected formation pressure below the permafrost is 9.0 ppg EMW. The surface holes on S-100, 101 and 102 were drilled with 9.6 - 9.7 pgg mud weight without problem, o,d3 Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i and S-101 'did not encounter any shallow gas problems. S-102 encountered hydrate shows at 2700' and 2850' TVDbkb, however there were no associated complications. Lost circulation while drilling has not been a problem in the first three wells of the Aurora development, despite several fault crossings. The closest known fault is 550' from the well plan near the top of the Kuparuk on S-103, converging to 400' from the plan at TD; lost circulation is not considered a likely hazard. The Ugnu interval on S-100i, S-101 and S-102 contained hydrocarbons. Triple combo LWD tools were used to mad pass the interval. Cement will need to be brought minimum 500 feet above the Ugnu formation. The surface casing will be set higher in this well than the previous three Aurora wells. The higher casing point will leave the SV1 sands exposed while drilling the 8-3/4" section, increasing the risk of differential sticking. pad is not a designated H2S pad. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Aurora S-105 Hazards and Contingencies Page ! of I rllllll_LI Nil N N lilY1 I" II ! Propoml Dais for 8-10~ Wp 02 vadol'n: s. loo (81ot18, EX-O) : . : o. oo N,O.OO E NlM o.oo o.~ooo.91o o, flo o.oo N iDjoo B oxx) 9oo.(x) o.10M) o.91o goo,(xJ o.Qo .'~ oAJo i~ (xoo i ioo,4~ 2.000327,';73 1099.96 2.9S .~ IJI6W 3.19 ISO0.O0 IO,~O~27.~3 1497,4S 3S.,.~ ~ 2,4.14W 4S.272.000 18S4.06 IS.ISm 327.'rL~ 1840.(xJ 112,84 N 71.t3w 1333S 11AS4.06 II,ISl 327.7131934.64 140,17 N 81.36 W L6.q.~ 0,,000 3263.03 $Ll21327.77220ag J2 ims~SaX 51433W 964A7 3.000 'Mo&aa$&12l327.772s422.47 4193.40 N2643J4w 49s7.1! 9MI,9423.780 327.773 6?(X),0O.fl31,21 N 3234.73 W M.TI 2.000 9983.~5 23.780 327.773 697L(30 $2~4,O~ N3299JgW 6187.33 0~]0 I0J83.t~ 23.780 327.?73 ?1Sg.(~ $~4]~ I N3M2~OW 6267.9? (X(XX) Shared Services Drilling ~-1tl3 wn fl2 · Eastings Scale: I inch = 160Oft Meamrmen Units: Single_r, owdlnmft Wdl TM Date for 8-103 (Slot18, EX..8) ~ IT,~ ~ ~ ~ ~~ ~Y ~x c~ S-I03 Tmr~S/lO/(X) EnlryPoint 6700.00 6634.00 SI31.21N 32~4.73W 5985854.00N 615614.00E Circle ~ 4800 m 3200 1250 ,~ 1600 II in Dir O 1.000~/1~: 900.00ft MD, 900.00ft TVD in Dir Rate ~ 2.000°/100ft: 1100.00ff MD, 1099.96ft 'r~D 0 in Dir Rate ~ 2.500°/100ft: 1500.00ft MD, 1497.45ff TVD Dir: 1854.06ft MD, 1840.00ft TVD pj.r..Q..3...- .o(~.. ;./.t..o(~t... ;.! .9.~....0~....M.p, .!...m~....~3.~ .D. ................ B Perm - lSt~i. O0 TV/) I DrillQuest' -3200 - 1600 0 -3200 - 1600 4800 3200 1600 ~ ~o ,i-- II .c_ o ~I Reference is Tree North Eastings 2500 3750 9 6/8" Casing 2883,11MD 2708.00 MD 3263.05ff MD, 2939.32ff TVD sv.~- 27o~.(,~) ~/) SVI - .~205.00 TV/) Tt;p Ugnu/Ug4A . Current Well Properties Well: 8-103 (81ot18, EX-8) Horizontal Coordmtes: Fief. Global Coorcllmtea: Ref. Structure Reference: Ref. Geoffaphlcal Coordinates: RKB EievaUon: Nofll~ Reference: Units: 5980774.79 N, 618929.79 E 97.52 8,1011.65 E 70° 21' 22.0612" N, 149° 02' 02.8599" W 66.00ft above Mean Sea Level 66Z}Oft above Structure Reference True North Feet Begin Dir ~ 2.000°/10Oft: 7964.88ft MD, 5422.47ft TVD 5000 ~6250 II ~n 7500 THRZ . 6534,00 TVD !!11111111111111 t11111 llllllllll II!11111111111111111 ii!!!!!!!!!111 iii!111111~1111111111111111 End Dir: 9681.94ft MD, 6700.00ff TVD i 0 1250 Scale: linch = 1250ft ,~;-I,93 7~'~r~ 8//0/00 6700.0~ TV/) ,~131.21 A" 32.t4.73 W 10183.55 MD 7159.02 'rvD I I I I 2500 3750 5000 6250 Section Azimuth: 327.773° (True North) Ve~)cal Sea!on Sperry-Sun Drilling Services Proposal Data - S-103 (S!ot18, EX-8) - S-103 Wp 02 '. :=... "~' = ..:".:'?i:.:(ft);::::..::i;::'.: .i:.iMl~:.:(.ft)!.', ' 'i.(°) (°). ' (ft)' . TvD.:(ft)':: ' (ft).' . :' (fi} . '. ~/lOOft) (fl) ...... ' ' '"~' ............ ~,~i .... ' ............... 327.773 ?!:::' :.. ." i::ii'.3".:i::':, .':,. ::::.! ~'~'.~ 2oo. OO ?..'i:..:.i:l:,.~!i::;~:~T/~:::it!!.~ ?i;!?i~i~:ii:;;::t;~,i'i...~;~ii~;!~:~,;ii!ii'~i~:. 1.(xx) .;:.':;~':..'.":"':"..':.':'::::~.~;® ,oo.oo!::'::.~!~i:i::~i~::i:.~:~:~ ~?iii?:;,~i:~~~ie!!i'~!?,?i'~,:ii~;~ 2.ooo o.ooo .....::.S!:~:':.'i..:; :.::"".,.'...:i~m ?:::::.':::.~;mi,:.:':'!.i/~S:i~l~.:i~ii:,i::~;~3':: 18~0.00 !i:~i.:i'::'i:!.'~i;~:~;:;iiii~;~i:;i:i~i!;:.