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Home My WebLink About202-139PBU L-103 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-139 50-029-23101-00-00 ADL 0028238 9370 7017 80 3003 9335 8548 20" 9-5/8" 7" 6326 29 - 109 28 - 3031 25 - 9360 2179 29 - 109 28 - 2653 25 - 7009 None8548 1490 5750 7240 5895 - 8782 4-1/2" 12.6# x 3-1/2" 9.2# L-80 23 - 85814393 - 6523 4-1/2" Baker Premier Packer 4-1/2" Baker S3 Packer 5722, 4284 8522, 6304 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY 2/10/2026 Borealis Oil; Schrader Bluff Oil, Orion Dev Area Borealis Oil; Schrader Bluff Oil, Orion Dev Area STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2026.01.23 15:02:58 - 09'00' Torin Roschinger (4662) 326-050 By Grace Chistianson at 8:01 am, Jan 26, 2026 10-404 J.Lau 1/26/26 DSR-1/27/26A.Dewhurst 26JAN26JLC 1/28/2026 01/28/26 Tubing Patch Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Well Name:L-103i Permit to Drill:202-139 Current Status:Not Operable, WAG API Number:50-029-23101-00 Estimated Start Date:January 2026 Estimated Duration:3 days Regulatory Contact:Abbie Barker Revision: 0 First Call Engineer:Tyson Shriver (907) 564-4542 (O) (406) 690-6385 (M) Second Call Engineer:Hunter Gates (907) 777-8326 (O) (215) 498-7274 (M) Current Bottom Hole Pressure:2,839 psi @ 6,600 TVDss 8.27 ppg | FL Shot 11/11/2021 Max Anticipated Surface Pressure:2,179 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:0 psi 11/4/2025 Min ID:1.781 @ 8,548 MD Nipple reducer Max Angle:56 deg @ 4,013 MD Last Tag:8,754 SLM 11/6/2025 Brief Well Summary: L-103 is a dual pool completion injector that has the ability to be mechanically manipulated to inject into either the Kuparuk (below the tubing tail) or Schrader (behind the WFRMs) reservoirs. A patch was set on 5/17/2025 in the blank section of pipe between production packers to isolate a hole that was found at 6,444 MD and return the well back to Kuparuk only injection. The patch passed a pressure test and was put back on injection 8/30/2025. On 10/14/2025 a decrease in WHIP occurred. The well was shut-inon 10/24/2025 after an uptick in water rate was observed in offset Schrader Bluff producer L-201. There was ~37k bbls of PWI injected into the well during this time. All of the water is allocated to the Schrader based on the leak size (see subsequent SL diagnostics) Slickline rigged up and set a plug in the nipple reducer in the tubing tail at 8,548 MD on 11/6/2025. An MIT-T was attempted but were unable to catch pressure. A LLR of 2 bpm @ 400 psi was established. An LDL was subsequently run which found a hole at 6,310 MD near a connection. No fluid flow was observed below this depth. A patch needs to be set to isolate the hole so the well can be returned to injection. Current Status: Not Operable, WAG (on PWI) Shut-in and freeze protected. Nipple reducer and plug set at 8,548 MD. No surface or tubing integrity issues (above production packer at 5,722 MD). Well passed an AOGCC MIT-IA to 2,211 psi on 7/7/2023 and a non-witnessed MIT-IA to 2,375 psi on 11/24/2024. Objective: - Patch hole in 3-1/2 tubing at 6,310 MD. - MIT-T well against nipple reducer and plug to confirm integrity of patches and 3-1/2 pipe between production packers. - Return well to Kuparuk only WAG injection. WBL Steps: 1 E SET STRADDLE PATCH ASSEMBLY. 2 F ASSIST SL - LOAD TUBING. PERFORM MIT-T. 3 S PULL PLUG FROM NIPPLE REDUCER. LOAD WELL AND SET PLUG IN NIPPLE REDUCER. PULL PLUG AFTER PASSING MIT-T. CONTINGENT LDL BASED ON MIT-T RESULTS. Tubing Patch Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Procedural Steps: E-Line 1. Make up and RIH with NSAK 3.5 Mono-Pak single-trip straddle patch. a. DO NOT have FB load well prior to running the patch. With the size of the leak and overbalanced fluid, the patch will get differently stuck at the hole when trying to run past. b. Contact Chris Lavoie or Carl Diller with NSAK. c. SL performed 24 x 2.73 patch drift to 6,434 MD without issue. 2. Set mid-element of lower packer at 6,316 MD. a. Tie-in using Read MemoryLDL, 80 fpm Down Pass, dated 7-Nov-2025 and tubing tally. b. 24-arm caliper pulled 11/24/24 which showed setting area to be in good condition. Fullbore Assist SL 1. Load tubing with diesel. Max pressure is 1,500 psi. a. Tubing volume down to top perf @ 8,722 MD = 119 bbls i. 4-1/2 Vol = 5,779 x 0.0152 bpf = 88 bbls ii. 3-1/2 Vol = 8,581 5,779 x 0.0087 bpf = 25 bbls iii. 7 Vol = 8,722 8,581 x 0.0383 bpf = 6 bbls 2. Perform MIT-T to 3,000 psi (max applied 3,300 psi) after patch is set. 3. Contingent LLR and LDL if MIT-T fails. Slickline 1. Pull plug from nipple reducer at 8,548 MD. 2. Load well with diesel. 3. Set plug in nipple reducer 4. MIT-T to 3,000 psi 5. If MIT-T passes, pull plug from nipple reducer. 6. CONTINGENT: If MIT-T fails, contact OE for discussion about running contingent LDL. Attachments Current Wellbore Schematic Proposed Wellbore Schematic Annotated Tie-in Log 4-1/2 x 3-1/2 Tubing Tally Patch Schematic Sundry Change Form Tubing Patch Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Current Wellbore Schematic: Tubing Patch Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Proposed Wellbore Schematic: Tubing Patch Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Annotated Tie-in Log: Tubing Patch Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Straddle patch set from 6,302 to 6,320 MD (ME depths = 6,305 and 6,316) Tubing Patch Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 4-1/2 x 3-1/2 Tubing Tally: Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Work Over Sundry ProcedureDate: January 23, 2026Subject: Changes to Approved Sundry Procedure for Well L-103Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) first call engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAK PreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 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.gov January 6, 2026 Ms. Vanessa Hughes PBW Asset Team Leader Hilcorp North Slope, LLC 3800 Centerpoint Dr. Suit 1400 Anchorage, AK 99503 Re: Docket Number: OTH-25-009 – Closeout Investigation of Self-reported Discovery of Unallocated Commingled Injection into PBU Orion/Borealis Wells L-103 (PTD# 202-139) and V-105 (PTD# 202-131) Prudhoe Bay Unit Dear Ms. Hughes: After completing its review of Hilcorp North Slope, LLC’s (Hilcorp) investigation into the self- reported incident noted above that was submitted on February 25, 2025, the Alaska Oil and Gas Conservation Commission (AOGCC) has decided that no further action is required on this matter. While not properly allocating injection between the two pools is a violation of conditions of approval contained in Area Injection Order No. 26A.002 and Conservation Orders No. 471.007 and 505A.001, which authorized downhole commingling of injection between the two pools and within the subject wells, Hilcorp did not configure the wells to be in commingled injection for the period when the unallocated injection occurred but rather the commingled injection occurred due to unknown at the time mechanical conditions down hole. When Hilcorp became aware of the unallocated commingling through unexpected flowing conditions of offset production wells, it notified the AOGCC and took actions to investigate the unintended downhole commingling, as well as to take corrective action and revise the injection reports for these wells to properly allocate the injection volumes. Because the unintended downhole commingling of injection couldn’t be predicted or detected until offset producers started showing anomalous production and Hilcorp’s action to correct the issue, there is no need for the AOGCC to take any further action on this matter. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner Cc: Phoebe Brooks (AOGCC) Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2026.01.06 10:30:23 -09'00' Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2026.01.06 11:07:19 -09'00' Hilcorp North Slope, LLC Vanessa Hughes, PBW Asset Team Leader 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 02/25/2025 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Investigation of Self-reported Discovery of Unallocated Commingled Injection into PBU Orion/ Borealis Wells L-103 (PTD# 202-139) and V-105 (PTD# 202-131), Hilcorp North Slope (HNS), LLC. Dear Mr. Wallace, Please see below for investigation information compiled regarding the self-reported discovery of unallocated commingled injection of produced water and enriched hydrocarbon gas into PBU Orion/ Borealis well L-103 (PTD# 202-139), between 03/09/2022-09/21/2024 and V-105 (PTD# 202-131), between 05/18/2024- 02/09/2025. Well History and Event Summary: L-103 is a multi-pool injector completion in the Orion and Borealis pools with AOGCC approval for both commingled water and enriched hydrocarbon gas (MI) injection with specific allocation methodology requirements for each service type. The completion style allows the Orion pool to be isolated from the Borealis with regulation of injection through waterflood mandrels between packers isolating the Orion perforations. From 03/9/2022- 08/17/2022, L-103 was on MI service and has since been on produced water injection into the Borealis pool with dummy waterflood regulator valves (DWFRVs) set in the two mandrels between the packers, isolating the Orion perforations from the wellbore. On 09/20/2024, Orion pool production trends in offset producer L-201 (PTD# 204-064) indicated possible communication with well L-103. L-103 was immediately shut- in and the AOGCC notified the same day. On 09/21/2024, a plug was set at 8569’ MD to isolate the Borealis and test tubing integrity between the packers isolating the Orion pool. This MIT-T failed with a liquid leak rate of 2 BPM at 240 psi. On 11/25/2024, a leak detection log found a hole in the 3.5” tubing at 6443’ MD. The tubing plug was then removed and an injection profile was run on 11/26/2024 to determine injection splits between the Orion and Borealis. Once this data was collected, a nipple reducer and plug were set at 8548’ MD in preparation for a tubing patch to be installed over the leak at 6443’ MD. Review of injection and offset production trends indicate that the hole in the tubing developed in March of 2022. Injection allocation corrections for L-103 have been submitted to the AOGCC on 02/17/2025. Allocation methodology was based on historic offset production changes to gas and water volumes in Borealis and Orion wells and more recently injection splits from the 11/26/2024 injection profile log. L-103 Borealis/ Orion allocation splits: Stemming from the investigation into L-103, all other active, multi-pool completion injection wells are under review. A recent result of this broader investigation led to diagnostic work on V-105 (PTD# 202-131), also resulting in the discovery of unintended commingled injection due to a completion component failure. WAG injection well, V-105 has a dual reservoir completion that can be mechanically manipulated to inject into the Borealis Oil Pool and/or Orion Oil Pool. V-105 was on PWI By Samantha Coldiron at 11:06 am, Feb 25, 2025 until 07/04/2024, after which it was placed on MI, and then returned to PWI on 01/25/2025. Throughout this timeframe V-105 was mechanically arranged to inject into the Borealis Oil Pool only. Due to an increase in water volumes found in offset Orion Pool producers, a tubing tail plug was set on 01/20/2025 and the well passed a MIT-T to 2641 psi indicating competent tubing across the upper injection zone. A subsequent injection profile log was executed on 02/9/2025 in V-105 due to the unresolved increased Orion producer water volumes. Interpretation of the log has shown that the majority of injection is not going into the intended Borealis perforations, but out the 3.5” tubing, up the backside of the tubing tail, through the apparently failed packer at 7555’ MD and into the Orion perforations. The well has been shut-in and freeze protected since this log was executed and work is being planned to set an IBP in the 7” casing to isolate the Borealis from the Orion perforations as soon as possible. Based on initial analysis, injection into the Orion perforations started on 05/18/2024. Additional work is being done to verify the timeframe of the packer failure and resolve the injection allocation. Allocation corrections on V-105 will be submitted to the AOGCC as soon as possible. Both L-103 and V-105 are authorized for produced water and enriched hydrocarbon gas injection into the Borealis pool (AIO 24C, Rule 2) and the Orion pool (AIO 26B, Rule 3). L-103 and V-105 were both approved for commingled injection in AIO 26A.002 based off approved allocation methodology from 08/21/2008. Unfortunately, due to the completion failures in both wells and the subsequent unrecognized commingled injection, volumes were not correctly allocated to the Orion and Borealis pools. We are retroactively allocating corrected injection volumes to both pools from the time of the completion failure dates and submitting updated 10-406’s to the AOGCC. Hilcorp does not believe that these incidents have promoted waste nor jeopardized ultimate recovery of hydrocarbons from the Borealis and Orion pools as all injection fluid and intervals were previously approved. Root cause of the incident: x Inadequate surveillance work process to monitor for anomalous deviations in injection pressures/ rates, resulting in unmonitored commingled injection. Contributing factors of the incident: x Initial failure of the 3.5” tubing sting resulting in commingled injection in L-103, failure of lower injection packer resulting in commingled injection in V-105. x Inadequate awareness of risk for unintended commingled injection in multi-pool completion wells. Actions to prevent recurrence: x Downhole logging verification of injection conformance in all active PBU multi-pool completion wells by 06/30/2025. x Implement immediate review and establish quarterly process by Reservoir Engineer for review of injection trends in active multi-pool completion wells. If you have any questions, please call me at 907-777-8445 or Oliver Sternicki at 907-564-4891. Sincerely, Vanessa Hughes PBW Asset Team Leader Digitally signed by Vanessa Hughes (793) DN: cn=Vanessa Hughes (793) Date: 2025.02.25 10:27:17 - 09'00' Vanessa Hughes (793) Reservoir Engineer finds anomalous offset production in well L-201. Well L-103 shut-in.09/20/2024AOGCC notified of possible unauthorized commingled injection into L-103. Plug set, MIT-T failed.09/21/2024L-103: Plug pulled, injection profile run to determine injection splits between Orion and Borealis Pools. Tubing tail plug reset.11/26/20243/2022Page 1/2Deviation from expected injection rate vs pressure into L-103 not recognized.L-103/ V-105 Misallocated Injection Timeline3-1 Lack of knowledge of hazards presentL-103: Leak detection log finds hole in 3.5” tubing at 6443’ MD.14.1 Lack of PSP for the task – No established review process evaluating injection conformance in multi-pool completion wells.11/25/202405/18/2024Deviation from expected injection rate vs pressure into V-105 not recognized.14.1 Lack of PSP for the task – No established review process evaluating injection conformance in multi-pool completion wells.Unallocated Injection into L-103 in Orion PoolInjection occurs through hole in tubing @ 6443’ MD in section straddling the Orion PoolInjection occurs up through the lower packer at 7555’ MD straddling the Orion PoolTubing failed due to corrosion/erosion of tubing.Packer failed due to corrosion, soft goods or mechanical failureL-103 Swapped from MI to water injectionAug 2022Dec 2023V-105 swapped from MI to water injection.L-103 Swapped from MI to water injectionSep 2021Tubing failure results in change to injection pressure vs rateChange in injection response does not trigger diagnostics/SIMarch 2022Unallocated Injection into V-105 in Orion PoolPacker failure results in change to injection pressure vs rateChange in injection response does not trigger diagnostics/SIImplement immediate review and establish quarterly process for review of injection trends in active multi-pool completion wells.Downhole logging verification of injection conformance in all active PBU multi-pool completion wells by 06/30/20253-1 Lack of knowledge of hazards presentCFCFBy Samantha Coldiron at 11:06 am, Feb 25, 2025 Page 2/2L-103/ V-105 Misallocated Injection TimelineCFOpportunity for ImprovementCritical/Causal FactorOFICorrective Action System CauseImmediate CauseV-105: I-Prof interpretation finalized indicating failure of lower completion packer, indicating unintended injection into the Orion perforations.02/14/2025V-105: Plug set, MIT-T passed to 2641 psi. Plug removed, well placed back on injection.01/20/202502/09/2025Possible anomalous V-105 injection volumes/ pressure noted. Injection profile logged. Well shut-in.Start of multi-pool injector completion review. 01/22/2025 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector L-103 (PTD #2021390) Tubing leak Date:Thursday, November 20, 2025 3:26:43 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 20, 2025 2:57 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector L-103 (PTD #2021390) Tubing leak Mr. Wallace, WAG Injector L-103 (PTD #2021390) additional tubing leak has been identified above the tubing patch. The well is now classified as NOT OPERABLE and will remain shut in until tubing integrity is restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 29, 2025 8:22 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #2021390) possible tubing patch leak Mr. Wallace, A tubing patch was installed on 05/17/25 to repair a leak in the tubing that was resulting in unintentional commingled injection. Recent data from offset producers indicate the patch may be leaking. The well has been shut-in and will now be classified as UNDER EVALUATION for up to 28- days for diagnostic testing. Plan Forward: 1. Slickline: Set TTP & MIT-T 2. Well Integrity: Additional diagnostics as needed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, July 30, 2025 1:30 PM To: Brenden Swensen <Brenden.Swensen@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Rich Burnett <Richard.Burnett@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Injector L-103 (PTD #202139) MIT-T passed after tubing patch All, WAG Injector L-103 (PTD #2021390) had a tubing patch set over the hole @ 6,443’ MD on 05/17/25 in accordance with Sundry #325-220. A subsequent MIT-T passed to 3,019 psi on 06/13/25. The well will now be classified as OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity Sent: Monday, December 9, 2024 10:07 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector L-103 (PTD #202139) tubing leak / misinjection All, Injector L-103 (PTD #202139) LDL run on 11/25 ID tubing leak at 6443’ below the production packer. A tubing patch plan is being drafted. At this time the well is classified as NOT OPERABLE and will remain shut in until the tubing leak is resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, November 15, 2024 11:06 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection All, AOGCC approved another 28-days of Under Evaluation to execute the diagnostic work that has yet to be completed. The Under Evaluation period will be extended another 28-days. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 18, 2024 5:01 PM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection All, The AOGCC approved a diagnostic plan forward for Injector L-103. The Under Evaluation clock will be extended an additional 28-days to execute the work. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, September 20, 2024 5:52 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; 'Alaska IMS User' <akimsuser@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection All, Injector L-103 (PTD #202139) was identified as having a possible tubing leak which may have resulted in unintentional comingled injection. The potential tubing leak was identified by overlaying responses from adjacent development wells. The well was shut in on 09/20, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T 3. Well Integrity: Further diagnostics as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector L-103 (PTD #2021390) possible tubing patch leak Date:Wednesday, October 29, 2025 10:41:10 AM Attachments:L-103.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 29, 2025 8:22 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #2021390) possible tubing patch leak Mr. Wallace, A tubing patch was installed on 05/17/25 to repair a leak in the tubing that was resulting in unintentional commingled injection. Recent data from offset producers indicate the patch may be leaking. The well has been shut-in and will now be classified as UNDER EVALUATION for up to 28- days for diagnostic testing. Plan Forward: 1. Slickline: Set TTP & MIT-T 2. Well Integrity: Additional diagnostics as needed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, July 30, 2025 1:30 PM To: Brenden Swensen <Brenden.Swensen@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Rich Burnett <Richard.Burnett@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Injector L-103 (PTD #202139) MIT-T passed after tubing patch All, WAG Injector L-103 (PTD #2021390) had a tubing patch set over the hole @ 6,443’ MD on 05/17/25 in accordance with Sundry #325-220. A subsequent MIT-T passed to 3,019 psi on 06/13/25. The well will now be classified as OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity Sent: Monday, December 9, 2024 10:07 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector L-103 (PTD #202139) tubing leak / misinjection All, Injector L-103 (PTD #202139) LDL run on 11/25 ID tubing leak at 6443’ below the production packer. A tubing patch plan is being drafted. At this time the well is classified as NOT OPERABLE and will remain shut in until the tubing leak is resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, November 15, 2024 11:06 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection All, AOGCC approved another 28-days of Under Evaluation to execute the diagnostic work that has yet to be completed. The Under Evaluation period will be extended another 28-days. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 18, 2024 5:01 PM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection All, The AOGCC approved a diagnostic plan forward for Injector L-103. The Under Evaluation clock will be extended an additional 28-days to execute the work. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, September 20, 2024 5:52 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; 'Alaska IMS User' <akimsuser@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection All, Injector L-103 (PTD #202139) was identified as having a possible tubing leak which may have resulted in unintentional comingled injection. The potential tubing leak was identified by overlaying responses from adjacent development wells. The well was shut in on 09/20, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T 3. Well Integrity: Further diagnostics as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. TREE= 4-1/16" CNV VA3.LFEAD= FMC ACTUATOR= NA KB. E LEV = 78A' BF. ELEV = 53A' KOP= 500' Max Angle = 56" CM 4013' Datum lrD= 8968' Datum TVD= 6600'SS 9-5/8" CSG, 400, L-80, D = 8.835" H 3031' Minimum ID =1.81" @ 6434' 1-TRIP PATCH 3-1/2' TBG, 9.2#, L-80, .0087 bpf, D = 2.992" — RM AOGCC APPROVAL WITH OE & I TO ANY COMMINGLED INJECTION ENCING. COMMINGLING INJECTION COMPLY WITH AIO 26B AND CO 505 3-1 /2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 857W PERFORATION SUMMARY REF LOG: TCP PEW ANGLEATTOPPERF: 52" c@5896 Note: Refer to Production DB for historical pert data SIZE SPF MHZVAL Opn/Sgz DATE 4-5/8" 5 5895 - 5962 O 08/09/02 4-518" 5 6018 - 6070 O 08/09/02 4-5/8" 5 6097 - 6119 O 08/09/02 4-518" 5 6194 - 6210 O 08/09/02 4-518" 5 6285 - 6372 O 08/09/02 4-5/8" 5 6398 - 6415 O 08/09/02 2-1/2' 6 8722 - 8782 O 10/20/02 7" CSG, 26#, L-80, .0383 bpf, D = 6.276" 9360' SAFETY NOTES: H2S READINGS AVERAGE 125 ppm W;ENONMi.WELLREQUIRESASSSVWHENON L-103 1019' 9-5/8" TAM PORT COLLAR GAS LIFT MANDRELS ST ND (D DLV TYPE I VLV LATCH PORT I DATE 5 4513 3503 51 DMY BK 11 4 5310 4008 50 =2 KBG-2 DMY BK 0 �11110/02 10/13/02 3 5645 4232 47 KBG-2 DMY BK 0 11/10/02 —99a1I:N 12 II 1,011 AJZLVA"I ZIU, r�a.� STI ND I ND DEV I TYPE I VLV LATCH PORT DATE 2 1 5822 5882 4348 4385 1 52 52 MMG-W MMG-W DMY DMY RK I RK 0 0 09/26/11 09/26/11 571� 4 VZHESXNP,ID=3.813" SCHRADER -ORION AUTHORIZED FOR WAG INJECTION INS 1-TRP PATCH, ID= 1.81" (05/17125) 8521' --�3-1/2"X4-12"XO,ID=2.930" 8626' —14-1/2- X 3-12" XO, ID = 2.992" 854� 3-1/2- HES X NIP. ID = 2.813" 856W 1-13-12- HES X NIP, D = 2.813" 8581' 3-Vz" WLEG KUPARUK-BOREALIS AUTHORIZED FOR WAG INJECTION — 8933' 7" MARKERJT W/ RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 08/09/02 DM/KAK ORIGINAL COMPLETION 12/1124 SV" SLT NP RED7 & RX PLUG - RJLL I 0728/10 GTWAGR WFR CIO (07/18/10) 05/1925 RB/JM) SET NS 1 TIP PATCH 02/15/11 M3/JMD ADDED SSSV SAFETY NOTE 07/0925 RB/JMD RJLLEDRX RUG (06/1325) 10/11/11 vAv P GLV CIO (0926/11) 01/17/12 TMN(JMD ADDED FPS SAFETY NOTE 0923/24 AB/JMD SET PX PLtJG BOREALIS UNIT WELL: L-103 PEFUT N7:'2021390 AR No: 50-029-23101-00 SI2C 34, T12N, R11 E, 2590' NSL & 3618' V41i lilcorp North Slope, LLC Wi L-m no clm +Tubing —On ■ el..e + OW.bi. + Nal Oger ♦ VMx Evl y—Man. IA —� Man. Oa M.n.00A Man. "A �— Men. VAT 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector L-103 (PTD #202139) MIT-T passed after tubing patch Date:Wednesday, July 30, 2025 3:25:27 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, July 30, 2025 1:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Injector L-103 (PTD #202139) MIT-T passed after tubing patch Mr. Wallace, WAG Injector L-103 (PTD #2021390) had a tubing patch set over the hole @ 6,443’ MD on 05/17/25 in accordance with Sundry #325-220. A subsequent MIT-T passed to 3,019 psi on 06/13/25. The well will now be classified as OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity Sent: Monday, December 9, 2024 10:07 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector L-103 (PTD #202139) tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) LDL run on 11/25 ID tubing leak at 6443’ below the production packer. A tubing patch plan is being drafted. At this time the well is classified as NOT OPERABLE and will remain shut in until the tubing leak is resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, November 12, 2024 8:00 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) current 28 day under evaluation period for diagnostics ends on 11/15. The well remains shut in and we have not yet executed our diagnostic intervention work in part due to inclement weather this month. With permission, we would like to reset the under evaluation period for an additional 28 days starting 11/15. Please call with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 18, 2024 2:45 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Today is the last day of the 28-day Under Evaluation clock. The Under Evaluation clock will be extended an additional 28-days to execute the planned action that was approved in the attached email. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, September 20, 2024 5:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) was identified as having a possible tubing leak which may have resulted in unintentional comingled injection. The potential tubing leak was identified by overlaying responses from adjacent development wells. The well was shut in on 09/20, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T 3. Well Integrity: Further diagnostics as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No 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. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-103 Tubing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-139 50-029-23101-00-00 9370 Conductor Surface Intermediate Production Liner 7017 80 3003 9335 8548 20" 9-5/8" 7" 6326 29 - 109 28 - 3031 25 - 9360 29 - 109 28 - 2653 25 - 7009 None 470 3090 5410 8548 1490 5750 7240 5895 - 8782 4-1/2" 12.6# x 3-1/2" 9.2# L-80 23 - 8581 4393 - 6523 Structural 4-1/2" Baker Premier Packer 8522, 6304 5722, 8522 4284, Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, Borealis Oil; Schrader Bluff Oil, Orion Dev Area Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028238 23 - 6353 N/A N/A Well Not Online Well Not Online 300 300 1300 1600 325-220 13b. Pools active after work:Borealis Oil; Schrader Bluff Oil, Orion Dev Area 4-1/2" Baker S3 Packer 5722, 4284 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 12:42 pm, Jun 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.18 12:08:35 - 08'00' Torin Roschinger (4662) RBDMS JSB 062725 JJL 6/30/25 DSR-6/23/25 ACTIVITY DATE SUMMARY 5/13/2025 ***WELL S/I ON ARRIVAL*** DRIFTED W/ 20' x 2.74" DMY WHIPSTOCK TO 6,425' SLM DRIFTED W/ 2.71-2.72" WRP DRIFT (WRP-31) & 20' x 2.70' DMY WHIPSTOCK (oal 27.16') TO 6,438' SLM SWAGED RESTRICTION ~6,440' SLM W/ 2.75" SWAGE UNTIL ABLE TO PASS FREELY SWAGED RESTRICTION ~6,440' SLM W/ 2.77" SWAGE UNTIL ABLE TO PASS FREELY DRIFTED FREELY W/ 2.71-2.72" WRP DRIFT (WRP-31) & 20' x 2.70' DMY WHIPSTOCK (oal 27.16') TO 6,600' SLM ***DRIFTED SMOOTHLY @ 40-50fpm*** ***PAD-OP NOTIFIED ON WELL STATUS, WELL S/I ON DEPARTURE*** 5/15/2025 T/I/O = 1103/320/350. Temp = SI°. T FL (e-line). T FL @ 6570'. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 5/17/2025 ***WELL SI ON ARRIVAL*** (PATCH SET) MIRU AK ELINE PT: 300/2500, FUNCTION WLVS LOG CORRELATED TO HAL LDL DATED 14- SET NS 350-272 1-TRIP STRADDLE PATCH 6437'-6448' ME-ME CCL STOP: 6422.6' CCL-TOP ME=14.4', CCL STOP=6422.6'. TAG AFTER SET TOP OF PATCH AT 6434' BOTTOM OF PATCH AT 6452' MIN ID=1.81" RDMO AKEL ***WELL SI ON DEPARTURE*** JOB COMPLETE 6/11/2025 T/I/O =1700/300/350. Temp = SI. T FL (SL request). T FL @ 6500' (48' below bottom of NS-1 patch, 94 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:30. 6/13/2025 ***WELL S/I ON ARRIVAL*** RAN 1-3/4" SAMPLE BAILER TO 1.781" RX-PLUG AT 8,548' MD (sandy schmoo) 2 x RAN 10' x 1-1/2" PUMP BAILER TO PLUG AT 8,548' MD (~1/2 gal sandy schmoo - metal marks) EQUALIZED & PULLED 1.781" RX-PLUG AT 8,548' MD LRS LOADED TBG W/ 140 BBLS DIESEL SET 1.781" RX-PLUG IN NIPPLE REDUCER AT 8,548' MD LRS PERFORMED PASSING MIT-T TO 3019 psi PULLED 1.781" RX-PLUG AT 8,548' MD ***WELL LEFT S/I ON DEPARTURE*** 6/13/2025 T/I/O= 1682/330?350, LRS Unit 76, LOAD AND TEST(PATCH TUBING/LINER) Pumped 140 bbls DSL down TBG to load, Pumped 4 bbls down TBG to pressure up to 3300 Psi, 15 min TBG lost 231 Psi, 30 min TBG lost 57 Psi, Bled TBG to Bleed tank, Equipment secured, Well left in Slicklines control, DSO notified upon departure, FWHP=673/323/350 Daily Report of Well Operations PBU L-103 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L-103 Tubing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-139 50-029-23101-00-00 ADL 0028238 9370 Conductor Surface Intermediate Production Liner 7017 80 3003 9335 8548 20" 9-5/8" 7" 6326 29 - 109 28 - 3031 25 - 9360 2179 29 - 109 28 - 2653 25 - 7009 None 470 3090 5410 8548 1490 5750 7240 5895 - 8782 4-1/2" 12.6# x 3-1/2" 9.2# L-80 23 - 85814393 - 6523 Structural 4-1/2" Baker Premier Packer 4-1/2" Baker S3 Packer 5722, 4284 8522, 6304 Date: Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY 4/25/2025 Current Pools: Borealis Oil; Schrader Bluff Oil, Orion Dev Area Proposed Pools: Borealis Oil; Schrader Bluff Oil, Orion Dev Area Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-220 By Gavin Gluyas at 11:36 am, Apr 11, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.11 11:22:14 - 08'00' Torin Roschinger (4662) 10-404 DSR-4/11/25SFD 4/16/2025JJL 4/15/25 , ADL0028238 SFD *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.16 11:55:43 -08'00'04/16/25 RBDMS JSB 041725 Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Well Name:L-103i Permit to Drill:202-139 Current Status:Not Operable, WAG API Number:50-029-23101-00 Estimated Start Date:February 2025 Estimated Duration:3days Regulatory Contact:Abbie Barker Revision:0 First Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Second Call Engineer:Hunter Gates (215) 498-7274 (M) Current Bottom Hole Pressure:2,839 psi @ 6,600’ TVDss 8.27 ppg | FL Shot 11/11/2021 Max Anticipated Surface Pressure:2,179 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:0 psi 11/24/2024 Min ID:2.813” @ 8,510’ MD X-nipple Max Angle:56 deg @ 4,013’ MD Last Tag:8,804’ MD 9/16/2019 Brief Well Summary: L-103 is a dual pool completion injector that has the ability to be mechanically manipulated to inject into either the Kuparuk (below the tubing tail) or Schrader (behind the WFRMs) reservoirs. Throughout the 2000’s, injection was swapped back and forth between the two reservoirs but since 2011 the well has exclusively WAG injected into the Kuparuk. In July 2024, an erroneously high-water rate was detected in offset Schrader producer well, L-201. Various offset injectors were manipulated to understand the source of elevated water production, but no culprit was found. Diagnostic work on L-103 in September revealed a downhole mechanical conformance issue. A plug was set in the tubing tail and a pressure test attempted. The pressure test failed with a LLR of 2 bpm @ ~240 psi meaning a majority of injection was going into the Schrader reservoir through either a hole in the tubing between the production packers or a dummy valve(s) let loose in the WFRMs. Slickline performed a memory leak detect log on 11/25/2024 which revealed a hole at ~6,444’ MD. A tubing patch needs to be set over the leak to restore mechanical conformance and isolate the Schrader Bluff reservoir. A nipple reducer with plug has been set at 8,548’ MD. Due to hole in the 3-1/2” tubing, the nipple reducer and plug could not be pressure tested. Current Status: Not Operable, WAG (on PWI) Shut-in and freeze protected. Nipple reducer and plug set at 8,548’ MD. No surface or tubing integrity issues (above production packer at 5,722’ MD). Well passed an AOGCC MIT-IA to 2,211 psi on 7/7/2023 and a non-witnessed MIT-IA to 2,375 psi on 11/24/2024. Objective: - Patch hole in 3-1/2’ tubing at ~6,444’ MD. - MIT-T well against nipple reducer and plug to confirm integrity of patch and 3-1/2” pipe between production packers to confirm the Schrader Bluff is isolated. - Return well to Kuparuk only WAG injection. WBL Steps: 1 E SET STRADDLE PATCH ASSEMBLY. CONTINGENT LDL IF MIT-T FAILS. 2 F ASSIST EL - LOAD TUBING AND SET STRADDLE PATCH. PERFORM MIT-T. 3 S PULL PLUG FROM NIPPLE REDUCER AFTER PASSING MIT-T. dual pool completion injector Return well to Kuparuk only WAG injection Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Procedural Steps: E-Line 1. Have fullbore load well with diesel. 2. Make up and RIH with NSAK 3.5” Mono-Pak straddle patch. a. Contact Chris Lavoie or Carl Diller with NSAK. b.NOTE:Patch length subject to change based on SL drifts. Contact OE for final length of patch. 3. Set mid-element of lower packer at 6,450’ MD. a. Tie-in using Halliburton Memory LDL, Up/Down Overlay pass, dated 25-Nov-2024 and tubing tally. b. Leak depth is determined based on the DOWN pass. The Up pass is not accurate as the tools were sucked into the leak while passing by. This caused the tools to stop moving momentarily as the cable was stretched to pull free from the leak. c. 24-arm caliper pulled 11/24/24 which showed setting area to be in good condition. Fullbore 1. Load tubing with diesel. Max pressure is 1,500 psi. a. Tubing volume down to leak @ 6,444’ MD = 94 bbls i. 4-1/2” Vol = 5,779’ x 0.0152 bpf = 88 bbls ii. 3-1/2” Vol = 6,444’ – 5,779’ x 0.0087 bpf = 6 bbls 2. Perform MIT-T to 3,000 psi (max applied 3,300 psi) after patch is set. 3. Contingent LLR and LDL if MIT-T fails. Slickline 1. If MIT-T passes, pull plug from nipple reducer at 8,548’ MD. 2. CONTINGENT: If MIT-T fails, and LDL shows patch is leaking, pull patch for redress. Attachments x Current Wellbore Schematic x Proposed Wellbore Schematic x Annotated Tie-in Log x 4-1/2” x 3-1/2” Tubing Tally x Sundry Change Form Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Current Wellbore Schematic: Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Proposed Wellbore Schematic: Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Annotated Tie-in Log: Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 Injection Conformance Repair Well: L-103 PTD: 202-139 API: 50-029-23101-00 4-1/2” x3-1/2” Tubing Tally: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: April 11, 2025Subject: Changes to Approved Sundry Procedure for Well L-103Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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:Tyson Shriver To:Roby, David S (OGC) Cc:Lau, Jack J (OGC); Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Wallace, Chris D (OGC) Subject:RE: [EXTERNAL] RE: PBU L-103 (PTD 202-139) Sundry application Date:Wednesday, April 16, 2025 8:58:07 AM Attachments:image001.png Mr. Roby, Better verbiage under the Brief Well Summary would be: “Throughout the 2000’s, injection was swapped back and forth between the two reservoirs as well as commingled, but since 2011 the well has been configured downhole to exclusively WAG inject into the Kuparuk. Through offset well production it was discovered that unintended commingled injection, both PWI and MI, took place in L-103 between March 2022 and September 2024. Hilcorp reported this issue immediately to AOGCC upon finding and subsequently submitted an investigation report.” As you stated, the most recent commingled injection is being addressed separately. If there is anything you need to help progress the immediate plan of restoring injection conformance in L-103, please let me know. Thank you, Tyson Shriver Hilcorp Alaska PBU GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Tuesday, April 15, 2025 4:01 PM To: Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: [EXTERNAL] RE: PBU L-103 (PTD 202-139) Sundry application Never mind, I see this issue is already being addressed. Sorry. Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 From: Roby, David S (OGC) Sent: Tuesday, April 15, 2025 3:58 PM To: tyson.shriver@hilcorp.com Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: PBU L-103 (PTD 202-139) Sundry application Forgot the attachment Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 From: Roby, David S (OGC) Sent: Tuesday, April 15, 2025 3:37 PM To: tyson.shriver@hilcorp.com Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: PBU L-103 (PTD 202-139) Sundry application Hi Tyson, In reviewing the subject sundry application, I noticed some issues with the well and your present request. Most notably, in your sundry application it states: According to AOGCC records the well has been a commingled injector on numerous occasions beginning in March 2005, including after 2011 when you state it began exclusively injecting into the Kuparuk. The periods of commingled injection are: March 2005 through February 2007 - Water August and September 2007 - Water February 2009 through May 2009 – Water July 2009 through November 2009 – Water January 2010 through June 2010 – Water March 2022 to August 2022 – Gas August 2022 through September 2024 – Water AIO 26C and CO 505B allow commingled injection between the Orion/Schrader Bluff and other oil pools so long as mechanical isolation between the pools is demonstrated and the AOGCC approves an allocation methodology. There’s no evidence in our files that the AOGCC ever approved commingled injection for this well. An undated (it was submitted sometime after Hilcorp bought BPXA and renamed it Hilcorp NS to become operator of the PBU) wellbore schematic (third page of attached document) indicates that it was understood that commingled injection was not allowed without AOGCC approval. Please explain the discrepancy between what the sundry states, that the well swapped back and forth between the pools until 2011 when it became an exclusive Kuparuk injector, and what the injection data submitted by BPXA/HNS shows that the well has a long history of commingled injection. Regards, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 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. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector L-103 (PTD #202139) tubing leak / misinjection Date:Monday, December 9, 2024 10:09:48 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, December 9, 2024 10:07 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector L-103 (PTD #202139) tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) LDL run on 11/25 ID tubing leak at 6443’ below the production packer. A tubing patch plan is being drafted. At this time the well is classified as NOT OPERABLE and will remain shut in until the tubing leak is resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, November 12, 2024 8:00 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) current 28 day under evaluation period for diagnostics ends on 11/15. The well remains shut in and we have not yet executed our diagnostic intervention work in part due to inclement weather this month. With permission, we would like to reset the under evaluation period for an additional 28 days starting 11/15. Please call with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 18, 2024 2:45 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Today is the last day of the 28-day Under Evaluation clock. The Under Evaluation clock will be extended an additional 28-days to execute the planned action that was approved in the attached email. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, September 20, 2024 5:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) was identified as having a possible tubing leak which may have resulted in unintentional comingled injection. The potential tubing leak was identified by overlaying responses from adjacent development wells. The well was shut in on 09/20, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T 3. Well Integrity: Further diagnostics as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Date:Tuesday, November 12, 2024 8:05:49 AM From: Wallace, Chris D (OGC) Sent: Tuesday, November 12, 2024 8:05 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Ryan, Additional 28 days monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, November 12, 2024 8:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) current 28 day under evaluation period for diagnostics ends on 11/15. The well remains shut in and we have not yet executed our diagnostic intervention work in part due to inclement weather this month. With permission, we would like to reset the under evaluation period for an additional 28 days starting 11/15. Please call with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 18, 2024 2:45 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Today is the last day of the 28-day Under Evaluation clock. The Under Evaluation clock will be extended an additional 28-days to execute the planned action that was approved in the attached email. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, September 20, 2024 5:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) was identified as having a possible tubing leak which may have resulted in unintentional comingled injection. The potential tubing leak was identified by overlaying responses from adjacent development wells. The well was shut in on 09/20, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T 3. Well Integrity: Further diagnostics as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Date:Monday, October 21, 2024 2:25:08 PM Attachments:FW EXTERNAL RE L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics .msg From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 18, 2024 2:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Today is the last day of the 28-day Under Evaluation clock. The Under Evaluation clock will be extended an additional 28-days to execute the planned action that was approved in the attached email. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, September 20, 2024 5:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) was identified as having a possible tubing leak which may have resulted in unintentional comingled injection. The potential tubing leak was identified by overlaying responses from adjacent development wells. The well was shut in on 09/20, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T 3. Well Integrity: Further diagnostics as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. 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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20241015 1653 L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Date:Thursday, October 17, 2024 2:58:28 PM From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, October 15, 2024 4:53 PM To: Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Tyson, We agree with the proposed plan forward. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Wednesday, October 9, 2024 2:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace, As discussed, see my previous email regarding PBU L-103 and Hilcorp’s proposed plan forward for identifying and remediating injection conformance. Please let me know if AOGCC agrees with this plan. Thank you, Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Monday, September 30, 2024 12:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace et al. L-103 was shut-in, and a plug set in the X-nipple at 8,569’ MD below the deep-set production packer on 9/21/2024. A subsequent pressure test of the wellbore to confirm pipe integrity between the two production packers failed with a liquid leak rate of 2 bpm @ ~240 psi. No TxIA communication was observed during the pressure testing efforts. Below is an outlined planned forward for identifying a leak location, logging for injection splits, and restoring injection conformance: 1. Run leak detect log between production packers to identify location of fluid offtake in the Schrader reservoir 2. Caliper the 3-1/2” x 4-1/2” tubing 3. Execute MIT-IA (AOGCC MIT-IA PASSED 7/7/2023) 4. Pull plug and perform IPROF to determine injection splits in current mechanical condition between the Kuparuk and Schrader reservoirs to help with corrective injection reporting / allocation 5. Re-set plug in nipple below deep production packer 6. Perform mechanical fix to restore conformance. Likely a dummy waterflood regulator changeout or patch (10-403 would be submitted for a patch set) 7. MIT-T to verify the Schrader interval is mechanically isolated 8. Pull plug and return to Kuparuk only injection Please let me know if AOGCC agrees with this plan forward. Further well analysis is still being conducted to pinpoint when communication to the Schrader reservoir began in L-103. Thank you, Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, September 20, 2024 5:21 PM To: chris.wallace@alaska.gov Cc: Tyson Shriver <Tyson.Shriver@hilcorp.com>; Vanessa Hughes <vhughes@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace, WAG injection well, L-103 (PTD# 202-139) has a dual reservoir completion that can be mechanically manipulated to inject into the Borealis Oil Pool and/or Orion Oil Pool. Currently, L-103 is lined up to PWI and is mechanically arranged to inject into the Borealis Oil Pool only (see attached schematic). It was discovered today through analysis of Orion Oil Pool production trends in offset well L-201 (PTD #204-046) that there is possible reservoir communication with well L-103. Based on preliminary data trending & analysis, communication between the two wells could have started as early as 9/7/2023 or more recently on 5/13/2024. Additional work is being done to understand the timeframe possible communication began. The most likely scenario for Orion Oil Pool communication between wells L-103 and L-201 is due to a hole in the tubing and/or compromised waterflood mandrels between the two production packers at 5,722’ MD and 8,522’ MD. As an immediate action to prevent any additional potential commingled injection, L-103 will be shut-in, and freeze protected. Slickline will install and test a tubing tail plug below the production packer at 8,522’ MD to eliminate potential cross between the Borealis and Orion Oil Pools while shut in. A lower likelihood scenario exists where the production packer at 8,522’ MD has failed and is the cause for injection fluids to be entering the Orion Oil Pool. Once the tubing tail plug is set and tested, a plan forward to diagnose the potential leak will be proposed to the AOGCC. Please respond with any questions or concerns. 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Oliver Sternicki To:PB Wells Integrity Subject:FW: [EXTERNAL] RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Date:Wednesday, October 16, 2024 4:03:16 PM From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, October 15, 2024 4:53 PM To: Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Tyson, We agree with the proposed plan forward. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Wednesday, October 9, 2024 2:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace, As discussed, see my previous email regarding PBU L-103 and Hilcorp’s proposed plan forward for identifying and remediating injection conformance. Please let me know if AOGCC agrees with this plan. Thank you, Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Monday, September 30, 2024 12:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace et al. L-103 was shut-in, and a plug set in the X-nipple at 8,569’ MD below the deep-set production packer on 9/21/2024. A subsequent pressure test of the wellbore to confirm pipe integrity between the two production packers failed with a liquid leak rate of 2 bpm @ ~240 psi. No TxIA communication was observed during the pressure testing efforts. Below is an outlined planned forward for identifying a leak location, logging for injection splits, and restoring injection conformance: 1. Run leak detect log between production packers to identify location of fluid offtake in the Schrader reservoir 2. Caliper the 3-1/2” x 4-1/2” tubing 3. Execute MIT-IA (AOGCC MIT-IA PASSED 7/7/2023) 4. Pull plug and perform IPROF to determine injection splits in current mechanical condition between the Kuparuk and Schrader reservoirs to help with corrective injection reporting / allocation 5. Re-set plug in nipple below deep production packer 6. Perform mechanical fix to restore conformance. Likely a dummy waterflood regulator changeout or patch (10-403 would be submitted for a patch set) 7. MIT-T to verify the Schrader interval is mechanically isolated 8. Pull plug and return to Kuparuk only injection Please let me know if AOGCC agrees with this plan forward. Further well analysis is still being conducted to pinpoint when communication to the Schrader reservoir began in L-103. Thank you, Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, September 20, 2024 5:21 PM To: chris.wallace@alaska.gov Cc: Tyson Shriver <Tyson.Shriver@hilcorp.com>; Vanessa Hughes <vhughes@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace, WAG injection well, L-103 (PTD# 202-139) has a dual reservoir completion that can be mechanically manipulated to inject into the Borealis Oil Pool and/or Orion Oil Pool. Currently, L-103 is lined up to PWI and is mechanically arranged to inject into the Borealis Oil Pool only (see attached schematic). It was discovered today through analysis of Orion Oil Pool production trends in offset well L-201 (PTD #204-046) that there is possible reservoir communication with well L-103. Based on preliminary data trending & analysis, communication between the two wells could have started as early as 9/7/2023 or more recently on 5/13/2024. Additional work is being done to understand the timeframe possible communication began. The most likely scenario for Orion Oil Pool communication between wells L-103 and L-201 is due to a hole in the tubing and/or compromised waterflood mandrels between the two production packers at 5,722’ MD and 8,522’ MD. As an immediate action to prevent any additional potential commingled injection, L-103 will be shut-in, and freeze protected. Slickline will install and test a tubing tail plug below the production packer at 8,522’ MD to eliminate potential cross between the Borealis and Orion Oil Pools while shut in. A lower likelihood scenario exists where the production packer at 8,522’ MD has failed and is the cause for injection fluids to be entering the Orion Oil Pool. Once the tubing tail plug is set and tested, a plan forward to diagnose the potential leak will be proposed to the AOGCC. Please respond with any questions or concerns. 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Date:Monday, September 30, 2024 12:27:15 PM Attachments:L-103.pdf From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Monday, September 30, 2024 12:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace et al. L-103 was shut-in, and a plug set in the X-nipple at 8,569’ MD below the deep-set production packer on 9/21/2024. A subsequent pressure test of the wellbore to confirm pipe integrity between the two production packers failed with a liquid leak rate of 2 bpm @ ~240 psi. No TxIA communication was observed during the pressure testing efforts. Below is an outlined planned forward for identifying a leak location, logging for injection splits, and restoring injection conformance: 1. Run leak detect log between production packers to identify location of fluid offtake in the Schrader reservoir 2. Caliper the 3-1/2” x 4-1/2” tubing 3. Execute MIT-IA (AOGCC MIT-IA PASSED 7/7/2023) 4. Pull plug and perform IPROF to determine injection splits in current mechanical condition between the Kuparuk and Schrader reservoirs to help with corrective injection reporting / allocation 5. Re-set plug in nipple below deep production packer 6. Perform mechanical fix to restore conformance. Likely a dummy waterflood regulator changeout or patch (10-403 would be submitted for a patch set) 7. MIT-T to verify the Schrader interval is mechanically isolated 8. Pull plug and return to Kuparuk only injection Please let me know if AOGCC agrees with this plan forward. Further well analysis is still being conducted to pinpoint when communication to the Schrader reservoir began in L-103. Thank you, Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, September 20, 2024 5:21 PM To: chris.wallace@alaska.gov Cc: Tyson Shriver <Tyson.Shriver@hilcorp.com>; Vanessa Hughes <vhughes@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace, WAG injection well, L-103 (PTD# 202-139) has a dual reservoir completion that can be mechanically manipulated to inject into the Borealis Oil Pool and/or Orion Oil Pool. Currently, L-103 is lined up to PWI and is mechanically arranged to inject into the Borealis Oil Pool only (see attached schematic). It was discovered today through analysis of Orion Oil Pool production trends in offset well L-201 (PTD #204-046) that there is possible reservoir communication with well L-103. Based on preliminary data trending & analysis, communication between the two wells could have started as early as 9/7/2023 or more recently on 5/13/2024. Additional work is being done to understand the timeframe possible communication began. The most likely scenario for Orion Oil Pool communication between wells L-103 and L-201 is due to a hole in the tubing and/or compromised waterflood mandrels between the two production packers at 5,722’ MD and 8,522’ MD. As an immediate action to prevent any additional potential commingled injection, L-103 will be shut-in, and freeze protected. Slickline will install and test a tubing tail plug below the production packer at 8,522’ MD to eliminate potential cross between the Borealis and Orion Oil Pools while shut in. A lower likelihood scenario exists where the production packer at 8,522’ MD has failed and is the cause for injection fluids to be entering the Orion Oil Pool. Once the tubing tail plug is set and tested, a plan forward to diagnose the potential leak will be proposed to the AOGCC. Please respond with any questions or concerns. 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Date:Monday, September 23, 2024 8:06:44 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, September 20, 2024 5:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector L-103 (PTD #202139) Possible tubing leak / misinjection Mr. Wallace, Injector L-103 (PTD #202139) was identified as having a possible tubing leak which may have resulted in unintentional comingled injection. The potential tubing leak was identified by overlaying responses from adjacent development wells. The well was shut in on 09/20, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T 3. Well Integrity: Further diagnostics as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Date:Monday, September 23, 2024 8:07:54 AM Attachments:L-103.pdf From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, September 20, 2024 5:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Tyson Shriver <Tyson.Shriver@hilcorp.com>; Vanessa Hughes <vhughes@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: L-103 (PTD# 202-139) Orion Oil Pool injection diagnostics Mr. Wallace, WAG injection well, L-103 (PTD# 202-139) has a dual reservoir completion that can be mechanically manipulated to inject into the Borealis Oil Pool and/or Orion Oil Pool. Currently, L-103 is lined up to PWI and is mechanically arranged to inject into the Borealis Oil Pool only (see attached schematic). It was discovered today through analysis of Orion Oil Pool production trends in offset well L-201 (PTD #204-046) that there is possible reservoir communication with well L-103. Based on preliminary data trending & analysis, communication between the two wells could have started as early as 9/7/2023 or more recently on 5/13/2024. Additional work is being done to understand the timeframe possible communication began. The most likely scenario for Orion Oil Pool communication between wells L-103 and L-201 is due to a hole in the tubing and/or compromised waterflood mandrels between the two production packers at 5,722’ MD and 8,522’ MD. As an immediate action to prevent any additional potential commingled injection, L-103 will be shut-in, and freeze protected. Slickline will install and test a tubing tail plug below the production packer at 8,522’ MD to eliminate potential cross between the Borealis and Orion Oil Pools while shut in. A lower likelihood scenario exists where the production packer at 8,522’ MD has failed and is the cause for injection fluids to be entering the Orion Oil Pool. Once the tubing tail plug is set and tested, a plan forward to diagnose the potential leak will be proposed to the AOGCC. Please respond with any questions or concerns. 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. TREE= 4-1/16" CIW WELLHEAD= FMC ACTUATOR= NA KB. ELEV = 78A' BE ELEV = 53A' KOP= 500' Max Angle = 56" @ 4013' Datum NO= 8968' Datum TVD= 6600'SS 9-5/8" CSG, 40#, L-80, ID=8.835" 3031' Minimum ID = 2.813" @ 8510' 3-1121' HES X NIPPLE 4-12" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 5779' 3-1/2" TBG, 92#, L-80, .0087 bpf, D = 2.992" :ONFIRM AOGCC APPROVAL WITH OE 8t I IRIOR TO ANY COMMINGLED INJECTION SAFETY NOTES: H2S RISADINGS AVERAGE 125 ppm WHEN Mi. WELL REQUIRES SSSV WHEN ON L -10 3 2216' I-14-1/2" FES X NP, ID = 3.813- GAS LIFT MANDR3-S ST M) TVD DEV TYPE VLV LATCH PORT DATE 5 4513 3503 51 KBG-2 DAM BK 0 11/10/02 4 5310 4008 50 KBG-2 DMY BK 0 10/13/02 3 5645 4232 47 KBG-2 DMA' BK 0 11/10/02 WATER INII3;TION MANDRELS ST MD I TVD I WV I TYPE I VLV LATCH PORT DATE 2 1 5822 5882 I 4348 4385 1 52 52 MMG-W NI DMY DMA' RK RK 0 0 09rW1I 0926111 5722' 1 17" X 4-1/2" BKR PREMER PKR D = 3.875- 5779' —j4-12" X 3-12" XO, ID=2.992" SCHRADER-ORION AUTHORIZED FOR WAG INJECTION 8510' 3-1/2"FESX NP, ID=2.813" :OMMENCING. COMMINGLING INJECTION1 8521 1131/rx41rz"xo,10=z.s3o LUST COMPLY WITH AJO 26B AND CO 505EL 8522• 7"X4-12" BKRS3 WR D=3.875" 85264-12- x 3-12- XO, ID = 2.992- 8548• 1—I3-12" HTS X NP, ID = 2.813- 3-12" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 8579' ' 856W --i 3-12" HES X NP, D = 2.813" PERFORATION SLIWMARY REF LOG: TOP Pf3iF ANGLEAT TOP PERF. 52- @ 5895' Note: Refer to Production DB for historical oerf data 4-518" 5 5895 - 5962 O 08/09/02 4-5/8" 5 6018 - 6070 0 08/09/02 8629' 7" MARKERJi W/ RA TAG 4-5/8" 5 6097 - 6119 0 08/09/02 4-5/8" 5 6194-6210 0 08/09/02 KUPARUK - BOREALIS 4-5/8" 5 695-6415 0 0809/02 AUTHORIZED FOR WAG INJECTION 4-518" 5 6398 - 6415 O 08/09/02 2-1/2" 6 8722 - 8782 0 1020/02 8933 7" MARKERJT W/ RA TAG 0 927W - 7" CSG, 26#, L-80, .0383 bpf, D = 6276" 936W DATE REV BY COMMENTS DATE I REV BY COMMENTS 08AMM DM/KAK ORIGINALCOMPLE MN 0728110 GTW%A WFRCJO 07/18/10 07/15/07 KSB/PJC GLV C/O & PLLJ-XX TTP 02M5/11 M3/JMJ ADDED SSSV SAFETY NOTE 1024/07 DAV/TLH GLV C/O 10N 1/11 C/ PJ GLV C/O 926/11 11116/07 MGS/PJC PULL XX/ SET MCX (1025/07) 01117112 TLUJM) ADDED H2S SAFETY NOTE 02A M JL YSV GLV C/O 1i09 06/11/09 M LY LH GLV C/O BOREALIS LINT WELL: L-103 PERMT N1: �M`1390 API No: 50-029-23101-00 SEC 34. T12N. R11E. 2590' NSL & 3618' WEL Hicorp NoM Slope, LLC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 10, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-103 PRUDHOE BAY UN BORE L-103 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/10/2023 L-103 50-029-23101-00-00 202-139-0 W SPT 4284 2021390 1500 1589 1590 1590 1590 374 381 379 380 4YRTST P Austin McLeod 7/7/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-103 Inspection Date: Tubing OA Packer Depth 331 2350 2225 2211IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230708163511 BBL Pumped:3.3 BBL Returned:3 Thursday, August 10, 2023 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 22, 2019 TO: Jim Regg P.1. Supervisor /\ SUBJECT: Mechanical Integrity Tests BP Explornion (Alaska) Inc. L-103 FROM: Guy COOK PRUDHOE BAY UN BORE I. 103 Petroleum Inspector Src: Inspector Reviewed By: P.J. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-103 API Well Number 50-029-23109-00-00 Inspector Name: Guy Cook Permit Number: 202-139-0 Inspection Date: 7/20/2019 ✓ Insp Num: mitGDC190720124217 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L 103 Type Inj W TVD j 4284 "Tubing -- 1310 1324 1321. 1323 PTD zo 13vo TYPe Test SPT Test psi soo IAL77e zs0a z43 - zazv BBL Pumped_�s ,, BBL Returned. 1.z OA4 347 - 341 348 -- Interval i 4YRTST P/F P Notes: Testing was completed with a triplex pump, calibrated gauges and a bleed trailer. IA was not to surface with fluid. Fluid level wsa ✓ approxiamately 60' from surface. Monday, July 22, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg tUI DATE: Monday,October 05,2015 P.I.Supervisor ��(Gt ` t t SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-103 FROM: Jeff Jones PRUDHOE BAY UN BORE L-103 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jeal-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-103 API Well Number 50-029-23101-00-00 Inspector Name: Jeff Jones Permit Number: 202-139-0 Inspection Date: 8/16/2015 Insp Num: mitJJ150817122338 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-103 iType Inj W TVD 4284 ITubing 1357 1355 1352 1355 — PTD 2021390 Type Test SPT Test psi 1500 I IA 469 2500 2429 ' 2419 Interval i4YRTST IPF P OA 330 333 334 334 ' i Notes: 1 well inspected,no exceptions noted. SCANNED ,r •5 r , 1` Monday,October 05,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Dd-.. - 139 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 ~escan Needed 1111111111111111111 R~CAN ~ Color Items: 0 Greyscale Items: DIGITAL DATA ~skettes, No. I 0 Other, NolType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: BY: 0 Other:: Date:/D ¡ ð 4- Isf mP . 1111111111111111111 r f . P Date: to ¡ tJ If Isl Vt1 +.;z = 'T~TAL PAGES 6~ (Count does 1°. t l1c1ude cover s~,¡e~, P' Date: J 0 I 0 if 151 yy~ Production Scanning . I IIIIIIIIIIII~ 111\1 Page Count from Scanned File: ( ÇJ::3 (Count does include CO/heet) Page Count Matches Number in Scanning Preparation: V YES 1\ :!i Helen ~ Date:/() ¡ '0 if . ~ YES NO Helen("Maria) BY: Project Proofing BY: Helen ~aria ) Scanning Preparation ~ x 30 =fRD Hele~9 ) Stage 1 BY: NO Isl rn P Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: 151 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • MEMORANDUM State of Alaska , Alaska Oil and Gas Conservation Commission DATE: Thursday, November 03, 2011 TO: Jim Regg g P.I. Supervisor � J l SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L -I03 FROM: Jeff Jones PRUDHOE BAY UN BORE L -103 • Petroleum Inspector Src: Inspector Reviewed 13y: P.I. Supry ,VP__.-- NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN BORE L - 103 API Well Number: 50 029 - 23101 - 00 - 00 Inspector Name: JeffJones Insp Num: mitJJ111024131227 Permit Number: 202 - 139 - Inspection Date: 10/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L -103 ' Type Inj. W ' TVD 4284 - IA 230 2520 , 2450 2435 - P.T.D 2021390 • TypeTest SPT Test psi 1500 ' OA 70 - 70 70 70 _ Interval 4YRTST P/F P " Tubing 1780 1780 1780 1780 Notes: 1 well inspected; no exceptions noted. _ Thursday, November 03, 2011 Page 1 of 1 Schium~erg~r ~ska Data & Consulting Services ?5 Gambell Street, Suite 400 chorage,AK 99503-2838 TN: Beth Well Job # Log Description Date BL Color CD NO. 5385 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 02-31A 17-09 12-30 17-09 13-27A 6146-00087 63S0-00042 88RH-00003 AWJB-00047 BALL-00009 SCMT - ~ -' TBG. CUT/FLOW DETECTION _ LDL MEM LDL USIT 12/24/09 01/05/10 12/26/09 01/03/10 1 1 1 1 1 1 1 1 JX-02A AWJI-00065 MEM LDL - 12/31/09 1 1 MPJ-19A L-103 W-217 12-05AL1 AP3Q-00075 BALL-00010 AYKP-00056 62NJ-00025 USIT _ RST/WFL - CH EDIT PDC USIT _ MCNL 12/29/09 12/29/09 01/06/1D 11/27/09 1 1 1 1 1 1 1 V-224 D-14A 11-27 3-27/M-33 AYKP-00059 AWJI-00060 AP30-00068 B8K5-00012 CH EDIT PDC USIT MCNL - C RST '~ - ~ RST 09/29/09 12/14/09 11/15/09 11/06/09 1 1 1 1 1 1 1 11/18/09 1 1 ASE ACKNOWLEDGE REC EIPT ev SIGNIN [: stun taFT~ azuiur_ Halo rnov a wn.~ r.,. :xploration (Alaska) Inc. technical Data Center LR2-1 E. Benson Blvd. "'•a, ~~ F E~ k~ V i 4 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 r / • • ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~ ~ ti~l '~`~`~~~~~ "4~''~ ... ~ ~Q(~:~ ~ .i'v a ` ' ~ bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0~ 2009 ~llask~ ~il ~C Gas Cons. Commission Anchorape ~~~- t~9 ~-t~3 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) I)AIR L pad 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor C.OffOS10~1 inhibitod sealant date ft bbis ft na al L-Ot 2010720 50029230110000 NA 6 NA 612 6/25/2009 1-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 702 6J26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 225 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231970000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 1~ 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1l10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 ~-214A 2060270 50029232580100 NA 0.25 NA 102 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 1.-219 2071480 50029233760000 surfaCe NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 o~iosios ~chr~u~mber~~r N0. 5297 A~aska Data & Consultin Services ."°~~ ~~~~~; ~,E _? L~~"~ p y; 9 ~~~ ~.~ L~- Com an State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnk2n l~TTRI; Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NVel9 Job # Log Description Date BL Color CD ~ ~ ~~ Z-06 AYTO-00035 GLS/PRODUCTION PROFILE 05/12/09 1 1 07-338 B4C4-00003 SCMT 05/30/09 1 1 17-14 AVY5-00049 PRODUC ION PRO ILE ~/- 05/31/09 1 1 12-01 AYTU-00039 PRODUCTION PROFILE O6/01/09 1 1 04-43 AXWS-00011 IBP/CROSS FLOW CHECK - ~'~. O6l0?J09 1 1 D-13A 804C-00059 USIT - 06/03/09 1 1 7-112 82WY-00011 MEM PROD PROFILE 06/03/09 1 1 06-05 B04C-00061 USIT 06/04/09 1 1 12-18 AViH-00014 PRODUCTION PROFILE 06l04/09 1 1 A-35 AY3J-00026 USIT a(p ~ 06/OM09 1 1 12-22 AXWS-00013 PROD PROF/GLS 06/05/09 1 1 12-16A AXWS-00014 PRODUCTION PROFILE O6/05/09 1 1 18-298 804C-00062 PSP XY-CALIPER LOG 06lO6l09 1 1 C-124 AXWS-00015 SCMT ~- / 06/06/04 1 1 B-27A AXBD-00028 MEM PROD PROFILE 06/11/09 1 1 L2-13A AWJI-00036 MEM CNL & INJ PROFILE ~ O6/17/09 1 1 L2-13dA AWJI-00036 MEM PROD PROFILE / ~ 06/17/09 1 1 07-29 614B-00064 LDL 06/20/09 1 1 17-01A AYQQ-00030 SBHP SURVEY 06/11/09 1 1 01-25 AP3Q-00041 LDL O6/15/09 1 1 L-202 B2WY-00010 MEM PROD PROFILE ~- (,/ 06/0?J09 1 1 L-103 AXBD-00027 MEM INJ PROFILE O6l04/09 1 1 GNf-03 AWJI-00034 MEM PRESS $ TEMP SURVEY ~"~--- O6/15/09 1 1 G-31B AWJI-00027 MCNL _~~ 04/30/09 1 1 15-29BPB1 09AKA0743 OH MWD/LWD EDIT - °~f ~ r 05/11/09 2 1 rI.GNJG FOVRIYVtltlLCVNC ~CVGr I or awrvirvu s~rvu nc~ unrv~rvu vrvt ~:vr~ tAGn i V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. / ' a ~ .~-.__._'. , ~. / ..... , g ~~...r, t ~, /~.. ~--.,.r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • MEMORANDUM To: gg Jim Re tt< P.I. Supervisor f 1 )~~{~i II'~ 9,47 FROVr: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 10, 2007 SL`BJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-103 PRUDHOE BAY LN BORE L-103 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .,1 J~ Comm Well Name: PRUDHOE BAY UN BORE L-103 API Well Number: 50-029-23101-00-00 Inspector Name: Bob Nobte mitRCN07t006t55022 Insp Num: Permit Number: 202-139-0 Inspection Date: 10/5/2007 Rel Insp Num: Packer Depth r Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ L-103 W , ~ Well ~ ~TYPe Inj. ~ TVD -, 4284 ~ IA 1000 4000 ~ I ~ 3890 3850 - - P T. ~ 2021390 ITypeTeSt ~ SPT ~! TCSt pSl 4000 ~ i OA ~, 320 ~i 320 ~ ~ 330 ~ 330 ~ ? Interval oTI-rER p~ _ P •' Tubin ~~ g '~, 2425 2425 _ 242 ~ 2425 _ _~~ ~----- NOteS' MIT-IA for pre-MI swap Wednesday, October 10, 2007 Page I of 1 04/27107 Scblumberger NO. 4232 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth U '" "'ì ·t·3° I Q.,. ÇI 0 d - ., -ì Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Aurora Well Job# Log Description Date BL Color CD L-103 11626079 INJECTION PROFILE 03/27/07 1 V-121 11630464 USIT 03/29/07 1 L-214 40011949 OH EDIT MWD/LWD OS/25/05 2 1 S-111 40011960 OH EDIT MWD/LWD 07/01/05 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2·1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger-DCS 2525 Gambel! St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Date Delivered: /\PH 3 0 Z007 Received by: . ü' iH SCANNED MAY 0.1 2007 06121/06 Seldlnberger d- - \~ U J:.~Bö NO. 3862 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~"r Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 _ . ." ¡f'f; ~{jihð\\1:-,(;"~ ,~ .> Field: Orion, Aurora, Borealis, Polaris Well Job # log Description Date BL Color CD S·111 11216189 MEMORY INJECTION PROFILE 04115/06 1 S-114A 10572082 RST UPFLOW WFL 03/01103 1 V-105 10663005 INJECTION PROFILE 03112/04 1 E-103 10580276 TEMPERATURE WARMBACK 06122/03 1 V-214 11162720 UBI 11/24/05 1 V-213 11076450 INJECTION PROFILE 07101/05 1 V-216 11076451 INJECTION PROFILE 07/02/05 1 V-221 11058523 INJECTION PROFILE 07/03/05 1 L-103 NIA INJECTION PROFILE 07/18/09 1 W-209 11076461 INJECTION PROFILE 08/20/05 1 W-207 10980589 INJECTION PROFILE 07120/05 1 W-212 NIA INJECTION PROFILE 07119/05 1 e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: elk Schlumberger·DCS 2525 Gambell St, Suite 400 Anchorage. AK 99503-2838 A TIN: Beth BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99506-4254 Received by: e RECEIVED JUN 2 3 2006 ~ 011 & Gas Coos. Ccmmlssicn Anchorage Id- . . "'. .·'···r··.···'.··'····················· . . ,. .. '" '" ....' i1 MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ~~!Æ~E :~ !ÆlfÆ~[«fÆ AT1ASHA. OILAlVD GAS CONSERVATION COMMISSION / Bruce Smith Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-103 Sundry Number: 304-408 Dear Mr. Smith: FRANK H. MURKOWSK/, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~'""'f&1 Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF T~OMMISSION DATED this~day of November, 2004 Encl. ,.. SCANNED NOV 1 6 2004 ') STATE OF ALASKA) ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALNOV 20 AAC 25.280 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: Suspend D RepairWell D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 78.40 KB 8. Property Designation: ADL-0028238 11. Total Depth MD (ft): 9370 Casing Total Depth TVD (ft): 7017.1 Length Size ¡ii', 'ì~' ,"( (, , F PerforateD waivé~tr'Ann~lar DisposalD StimulateD Time ExtensionD OtherŒJ Re-enter Suspended Well 0 Convert to WAG Inj 5. Permit to Drill Number: 202-1390 bottom top 109 9360 3031 Tubing Size: 3.5 " 9.3 # 4.5 12.6 # Packers and SSSV MD (ft): Development D Exploratory D Stratigraphic D Service ŒI 9. Well Name and Number: L-103 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9276 6858.8 MD TVD Conductor 80 Production 9335 Surface 3003 Perforation Depth MD (ft): 8722 - 8782 top 29 25 28 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6472.53 6523.0 Packers and SSSV Type: 3-1/2" Baker S-3 Packer 4-1/2" Baker Premier Packer 12. Attachments: Description Summary of Proposal D bottom 109.0 7008.6 2652.8 Tubing Grade: L-80 L-80 29.0 25.0 28.0 6. API Number 50-029-23101-00-00 Plugs (md): Junk (md): None None Burst Collapse 1490 7240 5750 Tubing MD (ft): 5779 23 470 5410 3090 8581 5779 8522 5722 Detailed Operations Program D BOP Sketch D 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒJ 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasO WAG ŒJ GINJD November 16, 2004 Printed Name Signature Bruce Smith ,~~._, .~ ^~~'A Commission Use Only 0 that a representative may witness P TestO Mechanciallntegrity Test D Other: - ct~t"/ ¡.q ç ~a ~ ~~~.~ ,~i.1' ~ "- Approved y. SCANNED NOV 1 6 2004 OR\G\NAL Form 10-403 Revised 06/2004 Contact Title Phone Petroleum Engineer 564-5093 Location Clearance 0 PluggedO AbandonedO WINJD WDSPLD Prepared by Garry Catron 564-4657. Bruce Smith 11/2104 Sundry Number:. ",-/ 8ð t.¡ - r.¡ ()v BY ORDER OF THE COMMISSION Date: /f 4rJf RBDMS BFL NOV ì 6 2004 SUBMIT IN DUPLICATE ~... ) TREE = 4-1/.,16" CIW WELLHEAD!: FMC A ëtüïÜÖR';;;"'" , "'''NÄ' KB~LB7-;--"'"78~¡'- 'm.........................."." .. .,."m........ BF. ELEV = 53.4' KOP = 500' ,..... ........... m.........'''' ..m....................... Max Angle = 56 @ 4013' ~".......,......... ~,~~,~.~,.. ~ Datum MD = 8968' ~DatumnrD = WOO'SS 9-5/8" CSG, 40#, L-80, 10 = 8.835" l-i 3031' Minimum ID = 2.813" @ 8510' 3-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" l-i 5779' 3-1/2" 1BG, 9.2#, L-80, .0087 bpf, 10 = 2.992" 1 13-1/2" 1BG, 9.2#, L-80, ,0087 bpf, 10 = 2.992" 1-1 8579' ~ ÆRFORA TION SUMMARY REF LOG: TCP PERF A NGLE AT TOP PERF: 52 @ 5895' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-5/8" 5 5895 - 5962 0 08/09/02 4-5/8" 5 6018 - 6070 0 08/09/02 4-5/8" 5 6097 - 6119 0 08/09/02 4-5/8" 5 6194 - 6210 0 08/09/02 4-5/8" 5 6285 - 6372 0 08/09/02 4-5/8" 5 6398 - 6415 0 08/09/02 2-1/2" 6 8722 - 8782 0 10/20/02 I PBTD l-i 9275' 17" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" l-i 9360' DA TE REV BY COM\l1ENTS 08/09/02 DMIKAK ORIGINAL COMPLETION 10/13/02 JB/KAK GLV C/O 12/30/02 DACIKK GLV CORRECTIONS 04/08/03 DRS/TP TV D/MD CORRECTIONS 10/17/04 BWS/KAK PERF CORRECTION L-103 = r-J x I L I ----1 I I ~ DA TE REV BY CO M\I1ENTS ) SAFETY NOTES: GLM'S @ STA#1 & #2 ARE 3-1/2" X 1-1/2" MMG-Ws, WHICH ARE WATERFLOOD MANDRELS. =---1 1019' l-i 9-5/8" TAM PORT COLLAR 1 1 2216' 1-1 4-1/2" HES X NIP, ID = 3.813" I ~ ST MD 5 4513 4 5310 3 5645 GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH PORT DATE 3503 51 KBG-2 DMY BK 16 11/10/02 4008 50 KBG-2 DMY BK 0 10/13/02 4232 47 KBG-2 DMY BK 20 11/10/02 WA TERFLOOD MANDRELS TVD DEV TYPE VLV LATCH PORT DATE 4348 52 MMG-W DMY RK 0 08/09/02 4385 52 MMG-W DMY RK 0 08/09/02 ST MD 2 5822 1 5882 5711' l-i 4-1/2" HES X NIP, 10 = 3.813" I x 5722' 1-1 7" X4-1/2" BKR PREMIER PKR, 10 = 3,875" I 5779' 1-1 4-1/2" X 3-1/2" XO, 10 = 2.992" I 8510' 1--1 3-1/2"HES XNIP, 10= 2.813" I ~ 8521' 1-1 3-1/2" X 4-1/2" XO, 10 = 2.930" 1 I 8522' 1-1 7" X4-1/2" BKR S-3 PKR, 10 = 3.875" I I 8526' 1-1 4-1/2" X 3-1/2" XO, 10 = 2.992" I I 8548' l-i 3-1/2" HES XNIP, 10 = 2,813" I I 8569' l-t 3-1/2" HES XNIP, 10 = 2.813" I I 8581' 1-1 3-1/2" WLEG 1 [ 8629' 1-1 7" MARKER JTW/ RA TAG I 8933' I~ 7" MARKER JTW/ RA TAG I SCANNED NO\J 1 6 2.004 BOREALIS UNIT WELL: L-103 PERMIT No: 2021390 API No: 50-029-23101-00 SEC 34, T12N, R11E, 2590' NSL &3618' WEL BP Exploration (Alaska) Cl w~.- ~'1 DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021390 Well Name/No. PRUDHOE BAY UN BORE L-103 Operator BP EXPLORATION (ALASKA) INC MD 9370 '-"'" TVD 7017 ------ Completion Date 8/9/2002 ..-- Completion Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, PWD, DEN, NEU, AZM DEN, USIT Well Log Information: Log/ Electr Data Digital Dataset Type ~/Frmt Numger Name ~ C ~043 See Notes Log Log Run Scale Media No 1 to 3 .--------..... \ Current StatU(1~1~~ JpuJ 2~J~~~1. API No. 50-029-23101-00-00 ////u-_u'" .~ ~/ ) --= ~_u~~<~~~;-=::: Directional Survey Yes ---~--_._~~----- --- _...~._-_._------~ (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 108 9325 J.og Density 1'1 f) 25 Blu 3 to 3 3000 9325 l.Jc6g Neutron Mi) 25 Blu 3 to 3 3000 9325 415g Neutron ì I/' f::> 25 Blu 3 to 3 3000 9325 ~ (.......Bâmma Ray 5 Col 3740 9254 ~ ~ ~ J..Ðg ~& Rpt {lOg ~perature Induction/Resistivity (") [> -Sonic C (? ..- llJ \ r Density ì 1/ Þ 5 Col 25 Blu 1 to 3 5 Col 25 Blu 3 to 3 Directional Survey Directional Survey Induction/Resistivity TV D 25 Blu 1 to 3 Well Cores/Samples Information: Name Interval Start Stop Received Sent 3740 9254 108 9325 3740 9254 3000 9325 0 9370 0 9370 108 9325 OH/ CH Received Comments ------~~.._--- --------- Open 9/13/2002 LDWG formatted open hole edit of measurement while drilling data. Slim Pulse gamma ray and vision density / neutron, vision resistivity Quadrant Quadrant Open 9/13/2002 Open 9/13/2002 Open 9/13/2002 Case 8/20/2002 Case 8/20/2002 Open 9/13/2002 Case 8/20/2002 Open 9/13/2002 Open 8/7/2002 Open 8/7/2002 Open 9/13/2002 Sample Set Number Comments Quadrant A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/1/2002. -~ Quadrant Permit to Drill 2021390 MD 9370 TVD 7017 Well Cored? ADDITIONAL INFORMATION Y~ Chips Received? >(H~ Analysis Received? Comments: ~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. PRUDHOE BAY UN BORE L-103 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23101-00-00 Completion Date 8/9/2002 Completion Status 1WINJ Daily History Received? Formation Tops ~ Current Status 1WINJ UIC Y t)N '?JyN Date: --_._--_._--~---- -- --._---- -~-'--'._-- -~---------------_.~-_..~-_o_~- ¿)JL W~~..... ~ ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Pre-Prod Converted to Water Inj 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X 2689'FNL,3618' FEL, Sec. 34,T12N, R11E,UM At top of productive interval 1600' FNL, 687' FEL, Sec. 34, T12N, R11 E, UM At effective depth 2340' FNL, 3754' FEL, Sec. 35, T12N, R11 E, UM At total depth 2356' FNL, 3711' FEL, Sec. 35, T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 583296,5978313) (asp's 586212, 5979435) (asp's 588434, 5978721) (asp's 588477,5978706) 9360 feet 7009 feet Plugs (measured) Effective depth: measured 9275 feet Junk (measured) true vertical 6936 feet Casing Length Size Cemented Conductor 108' 20" 260 sx Arctic Set (Aprox) Surface 3003' 9-5/8" 490 sx PF 'L', 285 sx Class 'G' Production 9335' 7" 307 sx Class 'G', 313 sx Class 'G' Plugging - Perforate - Repair well - Other _X 6. Datum elevation (DF or KB feet) RKB 78 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L -1 03 9. Permit number / approval number 202-139 / 302-323 10. API number 50-029-23101-00 11. Field / Pool Prudhoe Bay Field / Borealis Pool RECEIVED DEC 1 9 2002 Alaska Oil & Gas Gons. Commission Aru::horaot;t . Measured Depth Trué'Vertlcal Depth 136' 133' 3031' 2653' 9360' 7009' Perforation depth: measured Open Perfs 5895'-5962',6018'-6070',6097'-6119', 6194'-6210', 6285'-6372', 6398'-6415' true vertical Open Perfs 4393'-4434',4469'-4501',4517'-4531', 4577'-4587', 4633'-4687', 4703'-4713' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 5779'. 4-1/2" X 3-1/2" XO @ 5779'. 3-1/2" 9.3# L-80 TBG @ 8521'. 3-1/2" X 4-1/2" XO @ 8522'. 4-1/2" X 3-1/2" XO @ 8526'. 3-1/2" 9.2# L-80 TBG @ 8581'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 5722' MD. 7" x 4-1/2" Baker S-3 Packer @ 8522' MD. 4-1/2" HES 'X' Landing Nipple @ 2216'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Prior to well operation Shut-In Subsequent to operation 12/04/2002 15. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations ~ Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ax~Þ(J~ DeWayne R. Schnorr Casing Pressure Tubing Pressure 16. Status of well classification as: 1042 1621 Title: Technical Assistant Form 10-404 Rev 06/15/88 . Suspended - Service WATER Injector Date December 05. 2002 Prepared by DeWayne R. Schnorr 564.5174 ~ SUBMIT IN DUPLICATE ( L-103 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/09/2002 11/10/2002 11/11/2002 12/04/2002 12/04/2002 NEW WELL POST: GAS LIFT--TO DUMMY VALVES; STATIC BOTTOM HOLE NEW WELL POST: GAS LIFT--TO DUMMY VALVES NEW WELL POST: MIT-IA STARTED WATER INJECTION TESTEVENT --- INJ PRESS, PSI: 1,621 TYPE: PW VOL: 1,042 BWPD EVENT SUMMARY 11/09/02 PERFORM SUCCESSFUL SBHPS @ 6500' 66001, AND 6700. TVD PULLED LGLV AND OGLV FROM ST'S #1 3 & 5. SET DGLV IN ST# 5. 11/10/02 SET DGLV IN STA. # 3 @ 56391 SLM. PULLED 4 1/2 CATCHER SUB FROM 57621 SLM (CATCHER EMPTY) «< PROBLEMS W/ PARRIFIN IN THIS WELL »> 11/11/02 MIT IA TO 3000 PSI. PASSED. LOST 200 PSI IN 30 MINUTES / (150 PSI IN 12/04/02 STARTED WATER INJECTION. 12/04/02 TESTEVENT --- INJ PRESS, PSI: 1,621 TYPE: PW VOL: 1,042 BWPD FLUIDS PUMPED BBLS 63 63 DIESEL TOTAL Page 1 .. .~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner ~I, SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder' . \ BPXA Petroleum Engineer .Æ:r:Y'~ l & V Pads Q\~ ~1œ,~1~ FROM: Jeff Jones PBU Petroleum Inspector PBF/Borealis NON. CONFIDENTIAL ~vf; DATE: December 14, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. T.V.D. 4283 Tubing 1520 1520 1520 1520 Interval Test psi 1071 Casing 1645 2120 2110 2110 P/F OA 360 410 390 390 Notes: Pretest pressures obseved 15 min. & stable. Test fluid: 36 BBlS diesel. . ~f1 \ \ ~<::1¡ ~~ ..\\\,.)\ U \X')(" \<---<KJ Packer Depth Pretest Initial 15 Min. 30 Min. T.V.D. 6422 Tubing 1560 1560 1560 1560 Interval Test psi 1606 Casing 350 2040 2040 2030 P/F OA 340 340 340 340 Notes: Pretest pressures obseved 15 min. & stable. Test fluid: 3.9 BBlS diesel. Well L-103 Type Inj. P.T.D. 2021390 Type test s P I f Well V-104 Type Inj. P.T.D. 2021420 Type test s P I f Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring p= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details December 14, 2002: I traveled to BPXA's water injection wells L-I03 and V-I04 to witness initial MITIs. Bryan McLellan was the BPXA representative for the tests, which were performed in a safe and proficient manner. The pretest pressures were monitored and found to b~ stable and the standard annulus pressure test was then performed with both wells passing the MIT. Summary: I witnessed successful MITIs on BPXAls water injection wells L-l 03 and V-I 04 in the Prudhoe Bay Field. M.I.T.'s performed: ~ Number of Failures: Q Attachments: Wellbore schematics (2) Total Time during tests: 5.5 cc: MIT report form 5/12/00 L.G. MITPBU l-103, V-104 12-14-02 JJ.xls 12/18/2002 \ 4 ~TD -It ~ ()~ \ 1f1o -. .. TREE- 4.1/16n ClVV wsrH~O" FM; AcrUA TOR ¡.-"""-- ,- - --- filA' .~. ~fN = ._, -"t6~4i" ,~~,-~ËV a: 53.4' KOP.. -- 500' "xÂ"~";--66 @ 4013' 'D1tum M5.'~ "" --.- C9turn lYD =' "'j~~ø_õ'-SS' L.1 03 ... - , I 1 9.518" CSG. 40#. L-BO. ID = B.83S~r...H 30'31' 'rJ Minimum ID = 2.813n @ 8510. ' 3-1/211 HES X NIPPL..E 1 A- G.r.;; éJ . (J /"6' ~ . JrJbth'~ o/)~1/ 1YtÎ~ 8: r- 4-1/~" TeG, 12.'?~ï.-ao, .0152 DpT~, ID = 3.958" H fñ79' I I. ,_3~ 1/2" TBG, 9~2#, L.~, ,0087 bpf. D :=_~: ~2". I I 3..1/2"TBG. 9.2#, L-BO, .oositìPCIb =~'992D H ,,- _~5,79-''''' PERFORATION SUMMA. R'( R6=LOG: Try PERF ANGLE AT TOP PERF; 52 @ 5695' r-blé:. A.et er to Roduction DB for his toriœJ perf data SIZE SPF INTERV Al OpnÏS~' - Q4. TE 4-:'/8" b 5lt95 .5962 0' 'óäxjgid2. 4--5/8" 5 6018.6070 0 OB~9/02 . 406/8" 5 6097 - 6119 0 OSXJ9102 4-5/88 5 6194 - 621 0 0 06K19/02 4.51&" 5 6285 . 6372 0 OI;l,Q9/02 4.S/S" 5 6398 - 6415 0 08,09/02 I mro H 9275' 17" CSG. 26#. L-BO, .03a3t;i, ~p .:,6,27ë~;-- H .~360' I l . lZ/17/0Z( 40P P.Ø04 SAFElY f\DTES: GlM'S @ STA 1t1 ~ #2 ARE 3-1/2" X 1-1/2" MM3-Ws, WHCHARE; WATIRFLOOO ~NORELS. ,. =--1. 1019" H- -9.?~" 'I'AMPORTCOu..AR"] I 2216'" H ,~Y2" res X -ÑlP, 10 = $.~!~'~ I ~ ST MD 5 -451a 4 5310 3 5645 ìVD OaJ T:Y.PE VL V LA TOi PORT DA Te 3503 51 KBG-2 roM!: BK 16 'Ùjfi3/02 4006 50 KBG-2 av1Y ßK 0 10/13102 4232 47 KBG-2 SO BK 20 10/U/02 wArëRflöoo -W.toDR8.S -- , TVD OE.V - rVÆ Vl v LA Ta-I PORT i:Lo\ TE 4348' . '""52 M\1(7W I:tv1Y RK ,- '0 08~9/02 4S85 52 Mv1G-W [NY RK 0 06'()9/02. ST 'MD 2 5822 , :;882 I 5711' 11 '4=1/~U,~~~_,~P,1D =3.813" I ~"''''~~~~__H 7"X4.112"ßKR~PKR.D=3.~~~ .J I 5779' H ~~1/2"'X 3-1/2ï xc, ID = 2.992" I --.J ~ . --. --.-... ~,1E, ,~e¡ BY COMv1ENì5 _Q~09tJ2 OM'KAK. ORJGINð.I. COMPLETON 10113102 JEVKAK Gt.V ao .."'",. .- n. '''' 0'."' DATE REV BY . '.\1 "".,' - . .- ... . -- -.," '.".0__"'" COMWENfS o' .-..... .".'-'" ~. ,"V...M....a_.- ~ I ,~1.0', Jf' 3-112")ESX NP,ID =2.~.1~~ I I 8521' H 3-112" X4~1/2" XO, I.~.....~.~,~"I I 8522" H 7" X 4-1/2" BKR 5.3 FKR. [)~'3.87~""1 I 852~' J-L 4.1/2" £à~Úz.-xÓ~ïD = 2.992" I I 8548' H.._. ..~-1/2~ 'ÆSX NIP, ID = 2, a13" I [". ~.69' H, ~~Y2"I-ESX NP;-iO'=2.013" f I 8581' t-I 3-1/2" WlB3 . I 8629' 1-1 '7" ~F«e~~TW/8ðJAG..J .--t _~933' H r ~R~R..JT~I RßJ~(;.J ~ B~I?ALlS WB.L: L.103 PERMT I'b: 2021390 AR NI): 50-029-23101-00 ... ...~~34. í12N. R11E, 2590' NSL &3G'1S'Wa. SP E.xploratlOrl (AIa$ ka) ~~~~ ~f\L~ ~ M ('r ~~~ ~-lO?t '!'''