~:i~ii:~ 2.5oo 0.000 12 October, 2000 - 15:25 -1- DriilQuest North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S- 103 (Slot18, EX-8) - T 12 Surface Coordinatea: E (70°21'22.0612" N, 149° 02' 02.8599" W) Mean Sea Level Proposal Ref: pro10500 Sperry-Sun Drilling Services Proposal Report for S-103 (Slot18, EX-8) - S-103 Wp 02 North Slope Alaska Meaeured Depth (It) Incl. 0.000 0.0(x) 0.000 0.000 0.000 Sub-Sea Vertical Local Coordinates Azim. Depth Depth Northings Eaetinge (ft) (ft) (ft) (ft) 0.000 -66.00 0.00 0.00 N 0.00 E 0.000 34.00 100.00 0.00 N 0.00 E 0.000 134.00 200.00 0.00 N 0.00 E 0.000 234.00 300.00 0.00 N 0.00 E 0.000 334.00 400.00 0.00 N 0.00 E ~.00 0.~ 0.~ 434.00 ~.00 0.~ 0.~ 534.00 700.00 0.~ 0.~ 634.00 ~.00 0.~ 0.~ 734.00 ~.00 0.~ 0.~ 834.00 1000.00 1.000 327.773 933.99 1100.00 2.000 327.773 1033.96 1200.00 4.000 327.773 11 33.82 1300.00 6.000 327.773 1233.43 1400.00 8.0(X) 327.773 1332.68 1500.00 10.000 327.773 1431.45 1600.00 12.500 327.773 1529.52 1700.00 15.000 327.773 1626.64 1800.00 17.500 327.773 1722.64 1854.00 18.851 327.773 1774.00 1881.53 18.851 327.773 1800.00 1900.00 18.851 327.773 1817.48 1954.06 18.851 327.773 1868.64 2000.00 20.230 327.773 1911.93 2100.00 23.230 327.773 2004.81 Global Coordinates Northinge Eaetinge (ft) (ft) 5980774. 500.00 0.00 N 0.00 N 600.00 0.00 N N 700.00 0.00 N 0.00 N 800.00 0.00 N N 900.00 0.00 N 5980774.79 N 999.99 0.74 1099.96 ;W 1199.32 7.38 4.65 W 1299.43 14.75 N 9.30 W 1398.68 25.06 N 15.80 W 1497.45 38.29 N 24.14 W 1595.52 54.80 N 34.54 W 1692.64 74.90 N 47.22 W 1788.64 98.57 N 62.14 W 1840.00 112.34 N 71.13 W 1866.00 120.35 N 75.86 W 1883.48 125.39 N 79.05 W 1934.64 140.17 N 88.36 W 1977.93 153.17 N 96.56 W 2070.81 164.48 N 116.30 W 618929.79 E 618929.79 E E E E 618929.79 E 618929.79 E 618929.79 E 618929.79 E 618929.79 E 5980775.52 N 5980777.71 N 5980782.09 N 5980789.39 N 5980799.60 N 5980812.70 N 618929.31 E 618927.88 E 618925.02 E 618920.26 E 618913.60 E 618905.04 E 5980829.03 N 5980548.93 N 5980872.35 N 5980886.48 N 618894.38 E 618881.39 E 618866.09 E 618856.88 E 5993893.92 N 5980898.91 N 5980913.54 N 5980926.41 N 5980957.40 N 618652.02 E 618848.76 E 618839.21 E 618830.81 E 618810.56 E Dogleg Rate (,/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1.000 1.000 2.000 2.000 2.000 2.000 2.500 2.500 2.500 2.500 0.000 0.000 0.000 3.000 3.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (fi) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.87 3.49 8.72 17,44 29.63 45.27 64.78 88.54 116.52 135.38 142.26 148.23 165.70 181.06 218.08 Comment in Dir O 1.000°1100ft: .00ft MD, 900.00ft TVD Increase in Dir Rate 0 / 2.500°/100ft: 1500.0Oft MD, 1497.45ft TVD End Dir: 1854.06ft MD, 1840.00ft TVD B Perm Beein Dir O 3.000"/100ft: 1954.06ft MD, 1934.64ft TVD Continued... 12 October, 2000- 15:25 - 2 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-103 (Slot18, EX-8) - S-103 Wp 02 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (it) (it) 2200.00 26.230 327.773 2095.63 2161.63 2300.00 29.230 327.773 2184.14 2250.14 2400.00 32.230 327.773 2270.09 2336.09 2500.00 35.230 327.773 2353.24 2419.24 2600.00 38.230 327.773 2433.38 2499.38 2700.00 41.230 327.773 2510.28 2576.28 2600.00 44.230 327.773 2583.73 2649.73 2883.11 46.723 327.773 2642.00 2708.00 2900.00 47.230 327.773 2653.52 2719.52 3000.00 50.230 327.773 2719.48 2785.48 3100.00 53.230 327.773 2781.41 2847.41 3200.00 56.230 327.772 2839.14 2905.14 3263.05 56.121 327.772 2873.32 2939.32 3300.00 58.121 327.772 2892.83 2658.83 3400.08 58.121 327.772 2945.65 3011.65 3500.00 58.121 327.772 2998.46 3064.46 3600.00 56.121 327.772 3051.27 3117.27 3700.00 58.121 327.772 3100.08 3170.08 3766.11 58.121 327.772 3139.00 3205.08 3800.00 58.121 327.772 3156.90 3222.90 3900.00 58.121 327.772 3209.71 3275.71 i:::.', ' ,.~)00.00 58.121 327.772 3262.52 3328.52 ,,!, ,, ~.~, 00.00 56.121 327.772 3315.33 3381.33 .,..4200.00 58.121 327.772 3368.15 3434.15 '~ 4,.~00.00 56.121 327.772 3420.96 3486.96 ;. g Local Coordinates Global Coordinates Northings Eastings Northings (it) (it) (it) 219.87 N 138.60 W 259.23 N 163.41 W 3O2.45 N 190.66 W 349.41 N 220.27 W 400.00 N 252.16 W 322.42 454.08 N 511.46 N 561.58 N 572.02 N 635.60 N 702.05 771.~ .06 W 576.35 W 842.42 914.26 N 621.63 W 666.92 W 712.20 W 742.14 W 757.49 W 986.09 N 1057.93 N 1129.76 N 1177.25 N 1201.59 N 802.77 W 848.05 W 893.34 W 938.62 W 983.91 W 1273.43 N 1345.26 N 1417.10 N 1488.93 N 1560.76 N 5981341.02 N ' 5981403.95 N 5981469.68 N 5981538.00 N 5981582.40 N 5981608.68 N 5981679.78 N Eastinga (ft} 618787.71 E 618762.28 E 618734.35 E 618704.05 E 618671.31 E 618636.38 E 618599.29 E 618566.90 E 618560.15 E 618519.07 E 618476.16 E 618431.53 E 618402.57 E 618385.42 E 618339.00 E 618292.56 E 616246.16 E 618199.74 E 618169.05 E 618153.32 E 618108.90 E 618060.43 E 618014.07 E 617967.65 E 617921.23 E 5981750.89 N 5981621.99 N 5981893.10 N 5981940.11 N 5981964.21 N 5982035.31 N 5962106.42 N 5962177.52 N 5982248.63 N 5982319.74 N Dogleg Rate (o/~omt) 3.000 3.000 3.00O 3.O0O 3.000 3.000 3.000 3,000 3.000 3.000 3.000 3.000 3.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (it) 259.91 306.43 357.53 413.05 472.85 536.76 676.20 751.35 829.85 911.49 964.47 1080.76 1165.68 1250.59 1335.51 1391.65 1420.43 1505.34 1590.26 1675.18 1760.09 1845.01 Comment End Dir: 3~.05ft MD, 2939.32ft TVD SVl Con~ued... ( 12 October, 2000 - 15:25 - 3 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-103 (Slot18, EX-8) - S-103 Wp 02 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 4400.00 58.121 327.772 3473.77 3539.77 4500.00 58.121 327.772 3526.58 3592.58 4500.79 58.121 327.772 3527.00 3593.00 4600.00 58.121 327.772 3579.40 3645.40 4700.00 58.121 327.772 3632.21 3698.21 4800.00 58.121 327.772 3665.02 3751.02 4900.00 58.121 327.772 3737.83 3803.83 5(X)0.00 58.121 327.772 3790.65 3856.65 5100.00 58.121 327.772 3843.46 3909.46 5200.00 58.121 327.772 5896.27 3962.27 5300.00 58.121 327.772 3949.08 4015.08 5400.00 58.121 327.772 4001.90 4067.90 5500.00 58.121 327.772 4054.71 4120.71 5800.00 58.121 327.772 4107.52 4173.52 5700.00 58.121 327.772 4160.33 4226.33 5800.00 58.121 327.772 4213.15 4279.15 5900.00 58.121 327.772 4265.98 4331.98 6000.00 58.121 327.772 4318.77 4384.77 6100.00 58.121 327.772 4371.58 4437.58 6200.00 58.121 327.772 4424.40 4490.40 63(X).00 58.121 327.772 4477.21 4543.21 6400.00 58.121 327.772 4530.02 4698.02 6500.00 58.121 327.772 4582.83 4648.83 6600.00 58.121 327.772 4635.65 4701.65 6700.03 58.121 327.772 4688.46 4754.46 6782.45 58.121 327.772 4732.00 4798.03 6800.00 58.121 327.772 4741.27 4807.27 6900.00 58.121 327.772 4794.08 4860.08 7000.00 58.121 327.772 4545.90 4912.90 7058.90 58.121 327.772 4378.00 4944.00 Local Coordinates Global Coordinates Northinge Eaetinge Northings Eaetinge (ft) (ft) (ft) (ft) 1632.60 N 1029.19 W 598,?.390.~ 617874.81 E 1704.43 N 1074.46 W 617928.39 E 1705.00 N 1074.83 W 617928.02 E 1776.27 N 1119.76 W .617781.97 E 1848.10 N 1165.05 W N 617735.55 E 1919.94 N 1210.33 N 617689.13 E 1991.77 N 1255.62 N 617642.71 E 2063.60 N 1300.90 N 617596.26 E 2135.44 N I N 617549.87 E 2207.27 N 5982959.69 N 617503.45 E 2279.11 N 5983050.80 N 617457.05 E 2350.94 1 W 5983101.91 N 617410.61 E W 5983173.01 N 617364.19 E W 5983244.12 N 617317.78 E 2586.4Z W 5983315.22 N 617271.36 E 2638.28 N 1663.18 W 5983386.33 N 617224.94 E 2710.11 N 1708.46 W 5983457.44 N 617178.52 E 2781.95 N 1753.75 W 5983528.54 N 617132.10 E 2853.78 N 1799.03 W 5983599.65 N 617085.68 E 2925.61 N 1844.32 W 5983670.75 N 617039.26 E 2997.45 N 1889.60 W 5983741.86 N 616992.34 E 3069.28 N 1934.89 W 5983812.97 N 616946.42 E 3141.12 N 1980.17 W 5983884,07 N 616900.00 E 3212.95 N 2025.45 W 5983955.18 N 616853.58 E 3284.78 N 2070.74 W 5984026.29 N 616807.16 E 3344.01 N 2108.07 W 5984084.91 N 616768.89 E 3356.62 N 2116.02 W 5984097.39 N 616760.74 E 3428.45 N 2161.31 W 5964168.50 N 616714.32 E 3500.29 N 2206.59 W 5984239.60 N 616667.90 E 3542.59 N 2233.26 W 5984281.48 N 616640.57 E Dogleg Rate (°ll00ft) o.0oo 0.030 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.030 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (~t) 1929.93 2014.64 2015.51 2099.76 2184.68 2269.59 2354.51 2439.43 2524.34 2609.26 2694.18 2779.08 2864.01 2948.93 3333.34 3118.76 3203.68 3288.59 3373.51 3458.43 3543.34 3628.26 3713.18 3798.08 3883.01 3953.02 3967.93 4052.84 4137.76 4187.77 Comment Top Ugnu/Ug4A Top Schrader/Mb1 WS2/Schrader Na Continued... 12 October, 2000 - 15:25 .4 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-103 (Slot18, EX-8) - S-103 Wp 02 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 7100.00 58.121 327.772 4899.71 4965.71 7200.03 58.121 327.772 4952.52 5018.52 7293.69 58.121 327.772 5002.00 5068.00 7300.00 58.121 327.772 5005.33 5071.33 7400.00 58.121 327.772 5058.15 5124.15 7500.00 58.121 327.772 5110.96 5176.96 7600.00 58.121 327.772 5163.77 5229.77 7700.00 58.121 327.772 5216.58 5282.58 7900.00 58.121 327.772 5269.40 5335.40 7900.00 58.121 327.772 5322.21 5388.21 7903.39 58.121 327.772 5324.00 5390.00 7964.88 58.121 327.772 5356.47 5422.47 8000.00 57.419 327.772 5375.20 5441.20 