~?'1 ~~"~'"!-~~ ~~:~\~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REcOMPLETION REPORT AND LOG Revised: 11/05/02, 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2590' NSL, 3617' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 3679' NSL, 687' WEL, SEC. 34, T12N, R11E, UM At total depth 2922' NSL, 1573' EWL, SEC. 35, T12N, R11 E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 78.40' ADL 028238 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/26/2002 8/2/2002 8/9/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9370 7017 FT 9276 6937 FT 181 Yes 0 No 22. Type Electric or Other Logs Run DIR, GR, PWD, DEN, NEU, AZM DEN, US IT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 34" x 20" 91.5# H-40 Surface 108' 42" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 3031' 12-1/4" 490 sx PF 'L', 285 sx Class 'G' 7" 26# L-80 25' 9360' 8-3/4" 307 sx Class 'G', 313 sx Class 'G' 'f ( i'~ 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25. Put on Production Classification of Service Well Pre-Produced Injector 7. Permit Number 202-139 8. API Number 50- 029-231 01-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number L-103i 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2216' MD 1900' (Approx.) AMOUNT PULLED 2-1/2" Gun Diameter, 6 spf MD TVD 8722' - 8742' 6472' - 6489' 8742' - 8762' 6489' - 6506' 8762' - 8782' 6506' - 6523' TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 5779' 3-1/2",9.3#, L-80 5779' - 8581' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3100' Freeze Protect with 103 Bbls of Diesel Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of Ifthology, porosity, fractures, apparent dips and presence of oil, gas or water. Submft R ~I~ E , V E D No core samples were taken. NOV ;) n ':.... t l' 4-5/8" Gun Diameter, 5 spf MD TVD 5895' - 5962' 4393' - 4434' 6018' - 6070' 4469' - 4501' 6097' - 6119' 4517' - 4531' 6194' - 6210' 4577' - 4587' 6285' - 6372' 4633' - 4687' 6398' - 6415' 4703' - 4713' 26. 27. Date First Production October 22, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL OIL-BBL GAs-McF WATER-BBL RBDMS 8Ft Form 10-407 Rev. 07-01-80 PACKER SET (MD) 5722' 8522' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) NOV 1 8 2002 Alaska Oil & Gas G-oßs. Commission Anchorage Submit In Duplicate ( 29. Geologic Markers Marker Name Measured Depth Schrader Bluff N Sands 5639' Schrader Bluff 0 Sands 5894' Base of Schrader Bluff / 6547' Top of Colville HRZ 8384' Kalubik 8616' Kuparuk C 8720' LCU / Kuparuk B 8897' Kuparuk A 9072' Miluveach 91731 31. List of Attachments: 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4227' 4392' 4795' 61891 6383' 6471' 6619' 6766' 6850' RI€~'VED NOV 1 8 2002 ,ÆUasb Oil & Gas Cons. Commission Anchorage Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I ~erebY certify that the fo.r7.e in~ is true anÆi~ct. to the best of my knowledge Date I \-[ <:. 0... Signed Terrie Hubble ~ðAALe fVl~, Title Technical Assistant V ~ L -1 03i 202-139 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: James Franks, 564-4468 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 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 28: If no cores taken, indicate 'none', ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 Well: Field: API: Permit: ( L-103i (Pre-Produced Injector) Prudhoe Bay Unit 50-029-23101-00 202-139 Rig Accept: 07/26/02 Rig Spud: 07/26/02 Rig Release: 08/09/02 Drilling Rig: Nabors 9ES POST RIG WORK 10/13/02 PULL B & R. PULL 1" DGLV-BK FROM STA-5 @ 4513' MD. PULL SHEAR VLV-BK FROM STA-3 @ 5645' MD. SET 1" DOME-BK (1/4" PORT, 1817# TRO) IN STA-5. SET 1" SIO (20/64" PORT) IN STA-3. PULL 31/2" RHC PLUG BODY. DRIFT AND TAG W/2.5" X 10' D-GUN TO 9264' SLM, 13' COR = 9277' COR MD. LEFT WELL SHUT IN, PRE PERF. 10/20/02 RIH, TAGGED PBTD @ 9275', LOGGED PRESS/ TEMPI JEWELRY LOG UP TO 5600', POOH. BHP= 3003 PSI, BHT= 160 DEGF. RIH FOR 3 GUN RUNS. WI 2.5" HSD, 6 SPF PJ. SHOT 8722'-8782' (60'), ALL RUNS HAD WHP= 22 DEGF., WHP= 0, IA= 0, OA= 0 BEHORE & AFTER SHOOTING. ALL SUCCESSFUL SHOTS. OOH, RDMO, LEFT WELL SHUT IN, READY TO POP. NOTIFIED DSO OF STATUS. JOB COMPLETE. 10/21/02 PUMP HOT DIESEL DOWN IA TO WARM WELL BORE FOR POP & TEST- START PSI T/I/O/= 0/50/200- PUMPED 100 BBLS DIESEL @ 180 DEG F & 20 BBLS NEAT- FINAL PSI T/I/O= 300/550/360 - WELL TURNED OVER TO PAD OPERATOR TO POP. --f7."" bp October 11 , 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: .,. ...\ll.'II. -..,~ ~...- ~- ~...~ ..~ F"'-' .,.,,,,\9. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Re: Sundry Notice for L-1 03 Conversion from Pre-Produced Injector to Water Injector BP Exploration Alaska, Inc. proposes to copvert well L-103 from a pre-produced injection well to an active injector (water only) as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: S Drift, run initial Borealis GL design, place MEOH in IA. E Jewelry log E Perforate 60' (Bottom shot @ 87821MD) / 0 Hot Oil Well simultaneously to POP S Run Static Survey, POP S SI Freeze Protect IA and pull/dummy Gas Lift design 0 Ann Com MIT / 0 Pump Neat MEOH place on Injection Slickline Work: 1. Drift and tag to at least 8850' MD, to verify access to perfs. 2. Run DHSIT wI dual gauges. Recover DHSIT wI gauges after + 72 hours. 3. DGLVs MITIA to 4000 psig. / Last test: Max Deviation: Top Perf deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Well bore Fluids: BHT & BHP: Reference Log: Note: New completion, never tested. / 56° @ 4013' MD 33° @ 8967' MD 2.813" X nipple @ 8510" MD None initial entry None initial entry Not tested (new well). Offset well L-106 '0' ppm on 09/02/2002. Freeze protected tubing & IA to 3500' with diesel. L-119i 152°F & 2860 psi a @ 6600' TVDSS Schlumberger Vision Log August! 02/2002 Simops on QoinQ Construction. drillinQ. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW@BP.com Sincerely, ~~~ Bruce W. Smith GPB Borealis Development Engineer (' ( a¡.JGÆ- 10114102- J¡r- 4f/~ jVl '-ð /0/' S-/ø?'" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Pre-Producer / Alter casing - Repair well - Converted to Inject Change approved program - 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2689' FNL, 3618' FEL, Sec. 34, T12N, R11 E, UM At top of productive interval 1600' FNL, 687' FEL, SEC 34, T12N, R11 E, UM At effective depth 2340' FNL, 3754' FEL, Sec. 35, T12N, R11 E, UM At total depth 2356' FNL, 3711' FEL, Sec 35 T12N, R11E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 108' 20" Surface 3003' 9-5/8" Production 9335' 7" Perforation depth: Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 583296, 5978313) (asp's 586212, 5979435) (asp's 588434, 5978721) (asp's 588477, 5978706) 9360 feet 7009 feet 9275 feet 6936 feet Plugs (measured) Junk (measured) Re-enter suspended well - Pre-Producer Converted /,/ Time extension - Stimulate - to Injector Variance - Perforate - Other _X 6. Datum elevation (DF or KB feet) RKB 78.4 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well numb~ L-103 9. Permit number / approval number 202-139 / 10. API number 50-029-23101-00 11. Field / Pool Prudhoe Bay Field / Borealis Pool Measured Depth 136' 3031' True vertical Depth 136' 2653' Cemented 260 sx ArcticSet (Aprox) 490 sx PF 'L', 285 sx Class 'G" 307 sx Class 'G', 313 sx Class 'G' 9360' 7009' measured Open Perfs 5895'-5962', 6018'-6070', 6097'-6119', 6194'-6210', 6285'-6372', 6398'-6415'. true vertical Open Perfs 4393'-4434',4469'-4501',4517'-4531', 4577'-4587', 4633'-4687', 4703'-4713' 4-1/2" 12.6# L-80 TBG @ 5779'.4-1/2" X 3-1/2" XO @ 5779'. 3-1/2" 9.2# L-80 TBG @ 8521'. 3-1/2" X 4-1/2" XO @ 8522'. 4-1/2" X 3-1/2" XO @ 8526'. 3-1/2" 9.2# L-80 TBG @ 8581'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 5722' MD. 7" x 4-1/2" Baker S-3 Packer @ 8522' MD. 4-1/2" HES 'X' Landing Nipple @ 2216'. 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operatio/ 15. Status of well classification as: October 21, 2002 16. If proposal was verbally approved Name of approver Date approved Service WATER INJECTOR AlaCaDl&S,.CJons. GommtSSfon 17. I hereby certify that the foregoing is true an ,'correct to the best of my knowledge. Questions? Call Bruce W. smAr""". ~0 Tubing (size, grade, and measured depth Signed Bruce W. Smith Oil- Title: Borealis Development Petroleum Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - ~BpP Test - Location clearance- Mechanical Integrity Te~t ~d . I J - Subs~quent f~.rm required 10- M t: T of' e~ UÁ ~. .() nor' "{V IM'e.{. {-,¿ tv-- ~ U '0nglnal Signed By I Approved by order of the Commission Cammy Oechsli Taytor Form 1 0~403 Rev 06/15/88 . Gas- BKtCEIV[D sus~Jdl1 )2002 Date October 11. 2002 Prepared by DeWayne R. Schnorr 564-5174 t( ðl I Approval no. So 7~-- 3:2.3 Commissioner Date I tJ)S- j;;;). SUBMIT IN TRIPLICATE (' lREE= 4-1/16"CIW WELLHEA 0 = Frvc Ã-ëTüÄTÖì~^-;~-----'^-NÃ 'ï<ä:1iE:l';-------Yã.'4' SF."ELEV =- -------53.4: 'RõÞ = .'--------šod tv'ax~ñ9le = 56 @ 40 1! D3tum M) = ...~,."......,.""^,..,...~.~._~ D3tum lV 0 = 8800' SS 9-518" CSG, 40#, L-80, 10 = 8.835" H 3031' Minimum ID = 2.813" @ 8510' 3.1/2" HES X NIPPLE 4-1/2"TBG, 12.6#, L-80,.0152 bpf,10=3.958" H-._5779' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" 1 3-1/2" TBG, 9.2#, L-80, .0087 bpf, 10 = 2.992" H 8579' PERFORATION SUMMA. RY REF LOG: TCP PERF ANGLE AT TOP PERF: 52 @ 5895' f\bte: Refer to A"oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA TE 4-5/8" 5 5895 - 5962 0 08/09/02 4-5/8" 5 6018 - 6070 0 08/09/02 4-5/8" 5 6097 - 6119 0 08109/02 4-5/8" 5 6194 - 6210 0 08109/02 4-5/8" 5 6285 - 6372 0 08/09/02 4-5/8" 5 6398 - 6415 0 08109/02 I R3TO H 9275' 17" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 9360' L-1 03 = ~ :8: (' SAFETY NOTES: GLM'S @ STA #1 & #2 ARE 3-1/2" X 1-1/2" MM3-Ws, WHICH ARE W A TERFLOOO MA NDR8...8. =~ 1019' H g.518" TAM PORT COLLAR I 1 2216' H 4-1/2" I-ES X NIP, 10 = 3.813" I . I l ~ ST MO 5 4513 4 5310 3 5645 I i ~ .... --.J . . ~ DA TE REV BY COMMENTS 08109102 OIVVKAK ORlGINÞ.L COMPLETON DATE REV BY COMrvENTS PORf DATE 0 08/09/02 0 08/09/02 08/09/02 ST MO 2 5822 1 5882 TVO OEV TYPE VL V LA TO! 3503 51 KBG-2 D\t1Y BK-5 4008 50 KBG-2 D\t1Y BK-5 4232 47 KBG-2 OCK BEK-2 W A TERFLOOO MA I\DRB.S TVO OEV TYPE VLV LA TO! PORf DATE 4348 52 WMG-W D\t1Y RK 0 08/09/02 4385 52 WMG-W D\t1Y RK 0 08/09/02 5711' H 4-1/2"f-ESXNIP,10=3.813" 1 5722' H 7" X 4-1/2" BKR ffiEMER PKR, D = 3.875" I 5779' H 4-1/2" X 3-1/2" XO, 10 = 2.992" I P () (rL\/ í c, 8510' 8521' 8522' 8526' 8548' I~ 3-1/2" HES X NIP, 10 = 2.813" I H 3-1/2" X 4-1/2" XO, 10= 2.930"1 H 7" X4-1/2" BKR &3 A<R, 10 = 3.875" I H 4-1/2" X 3-1/2" XO, 10= 2.992" I H 3-1/2" HES X NIP, 10 = 2.813" I H 3-1/2" f-ES X NIP, 10 = 2.813" I H 3-1/2" WLEG 8569' 8581' gO(~Jt $ 8629' ~ T' MA.RKERJTW/ RA TAG I 8933' H T' MA.RKERJTW/RA TAG I GPB BOREALIS WELL: L-103 PERMT f\b: 2021390 AR No: 50-029-23101-00 SEC34, T12N, R11E, 2590' NSL &3618'WB. BP Exploration (Alaska) Scblum~erDer Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well L-103 . ~~.../:s, L-103 L-103 L-103 L-103 ....../ Job# Log Description 22350 OH EDIT SLlMPULSE/GR & VISION RESISTIVITY 22350 MD VISION RESISTIVITY 22350 TVD VISION RESISTIVITY 22350 MD VISION DEN/NEUTRON QUADRANT 22350 TVD VISION DEN/NEUTRON QUADRANT 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 SEP 1 3 2002 Alaska Oi: & Gas Cons. Commission Anchorage 08/03/02 08/03/02 08/03/02 08/03/02 08/03/02 NO. 2391 '09/03/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Bet~ - Receive(þy; / ~ BL CD ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REcOMPLETION REPORT AND LOG ( 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned ria Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface l"¡ 2590' NSL, 3617' WEL, SEC. 34, T12N, R11E, UM 1.... DAre. ~ At top of productive interval I~' ~,.q,þ~:¡¡ 3~~~~~?à~~t~7' ~EL, SEC. 34, T12N, R11 E, UM .j ~""' ~..'V¡ J 2922 NSL, 1573 EWL, SEC. 35, T12N, R11 E, UM~~~~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 78.40' ADL 028238 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/26/2002' 8/2/2002 8/9/2002 17. Total Depth (MO+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9370 7017 FT 9276 6937 FT ria Yes 0 No 22. Type Electric or Other Logs Run DIR, GR, PWD, DEN, NEU, AZM DEN, US IT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 34" X 20" 91.5# H-40 Surface 108' 42" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 3031' 12-1/4" 490 sx PF 'L', 285 sx Class 'G' 7" 26# L-80 25' 9360' 8-3/4" 307 sx Class 'G., 313 sx Class 'G' fít"V' h. ,>~,';:;;'~.T ¡;¡ L'1o..I\J\ I < VI'<.'t ~ :..Y~~.''''¡') ;. \.: A.o~¡¡-¡. I ~ Surf. ' ._~ t~;,~:.-.,:;~... :::J Classification of Service Well Water & Gas Injector 7. Permit Number 202-139 8. API Number 50- 029-231 01-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number L-103i 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2216' MD 1900' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf MD TVD 5895' - 5962' 4393' - 4434' 6018' - 6070' 4469' - 4501' 6097' - 6119' 4517' - 4531' 6194' - 6210' 4577' - 4587' 6285' - 6372' 4633' - 4687' 6398' - 6415' 4703' - 4713' 25. TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 5779' 3-1/2",9.3#, L-80 5779' - 8581' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3100' Freeze Protect with 103 Bbls of Diesel PACKER SET (MD) 5722' 8522' MD TVD 26. 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. RBDMS 8FL Form 10-407 Rev. 07-01-80 ~ I J\L SEP 2 3 ~mit In Duplicate 29. Geologic Markers Marker Name Measured Depth Schrader Bluff N Sands 5639' Schrader Bluff 0 Sands 5894' Base of Schrader Bluff I 6547' Top of Colville HRZ 8384' Kalubik 8616' Kuparuk C 8720' LCU / Kuparuk B 8897' Kuparuk A 9072' Miluveach 9173' 31. List of Attachments: ( 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4227' 4392' 4795' 6189' 6383' 6471' 6619' 6766' 6850' Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~AW t1u.M-ee Title Technical Assistant L-103i 202-139 Well Number Permit No. / Approval No. Date œ ~S..O~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: L-103 Common Name: L-103 Test Date 7/30/2002 Test Type Test Depth (TMD) 3,031.0 (ft) LOT BP EXPLORATION Leak-Off.TesfSlImmary- Test DeptÞ (TVO) 2,652.0 (ft) AMW 9.70 (ppg) Suiface Pressure Leak Off Pressure (BHP) 710 (psi) 2,046 (psi) Page 1 of 1 EMW 14.85 (ppg) -'--" -~, Printed: 6/12/2002 2:47:12 PM ( BPEXPLORATION Operalioó$'..Silmn1aij.....Repørt Page 1 of7 Legal Well Name: L-103 Common Well Name: L-103 Spud Date: 7/26/2002 Event Name: DRILL +COMPLETE Start: 7/26/2002 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: 9-ES HOÜrS<TáSk COde.' NPT Phâ$Ø DesèriptioriQfOperations 7/26/2002 07:00 - 14:30 7.50 RIGU P PRE NIU RISER & M/U TURNBUCKLES, VALVES & SECURE CELLAR FOR SPUD. LOAD & STRAP DP IN PIPESHED, TAKE ON WATER. BUILD SPUD MUD. P/U DP & STAND BACK IN DERRICK. RABBIT EACH JT. 14:30 -16:00 1.50 RIGU P PRE LOAD PIPE SHED W/ BHA# 1. BRING MISC. BHA EQUIP TO FLOOR. 16:00 - 18:00 2.00 RIGU P PRE P/U HWDP & DC, STAND BACK IN DERRICK. 18:00 - 18:30 0.50 DRILL P SURF HOLD PRE-SPUD MTG W/ ALL PERSONNEL. 18:30 -19:00 0.50 DRILL P SURF FILL HOLE & CHECK ALL EQUIP FOR LEAKS. 19:00 - 21:00 2.00 DRILL P SURF MIU BIT, MOTOR, ORIENT SUB, MIU COLLAR STAND. TEST MWD EQUIP, OK. 21 :00 - 00:00 3.00 DRILL P SURF SET PARAMETERS, TAG UP @ 108' SPUD 121/4" HOLE & DRILL F/108 TO 355'. P/U 56K, S/O 56K, ROT 56K. 650 GPM, 1150 PSI, 80 RPM, WOB 10-20K, TORQ 1000 OFF, 1600 ON. ART 1.5 HRS 7/27/2002 00:00 - 00:30 0.50 DRILL P SURF Circulate & clean hole. Trip for jar stand. 00:30 - 10:30 10.00 DRILL P SURF Directionallty drill from 355 to 1654'. P/U 83K, S/O 77K, Rot 80K. 220 SPM, 650 GPM, 2390 Psi On, 2170 Psi Off. 80 RPM. Torq 4.7K On, 2.5K Off. AST 6.1 Hrs, ART 2 Hrs. 10:30 - 11 :30 1.00 DRILL P SURF Circulate & pump sweeps to clean hole @ 80 RPMs, 2170 Psi. 11:30 -13:30 2.00 DRILL P SURF Monitor well, well dead. POH w/ DP. Stand back HWDP & DCs. Break off bit. P/U 94K, S/O 68K. 13:30 -14:00 0.50 DRILL P SURF Clear floor. M/U new bit (#2) & RIH wI MWD. 14:00 - 14:30 0.50 DRILL P SURF Service Top Drive. 14:30 - 15:30 1.00 DRILL P SURF RIH wi DCs, HWDP & DP to 1561'. Fill pipe & wash down to 1654'. (pushed something from 1400 to TD). No fill. 15:30 - 22:00 6.50 DRILL P SURF Directionally drill from 1654 to 3041'. P/U 92K, SIO 78K, Rot 80K, 230 SPM, 3300 Psi, Torq on 6800. off 2600. 80 RPM. AST2.3 Hrs, ART 1.9 Hrs. (TVD @ 3041' MD = 2658') 22:00 - 23:00 1.00 DRILL P SURF Pump walnut & Sapp sweep to clean hole. 80 RPM, 3300 Psi. 23:00 - 00:00 1.00 DRILL P SURF Monitor well. POOH w/ DP. 7/28/2002 00:00 - 02:00 2.00 DRILL P SURF Con't wiper trip, pull out of hole. P/U 110K, SIO 80K, Had 30K over-pull @ 2350',1900' 1561-1357'. Wiped tight spots. Pulled to BHA @ 910'. 02:00 - 05:00 3.00 DRILL P SURF Run in hole, hit obstuction @ 1350'. push to 1950', then no go.M/U top drive & ream down 1 stand. Con't to push obstruction to 2962'. 05:00 - 07:00 2.00 DRILL P SURF M/U top drive, fill pipe & circulate, pump sweeps & clean hole. 650 gpm, 80 rpm, 2950 psi, torq 3-4k. Monitor well, dead. 07:00 - 08:30 1.50 DRILL P SURF POOH & stand back DP. PIU 105K, S/O 77K. Hole in excellent condition. 08:30 - 09:30 1.00 DRILL P SURF Stand back HWDP, jars & DCs. 09:30 - 10:30 1.00 DRILL P SURF UD MWD, stabs, lead DC, mud motor & bit. 10:30 - 11 :00 0.50 DRILL P SURF Clean & clear floor. 11 :00 - 13:30 2.50 DRILL P SURF Make dummy run wi csg hanger on landing jt. RlU 9 5/8" casing tools. 13:30 - 20:00 6.50 DRILL P SURF Hold PJSM. RIH w/ shoe track, check floats. Run 73 jts 9 5/8" 40# L-80, BTC casing. MIU torq 840Qft-lbs. Tight hole f/1850 to 3029'. Set @ 3031'. 20:00 - 20:30 0.50 DRILL P SURF RID fill-up tool. M/U cementing head & flow lines. 20:30 - 23:00 2.50 DRILL P SURF Break circulation, stage up pumps to 8 bpm. @ 450 psi. Had full retums. condition mud f/ cementing ops. 23:00 - 00:00 1.00 DRILL P SURF Hold PJSM. Test lines to 3500 psi, OK. Begin cementing Printed: 8/1212002 2:47:20 PM (. ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-103 L-103 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 9-ES 7/26/2002 Spud Date: 7/26/2002 End: 7/28/2002 23:00 - 00:00 1.00 DRILL P SURF operation. Mix & pump 75 bbls of 10.2 ppg Alpha spacer. 7/29/2002 00:00 - 02:00 2.00 DRILL P SURF Cement surf casing as follows: Pump 75 bbl Alpha spacer @ 10.2 ppg. Mix & pump 360 bbls lead cmt @ 10.7 ppg. Mix & pump 58.4 bbls tail cement @ 15.8 ppg. Drop plug & chase wI 10 bbls wtr. Displace plug w/214 bbls of mud. Bump plug to 1350 psi, float held. Reciprocated casing thru 70+ bbls of displacement. Had full returns thru-out job. Circulated out 70 bbls cement. PD @ 0150 hrs. 02:00 - 03:00 1.00 DRILL P SURF Bleed off all lines. Flush all cementing lines& riser. 03:00 - 04:00 1.00 DRILL P SURF Rig down all cementing equip & UD landing jt. 04:00 - 05:00 1.00 DRILL P SURF Rig down casing equip. Clear & clean floor. 05:00 - 05:30 0.50 DRILL P SURF Change out bails on top- drive. 05:30 - 07:30 2.00 DRILL P SURF Nipple down riser. Crossover 20" to 16" air boot. 07:30 - 09:30 2.00 DRILL P SURF Nipple up 11" x 5M Slim hole Speed Head & test to 1000 psi, ok. 09:30 - 13:00 3.50 DRILL P SURF NIU BOPE. Install 2 7/8" x 5" rams in bottom gate. 13:00 - 13:30 0.50 DRILL P SURF MIU stack washer & flush out BOP stack. 13:30 - 14:00 0.50 DRILL P SURF RlU test equip. Fill lines & BOP stack. 14:00 - 16:30 2.50 DRILL P SURF Test BOPE. LP 250 psi, HP 4000 psi. Ann. test LP 250 psi, HP 3500 psi. BOP test witnessing waived by Chuck Sheve wI AOGCC. 16:30 - 17:00 0.50 DRILL P SURF RID test equip. Install wear bushing. 17:00 - 23:00 6.00 DRILL P SURF MIU ported sub. P/U DP & stand back in derrick. Tested choke manifold while P/U DP. 23:00 - 00:00 1.00 DRILL P SURF Hold PJSM. MIU BHA#3. 7/30/2002 00:00 - 02:00 2.00 DRILL P PROD1 MlU BHA #3. LOAD RADIO ACTIVE SOURCE. 02:00 - 03:00 1.00 DRILL P PROD1 RIH WI DCS, JARS &STANDS OF HWDP. SURFACE TEST MWD EQUIP. 03:00 - 05:00 2.00 DRILL P PROD1 RIH WI SINGLES. TEST TAM COLLAR AFTER RUNNING PAST IT TO 1000 PSI, OK. HOLD TRIP DRILL. 05:00 - 06:00 1.00 DRILL P PROD1 CUT & SLIP 40' OF DRILLING LINE. CHECK BRAKES, OK. GREASE CROWN. CLEAN UNDER DRAWWORKS. 06:00 - 06:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE. 06:30 - 07:30 1.00 DRILL P PROD1 FILL PIPE @ 2865'. BREAK CIRCULATION. TEST CASING TO 3500 PSI, 30MIN. OK. CHART SAME. 07:30 - 10:00 2.50 DRILL P PROD1 WASH DOWN & TAG UP ON FLOAT COLLAR @ 2949'. DRILL OUT SHOE TRACK & 20' OF NEW HOLE. 500 GPM, 1950 PSI, 50 RPM, 4K TORQ, P/U 108K, S/O 76K, ROT 87K. 10:00 - 11 :00 1.00 DRILL P PROD1 DISPLACE SPUD MUD TO NEW 9.7 PPG LSND @ 10 BPM, 930 PSI. 11 :00 - 11 :30 0.50 DRILL P PROD 1 PERFORM LEAK OFF TEST TO 14.85 EMW. ' 11 :30 - 12:00 0.50 DRILL P PROD1 OBTAIN INITIAL BENCHMARK ECD READINGS. 12:00 - 16:00 4.00 DRILL P PROD1 DIRECTIONALL Y DRILL F/3061 TO 4273'. P/U 112K, SIO 80K, ROT 94K. 600 GPM, TORQ OFF 3200, ON 6000, BACK REAM EVERY STAND & PUMP SWEEPS EVERY 200'. AST 1.0 HRS, ART 1.8 HRS. 16:00 - 17:00 1.00 DRILL P PROD1 PUMP HI-LO VIS SWEEPS TO CLEAN HOLE. ECD 10.4 CALC VS ACTUAL 10.7. 17:00 - 17:30 0.50 DRILL P PROD1 MONITOR WELL, WELL STATIC. POOH & STARTED TO SWAB & PULL TIGHT @ 4080'. RIH TO 4179'. 17:30 - 23:30 6.00 DRILL P PROD1 BREAK CIRCULATION & STAGE UP PUMPS TO DRLG RATES, START BACK REAMING OUT OF HOLE. 100 RPM, WATCHING ECDS & PUMPING SWEEPS @ 3600' TO Printed: 8/1212002 2:47:20 PM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-103 L-103 DRILL +COMPLETE NABORS NABORS 9ES Start: 7/26/2002 Rig Release: Rig Number: 9-ES Spud Date: 7/26/2002 End: 7/30/2002 17:30 - 23:30 6.00 DRILL P PROD1 LOWER ECD. 23:30 - 00:00 0.50 DRILL P PROD1 MONITOR WELL @ SHOE. PUMP HI-LO VIS SWEEPS @ 600 GPM & 100 RPM. 7/31/2002 00:00 - 00:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE AT SHOE. 00:30 - 01 :30 1.00 DRILL P PROD1 RIH TO BOTTOM. PRECAUTIONARY REAM DOWN LAST STAND. HOLE CONDITION GOOD. 01 :30 - 12:00 10.50 DRILL P PROD1 DRILL AHEAD TO 5862' MD. 600 GPM @ 3100 PSI ON BOTTOM. ECD WITHIN 0.5 PPG OF CALC. AST 2.5, ART 3.6. 12:00 - 13:00 1.00 DRILL P PROD1 CIRC HOLE CLEAN FOR SHORT TRIP. PUMP HI-LO SWEEP @ 110 RPM. CLEAN HOLE & REDUCE ECD TO 10.59. CALC ECD 10.35. 13:00 - 14:00 1.00 DRILL P PROD1 POH TO 4530' - NO PUMP OR ROTARY, THEN STARTED SWABBING. 14:00 - 15:00 1.00 DRILL P PROD1 KELLY UP & PUMP/BACKREAM UP TO 4100' - ABOVE PREVIOUS SHORT TRIP DEPTH. 15:00 - 15:30 0.50 DRILL P PROD1 RIH TO 5768'. 15:30 -16:30 1.00 DRILL P PROD1 PUMP HI-LO SWEEPS & CLEAN HOLE. ECD 10.56. NO FILL ON BOTTOM. 16:30 - 00:00 7.50 DRILL P PROD1 DIRECTIONALL Y DRILL F/5862 TO 6887'. PIU 161K, SIO 93K, ROT 117K. 575 GPM, 3250 PSI, TORQ OFF 7200, ON 8600. CONTROL DRLG @ 360 FPH. TO 6000'. BACK REAM EVERY STAND. PUMP SWEEPS EVERY 200'. AST .8, ART 3.2. 8/1/2002 00:00 - 07:00 7.00 DRILL P PROD1 DIRECTIONALLY DRILL FROM 6887 TO 7540'. P/U 182K, 510 97K, ROT 128K. 189 SPM, 560 GPM, 3450 PSI ON, 3280 PSI OFF. 100 RPM, TORQ 8-9 ON, 8 OFF. CALC ECD 10.85, ECD 11.08, RECIPROCATE EACH STAND @ 560 GPM, 100RPM. 07:00 - 08:00 1.00 DRILL P PROD1 CIRCULATE HOLE CLEAN. PUMP HI-LO SWEEP @ 560GPM, 3350 PSI, 110 RPM.CALC ECD 10.85, ECD 10.94. 08:00 - 11 :00 3.00 DRILL P PROD1 ORIENT TO HIGH SIDE. MONITOR WELL, OK. PUMP DRY JOB. POOH TO CSG SHOE NO PROBLEMS. HOLE CONDITION GOOD. 11 :00 - 13:00 2.00 DRILL P PROD1 CHANGE OUT LINERS F/5/5" TO 5" ON BOTH MUD PUMPS. 13:00 - 14:00 1.00 DRILL P PROD1 CUT & SLIP 40' OF DRILLING LINE. 14:00 - 15:00 1.00 DRILL P PROD1 SERVICE CROWN, DRAWWORKS & TOP DRIVE. CHANGE DIES IN GRIPPER. 15:00 - 17:00 2.00 DRILL P PROD1 RIH HOLE TO 5300' & FILL PIPE. BREAK CIRCULATION. CONT TO RIH TO 7446'. HOLE IN GOOD CONDITION. 17:00 - 18:00 1.00 DRILL P PROD1 FILL PIPE. STAGE UP PUMPS TO 600 GPM. 3600 PSI. PUMP HI-LO SWEEP AROUND & CLEAN HOLE. ESTABLlSHN ECDS. ECD 11.5, CALC 10.85. CIRCULATE & REDUCE ECD TO 10.9. 18:00 - 00:00 6.00 DRILL P PROD1 DIRECTIONALL Y DRILL FROM 7540 TO 7870'. P/U 182K, SIO 104K, ROT 129K. TORQ 8400 OFF, 9400 ON. 600 GPM, 4150 PSI. 8/2/2002 00:00 - 11 :30 11.50 DRILL P PROD1 DIRECTIONALL Y DRILL F/7870 TO 8660'. PIU 202K, 5/0 110K, ROT 142K. 234 SPM, 587 GPM, 4350 PSI ON, 4080 PSI OFF, 100 RPM, TORQ 10.5K ON, 9K OFF. CALC ECD 10.74, ECD 11.02. AST 1.8, ART 5.5. 11 :30 - 12:30 1.00 DRILL P PROD1 CIRCULATE. CHANGE OUT DISCHARGE GASKET. #3 POT, Printed: 8/1212002 2:47:20 PM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-103 L-103 DRILL +COMPLETE NABORS NABORS 9ES Start: 7/26/2002 Rig Release: Rig Number: 9-ES Spud Date: 7/26/2002 End: 8/212002 11 :30 - 12:30 1.00 DRILL P PROD1 #1 PUMP. TORQ STUDS ON POT. 12:30 - 20:30 8.00 DRILL P PROD1 CON'T DIRECTIONALL Y DRILLING F/8660 TO 9370'. P/U 225K, SIO 117K, ROT 157K. 220 SPM, 550 GPM. 4200 PSI. AST .8, ART 3.8. 20:30 - 23:30 3.00 DRILL P PROD1 CIRCULATE & CLEAN HOLE. PUMP HI-LO SWEEPS. 220 SPM, 550 GPM, 3800 PSI. RECIPROCATE CSG. SPOT LUBE PILL, MONITOR WELL, OK. PUMP DRY JOB. 23:30 - 00:00 0.50 DRILL P PROD1 POOH FI CSG. 8/3/2002 00:00 - 03:00 3.00 DRILL P PROD1 POH TO 8870' - STARTED SWABBING. BACKREAM OUT TO 7540'. 03:00 - 04:00 1.00 DRILL P PROD1 CIRC LO-HI VIS SWEEP AROUND TO CLEAN HOLE TO 11.1 PPG ECD VS 10.9 PPG CALC. 04:00 - 06:30 2.50 DRILL P PROD1 MONITOR WELL - STATIC. PUMP PILL. POH TO SHOE - OK. 06:30 - 07:00 0.50 DRILL P PROD1 CIRC AT SHOE TO CLEAN UP CASING @ 600 GPM. 07:00 - 07:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE & CROWN. 07:30 - 11 :00 3.50 DRILL P PROD1 RIH TO 3450'. HIT OBSTRUCTION & TRY TO WORK THRU SAME - NO GO. KELLY UP AND REAM STAND BACK DOWN & BACKREAM. RUN THRU DRY - OK. CONT RIH TO 9328'. 11 :00 - 13:30 2.50 DRILL P PROD1 BREAK CIRC & STAGE PUMPS UP TO 550 GPM. CIRC SWEEP AROUND. TAG UP @ 9370'. CIRCULATE HI-LO SWEEPS. 220 SPM, 550 GPM, 3000 PSI, ROT 157K. 13:30 - 14:00 0.50 DRILL P PROD 1 SPOT LUBE Pill, MONITOR WELL, OK. PUMP DRY JOB. 14:00 - 16:00 2.00 DRILL P PROD1 POOH TO 6000'. SPOT STEEL SEAL PILL. 16:00 - 18:00 2.00 DRILL P PROD1 CONT POH TO SHOE. HOLE IN GOOD SHAPE. GO BACK THRU AREA AT 3450' - NO PROBLEMS. 18:00 - 19:00 1.00 DRILL P PROD1 CIRCULATE. PUMP HI-LO SWEEP @ SHOE (3029'). 220 SPM, 550 GPM, 2050 PSI. 19:00 - 20:00 1.00 DRILL P PROD1 CON'T TO POOH FOR CASING. 20:00 - 22:00 2.00 DRILL P PROD1 PJSM. DOWN LOAD RADIOACTIVE SOURCE FROM LWD TOOLS. UD BHA. 22:00 - 22:30 0.50 DRILL P PROD1 CLEAR & CLEAN RIG FLOOR. 22:30 - 23:00 0.50 CASE P COMP MIU DIVERTER SUB & FLUSH OUT BOP STACK. 23:00 - 23:30 0.50 CASE P COMP PULL WEAR BUSHING & INSTALL TEST PLUG. 23:30 - 00:00 0.50 CASE P COMP CHANGE OUT TOP RAMS TO 7" FOR CASING. 8/4/2002 00:00 - 01 :00 1.00 BOPSUR P COMP FINISH INSTALLING 7" PIPE RAMS. TEST BONNET SEALS TO 3500 PSI., OK. 01 :00 - 01 :30 0.50 CASE P COMP P/U CSG HANGER & MAKE DUMMY RUN. 01 :30 - 02:00 0.50 CASE P COMP CHANGE OUT BAILS ON TOP DRIVE. 02:00 - 03:00 1.00 CASE P COMP RIU CSG RUNNING EQUIP. 03:00 - 09:00 6.00 CASE P COMP PJSM. MIU SHOE TRACK. P/U FRANKS TOOL. CIRCULATE & CHECK FLOATS, OK. RIH W/7" 26#, L-80, BTC CASING TO SHOE @ 3030'. FILL EVERY JT. 09:00 - 09:30 0.50 CASE P COMP BRAK CIRCULATION, STAGE PUMPS UP TO 6 BPM, 380 PSI. CIRCULATE 1.5 ANN. VOL. P/U 107K, SIO 85K. 09:30 -14:00 4.50 CASE P COMP CON'T TO RUN 7" CASING. BREAK CIRC EVERY 5 JTS, CIRC 10 MIN EVERY 25 JTS. 14:00 - 16:00 2.00 CASE P COMP CON'T TO RUN 7" CASING, LIMITING RUNNING SPEED TO 15'/MIN, TO AVOID LOSING MUD. 16:00 -17:00 1.00 CASE P COMP CIRC 1.5 ANN. VOL. @ 5708'. 6 BPM @ 695 PSI. P/U 150K, S/O 93K. Printed: 8/1212002 2:47:20 PM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-103 L-103 DRILL +COMPLETE NABORS NABORS 9ES Start: 7/26/2002 Rig Release: Rig Number: 9-ES Spud Date: 7/26/2002 End: . .'. Date From - To Hours. Task èodè NPT Phase'. Description of Operations 8/412002 17:00 - 20:30 3.50 CASE P COMP CON'T RUNNING 7" CASING. 170 JTS IN. BREAK CIRC EVERY 5 JTS, CIRC 10 MIN EVERY 10 JTS. 20:30 - 21 :00 0.50 CASE P COMP CIRCULATE 1.5 ANN. VOL. @ 6915'. 6 BPM @ 640 PSI. P/U 190K, SIO 103K. 21 :00 - 00:00 3.00 CASE P COMP CON'T RUNNING 7" CASING. FILL EACH JT. CIRCULATE EVERY 5 JTS, CIRCULATE 15 MIN EVERY 15 JTS. CIRCULATE BOTTOMS UP EVERY 30 JTS. 8/5/2002 00:00 - 01 :00 1.00 CASE P COMP CONT RUNNING 7" CASING. 01 :00 - 02:00 1.00 CASE P COMP CBU AT 6 BPM - NO LOSSES. 02:00 - 05:00 3.00 CASE P COMP CONT RUNNING 7" CASING. MU HANGER AND LANDING JOINT. LAND CASING - OK. 05:00 - 05:30 0.50 CASE P COMP LD FRANKS CASING TOOL. RU CEMENT HEAD. 05:30 - 08:00 2.50 CASE P COMP BREAK CIRC AND STAGE UP TO 7 BPM @ 1000 PSI - NO LOSSES. CIRC & COND MUD WHILE RU HOWCO & SPOTTING TRUCKS. 08:00 - 08:15 0.25 CEMT P COMP RU FLOWMETER AND WASH UP LINE ON RIG FLOOR. 08: 15 - 08:30 0.25 CEMT P COMP SAFETY MEETINGS WITH ALL PERSONNEL. 08:30 - 09:45 1.25 CEMT P COMP BATCH MIX STAGE 1 SLURRY WHILE CO NT CIRC. 09:45 - 10:20 0.58 CEMT P COMP SWITCH TO CEMENTERS. PUMP 5 BBL WATER. TEST LINES TO 4000 PSI. PUMP 5 BBL WATER FOLLOWED BY 30 BBL ALPHA SPACER AT 11.1 PPG. 10:20 - 10:40 0.33 CEMT P COMP RELEASE BYPASS PLUG. PUMP 65 BBL (315 SX) PREMIUM G WITH LATEX AT 15.8 PPG. 6 BPM @ 600 PSI. LOAD SHUT OFF PLUG & RELEASE SAME. 10:40 - 11 :45 1.08 CEMT P COMP DISPLACE WITH 355 BBL MUD WITH RIG PUMP. 7 BPM @ 650 PSI. SLOW RATE AS PLUGS PASS ES CEMENTER. RECIPROCATE PIPE THROUGHOUT DISPLACEMENT. BUMP PLUG WITH 1200 PSI. CIP AT 11 :45 HRS. 11 :45 - 11 :55 0.17 CEMT P COMP LOAD ES CEMENTER CLOSING PLUG IN HEAD. PRESSURE UP TO 3100 PSI AND OPEN CEMENTER - OK. 11 :55 - 12:50 0.92 CEMT P COMP BREAK CIRE & STAGE UP TO 7 BPM - OK. CBU X 1.5 WHILE AIR UP & PRIME UP CEMENTERS FOR 2ND STAGE. 12:50 - 13:15 0.42 CEMT P COMP PUMP 5 BBLWA TER. TEST LINES TO 4000 PSI. PUMP 5 BBL WATER FOLLOWED BY 35 BBL ALPHA SPACER AT 10.2 PPG. 13:15 -13:35 0.33 CEMT P COMP MIX & PUMP 68 BBL (320 SX) CLASS G WITH CALSEAL @ 15.6 PPG. 5 BPM @ 500 PSI. 13:35 - 14:45 1.17 CEMT P COMP RELEASE ES CLOSING PLUG AND KICK OUT WITH 5 BBL WATER. SWITCH TO RIG PUMP AND DISPLACE WITH 252 BBL MUD AT 7 BPM. SLOW TO 6 BPM AFTER SEEING SLIGHT LOSS. NO LOSS AT 6 BPM @ 600 PSI. BUMP PLUG AND PRESSURE UP TO 2600 PSI (TWICE) TO CLOSE ES CEMENTER. BLEED OFF PRESSURE AND CHECK FOR FLOWBACK - NONE. CIP AT 14:45 HRS. 14:45 - 16:00 1.25 CEMT P COMP RID CEMENTING HEAD, 7" SPIDERS, LONG BAILS & BACK OUT LANDING JT. 16:00 -17:00 1.00 CEMT P COMP RUN PACKOFF & TEST TO 5000 PSI, OK. 17:00 - 17:30 0.50 CEMT P COMP PIU JOHNNY WHACKER & FLUSH OUT BOPE. M/U & RUN TEST PLUG. 17:30 - 18:30 1.00 CEMT P COMP CHANGE OUT TOP PIPE RAMS TO 3.5" X 6", 18:30 - 22:00 3.50 CEMT P COMP TEST BOPE. LP 250 PSI, HP 4000 PSI. TEST ANNULAR TO 3500 PSI. TEST WITNESSED BY JOHN CRISP WI AOGCC. 22:00 - 22:30 0.50 CEMT P COMP PULL TEST PLUG. INSTALL WEAR BUSHING. RILDS. Printed: 8/1212002 2:47:20 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-103 L-103 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 9-ES 7/26/2002 Spud Date: 7/26/2002 End: 8/512002 22:30 - 00:00 1.50 CEMT P COMP MlU BHA #4. RIH. 8/6/2002 00:00 - 04:00 4.00 CEMT P COMP Continue RIH slowly to prevent mud flowback with BHA #4 to 6570'. 04:00 - 05:30 1.50 CEMT P COMP Ream down and tag Howco ES cementer at 6723'. Drill same wI 240 gpm 1020 psi, 60 rpm's, 6-8k wob. 05:30 - 08:00 2.50 CEMT P COMP Continue RIH to 9183'. 08:00 - 09:00 1.00 CEMT P COMP Wash last stand down tag PBTD at 9276'. P/U and circulate sweep around to surface. 09:00 -10:00 1.00 CEMT P COMP Pressure test 7" casing to 4000 psi for 30 min. 150 psi pressure loss in 30 min - OK. 10:00 - 13:00 3.00 CEMT P COMP Flush all pumps and lines. Circulated hole with seawater to displace mud. Rotate and reciprocate while displacing. Displace seawater by reverse circulating 600 bbls 9.1 ppg filtered KCL brine. 13:00 - 14:00 1.00 CEMT P COMP TOH to 6515'. 14:00 - 14:30 0.50 CEMT P COMP Spot 38 bbls viscosified 9.1 ppg KCL perf pill f/6515' to 5400'. 14:30 - 15:30 1.00 CEMT P COMP Cut & slip 130' of drill line. 15:30 -16:00 0.50 CEMT P COMP Sevice top drive. 16:00 -18:00 2.00 CEMT P COMP TOH 18:00 -18:10 0.17 CEMT P COMP PJSM with SWLS and crews on P/U of logging tools. 18:10 - 18:45 0.58 CEMT P COMP RlU floor and P/U USIT log tool. 18:45 - 23:30 4.75 CEMT P COMP RIH and log USIT fl 9250' to 3740' 23:30 - 00:00 0.50 CEMT P COMP RID loggers 8/7/2002 00:00 - 00:30 0.50 PERF P COMP Load perf guns in pipe shed. Bring perforating tools to rig floor. 00:30 - 01 :00 0.50 PERF P COMP PJSM with Howco and Nabors crews. Review perf gun handling procedures, crew member assignments. 01 :00 - 02:00 1.00 PERF P COMP Wait on log processing and review of logs by SWS and town engineer. (good cement across perf intervals). Same time rig crews made semi-annual change out of hydraulic system filters. 02:00 - 04:30 2.50 PERF P COMP P/U 261' (520' gross) of Howco 4 5/8" 5 spf scallop guns. RIH to 100' below RT. 04:30 - 07:30 3.00 PERF P COMP RIH with guns on 4" DP to 6452'. Easy in & out of slips. 141k up, 85k dn 07:30 - 09:30 2.00 PERF P COMP PJSM wI SWS and crews. RlU SWS. RIH correlate with DP in tension found RA tag at 5819' vs 5790' needed for top shot @ 5895'. POH and RD SWS 09:30 - 10:30 1.00 PERF P COMP PIU 29' and set top shot at 5895" with DP in tension. Pump down dp & annulus. Pressure up to 2700 psi then bleed off to 0 psi. Guns fired after 5 1/2 min (monitored with recorder). Initial loss of 4 bbl. Monitor loss rate f/15 min additional 3 bbls. Perf Intervals: 4 5/8" Scallop guns. 5 spf 0.37" dia. 52" pen. 5895' - 5962' 6018' - 6070' 6097' - 6119' 6194' - 6210' 6285' - 6372' 6398' - 6415' 10:30 - 11:30 1.00 PERF P COMP Circulate 2 times around @ 9 bpm 970 psi through by-pass in an effort to clean up firing debris. 11 :30 - 13:00 1.50 PERF P COMP Monitor well - stable. TOH to guns. 13:00 - 13:10 0.17 PERF P COMP PJSM with crews covering gun laydown procedures. 13:10 - 15:00 1.83 PERF P COMP UD perf gun BHA. All shots fired. Printed: 8/1212002 2:47:20 PM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-103 L-103 DRILL +COMPLETE NABORS NABORS 9ES . Frôm : To . HouiSTask Code. NÞT PRase' 81712002 15:00 - 15:30 15:30 - 16:30 16:30 - 19:00 19:00 - 20:15 0.50 PERF P 1.00 PERF P 2.50 PERF P 1.25 PERF P COMP COMP COMP COMP 20:15 - 00:00 3.75 RUNCOM=» 8/8/2002 00:00 - 04:30 4.50 RUNCOM=» 04:30 - 05:00 0.50 RUNCOI\ P 05:00 - 06:30 1.50 RUNCOI\ P COMP COMP COMP COMP 06:30 - 08:00 08:00 - 08: 15 1.50 RUNCO" P 0.25 RUNCOÞIP COMP COMP 08: 15 - 20:30 12.25 RUNCOI\.P COMP 20:30 - 21 :00 21 :00 - 22:00 0.50 RUNCOM=» 1.00 RUNCOI\P COMP COMP 22:00 - 22:45 0.75 RUNCOI\P COMP 22:45 - 23:45 1.00 RUNCOI\P COMP 23:45 - 00:00 0.25 RUNCOI\.P COMP 8/9/2002 00:00 - 00:30 0.50 WHSUR P COMP 00:30 - 03:30 3.00 BOPSURP COMP 03:30 - 06:00 2.50 WHSUR P COMP 06:00 - 07:00 1.00 WHSUR P COMP 07:00 - 09:30 2.50 CHEM P COMP 09:30 - 10:30 1.00 WHSUR P COMP 10:30 - 12:00 1.50 RIGD P COMP Start: Rig Release: Rig Number: 9-ES Spud Date: 7/26/2002 End: 7/26/2002 Ðescñption of Operations Clear rig floor of perf gun equipment. P/U BHA #5 RIH to 9276' PBTD. Circulate work junk baskets. Clean-up hole by pumping 25 bbl hi-vis pill followed by clean 9.1 KCL brine @ 600 gpm 110 RPM's 2600 psi. PJSM with crews about LODP. UD all 4" DP and BHA #5 in preparation for rig move to V-pad. Continue to LDOP and BHA #5. Recover 1/2 gal of debris in junk baskets. Clear rig floor. Pull wear bushing. Some debris between puller and WB. P/U Johnny Wacker cleanout stack and wellhead area. Make dummy run with tbg hanger. C/O bales on topdrive. Load pipe shed with completion jewelry. RIU floor to run completion string. PJSM with crews. Review tbg running procedure and running order. Run 31/2" 9.2# TCII L-80 & 41/2" 12.6# L-80 TCII completion string wI jewelry. Make-up using Best-O-Life 2000 PTC & Torque-Turn: 2300ft1# & 2700 ft/#, (No fricton factor allowance used). Baker-Locked connections below Baker S-3 packer. Same time FP OA to 2340' with 66 bbls diesel M/U FMC tbg hanger and landing joint. Land tbg. RILDS Reverse circulate 50 bbls clean 9.1 ppg KCL brine, followed by 10 bbls corrosion inhibited brine, then 103 bbls KCL brine. Spotting inhibited brine between Premium packer and DCK valve. Drop 1.32" ball rod. UD landing joint. Pressure up on tbg to 2800 psi and set Baker S-3 packer. Continue pressure up to 4200 psi and set Baker Premium packer. Hold 4200 psi and test tbg for 30 min - OK. Bleed down tbg to 2500 psi. Pressure up IA to 4000 psi and test for 30 min - OK Bleed off IA then tbg to zero. Pressure up IA to 3100 psi and shear Camco DCK valve. Line up on tbg side and confirm ability to pump. 2 bpm @ 670 psi. (The DCK valve appears to work better than previous RPvalve runs.) Pump 50 bbls inhibited 9.1 KCL brine down IA. InstalllWC and test to 1000 psi. Nipple down and setback BOP stack. N/U 11" x 4" 5M adapter flg and 4 1/8" 5M production tree. Test adaptor, tree and pack-off to 5000 psi. OK RU lubricator & pulllWC. Rev circ in 103 bbl diesel to IA. Connect tbg & IA and U tube diesel to freeze protect IA and tubing to 3100' MD. Install BPV in tubing hanger & test from below to 1000 psi - OK RD DSM & Little Red. Blow down lines. RD lines from tree. Secure tree & clean out cellar. Suck fluid out of pits. RELEASE RIG FROM 1-103i AT 12:00 HRS ON 08/09/2002. Printed: 8/12/2002 2:47:20 PM ¡,-....., ANADRILL SCHLUMBERGER Survey report Client. "'" .... .........: BP Exploration (Alaska) Inc. Field..... ...............: Prudhoe Bay / Borealis Well. . . . . . . . . . . . . . . . . . . . .: L-103i API number...... .........: 50-029-23101-00 Engineer.................: Franco COUNTY:........... ..... ..: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions... ..: Minimum curvature Method for DLS..... ......: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 49.90 ft KB above permanent.......: N/A DF above permanent.. .....: 78.40 ft ----- Vertical section origin---------------- Latitude (+N/S-) ... ......: 0.00 ft Departure (+E/W-) ........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) .... .....: N 70.35071599 Departure (+E/W-)... .....: W 149.32370758 Azimuth from rotary table to target: 86.22 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] .~. 3-Aug-2002 09:09:39 Spud date................: Last survey date.... .....: Total accepted surveys...: MD of first survey..... ..: MD of last survey........: Page 1 of 5 26-Jul-02 03-Aug-02 102 0.00 ft 9370.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date............: 26-Jul-2002 Magnetic field strength..: 1149.56 HCNT Magnetic dec (+E/W-) .....: 25.85 degrees Magnetic dip....... ......: 80.77 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.56 HCNT 80.77 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.85 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.85 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 <~ ~.. ~'\ -, ANADRILL SCHLUMBERGER Survey Report -------- -------- Seg Measured # depth (ft) --- -------- -------- 1 2 3 4 5 0.00 137.40 200.34 292.35 385.22 6 7 8 9 10 476.34 568.47 660.82 753.50 845.59 11 12 13 14 15 938.68 1031.82 1125.77 1217.64 1310.95 16 17 18 19 20 1405.21 1497.62 1591.14 1685.92 1779.12 21 22 23 24 25 1873.13 1966.92 2059.97 2153.18 2246.16 26 27 28 29 30 2340.39 2432.99 2527.15 2619.96 2713.51 ------ ------ Incl angle (deg) ------ ------ 0.00 0.16 0.22 0.43 0.59 0.53 1.15 1.55 2.57 3.22 4.69 7.77 10.70 13.00 14.94 19.69 22.77 23.52 25.39 26.50 28.68 32.33 35.70 37.06 38.04 39.71 40.99 42.85 46.96 51.31 ------- ------- ------ ------ Azimuth Course angle length (deg) {ft} ------- ------- 70.00 115.56 200.01 167.97 128.52 120.84 71.01 57.49 62.12 68.80 71.90 72.47 70.66 70.06 72.97 74.86 72.92 71.25 69.93 68.54 65.91 64.84 64.70 64.67 64.40 62.63 62.86 63.87 64.86 64.63 ------ ------ 0.00 137.40 62.94 92.01 92.87 91.12 92.13 92.35 92.68 92.09 93.09 93.14 93.95 91.87 93.31 94.26 92.41 93.52 94.78 93.20 94.01 93.79 93.05 93.21 92.98 94.23 92.60 94.16 92.81 93.55 -------- -------- TVD depth ( ft) -------- -------- 0.00 137.40 200.34 292.35 385.21 476.33 568.45 660.78 753.39 845.37 938.23 1030.81 1123.53 1213.44 1303.99 1393.95 1480.08 1566.07 1652.35 1736.15 1819.47 1900.27 1977.38 2052.42 2126.14 2199.50 2270.07 2340.13 2405.85 2467.04 ~. 3-Aug-2002 09:09:39 -------- -------- Vertical section (ft) -------- -------- 0.00 0.17 0.20 0.17 0.58 1.27 2.51 4.50 7.50 11.85 18.03 27.84 42.42 60.56 82.35 109.76 142.44 178.08 215.85 254.84 295.99 340.47 388.90 440.33 492.99 547.53 602.52 660.49 721.29 787.11 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 -0.08 -0.23 -0.74 -1.38 -1.88 -1.80 -0.83 0.82 2.72 4.84 7.92 12.73 19.08 26.18 33.89 43.21 54.52 67.58 82.04 98.93 118.78 140.97 164.61 188.97 215.36 242.81 271.00 299.32 329.51 0.00 0.17 0.21 0.22 0.67 1.40 2.64 4.57 7.46 11.70 17.75 27.38 41.67 59.43 80.80 107.76 139.89 174.86 211.86 249.98 290.10 333.36 380.44 430.42 481.58 534.50 587.79 644.03 703.09 767.06 --------------- --------------- Page Total displ (ft) At Az im (deg) --------------- --------------- 0.00 0.19 0.32 0.77 1.53 2.35 3.20 4.64 7.51 12.01 18.40 28.50 43.57 62.42 84.93 112.96 146.41 183.17 222.38 263.10 306.50 353.89 405.72 460.82 517.33 576.25 635.97 698.72 764.15 834.84 0.00 115.56 137.99 163.22 154.07 143.43 124.34 100.29 83.76 76.93 74.74 73.86 73.01 72.20 72.05 72.54 72.83 72.68 72.31 71.83 71.17 70.39 69.67 69.07 68.57 68.05 67.55 67.18 66.94 66.75 2 of 5 ----- DLS (deg/ 100f) 0.00 0.12 0.41 0.29 0.40 0.11 0.98 0.55 1.11 0.79 1.60 3.31 3.13 2.51 2.21 5.07 3.42 1.07 2.06 1.36 2.66 3.93 3.62 1.46 1.07 2.13 1.39 2.10 4.49 4.65 .~ ----- ------ ------ Srvy tool type Tool qual type ----- ------ ------ TIP MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~. MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFRjISA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ,...-.,,,,, MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -, ~, .~ ANADRILL SCHLUMBERGER Survey Report 3-Aug-2002 09:09:39 Page 3 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azirn (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2807.36 54.71 63.60 93.85 2523.50 856.55 362.24 834.48 909.71 66.53 3.73 MWD_IFR_MSA 32 2901.20 55.14 64.72 93.84 2577.43 927.72 395.71 903.60 986.45 66.35 1.08 MWD_IFR_MSA 33 2978.48 54.31 64.81 77.28 2622.06 986.44 422.61 960.67 1049.51 66.25 1.08 MWD_IFR_MSA 34 3077.32 53.92 64.92 98.84 2679.99 1061.02 456.62 1033.16 1129.57 66.16 0.40 MWD_IFR_MSA 35 3170.45 54.47 65.19 93.13 2734.48 1131.45 488.48 1101.65 1205.09 66.09 0.64 MWD_IFR_MSA ~.. 