8100.00 55.419 327.772 5430.51 54,96.51 8200.63 53.419 327.7~ 5488.69 5554.69 8300.00 51.419 327.772 5549.68 5815.68 8400.00 49.419 327.772 5613.39 5679.39 8500.00 47.419 327.772 5879.76 5745.76 8600.00 45.419 327.772 5748.69 5814.69 8700.00 43.419 327.772 5820.11 5886.11 8800.00 41.419 327.772 5893.93 5959.93 8900.00 39.419 327.772 5970.06 6036.06 g000.00 37.419 327.772 6048.41 6114.41 9100.00 35.419 327.772 6128.87 6194.87 9200.00 33.419 327.772 6211.36 6277.36 Local Coordinates Northings Eaetings (ft) 3572.12 N 2251.88 W 3643.96 N 2297.16 W 3711.26 N 2339.59 W 3715.79 N 2342.45 W 3787.62 N 2387.73 W 3859.48 N 3931.29 N 4003.13 N 4074.96 N 4148.80 N 4149.23 N 4193.40 4357.80 N 4424.84 N 4490.03 N 4553.31 N 4614.58 N 4673.79 N 4730.85 N 4785.69 N 4838.25 N 4888.47 N 4938.29 N 2478.30 2523.58 W W W W 2789.43 W 2830.53 W 2870.42 W 2909.05 W 2946.37 W 2982.34 W 3016.92 W 3050.05 W 3081.71 W 3111.85W Global Coordinates Northlnga (ft) 5984310.' N N N N N 5984879.58 N 5984881.97 N 5984625.69 N 5934950.57 N 5985020.33 N 5985088.43 N 5985154.78 N 5985219.32 N 5985281.95 N 5985342.61 N 5985401.21 N 5985457.69 N 5985511.98 N 59,85564.01 N 5985613.72 N 5985661.05 N Eastings (ft) 616621.49 E 616575.07 E 616531.58 E 616528.65 E 616482.23 E 616435.81 E 616389.39 E 616342.97 E 616296.55 E 616250.13 E 616248.55 E 616220.01 E 616203.77 E 616158.24 E 616113.78 E 616070.46 E 616028.33 E 615987.44 E 615947.85 E 615909.59 E 615872.72 E 615837.28 E 615803.31 E 615770.86 E 615739.98 E Dogleg Rate (°ll00ft) 0.000 0.000 0.000 0.000 0.000 0.003 0.003 0.000 0.000 0.000 0.030 0.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 2.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 4222.68 4307.59 4387.15 4392.51 4647.26 4732.18 4817.09 4902.01 4904.89 4957.11 4986.81 5070.12 5151.44 5230.69 5307.76 5524.98 5857.26 5719.40 5778.76 5835.29 Comment WS1/Schrader Oa Base West SaldBa,se Obf Continued... 12 October, 2000 - 15:25 - 5 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-103 (Slot18, EX-8) - S-103 Wp 02 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea (ft) Vertical Local Coordinates Global Coordinates Depth Northings Fastings Northinge Fastings (ft) (ft) (ft) (ft) (ft) 9300.00 31.419 327.772 6295.77 6361.77 9400.00 29.419 327.772 6382.00 6446.00 9497.81 27.463 327.772 6466.00 6534.00 9500.00 27.419 327.772 6469.95 6535.95 9600.00 25.419 327.772 6559.50 6625.50 9672.10 23.977 327.772 6625.00 6691.00 9681.94 23.780 327.773 6834.00 6700.00 9690.68 23.780 327.773 6642.00 670800 9700.00 23.780 327.773 6850.53 6716.53 9709.26 23.780 327.773 6559.00 6725.00 9747.51 23.780 327.773 6894.00 6760.00 9794.50 23.780 327.773 6737.00 680300 9800.00 23.780 327.773 6742.04 6808.04 9813.07 23.780 327.773 6754.00 6820.00 9831.65 23.780 327.773 6771.00 6837.00 9900.00 23.780 327.773 68.33.55 6899.55 9912.52 23.780 327.773 6845.00 6911.00 9983.55 23.780 327.773 6910.00 697600 10000.00 23.780 327.773 6925.06 6991.06 10100.00 23.780 327.773 7016.57 7082.57 10183.55 23.780 327.773 7093.02 7159.02 4981.64 N 5024.46 N 5063.87 N 5064.72 N 5102.36 N 3140.44 W 3167.44 W 3192.28 W 3192.82 W 3216.55 W 5127.84 N 5131.21 N 3232.61 3234.73 5134.19 N 5137.37 N 5140.53 51,' 5171.48 5175.94 N 5182.28 N 5205.59 N 5209.86 N 5234.09 N 5239.70 N 5273.81 N 5302.31 N W W W W 3282.93 W 3268.93 W 3281.63 W 3284.32 W 3299.59 W ~.13W 3324.63 W 3342.60 W 5985705J N 5965860.10 N 5965863.22 N 5985876.14 N 5985892.00 N 5965893.86 N 5985898.28 N 5985904.55 N 5965927.63 N 5965931.65 N 5965955.84 N 5965961.39 N 5965995.16 N 5986023.37 N 615710.68 E 615682.98 E 615657.52 E .615656.97 E 615632.64 E 615616.18 E 615914.00 E 615612.07 E 615610.02 E 615607.98 E 615598.55 E 615589.19 E 615587.98 E 615585.10 E 615581.00 E 615565.63 E 615563.18 E 615547.52 E 615543.89 E 615521.65 E 615503.43 E Dogleg Rate (o/looft) 2.000 2.000 2.000 2.000 2.000 0.000 0.0(X) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section 5888.89 5939.52 5986.10 5987.11 6031.60 6061.73 6065.71 6069.24 6O72.99 6076.73 6092.15 6111.10 6113.31 6118.59 6126.08 6153.64 6158.68 6187.33 6193.96 5234.28 6267.97 Comment THRZ BHRZ End Dir: 9681.94ft MD, Tal~et'- $'103 Taro 8/10/00, 200:00 Radius., GeOlogical Kup C4A Kup C3B Kup C3A Kup C2 Kup Cl Kup B/LCU Kup A Miluveach End Dir: 10183.55ft MD, 715_9.0~ff TVD /" L;aslng 12 October, 2000 - 15:25 - 6 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-103 (Slot18, EX-8) - S-103 Wp 02 North Slope Alaska All data is in feet unless otherwise stated. Directions and coordinates am relative to True North. Vertical depths are relalfve to S-103 (Slot18, EX-8). Northings and Eastings are relative to S-103 (Slot18, EX-8). The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-103 (Slot18, EX-8) and calculated along an Azimuth of 327 Based upon Minimum Curvature type calculations, at a Measured Depth of 10183.1 The Bottom Hole Displacement is 6267.97ft., in the Direction of 327.773° (True). Comments Meaaured S t a t i o n Depth TVD (it) (It) 1100.00 1099.96 1500.00 1497.45 1854.06 1840.00 1954.06 1934.64 3263.05 2939.32 7964.88 5422.47 9681.94 6700.00 10183.55 7159.02 Coordinates Northinga Eastings Corn, (It) (it) 0.00 N 0.00 E 2.95 N 1.86 W 38.29 N 24.14 W 112.64 N 71.13 W 140.17 N 88.38 W 815.88 N 514.33 W 4193.40 N 2643.54 W 5131.21 N 3234.73 W 5302.31 N 3342.60 W Begin D : 900.00ft MD, 900.00ft TVD Increase in O 2.000°/100ft: 1100.00ft MD, 1099.96ft TVD Increase in Dir Rate O 2.50(Y'/100ff: 1500.00ft MD, 1497.45ft TVD End Dir: 1854.06ft MD, 1840.00ft TVD Begin Dir ~ 3.000~ll00ft: 1954.06ft MD, 1934.64ft TVD End Dir: 3293.05ft MD, 2939.32ft TVD Begin Dir ¢} 2.000°/100ft: 7964.88ff MD, 54,?.2.47ft TVD End Dir: 9681.94ff MD, 6700.00ft TVD End Dir: 10183.55ft MD, 7159.02ft TVD Alaska State Plane 4 PBU_WOA S Pad 12 October, 2000- 15:25 Continued... - 7. DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-103 (S!ot18, EX-8)- S-103 Wp 02 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northinge Eeatinga Formation Name (ft) (ft) (ft) (ft) (ft) 1881.53 1866.00 1800.00 120.35 N 75.86 W B Perm 2883.11 2706.00 2642.00 561.56 N 354.02 W SV3 3766.11 3205.00 3139.00 1177.25 N 742.14 W SV1 4500.79 3593.00 3527.00 1705.00 N 1074.83 W 6782.45 4798.00 4732,00 3344.01 N 2108.07 W 7058.90 4944.00 4878.00 7293.69 5068.00 5002,00 7903,39 5390.00 5324.00 9497.81 6534.00 6468.00 9672,10 6691.00 6625.00 9681.94 6700.00 6634.00 9620.68 6708.00 6642.00 9709.26 6725.00 6859.00 9747.51 6760.00 6894.00 9794.50 6803.00 6737.00 9813.07 6820.00 6754.00 9831.65 6837.00 6771.00 9912.52 6911.00 6845.00 9983.55 6976.00 6910.00 3542.59 N 2233.26 W 3711.26 N 2339.59 W 4149.23 N 2615.69 W 5063.87 N 3162,28 W 5127.84 N 3232.61 5131.21 N 5134.19 N 3236.61 V~ 5140.53 N 3240.61 W 5153.58 N 3248.83 W 5169.60 N 3256.94 W W~ C3B Kup C3A Kup C2 5175.94 N 3262.93 W Kup Cl 5182.28 N 3266.93 W Kup B/LCU 5208.86 N 3284.32 W Kup A 5234.09 N 3299.59 W Miluveach Continued... 12 October, 2000- 15:25 - 8 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S- 103 (Slot18, EX-8) - S- 103 Wp 02 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 2883.11 2708.00 <Surface> <Surface> 10183.55 7159.02 Targets aseoclatsd with this wellpath Target Name S-103 Targ 8/10/00 Ceaing Detail 9 5/8" Casing 7' Casing Mean Target Entry Coordinatee TVD Northinge Eeatinge (ft) (ft) (ft) 6700.00 5131.21 N 3234.73 W 6634.00 5985854.00 N 615614.00 E 70° 22' 12.5234" N 149~ 03' 37.4933" W Target Target Shape Type Circle Geological 12 October, 2000.15:25 - 9 - DrillQuest 1.05.05a H 1 751 40 0175140 VENDOR ~l .~KASTAT 10 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 092600 ~KO92600D 100. O0 100. O0 PYMT CDMMENTS' PERMIT TO DRILL ~EE HANDLI~Q INST- S/H TERRIE HUBBLE X4&28 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 1 OO. OO ~[ OO_ OO '.':rl;:,.':ANDH(~RAGEi'ALASK~r.99519-66 "! "...::i~ii1!'.,:(: ':.';':%,,.?::'."".i'.::'::,:2.' '::%!', : :?.'"' ....,..?.:.' ..!..,!:::~,.,. ..':'"!'"i'i?~i',;'~'?'..'(':''''~'I?':'':~' ' ?:?,;',?!"': '" '''?''ii'ii',.':'!'' ' ...... '.':'i':i:.:i:.'.'" .... : .... ,.i~?iI ...~;~:~:':'::::?:':...." ' ............ !... '.' '" ='..:.,::: ""' ':' ":'~:' 4~2 '": ' .:'"::~:!::': 001751'40.: ' ""' 'P~'~.':{'::. ' :"i: ." ii" .;::.i .:"ONE~'. '"~U~'~:~D![:i!!iiA i~i~i.iO0~'~"~;~"~'A~'~~;'""~.~ ~'~' ~.:~.~i~'~'~:~,~ q~..:;',IDOLLAR ' .'.'?'.'?:.:.ii:!:""';i!::..':!:'.v!:,'~'. "'"i' ':i?":' '"'?.".'.::.?:~: ;i?,;;! ~:iii!i!:.:~i:,!i{!!::' ' i:::i'.,".i:" "::i:i?: :".." :?;'? ?.:.'.i:;;:! '{:i?:?i? DATE '.?!!i:? (?::::.:....:'i:.::i:i!:';? ;~"{.'i'I' .:!i::.~.i!,!i:~OUNT ' "' :' '"' !"/"; ":"?~""" ' :" ' ' ...... "" ...... '""'"' ' ' "" ..... ": ......... I' °9/26/°0' [':"' ' ....... "°°' °'° I I I J . ?.P" .::'," '.V,": '..':: ! :.!' iii .[;: ii ':."! ::; . NO.T."~:VALID AFTER~.....~..... :.... ,120 D',A. YS . .," '::"..' .::'::." ....... ~o.......T...'h:e:',:~..S:'TATE':.i: OF ALAS~A,?i:~.!'.': ..... ':?ii::'ii:i:;':.:. :~::.:.::..:.:::'... , .:;:t',.~.~.".'