36 3263.56 54.83 64.60 93.11 2788.35 1202.20 520.70 1170.42 1281.02 66.02 0.65 MWD_IFR_MSA 37 3357.32 55.04 65.18 93.76 2842.22 1273.68 553.26 1239.91 1357.74 65.95 0.55 MWD_IFR_MSA 38 3451.35 55.29 65.40 94.03 2895.93 1345.77 585.53 1310.02 1434.92 65.92 0.33 MWD_IFR_MSA 39 3545.54 55.00 65.32 94.19 2949.76 1418.00 617.75 1380.27 1512.21 65.89 0.32 MWD_IFR_MSA 40 3637.88 55.38 65.45 92.34 3002.47 1488.85 649.33 1449.20 1588.02 65.86 0.43 MWD_IFR_MSA 41 3731.55 55.44 65.73 93.67 3055.65 ,1561.02 681.20 1519.42 1665.13 65.85 0.25 MWD_IFR_MSA 42 3825.93 55.86 65.91 94.38 3108.90 1634.06 713.11 1590.50 1743.05 65.85 0.47 MWD_IFR_MSA 43 3919.68 56.20 65.52 93.75 3161.28 1706.88 745.09 1661.37 1820.80 65.84 0.50 MWD_IFR_MSA 44 4013.26 56.28 65.72 93.58 3213.29 1779.70 777.20 1732.23 1898.60 65.84 0.20 MWD_IFR_MSA 45 4107.16 56.08 64.60 93.90 3265.55 1852.50 809.97 1803.03 1976.60 65.81 1.01 MWD_IFR_MSA 46 4199.16 55.94 64.02 92.00 3316.98 1923.27 843.04 1871.77 2052.86 65.75 0.54 MWD_IFR_MSA 47 4290.62 54.79 63.06 91.46 3368.96 1992.71 876.57 1939.14 2128.05 65.68 1.53 MWD_IFR_MSA 48 4383.94 53.31 62.22 93.32 3423.75 2061.94 911.28 2006.23 2203.49 65.57 1.75 MWD_IFR_MSA 49 4477.17 51.73 62.19 93.23 3480.48 2129.52 945.78 2071.68 2277.35 65.46 1.69 MWD_IFR_MSA ~ 50 4570.98 50.45 63.41 93.81 3539.40 2196.50 979.15 2136.59 2350.27 65.38 1.70 MWD_IFR_MSA 51 4664.97 50.11 63.79 93.99 3599.46 2263.23 1011.29 2201.35 2422.53 65.33 0.48 MWD_IFR_MSA 52 4758.19 50.53 67.91 93.22 3659.00 2330.46 1040.63 2266.79 2494.24 65.34 3.43 MWD_IFR_MSA 53 4851.24 51.31 72.37 93.05 3717.68 2399.84 1065.14 2334.70 2566.19 65.48 3.81 MWD_IFR_MSA 54 4944.31 51.88 76.12 93.07 3775.50 2471.17 1084.93 2404.87 2638.27 65.72 3.22 MWD_IFR_MSA 55 5036.90 50.29 79.97 92.59 3833.68 2542.45 1099.87 2475.32 2708.68 66.04 3.66 MWD_IFR_MSA 56 5131.50 50.62 86.73 94.60 3893.95 2615.23 1108.30 2547.70 2778.33 66.49 5.52 MWD_IFR_MSA 57 5224.91 50.56 92.59 93.41 3953.28 2687.21 1108.73 2619.82 2844.77 67.06 4.85 MWD_IFR_MSA 58 5318.48 49.79 93.25 93.57 4013.21 2758.58 1105.07 2691.58 2909.61 67.68 0.99 MWD_IFR_MSA 59 5412.11 49.15 94.19 93.63 4074.05 2829.14 1100.46 2762.60 2973.71 68.28 1.02 MWD_IFR_MSA 60 5505.56 47.35 94.24 93.45 4136.28 2898.17 1095.33 2832.13 3036.56 68.86 1.93 MWD_IFR_MSA ,..-.... ,,~ .~ ANADRILL SCHLUMBERGER Survey Report 3-Aug-2002 09:09:39 Page 4 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5599.32 46.76 93.82 93.76 4200.16 2966.17 1090.51 2900.59 3098.81 69.40 0.71 MWD_IFR_MSA 62 5693.31 47.06 94.77 93.99 4264.37 3034.13 1085.37 2969.03 3161.20 69.92 0.80 MWD_IFR_MSA 63 5787.93 50.93 96.46 94.62 4326.44 3104.55 1078.35 3040.07 3225.66 70.47 4.31 MWD_IFR_MSA 64 5883.43 52.32 97.95 95.50 4385.73 3178.04 1068.95 3114.34 3292.69 71.06 1.90 MWD_IFR_MSA 65 5977.27 51.95 98.39 93.84 4443.33 3250.52 1058.43 3187.68 3358.80 71.63 0.54 MWD_IFR_MSA ~, 66 6070.42 51.54 98.87 93.15 4501.00 3321.96 1047.45 3259.99 3424.14 72.19 0.60 MWD_IFR_MSA 67 6162.11 51.81 98.97 91.69 4557.86 3392.13 1036.30 3331.05 3488.53 72.72 0.31 MWD_IFR_MSA 68 6256.11 52.25 99.26 94.00 4615.69 3464.36 1024.56 3404.22 3555.06 73.25 0.53 MWD_IFR_MSA 69 6348.69 51.92 99.27 92.58 4672.58 3535.51 1012.80 3476.31 3620.84 73.76 0.36 MWD_IFR_MSA 70 6441.54 51.99 99.14 92.85 4729.81 3606.77 1001.10 3548.49 3687.00 74.25 0.13 MWD_IFR_MSA 71 6534.25 52.10 99.24 92.71 4786.83 3678.00 989.43 3620.65 3753.41 74.72 0.15 MWD_IFR_MSA 72 6627.32 53.00 98.66 93.07 4843.42 3750.07 977.93 3693.64 3820.90 75.17 1.09 MWD_IFR_MSA 73 6721.59 53.42 100.20 94.27 4899.88 3823.57 965.56 3768.11 3889.85 75.63 1.38 MWD_IFR_MSA 74 6814.11 52.46 103.60 92.52 4955.64 3894.63 950.36 3840.34 3956.18 76.10 3.11 MWD_IFR_MSA 75 6905.84 50.18 104.14 91.73 5012.97 3962.87 933.20 3909.85 4019.68 76.58 2.53 MWD_IFR_MSA 76 7000.24 47.64 105.15 94.40 5075.01 4030.37 915.22 3978.68 4082.59 77.05 2.81 MWD_IFR_MSA 77 7093.04 43.42 106.21 92.80 5140.01 4092.80 897.35 4042.43 4140.83 77.48 4.62 MWD_IFR_MSA 78 7187.05 39.70 109.74 94.01 5210.35 4150.72 878.18 4101.75 4194.70 77.92 4.67 MWD_IFR_MSA 79 7280.17 38.63 117.60 93.12 5282.59 4202.84 854.65 4155.53 4242.51 78.38 5.45 MWD_IFR_MSA ~~, 80 7372.88 36.19 121.73 92.71 5356.24 4249.84 826.84 4204.48 4285.01 78.87 3.77 MWD_IFR_MSA 81 7466.27 36.13 122.08 93.39 5431.64 4294.60 797.72 4251.25 4325.45 79.37 0.23 MWD_IFR_MSA 82 7562.89 36.11 122.38 96.62 5509.69 4340.67 767.34 4299.43 4367.37 79.88 0.18 MWD_IFR_MSA 83 7655.61 35.91 122.07 92.72 5584.69 4384.77 738.28 4345.55 4407.82 80.36 0.29 MWD_IFRjISA 84 7749.93 35.31 122.25 94.32 5661.37 4429.23 709.04 4392.04 4448.91 80.83 0.65 MWD_IFR_MSA 85 7842.18 34.55 121.56 92.25 5737.00 4472.13 681.13 4436.88 4488.86 81.27 0.93 MWD_IFR_MSA 86 7935.07 33.91 118.22 92.89 5813.81 4515.60 655.09 4482.16 4529.78 81.68 2.14 MWD_IFR_MSA 87 8025.74 32.37 118.97 90.67 5889.73 4557.46 631.37 4525.68 4569.51 82.06 1.76 MWD_IFR_MSA 88 8119.02 32.30 119.27 93.28 5968.54 4599.35 607.09 4569.27 4609.42 82.43 0.19 MWD_IFR_MSA 89 8212.23 32.70 120.33 93.21 6047.16 4641.07 582.20 4612.73 4649.32 82.81 0.75 MWD_IFR_MSA 90 8305.91 35.08 119.33 93.68 6124.92 4684.58 556.23 4658.04 4691.14 83.19 2.61 MWD_IFR_MSA ~ ,,-..., ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 96 97 98 99 100 101 -------- -------- 91 92 93 94 95 8399.22 8492.21 8586.16 8680.05 8773.09 8867.31 8960.00 9054.95 9146.99 9242.12 9298.48 Projected to TD 102 9370.00 ------ ------ Incl angle (deg) ------ ------ 34.25 33.38 32.46 32.25 32.98 33.24 33.37 33.21 32.92 32.27 31.81 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 119.59 118.88 119.17 114.08 109.50 109.88 109.53 108.46 108.96 109.01 110.00 31.81 110.00 ------ ------ 93.31 92.99 93.95 93.89 93.04 94.22 92.69 94.95 92.04 95.13 56.36 71.52 [(c)2002 Anadrill IDEAL ID6_1C_10J -------- -------- TVD depth (ft) -------- -------- 6201.66 6278.92 6357.78 6437.11 6515.49 6594.41 6671.88 6751.25 6828.38 6908.53 6956.31 7017. 08 ~" 3-Aug-2002 09:09:39 -------- -------- Vertical section (ft) -------- -------- 4728.97 4772.36 4815.28 4858.57 4903.79 4951.00 4997.68 5045.73 5092.13 5139.38 5166.84 5201.34 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) --------------- --------------- Page Total displ (ft) At Azim (deg) ---------------- ---------------- --------------- --------------- 530.13 504.85 480.08 457.57 438.99 421.65 404.49 387.52 371.42 354.75 344.76 4704.25 4749.41 4794.06 4838.93 4885.48 4933.93 4981.85 5031.13 5078.69 5127.15 5155.33 4734.03 4776.17 4818.03 4860.52 4905.16 4951.92 4998.24 5046.03 5092.25 5139.40 5166.85 331.87 5190.75 5201.35 83.57 83.93 84.28 84.60 84.87 85.12 85.36 85.60 85.82 86.04 86.17 86.34 5 of 5 ----- DLS (deg/ 100f) ----- 0.90 1.03 0.99 2.91 2.77 0.35 0.25 0.64 0.43 0.68 1.24 ~ ----- ------ ------ Srvy tool type Tool qual type ----- ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ,~, MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA 0.00 Projected bp L-103 Schlumberger Survey Report - Geodetic Report Date: 3-Aug-02 Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 86.340° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structu re 1 Slot: L -Pad 1 L -103 TVD Reference Datum: KB Well: L-103 TVD Reference Elevation: 78.400 ft relative to MSL Borehole: L -1 03 Sea Bed 1 Ground Level Elevation: 44.100 ft relative to MSL UWI/API#: 500292310100 Magnetic Declination: +25.835° Survey Name 1 Date: L-1031 August 3,2002 Total Field Strength: 57501.413 nT ~'\ Tort 1 AHD 1 DDII ERD ratio: 155.665° 15587.34 ft 16.0651 0.79E Magnetic Dip: 80.776° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: August 05, 2002 Location Lat/Long: N 70 21 2.578, W 149 1925.347 Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 5978312.770 ftUS, E 583296.820 ftUS North Reference: True North Grid Convergence Angle: +0.63691429° Total Corr Mag North .> True North: +25.835° Grid Scale Factor: 0.99990788 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I N/.S I E/-W I DLS Northing I Easting Latitude I Longitude (ft) to) to) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978312.77 583296.82 N 7021 2.578 W 1491925.347 137.40 0.16 115.56 137.40 0.17 -0.08 0.17 0.12 5978312.69 583296.99 N 7021 2.577 W 1491925.342 200.34 0.22 200.01 200.34 0.20 -0.23 0.21 0.41 5978312.54 583297.03 N 7021 2.575 W 1491925.341 292.35 0.43 167.97 292.35 0.17 -0.74 0.22 0.29 5978312.03 583297.05 N 7021 2.570 W 1491925.341 385.22 0.59 128.52 385.21 0.58 -1.38 0.67 0.40 5978311.40 583297.50 N 70 21 2.564 W 1491925.328 476.34 0.53 120.84 476.33 1.27 -1.88 1.40 0.11 5978310.90 583298.24 N 7021 2.559 W 149 1925.306 568.47 1.15 71.01 568.45 2.52 -1.80 2.64 0.98 5978311.00 583299.48 N 7021 2.560 W 149 1925.270 660.82 1.55 57.49 660.78 4.51 -0.83 4.57 0.55 5978311.99 583301.40 N 7021 2.569 W 149 1925.214 .~ 753.50 2.57 62.12 753.39 7.50 0.82 7.46 1.11 5978313.67 583304.27 N 7021 2.586 W 1491925.129 845.59 3.22 68.80 845.37 11.85 2.72 11.70 0.79 5978315.62 583308.49 N 7021 2.604 W 1491925.005 938.68 4.69 71.90 938.23 18.03 4.84 17.75 1.60 5978317.81 583314.52 N 7021 2.625 W 1491924.828 1031.82 7.77 72.47 1030.81 27.83 7.92 27.38 3.31 5978321.00 583324.11 N 7021 2.655 W 1491924.547 1125.77 10.70 70.66 1123.53 42.39 12.73 41.67 3.13 5978325.96 583338.34 N 7021 2.703 W 1491924.130 1217.64 13.00 70.06 1213.44 60.53 19.08 59.43 2.51 5978332.50 583356.03 N 7021 2.765 W 1491923.610 1310.95 14.94 72.97 1303.99 82.31 26.18 80.80 2.21 5978339.84 583377.32 N 7021 2.835 W 1491922.986 1405.21 19.69 74.86 1393.95 109.70 33.89 107.76 5.07 5978347.85 583404.19 N 7021 2.911 W 1491922.198 1497.62 22.77 72.92 1480.08 142.36 43.21 139.89 3.42 5978357.53 583436.21 N 7021 3.003 W 149 1921.259 1591.14 23.52 71.25 1566.07 177.99 54.52 174.86 1.07 5978369.23 583471.05 N 7021 3.114 W 1491920.237 L-103 ASP Final Survey.xls Page 1 of 4 8/5/2002-2:44 PM Grid Coordinates Geographic Coordinates Station 10 I MO I Incl I Azim I TVD I VSec I NI-S I EI.W I OLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (01100ft) (ftUS) (ftUS) 1685.92 25.39 69.93 1652.35 215.74 67.58 211.86 2.06 5978382.69 583507.90 N 7021 3.242 W 1491919.156 1779.12 26.50 68.54 1736.15 254.71 82.04 249.98 1.36 5978397.58 583545.85 N 7021 3.384 W 149 19 18.042 1873.13 28.68 65.91 1819.47 295.82 98.93 290.10 2.66 5978414.90 583585.77 N 7021 3.550 W 14919 16.869 1966.92 32.33 64.84 1900.27 340.26 118.78 333.36 3.93 5978435.24 583628.81 N 7021 3.746 W 14919 15.605 2059.97 35.70 64.70 1977.38 388.66 140.97 380.44 3.62 5978457.94 583675.63 N 7021 3.964 W 14919 14.229 2153.18 37.06 64.67 2052.42 440.05 164.61 430.42 1.46 5978482.14 583725.34 N 7021 4.196 W 14919 12.768 2246.16 38.04 64.40 2126.14 492.66 188.97 481.58 1.07 5978507.07 583776.22 N 7021 4.436 W 14919 11.273 2340.39 39.71 62.63 2199.50 547.15 215.36 534.50 2.13 5978534.04 583828.84 N 7021 4.695 W 149 199.726 ~ 2432.99 40.99 62.86 2270.07 602.09 242.81 587.79 1.39 5978562.08 583881.82 N 7021 4.965 W 149 198.168 2527.15 42.85 63.87 2340.13 660.01 271.00 644.03 2.10 5978590.89 583937.73 N 7021 5.243 W149196.525 2619.96 46.96 64.86 2405.85 720.76 299.32 703.09 4.49 5978619.86 583996.47 N 7021 5.521 W149194.799 2713.51 51.31 64.63 2467.04 786.53 329.51 767.06 4.65 5978650.75 584060.09 N 7021 5.818 W 149 192.929 2807.36 54.71 63.60 2523.50 855.90 362.24 834.48 3.73 5978684.23 584127.14 N 7021 6.140 W 149190.958 2901.20 55.14 64.72 2577.43 927.02 395.71 903.60 1.08 5978718.46 584195.88 N 7021 6.469 W 1491858.938 2978.48 54.31 64.81 2622.06 985.69 422.61 960.67 1.08 5978745.99 584252.64 N 7021 6.733 W 1491857.270 3077.32 53.92 64.92 2679.99 1060.21 456.62 1033.16 0.40 5978780.80 584324.75 N 7021 7.068 W 1491855.151 3170.45 54.47 65.19 2734.48 1130.58 488.48 1101.65 0.64 5978813.41 584392.87 N 7021 7.381 W 1491853.149 3263.56 54.83 64.60 2788.35 1201.27 520.70 1170.42 0.65 5978846.40 584461.27 N 7021 7.698 W 1491851.139 3357.32 55.04 65.18 2842.22 1272.70 553.26 1239.91 0.55 5978879.73 584530.38 N 7021 8.018 W 1491849.108 3451.35 55.29 65.40 2895.93 1344.72 585.53 1310.02 0.33 5978912.77 584600.13 N 7021 8.335 W 149 1847.059 3545.54 55.00 65.32 2949.76 1416.89 617.75 1380.27 0.32 5978945.77 584670.01 N 7021 8.652 W 149 1845.005 3637.88 55.38 65.45 3002.4 7 1487.69 649.33 1449.20 0.43 5978978.11 584738.58 N 7021 8.962 W 149 1842.991 3731.55 55.44 65.73 3055.65 1559.80 681.20 1519.42 0.25 5979010.75 584808.43 N 7021 9.276 W 149 1840.938 3825.93 55.86 65.91 3108.90 1632.78 713.11 1590.50 0.47 5979043.45 584879.15 N 7021 9.589 W 1491838.860 3919.68 56.20 65.52 3161.28 1705.55 745.09 1661.37 0.50 5979076.21 584949.65 N 7021 9.904 W 1491836.789 ~, 4013.26 56.28 65.72 3213.29 1778.31 777.20 1732.23 0.20 5979109.11 585020.15 N 70 21 10.219 W 1491834.717 4107.16 56.08 64.60 3265.55 1851.05 809.97 1803.03 1.01 5979142.66 585090.56 N 70 21 10.541 W 1491832.648 4199.16 55.94 64.02 3316.98 1921.77 843.04 1871.77 0.54 5979176.48 585158.92 N 70 21 10.866 W 1491830.638 4290.62 54.79 63.06 3368.96 1991.14 876.57 1939.14 1.53 5979210.75 585225.91 N702111.196 W1491828.669 4383.94 53.31 62.22 3423.75 2060.31 911.28 2006.23 1.75 5979246.21 585292.61 N702111.537 W1491826.708 4477.17 51.73 62.19 3480.48 2127.82 945.78 2071.68 1.69 5979281.43 585357.66 N 70 2111.876 W 14918 24.795 4570.98 50.45 63.41 3539.40 2194.74 979.15 2136.59 1.70 5979315.51 585422.20 N 70 21 12.204 W 149 1822.897 4664.97 50.11 63.79 3599.46 2261.42 1011.29 2201.35 0.48 5979348.37 585486.58 N 70 21 12.520 W 1491821.004 4758.19 50.53 67.91 3659.00 2328.60 1040.63 2266.79 3.43 5979378.43 585551.69 N 70 21 12.809 W 1491819.091 4851.24 51.31 72.37 3717.68 2397.93 1065.14 2334.70 3.81 5979403.69 585619.32 N 7021 13.049 W 1491817.106 L-1 03 ASP Final Survey.xls Page 2 of 4 8/5/2002-2:44 PM Grid Coordinates Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I N/-S I E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 4944.31 51.88 76.12 3775.50 2469.23 1084.93 2404.87 3.22 5979424.26 585689.26 N 70 21 13.244 W 14918 15.054 5036.90 50.29 79.97 3833.68 2540.48 1099.87 2475.32 3.66 5979439.98 585759.53 N 70 21 13.391 W 14918 12.995 5131.50 50.62 86.73 3893.95 2613.26 1108.30 2547.70 5.52 5979449.22 585831.81 N 70 21 13.473 W 1491810.879 5224.91 50.56 92.59 3953.28 2685.25 1108.73 2619.82 4.85 5979450.45 585903.91 N702113.477 W 149 188.771 5318.48 49.79 93.25 4013.21 2756.64 1105.07 2691.58 0.99 5979447.59 585975.70 N 70 21 13.441 W 149 186.674 5412.11 49.15 94.19 4074.05 2827.21 1100.46 2762.60 1.02 5979443.76 586046.76 N 70 21 13.395 W 149 184.598 5505.56 47.35 94.24 4136.28 2896.27 1095.33 2832.13 1.93 5979439.41 586116.33 N702113.345 W 149 182.566 5599.32 46.76 93.82 4200.16 2964.29 1090.51 2900.59 0.71 5979435.35 586184.84 N 70 21 13.297 W 149 180.565 5693.31 47.06 94.77 4264.37 3032.26 1085.37 2969.03 0.80 5979430.97 586253.33 N 70 21 13.246 W 1491758.564 5787.93 50.93 96.46 4326.44 3102.71 1078.35 3040.07 4.31 5979424.74 586324.43 N 70 2113.177 W 1491756.488 5883.43 52.32 97.95 4385.73 3176.23 1068.95 3114.35 1.90 5979416.17 586398.80 N 70 21 13.084 W 1491754.317 5977.27 51.95 98.39 4443.33 3248.74 1058.43 3187.68 0.54 5979406.46 586472.23 N 70 21 12.980 W 1491752.174 6070.42 51.54 98.87 4501.00 3320.21 1047.45 3259.99 0.60 5979396.29 586544.66 N 70 21 12.872 W 1491750.060 6162.11 51.81 98.97 4557.86 3390.41 1036.30 3331.06 0.31 5979385.93 586615.84 N 70 21 12.762 W 1491747.983 6256.11 52.25 99.26 4615.69 3462.68 1024.56 3404.22 0.53 5979375.01 586689.12 N 70 21 12.646 W 1491745.845 6348.69 51.92 99.27 4672.58 3533.87 1012.80 3476.31 0.36 5979364.05 586761.33 N 70 2112.530 W 1491743.738 6441.54 51.99 99.14 4729.81 3605.16 1001.10 3548.49 0.13 5979353.16 586833.63 N 70 2112.415 W 14917 41.628 6534.25 52.10 99.24 4786.83 3676.43 989.43 3620.65 0.15 5979342.29 586905.91 N 70 21 12.300 W 1491739.519 6627.32 53.00 98.66 4843.42 3748.53 977.93 3693.64 1.09 5979331.61 586979.01 N 70 2112.186 W 14917 37.386 6721.59 53.42 100.20 4899.88 3822.06 965.56 3768.11 1.38 5979320.07 587053.61 N 70 21 12.064 W 1491735.210 6814.11 52.46 103.60 4955.64 3893.17 950.36 3840.34 3.11 5979305.66 587125.99 N 70 2111.915 W 14917 33.099 6905.84 50.18 104.14 5012.97 3961.45 933.20 3909.85 2.53 5979289.28 587195.69 N 70 2111.745 W 14917 31.067 7000.24 47.64 105.15 5075.01 4028.99 915.22 3978.69 2.81 5979272.07 587264.71 N 702111.568 W 14917 29.056 7093.04 43.42 106.21 5140.00 4091.47 897.35 4042.43 4.62 5979254.91 587328.65 N 70 2111.392 W 14917 27.193 7187.05 39.70 109.74 5210.35 4149.44 878.18 4101.75 4.67 5979236.40 587388.17 N 70 2111.203 W 1491725.459 7280.17 38.63 117.60 5282.59 4201.62 854.65 4155.54 5.45 5979213.48 587442.21 N 70 21 10.972 W 1491723.887 7372.88 36.19 121.73 5356.24 4248.68 826.84 4204.48 3.77 5979186.22 587491.45 N 70 2110.698 W 1491722.457 7466.27 36.13 122.08 5431.64 4293.51 797.72 4251.26 0.23 5979157.62 587538.55 N 7021 10.411 W 149 1721.091 7562.89 36.11 122.38 5509.68 4339.65 767.34 4299.44 0.18 5979127.78 587587.06 N 70 2110.112 W 1491719.683 7655.61 35.91 122.07 5584.69 4383.82 738.28 4345.55 0.29 5979099.23 587633.49 N 7021 9.826 W 14917 18.336 7749.93 35.31 122.25 5661.37 4428.35 709.04 4392.04 0.65 5979070.52 587680.30 N 7021 9.538 W 14917 16.977 7842.18 34.55 121.56 5737.00 4471.31 681.13 4436.88 0.93 5979043.11 587725.44 N 7021 9.263 W 14917 15.667 7935.07 33.91 118.22 5813.81 4514.84 655.08 4482.16 2.14 5979017.57 587771 .00 N 7021 9.007 W 14917 14.344 8025.74 32.37 118.97 5889.73 4556.76 631.37 4525.68 1.76 5978994.34 587814.78 N 7021 8.774 W 14917 13.072 8119.02 32.30 119.27 5968.54 4598.70 607.09 4569.27 0.19 5978970.55 587858.63 N70218.534 W1491711.799 L-103 ASP Final Survey.xls Page 3 of 4 8/5/2002-2:44 PM Grid Coordinates Geographic Coordinates Station 10 I MO I Incl I Azim I TVO I VSec I N/.S I E/.W I OLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8212.23 32.70 120.33 6047.16 4640.48 582.20 4612.73 0.75 5978946.15 587902.36 N 70 21 8.289 W 14917 10.529 8305.91 35.08 119.33 6124.91 4684.05 556.23 4658.04 2.61 5978920.69 587947.96 N 7021 8.034 W 149 179.205 8399.22 34.25 119.59 6201.66 4728.50 530.13 4704.25 0.90 5978895.10 587994.45 N 7021 7.777 W 149 177.855 8492.21 33.38 118.88 6278.92 4771.95 504.85 4749.41 1.03 5978870.33 588039.88 N 7021 7.528 W 149 176.536 8586.16 32.46 119.17 6357.78 4814.92 480.08 4794.06 0.99 5978846.06 588084.79 N 7021 7.284 W 149 17 5.231 8680.05 32.25 114.08 6437.11 4858.28 457.57 4838.94 2.91 5978824.06 588129.92 N 7021 7.062 W 149 173.920 8773.09 32.98 109.50 6515.49 4903.54 438.99 4885.48 2.77 5978805.99 588176.66 N 7021 6.879 W 149172.560 8867.31 33.24 109.88 6594.41 4950.79 421.65 4933.93 0.35 5978789.19 588225.30 N 7021 6.708 W 149171.144 8960.00 33.37 109.53 6671.88 4997.51 404.49 4981.85 0.25 5978772.57 588273.40 N 7021 6.539 W 149 16 59.744 9054.95 33.21 108.46 6751.25 5045.60 387.52 5031.13 0.64 5978756.15 588322.85 N 7021 6.372 W 1491658.304 9146.99 32.92 108.96 6828.38 5092.04 371.42 5078.69 0.43 5978740.58 588370.59 N 7021 6.213 W 1491656.915 9242.12 32.27 109.01 6908.53 5139.34 354.75 5127.15 0.68 5978724.45 588419.22 N 7021 6.049 W 149 1655.499 9298.48 31.81 110.00 6956.31 5166.82 344.76 5155.33 1.24 5978714.78 588447.51 N 7021 5.951 W 149 16 54.675 9370.00 31.81 110.00 7017.08 5201.35 331.87 5190.76 0.00 5978702.28 588483.08 N 7021 5.824 W 1491653.640 L-103 ASP Final Survey.xls Page 4 of 4 8/5/2002-2:44 PM bp VERTICAL Client: Well: Field: Structure: Section At: SECTION VIEW BP Exploration Alaska L-I03 Prudhoe Bay Unit - WOA L-pad 86.34 deg August 05, 2002 Schlumberger Date: 0 --~-------t-----------~-~-'r-_n__~___'-O' ,--,-,--------------",--,----'~'--",---~-____~_n_~_'_'--'-!- -_____,n,- ..-- ' I ' t------~------~--------------------~------1------- j I j ~---------------------------4------~------~------ ì ! : ¡ ~ ........ - - - t = = = ;; ;; ;; ;; ;; ;; ;; ;; ;; = =' ;;;;;;;;;;;;;;;;;;;;;;;; d ;; ;; ;; ;; ;; ;; d ;; ;; ;; ;; ;; ;; ~;; ;; ;; - - - ~ ~ 2000 -= = ::'::' = -= = = = = = = = = = = = = = ~;-:.c=- = ::'::'~::'- = = =::'- = ~ - ::'c=-~~::' -::' f::,::, = = = = ::,1 ::' = = = = :: ~II :0> = = = =1 - - - = = = = = = = = = = - - þ - - - - - = = = = = J, = = = = = = j, = - - - - - -: - - - ~ I -~-!--- c~ ---t-- -------- -------~------~------ ~ã I I :ê ; 4000 ------i,! -- "'-- -- - - - - - - - - - - - - --,---"--=-=--=-=-= = ~= = = - - - g~ ---t ==========----- ---- -~======~===--- ~~ ---+---------------------- --~------~------ .~ 'ã5 - - - 1- - - - - - - - - - - - - - -l - - - - - - -i - - - ~~ : ! > > ___1_____- ()) ~ 6000- I ::J 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I 1 I i 8000 ---~-+--_____~n_n__n_~:-'---__------- I I -4000 .~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~-~ ~ ~ ~ ~ ~ ; ~j~,iI~~-l;~t~~ ~ : ~ ~ I 2000 I 4000 ---~+-~- i -------~-------~--~-~~ --, ~----i--~_._-- I -2000 I 0 ~ 6000 I 8000 I 10000 Vertical Section Departure at 86.34 deg from (0.0, 0.0). (1 in = 2000 feet) bp PLAN VIEW Client: BP Exploration Alaska Well: L-I03 Field: Prudhoe Bay Unit - WOA Structure: L-pad Scale: 1 in = 1000 ft Date: 05-Aug-2002 ^ ^ ^ ::r:: l- e::: 0 z -1 000 , 3000 --+-- - --~---------,- - I I i I I I I I i I 2000 -- ~---- I I I i ¡ '--------"---'------------'-~-'-'---~-~-----"---"-'-----¡------' 0 1000 --l----------,---~----- i True North Mag Dee ( E 25.84° ) 2000 I 3000 I 4000 I ,-~-+----~~---- -, - -~--~-----~----------~-------~-~._--~~__~__-m.____- --~-- 5000 , i i - Schlumberger 6000 1000-+--- --.-. ----- --~- - -----~----- 0- '-1--- !- I I ,/' . 1& - J i I I ~ o_~- ----~ -~-~-------:----J--- -- ---__~O;:3(P: I ! ::r:: I- :::> 0 C/) V ~ i -1000 --+-------' I ! --~--------~--_.._---------_...~-~---~------~-- - i -! ------ -----------~~~ --- i I -1 000 I 1000 I 2000 «< WEST I 3000 I 4000 EAST »> 0 t 5000 I I 6000 - 3000 -~ - 2000 - 1000 -0 - -1000 Sc~IUllbepgep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth -~. Well L-103 dOS...¡gq S-112 ~O~../~c; S-113 aOd.-/4~ &~~' Job# 22367 USIT 22368 USIT 22369 SCMT Log Description 08/06/02 08/03/02 07/28/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED AUG 20 2002 Alaska 011 & Gas Cons. CommjssÎan Anchorage Date 8/19/2002 NO. 2329 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Color Sepia BL CD 2 2 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth ReC~Y: ~J)OI1f4Å ) a~-13C¡ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No L-103i Installation/Rig Nabors 9ES Data Su rveys Received By: ~(i ~p'~J LWD Log Delivery V1.1 , Dec '97 Dispatched To: Lisa Weepie Date Dispatche 6-Aug-02 Dispatched By: Nate Rose No Of Prints No of Floppies 2 j,v,o...,r h'j,:; . i Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com ~\~^ ~rs LJ ,j lbr" . ~ ¡ ... "-, t 0 ~r @ ~ IL\,~ ~ ra ff0\ 0 U W LSLn.J DJ) Lü/J ù l í I / / / .I TONY KNOWLES, GOVERNOR AIfA~1iA. OIL AND GAS CONSERVATION COMMISSION ,- I ! ! 