..'" >:.?:::" ':;'":.:4" "'.3.' .OO:'.i'~.' .:::~:OR C UP ! . , ,. .':.,,' ANCHORAQE AK 99501 ll';I,?5~NO,' I:ON~OA~qSl: O08NN ., A_DMINISTRATION 1. Permit fee attached .......... 2. Leasenumberappropriate. ~.~..~,i:~,.i/i~.~-i~i/i~ -.5~..,~¢,~- /'~__~,J-n, ~ .~.~,~. 0~__~,? ~ ~,~.,,,~ ~C ,=~c...i~_.~.~~ DATE ENGINEERING 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 ............. 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 _ '~,.5~O psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can.be issued WIG hydrogen sulfide measures ..... 6 N N · N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .... ' '., [~, fY N )_DATE 33. Seabed condition survey (if.off-shore). ' ' '" ' ' ' ~"~" Y N ~'. ~ 34. Contact name/phone for weekly progres;~ 're'p~rt; [~raio~y only] Y ANNULAR' DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N ' ~ . _ ' APPR DATE. (B) will not co.ntaminate freshwater; or cause drilling Waste .... Y N --- I CD I twW°!!i!::id~a~;rg~; rCoh~un~na ,g i~lot remg :it iYoOn fot rh ~rn;:llr ~vf:;d~c~mO Saa,; ~ NN ~.. . ~GEOLOGY: ~3'~' -~' M-'~~---~ENGINEERING: UlClAnnular B~.COMMISSION:..,7~li=~ '. . Comments/Instructions: ., ' i" lid :0 Z -r c:\rnsoffice\wordian~diana\checklist (rev, 02117100) Well History File 'APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file, To improve {he readability of the Well History file and to Simplify finding information, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effOrt has been made to, chronologically organize this category of information. 8 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri May 25 11:16:55 2001 Reel Header Service name ............. LISTPE Date ..................... 01/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/05/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Aurora MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-00250 ~PHIL ROGER. STEVE LEWIS S-103 500292298100 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 25-MAY-01 MWD RUN' 2 MWD' RUN 3 AK-MM-00250 AK-MMh00250 PHIL ROGER JEFF SACK GAVIN KIDD GAVIN KIDD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 4 AK-MM-00250 JEFF SACK GAVIN KIDD MAD RUN 4 AK-MM-00250 JEFF SACK GAVIN KIDD 35 12N 12E 4571 4496 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 64.61 35.88 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 109.0 8.750 9.625 3087.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 & 2 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUNS 3 & 4 WERE DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP),AND STABILIZED LITHO-DENSITY (SLD) o 4. RESISTIVITY DATA FROM 3087'MD / 2830'TVD TO 3233'MD / 2920'TVD ARE MISSING DUE TO TOOL MALFUNCTION. CLIENT'S WELLSITE REPRESENTATIVE INFORMED SSDS ENGINEER THAT IT WAS NOT NECESSARY TO WIPE OVER THIS INTERVAL AFTER THE TOOL BEGAN FUNCTIONING PROPERLY. 5. MAD PASS DATA WERE ACQUIRED WHILST RIH AFTER A SHORT TRIP, AFTER REACHING TD. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. 6. DEPTH SHIFTING/CORRECTION WAIVED BY E. WESTERGARD (BP EXPLORATION) ON 11/10/00. 7. MWD RUNS 1-4 REPRESENT WELL S-103 WITH API9:50-029-22981-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10078'MD / 7009'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" MUD WEIGHT: 10.5 - 10.8 PPG MUD SALINITY: 300 - 23,000 PPM CHLORIDES FORMATION WATER SALINITY: 23,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE ROP GR NPHI NCNT FCNT PEF RHOB DRHO FET RPX RPS RPD RPM $ START DEPTH STOP DEPTH 150.0 10079.0 166.0 10048..5 ' 3019.5 9993.5 3019.5 9994.0 3019.5 9994.0 3063.5 10038.0 3089.5 10038.0 3089.5 10038.0 3233.0 10029.0 3233.0 10029.0 3233.0 10029.0 3233.0 10029.0 3233.0 10029.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE. DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 150.0 870.0 2 810.5 3102.5 3 3019.5 5895.5 4 5810.0 10079.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing.., ................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF .MWD BARN 4 1 68 52 14 Name Service Unit Min Max DEPT FT 150 10079 GR MWD API 7.21 330.18 ROP MWD FT/H 0 559.76 RPX MWD OHMM 1.31 2000 RPS MWD OHMM 1.07 2000 RPM MWD OHMM 1.31 2000 RPD MWD OHMM 1.48 2000 FET MWD HOUR 0.17 16.95 NPHI MWD PU-S 11.38 75.82 FCNT MWD CNTS 405 1155 NCNT MWD CNTS 2008 3989 RHOB MWD G/CM 1.08 3.16 DRHO MWD G/CM -0.26 0.5 PEF MWD BARN 0 14.34 Mean Nsam 5114.5 19859 81.5564 19766 128.034 19859 14.4563 13593 16.327 13593 15.7079 13593 19.5581 13593 0.954084 13593 33.9256 13927 663.235 13928 2747.67 13950 2.28613 13898 0.0495884 13898 2.86238 13950 First Reading 150 166 150 3233 3233 3233 3233 3233 3019.5 3019.5 3019.5 3089.5 3089.5 3063.5 Last Reading 10079 10048.5 10079 10029 10029 10029 10029 10029 9993.5 9994 9994 10038 10038 10038 First Reading For Entire File .......... 150 Last Reading For Entire File ........... 10079 File Trailer Service name ............. STSLIB,001 Service Sub Level Name,.. Version Number ........... 1,0,0 Date of Generation ....... 01/05/25 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB,002 Physical EOF File Header Service name ............. STSLIB,002 Service Sub Level Name.,. Version Number ........... 1,0,0 Date of Generation ....... 01/05/25 Maximum Physical Record,.65535 File Type ................ LO Previous File Name ....... STSLIB,001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes, DEPTH INCREMENT.: .5000 FILE SUMMARY PBU TOOL CODE RPX FET RPD Rps RPM GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: START DEPTH STOP DEPTH 9430,5 10027,5 9430,5 10027,5 9430,5 10027,5 9430,5 10027,5 9430,5 10027,5 9450,5 10047,0 9480,5 10077,5 MAD RUN NO, MAD PASS NO, MERGE TOP 4 1 5810,0 MERGED MAD PASS, $ MERGE BASE 10079,0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 ,liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR RAT RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MAD API 4 .1 68 MAD FT/H 4 1 68 MAD OHMM 4 1 68 MAD OHMM 4 1 68 MAD OHMM 4 1 68 MAD OHMM 4 1 68 MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9430.5 10077.5 · GR MAD API 36.57 311.34 RAT MAD FT/H 0.46 393.63 RPX MAD OHMM 1.44 48.59 RPS MAD OHMM 1.63 63.4 RPM MAD OHMM 1.83 80.67 RPD MAD OHMM 2.12 88.19 FET MAD HOUR 7.53 16.48 Mean 9754 105.832 192.967 7.2851 9.13828 10.4079 11.3014 12.3413 Nsam 1295 1194 1195 1195 1195 1195 1195 1195 First Reading 9430.5 9450.5 9480.5 9430.5 9430.5 9430.5 9430.5 9430.5 Last Reading 10077.5 10047 10077.5 10027.5 10027.5 10027.5 10027.5 10027.5 First Reading For Entire File .......... 9430.5 Last Reading For Entire File ........... 10077.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 150.0 GR 166.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G):, MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 STOP DEPTH 870.0 810.0 07-NOV-00 Insite 5.46 Memory 870.0 .2 1.2 TOOL NUMBER PB01718CG8 12.250 Spud Mud 8.70 320.0 9.3 1000 16.0 .000 .000 .000 .000 .0 65.9 .0 .0 Depth Units ....................... Datum Specification Block sub-type.,,0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FT/H 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 150 870 510 1441 GR MWD010 API 19,01 91,61 45,0288 1289 ROP MWD010 FT/H 4,92 303,43 70,1671 1441 First Reading 150 166 150 Last Reading 87O 810 870 .First Reading For Entire File .......... 150 Last Reading For Entire File ........... 870 File Trailer Service name .............. STSLIB,003 Service Sub Level Name,., Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB,004 Service Sub Level Name,,, Version Number ........... 1,0,0 Date of Generation ....... 01/05/25 Maximum Physical Record,,65535 File Type ................ LO Previous File Name ....... STSLIB,003 Comment Record. FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 810.5 3042.5 ROP 870.5 3102.5 $ # LOG HEADER DATA DATE LOGGED: 09-NOV-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 5.46 Memory 3102.0 1.7 51.1 TOOL NUMBER ?B01718CG8 12.250 Spud Mud 9.30 280.0 9.2 600 12.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 .0 87.0 .0 .0 Name Service Unit Min Max DEPT FT 810.5 3102.5 GR MWD020 API 22 124.81 ROP MWD020 FT/H 0 313.88 Mean 1956.5 67.5259 82.9851 Nsam 4585 4465 4465 First Reading 810.5 810.5 87O.5 Last Reading 3102.5 3042.5 3102.5 First Reading For Entire File .......... 810.5 Last Reading For Entire File ........... 3102.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000' , FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 3019.5 5810.0 FCNT 3019.5 5810.0 NPHI 3019.5 5809.5 GR 3043.0 5865.5 PEF 3063.5 5854.0 RHOB 3089.5 5854.0 DRHO 3089.5 5854.0 ROP 3103.0 5895.5 RPM 3233.0 5845.0 FET 3233.0 5845.0 RPD 3233.0 5845.0 RPX 3233.0 5845.0 RPS 3233.0 5845.0 $ LOG HEADER DATA DATE LOGGED: 13-NOV-00 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN):.. , EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Insite 65.41 Memory 5895.0 50.3 55.2 TOOL NUMBER PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 8.750 Water Based 10.50 45.0 9.5 700 4.6 1.350 .850 1.950 2.700 68.0 112.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD030 API 4 1 68 ROP MWD030 FT/H 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 NPHI MWD030 ?U-S 4 1 68 FCNT MWD030 CNTS 4 1 68 NCNT MWD030 CNTS 4 1 68 RHOB MWD030 G/CM 4 1 68 DRHO MWD030 G/CM 4 1 68 PEF MWD030 BARN 4 1 68 0 4 8 12 16 20 24 28 32 36 40 44 48 52 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 3019.5 5895.5 GR MWD030 API 7.21 127.67 ROP MWD030 FT/H 0 559.76 RPX MWD030 OHMM 1.31 2000 RPS MWD030 OHMM 1.13 2000 RPM MWD030 OHMM 1.48 2000 RPD MWD030 OHMM 1.98 2000 FET MWD030 HOUR 0.17 1.44 NPHI MWD030 PU-S 24.34 75.82 FCNT MWD030 CNTS 405 861 NCNT MWD030 CNTS 2008 3264 RHOB MWD030 G/CM 1.08 3.16 DRHO MWD030 G/CM -0.25 0.33 PEF MWD030 BARN 0 14.34 Mean 4457.5 67.0404 174.465 24.0594 28.5173 26.7086 36.0567 0.515409 39.4095 602.06 2666.02 2.18597 0.0509295 3.48732 Nsam 5753 5646 5586 5225 5225 5225 5225 5225 5559 5560 5582 5530 5530 5582 First Reading 3019.5 3043 3103 3233 3233 3233 3233 3233 3019.5 3019.5 3019.5 3089.5 3089.5 3063.5 Last Reading 5895.5 5865.5 5895.5 5845 5845 5845 5845 5845 5809.5 5810 5810 5854 5854 5854 First Reading For Entire File .......... 3019.5 Last Reading For Entire File ........... 5895.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 5810.0 9993.5 FCNT 5810.5 9994.0 NCNT 5810.5 9994.0 RPM 5845.5 10029.0 RPS 5845.5 10029.0 RPD 5845.5 10029.0 FET 5845.5 10029.0 RPX 5845.5 10029.0 RHOB 5854.5 10038.0 DRHO 5854.5 10038.0 PEF 5854.5 10038.0 GR 5866.0 10048.5 ROP 5896.0 10079.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAGo RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 18-NOV- 00 Insite 65.41 Memory 10078.0 49.3 56.7 TOOL NUMBER PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 8.750 Water Based 10.80 43.0 9.0 23000 3.0 3.000 1.713 76.0 138.2 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ........... · ......... 60 .liN. Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 2.600 4.500 Name Service Order Units Size Nsam Rep Code Offset Channel DE?T FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 76.0 76.0 Name Service Unit DEPT FT GR MWD040 API ROP MWD040 FT/H RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU-S FCNT MWD040 CNTS NCNT MWD040 CNTS RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 BARN Min Max Mean Nsam 5810 10079 7944.5 8539 20.63 330.18 104.469 8366 0.76 350.64 131.042 8367 1.39 114.82 8.46005 8368 1.07 112.95 8.71542 8368 1.31 109.88 8.83899 8368 1.48 122.15 9.25627 8368 0.25 16.95 1.22799 8368 11.38 42.6 30.2825 8368 508 1155 703.881 8368 2345 3989 2802.13 8368 1.93 3.01 2.35232 8368 -0.26 0.5 0.0487022 8368 0.08 9.95 2.44551 8368 First Reading 5810 5866 5896 5845.5 5845.5 5845.5 5845.5 5845.5 5810 5810.5 5810.5 5854.5 5854.5 5854.5 Last Reading 10079 10048.5 10079 10029 10029 10029 10029 10029 9993.5 9994 9994 10038 10038 10038 First Reading For Entire File .......... 5810 Last Reading For Entire File ........... 10079 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... ,, Version Number ........... 1.0 0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 9430.5 RPD 9430.5 RPM 9430.5 RPS 9430.5 RPX 9430.5 GR 9450.5 RAT 9480.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10027.5 10027.5 10027.5 10027.5 , 10027.5 10047.0 1007715 18-NOV-00 Insite 65.41 Memory 10078.0 49.3 56.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PB01711HRLG6 PB01711HRLG6 8.750 Water Based 10.80 43.0 9.0 23000 3.0 3.000 1.713 2.600 4.500 76.0 138.2 76.0 76.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD041 API 4 1 68 4 2 RAT MAD041 FT/H 4 1 68 8 3 RPX MAD041 OHMM 4 1 68 12 4 RPS MAD041 OHMM 4 1 68 16 5 RPM MAD041 OHMM 4 1 68 20 6 RPD MAD041 OHMM 4 1 68 24 7 FET MAD041 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 9430.5 10077.5 9754 1295 First Reading 9430.5 Last Reading 10077.5 GR MAD041 API 36.57 311.34 RAT MAD041 FT/H 0.46 393.63 RPX MAD041 OHMM 1.44 48.59 RPS MAD041 OHMM 1.63 63.4 RPM MAD041 OHMM 1.83 80.67 RPD MAD041 OHMM 2.12 88.19 FET MAD041 HOUR 7.53 16.48 105.832 192.967 7.2851 9.13828 10.4079 11.3014 12.3413 1194 9450.5 10047 1195 9480.5 10077.5 1195 9430.5 10027.5 1195 9430.5 10027.5 1195 9430.5 10027.5 1195 9430.5 10027.5 1195 9430.5 10027.5 First Reading For Entire File .......... 9430.5 Last Reading For Entire File ........... 10077.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/05/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS W~iting Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File