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit L-1 03i BP Exploration (Alaska) Inc Permit No: 202-139 Sur. Loc. 2590' NSL, 3618' WEL, Sec. 34, T12N, RIlE, UM Btmhole Loc. 2929' NSL, 3744' WEL, Sec. 35, T12N, RIlE, UM Dear Mr. Crane, 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 or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Admiriistrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. A diverter waiver has been requested for Well L-103i for drilling the shallow section to a depth of approximately -2570' TVDss. The L-Pad in the western portion of the Prudhoe Bay Unit is located over a thick accumulation of sub-permafrost methane hydrates that are underlain by a significant accumulation of free hydrocarbon gas. The shallow section in the well would include the interval containing the methane hydrates, but not the underlying free gas accumulation. At least fifteen wells have been drilled from L-Pad, which demonstrates the shallow section can be successfully drilled without a diverter by using specialized mud treatments and drilling procedures. Therefore, the diverter waiver for well PBU L-I03i is approved provided BPXA employs a high-resolution, early kick detection system in addition to the other hydrate mitigation procedures described in the permit to drill application for the subject well. Commission approval of the diverter waiver for PBU L-103i does not guarantee approval of future diverter waiver requests on this or any other drill site. Diverter waiver applications will continue to be carefully considered on a case-by-case basis. Permit No. 202-139 July 2, 2002 Page 2 of2 t The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Ú/v QuJ,~ r, fJ I Camm~ChS¡i Tay¡:r Chair BY ORDER OF THE COMMISSION DATED this ~;Jv day of July, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. k1~Æ- 711/tPL Hole 42" 12-1/4" 8-3/4" STATE OF ALASKA ALASKAl.,- AND GAS CONSERVATION COMr1~ JION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil iii Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 78.4' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028238 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number L.103i 9. Approximate spud date 07/12/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9244' MD / 6937' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 54 0 Maximum surtace 2724 psig, At total depth (TVD) 6650' I 3388 psig Setting Depth T0P Botom MD TVD MD TVD Surface Surface 110' 110' Surface Surface 2864' 25781 Surface Surface 92441 69371 ~ -r/f 1 a. Type of work iii Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2590' NSL, 3618' WEL, SEC. 34, T12N, R11 E, (As Staked) At top of productive interval 3092' NSL, 4077' WEL, SEC. 35, T12N, R11E, UM At total depth 2929' NSL, 3744' WEL, SEC. 35, T12N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well . ADL 028239,1535' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casing Weiaht Grade CouDlinQ 34" x 20" 91.5# H-40 WLD 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-m 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Lenath 80' 2834' 9214' Quantitv of Cement (include stage data) 260 sx Arctic Set (Approx.) 497 sx PF ILl, 260 sx Class IG' 286 sx Class IG', 311 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECE\VED JUN 27 2002 Perforation depth: measured Alaska Oil & Gas Gons. Commission , Anchorage true vertical iii Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch iii Drilling Program B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jame ranks, 564-4468 Prepared By Name/Number: Sandra Stewman, 564-4750 21. ~~;~:y c~:~ ;::t, the f~r~¿~~.t:~h~~~~O~;;~~;~~;~~;':~~~~:~,~," ... Date ,. !:..;~:~l:. ..(,A':::;;;,,:t,\.(;';'?~:::/'::::¡'~',~;:¡,':;';¡;¡,::i",~;:;¡!/:{:':';:::::~~m~~jpp:ii;I~'¡iØñb~;:~:':!:::'i:?,;::,::\/!,:W:,',¡:";:',' "'<";;,",, ': ,'" , ",,', ,'"~ " ',' " " Permit Number. . API Number , I #~'~I)ò~te See cover letter Zð 2, -/3, 50- 0 z. 9 - ¿ 3 /0 ~~:?I 't/ b)-.... for other requirements Conditions of Approval: Samples Required 0 Yes B No Mud Log Re uired 0 Yes ØI No Hydrogen Sulfide Measures 0 Yes ID No Directional Survey Required BYes 0 No Require! Working Press~re for BOPE 02K: 03K 04K 0 5K q~10K 015K .0 3.5K psi for CTU Other' I ~ t- B 0 e t;- ~ 4- 000 (JC~. i4r TJ ~1.tf ~ f.£IL{;,~ 1O1 ~'WL"'-l~J .~ Pw W !tAl1.SeO'3c; (kJ"( t] dl.\Í.e.v~ riÓl4Mwl.€4 wcu..\ttd . by dlder of TV( U -¡ /'1 I~I'J Approved By J Commissioner the commission Date / 1'0"/ (/ ",,¿... Form 10-401 Rev. 12-01-85 0 ,~ i GIN A ~ ub it In Triplicate 20. Attachments { IWell Name: I L-1 03i Drill and Complete Plan Summary I Type of Well (service I producer I injector): Injector Surface Location: As Staked - slot N-S Target Location: Top Schrader Bluff Target Location: Top Kuparuk Bottom Hole Location: x = 583,296.25' Y = 5,978,312.95' 25901 FSL (26591 FNL), 36181 FEL (16611 FWL), Sec. 34, T12N, R11E X = 586,410' Y = 5,979,400' 36421 FSL (1637' FNL), 490' FEL (47891 FWL), Sec. 34, T12N, R11 E X = 588,110' Y = 5,978,870' 30921 FSL (21871 FNL), 4077' FEL (12021 FWL), Sec. 35, T12N, R11 E X = 588,444.61' Y = 5,978,710.61' 29291 FSL (23511 FNL), 37441 FEL (15351 FWL), Sec. 35, T12N, R11E I AFE Number: I BR5M4015 I 1 Estimated Start Date: 17/12/2002 I I MD: 19244' I TVD: 16937' I I RiQ: I Nabors 9ES I OperatinQ days to complete: 115.5 I BF/MS: 149.9' I I RKB: 178.4' I Well DesiQn (conventional, slim hole, etc.): I Ultra Slimhole (Iongstring) Objective: Schrader/Kuparuk Formation. This well is designed so that injection may be accomplished into the Schrader Bluff and Kuparuk formations. The Kuparuk is the primary target and the Schrader is a future contingency. Mud Program: 12 1A" Surface Hole (0-2864'): Densitv (ppg) 8.5 - 9.2 9.0 - 9.5 9.5 max / 8 3.4" Production Hole (2864' - 9244): Interval Density Tau 0 YP (ppg) 9.3-9.7 10.1 j' Initial Base PF to top SV SV toTO Upper Interval Top of HRZ toTO L-103i Drilling Program Viscosity (seconds) 250-300 200-250 150-200 4-7 25-30 4-7 20-30 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft:¿) (mls/30min) 50 - 70 15 - 20 8.5-9.5 30 - 45 <10 8.5-9.5 20 - 40 <5 8.5-9.5 LSND PV pH API HTHP Filtrate Filtrate 8-12 8.5-9.5 6-10 8-14 8.5-9.5 4-6 <10 by HRZ Page 1 ( ( Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1785 560 4" 17.5# 70 1500 10.0 N/A 20,20,20,16 1.117 1785-2,864' 700 4" 17.5# 90 2100 10.2 N/A 20,20,20,16 1.117 Production Hole: 8 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2864' - 9244' 650 4" 17.5# 270 2800 11.3 10 6x15 1.112 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110'-2864' Surface Superior hole cleaning practices at to SV-1 connections will greatly enhance cuttings transport in the sliding mode 165 60 500 9.5 Acceptable 210 60 600 9.5 Acceptable 180 80 500 9.5 Acceptable 220 80 600 9.5 Acceptable 260 80 700 9.5 Acceptable 190 100 500 9.5 Acceptable 225 100 600 9.5 Acceptable 265 100 700 9.5 Acceptable 2864'-9244' 9-5/8" to ROP's greater than 325'/hr require a TD G PM of 600 and 80 rpm along with sweeps and fully reamed connections to maintain minimum hole cleaning requirements 220 60 500 9.7 Acceptable 265 80 500 9.7 Acceptable 270 60 600 9.7 Acceptable 325 80 600 9.7 Acceptable 315 60 700 9.7 Acceptable 390 80 700 9.7 Acceptable 250 60 600 10.1 Acceptable L-103i Drilling Program Page 2 ( Directional: Ver. Anadrill P5 Slot NS KOP: 300' Maximum Hole Angle: Close Approach Wells: 54° at 4676' MD All wells pass major risk criteria. No special precautions are necessary. The Nearest Wells are: None L-119 - Center to center @ 29.6' - Allowable deviation @ 9.49' - 1054' MD L-120 - Center to center @ 104' - Allowable deviation @ 35.2' - 3751' MD IFR-MS corrected surveys will be used for survey validation. GyroData will be needed for surface hole close approaches to 1300'. Logging Program: Surface Drilling: Dir I GR Open Hole: Cased Hole: None Intermediate/Production Hole Drilling: Dir/G R/PW D/Dens/Neut/ AZM Dens Open Hole: Cased Hole: USIT cement evaluation Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV5 1581' 1480' SV4 1720' 1610' Base Permafrost 1765' 1670' SV3 2124' 1975' SV2 2326' 2140' SV1 2812' 2470' UG4A 3384' 2805' UG3 4014' 3175' UG1 4943' 3725' Ma 5238' 3910' WS2 Na 5548' 4105' WS1 Oa 5842' 4290' Potential Hydrocarbon 8.5 ppg EMW Obf Base 6478' 4690' CM2 (Colville) 6911' 4990' CM1 (Colville) 7708' 5625' THRZ 8248' 6056' BHRZ (Kalubik) 8485' 6245' K-1 8579' 6320' TKUP 8592' 6360' Hydrocarbon 8.3 ppg EMW Kuparuk C 8633' 6363' LCU (Kuparuk B) 8824' 6515' Kuparuk A 8993' 6650' Water 9.8 ppg EMW ' TMLV (Miluveach) 9094' 6730' TD Criteria 9244' 150' MD below Miluveach top L-103i Drilling Program Page 3 ( Casingrrubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size TbQ O.D. MD/TVD MDITVD bkb 42" 34"x20" 91.5# H-40 WLD 80' GL 11 0/11 0 12 %" 9 5/8" 40# L-80 BTC 2834' GL 2864'/2578' 8 3;4" 711 26# L-80 BTC-m 9214' GL 9244'/6937' Tubing 4 %11 12.6# L-80 TC-II 5058' GL 5088'/3870' Tubing 3 %11 9.2# L-80 TC-II 3353' 5088' 9244'6927' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min (50' max) from su rface shoe Test Type LOT EMW 12.3 ppg EMW Target 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. Casinq Size 19,.5/8" Surface I Basis: Lead: Based on 1784' of annulus in the permafrost @ 225°/0 excess and 369' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOC: To surface Tail: Based on 500' TVD (711' MD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2153' MD Total Cement Volume: Lead 368 bbl I 2064fe I 497 sks of Halliburton Permafrost L at 10.7 ppg and 4.15 dIsk. Tail 53 bbl I 299 fe I 260 sks of Halliburton Premium 'G' at 15.8 ppg and 1.15 dIsk. The 7" production casing will be cemented via an ES cementer in two stages. Casinq Size 17" Production Longstring 1 Basis: Stage 1: Based on TOC 1000' MD above top of Kuparuk + 300/0 + 80' shoe Cement Placement: From shoe to 7592' MD Stage 2: Based on TOC 500' MD above top of Schrader +300/0 excess volume Cement Placement: From 200' MD below Schrader 6678' MD to 4738' MD Total Cement Volume: Stage 1 60.6 bbls I 340 fe I 286 sks of Halliburton Premium "G" at 15.6 ppg and 1.19 dIsk. Stage 2 67.6 bbls 1379 fe I 311 sks of Halliburton Premium "G" at 15.6 ppg and 1.22 dIsk L-103i Drilling Program Page 4 ( Well Control: Surface hole will be drilled without diverter (diverter waiver has been requested). The intermediate/production hole, 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 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: . Maximum surface pressure: 3388 psi @ 6650' TVDss - Kuparuk A Sands 2724 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) ~ 4000 psi (The casing and tubing will be tested to 4000 psi as . Planned BOP test pressure: required for MI service.) . Planned completion fluid: 9.1 ppg filtered brine / 6.8 ppg diesel L-Pad wells have proven kick tolerances in the 25-55 bbl range. A heightened awareness of kick detection and pre-job planning will be essential while drilling/tripping in the productive intervals. Disposal: . No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. L-103i Drilling Program Page 5 ( DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor to be installed in July 2002. 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. Rig Operations: / 1. MIRU Nabors 9ES on Slot N-S. Diverter waiver has been requested. 2. Nipple up riser. PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/LWD assembly (page 4) and directionally drill surface hole to approximately 2864' MD 1 2578' TVD. Gyro to be run over the first 1300' of surface hole or until magnetic interferences dissipate. An intermediate wiperlbit trip to surface for a bit will be performed prior to exiting the Permafrost. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sand. 4. Run and cement the 9-5/8", 40# surface casing back to surface. 5. ND riser and NU casing 1 tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drilling assembly with MWD/LJ'D assembly (page 4) 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 9.3 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. . 8. Drill ahead and increase mud weight to 9.7 ppg prior to first wiper trip.! / 9. Drill to +1-100' above the HRZ, ensure mud is in condition to 10.1 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to TD at -9244'. 11. Condition hole for running 7" 26# long-string casing. This is to be done at Company Reps discretion. 12. Run and cement the 7" production casing in two stages utilizing a ES cementer. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 13. PU drill out assembly and drill out ES cementer. RIH to FC and test casing to 4000 psi. for 30 minutes. Cleanout casing utilizing seawater. After cleanout, displace well to 9.1 ppg brine and spot 9.1 ppg perf pill across the Schraçjer perforation interval. 14. RU Schlumberger and run USITíog on e-line from the 7" float collar to TOC. 15. Perforate Schrader interval DPC. 16. Make scraper run and POOH laying down excess drill-pipe. / 17. Run the combination 3-1/2" 9.3#, L-80 TC-II 1 4-1/2", 12.6#, L-80 TC-II completion assembly. Set packers and test the tubing to 4000 psi åfld annulus to 4000 psi for 30 minutes. Shear RP valve and install TWC. Test below to 2800 psi. ¡/ 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 19. RU hot oil truck and freeze protect well to lower GLM. 20. Rig down and move off. Estimated Spud Date: 7-12-2002 L-103i Drilling Program Page 6 (' (\ L-103i Hazards and Contingencies Job 1: MIRU Hazards and Contingencies >- L-Pad is not designated as an H2S site. None of the current producers on L-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ Due to the elevated landing ring height on L-Pad, the BOP stack will need to be run with a l' double flange adapter spool on bottom (13-5/8" x11") Reference RPs .:. UDrilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~~»>~i~"""1""",,,,,wv,.,,,~~~~~~,,,,,,,,,,,,,,,,,,- . ff,~"",;""",~~,'~~~,~,i~""~,~",,",':',,,,'_,~k~W1~ffi.,,;"",":,'-~'.I,,,'-~"~l1~,,,,,,,,,.,'.,'¡""'V"'.'_~ Job 2: DrillinQ Surface Hole ~ One 80' down thrown to the west fault is expected to be penetrated by L-103i in the surface interval @ 1165' MD +/-150'. No losses are anticipated. ~ All nearby wells pass major risk criteria. The closest existing well, L-119 is 29.6' center-center at -1050' MD. A GyroData survey will be utilized while drilling the surface hole until 1300' MD or clear of magnetic intereference. ~ Gas hydrates have been observed on all wells drilled on L-Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation >- Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. ~ Based on pore pressure data and experíence gained on the Borealís L-pad wells (and previous L- pad Ivishak well) the AOGCC has been asked for dispensation from the diverter requirement on the 12 1,~" surface hole. During the Surface Hole Planning Meeting and PJSM's the absence of a diverter on the surface hole on this well is to be discussed. Monitoring the hole, checking connections, importance of maintaining mud properties (including pre-treating with DrillTreat for Hydrates), focus on avoiding swabbing situations, importance of not loading up the hole (hole cleaning), evacuation drills, muster areas, etc. should be topics for discussion and action. The waiver has been justified based on extensive penetrations below "L" pad with no shallow gas problems and L-106 open hole surface logging. The absence of the ability to divert requires even greater diligence while drilling the surface hole. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations ~;mw~~mm!õ~ L-103i Drilling Program Page 7 ( Job 3: Install Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 225% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at :1:1 OOO'MD to allow remedial cementing. Notify AOGCC for witness if TAM port collar is required to circulate cement to surface. ~ Regularly monitor the cement top post job in the 9-5/8" x 20" annulus while rig is on the pad. Notify AOGCC and conduct Top Job if necessary. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Halliburton Cement Program" .:. "Surface Casing Port Collar Procedure" »~;A~~H_"'~"'__»¡'~~;;"'l, --¡.~m¡.»»»'PJ': m"",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, Job 7: DrillinQProduction Hole Hazards and Contingencies ~ KICK TOLERANCE: In the case scenario of 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.3 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 25.6 bbls. LOT's of 13.5ppg (L-01), 15.4ppg (L-116), 15.6 ppg (L-114), 13.7ppg (L-110), 13.8ppg (L-107), 15.2 ppg (L106), 13.2 ppg (L-115), 13.8 ppg (L-120) and 13.1 ppg on L-104 have been recorded in offset L-Pad wells. An accurate lOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 12.3 ppg. ~ l-Pad development wells have "kick tolerances" in the 25-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals ÞO- There are no "close approach" issues with the production hole interval of L-1 03i. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HrZ" L-103i Drilling Program Page 8 ( t Job 9: Case & Cement Production Hole Hazards and Contingencies ~ At the Company Representatives discretion, a hole conditioning trip may be run prior to running longstring. ~ The 7" casing is expected to be cemented to 500' MD above the top Schrader productive sand in a two stage job. The first stage will cover from TO to 500' TVD above the Kuparuk and the second stage will cover from 200' MD below the Schrader to 500' MD above the Schrader. ~ Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with +/-56 bbls of diesel/dead crude (2000'), the hydrostatic pressure will be 10.1 ppg vs the 9.8 ppg EMW of the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude however the hydrostatic pressure of the mud and diesel should exert a 46 psi overbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ~ A cement bond log (USIT) will be run to confirm the TOC and job quality. This will be done with the rig prior to perforating and running the completion. ~ Ensure a minimum hydrostatic equivalent of 10.1 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be issued detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. IIlntermediate Casing and Cementing Guidelines" .:. IIHalliburton Cement Program" Attached. .:. IIFreeze Protecting an Outer Annulus" Job 10: Perforate Well Hazards and Contingencies ~ The Schrader interval of the well will be DPC perforated prior to running the completion. After placing a brine perf pill weighte~,,!8'~'i;~~' ppg the well will be perforated across an 8.5 ppg EMW reservoir for an overbalance of~ll~i~. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. ~ A US IT log will be required from the ETD to the top of cement. Send results of USIT log into Anchorage office as soon as practical for evaluation. Notify Bruce Smith and Donn Schmohr immediately upon obtaining results of USIT log for review of possible remedial cement work. Reference RPs .:. See attached Initial Perforating Procedures ~~~ L-103i Drilling Program Page 9 (' ( Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The Schrader interval of the well will be perforated. ~ Take care while passing through ES cementer with packer and completion string. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus ~WWI.I.mH!m_~"".""''''''''«I.:_m_.m._L.I.:_II-JI.:.-.T"'1.-,---,-" I.!.I.II~""..:!_.¡'~'.U."'~"".::..",-,.:.~}-,-.,,_I.. -.W""'''''-''.'-''.;'".;'.;-;-:'' Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus ~"1S~-"""'''''':'''''''''''''''';'::',-.,.. ~~-~:"'..::;;.;~., L-103i Drilling Program Page 10 \ \ Proposed L-103i Completion TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = 49.9' RKB-MSL = 78.4' I i 4-112" 'X' Landing Nipple with 3.813" seal bore. I 2218' I 9-5/8",40 #/ft, L-80, BTC ~ ~ 2864' Gas Lift Mandrels with handling pups installed. L GAS LIFT MANDRELS TVD Type I Valve Type # 1 2 3 4 5 3-1/2" MMGW 3-1/2" MMGW 4-1/2" KBG-2 4-1/2" KBG-2 4-1/2" KBG-2 Dummy Dummy RP Dummy Dummy 4000' 3500' L 4-1/2" 'X' Landing Nipple with 3.813" seal bore approx 10' above packer ~~ ~ 4-112" 12.6# L-80, TC-II Tubing . lEI 7" x 4-1/2" Baker "Premium" ~ Production Packer with anchor 200' above Schrader productive interval with 6' pup below and full 30' joint below. 3-1/2" MMGW Water Flood GLM ~ with Injection Valve with New - Vam BxP L 3-1/2" TC-II 9.3 # L-80 Tubing below top packer ---- -!:-- Schrader Perforations: ??? 1r 3-1/2" 'X' Landing Nipple with 2.813" seal bore 7" x 4-1/2" Baker "S-3" Packer 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" 'XN' Landing Nipple with 2.75" seal bore 3-1/2" WireLine Entry Guide set at 150' above Kuparuk Plug Back Depth I 7",26 #/ft, L-80, BTC-Mod ~., I 9164' :~ 92441 Date 06/26/02 Rev By jdf Comments Borealis WELL: L-103i API NO: 50-?? Proposed Completion (P6) BP Alaska - - - I KBE Bid 1.5/100 G1 SV6 SV5 Report Date: Client: Field: Structure 1 Slot: Well: Borehole: UWI/API#: Survey Name 1 Date: Tort 1 AHD 1 DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: L-103 Proposed Well Profile - June 18, 2002 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) L-Pad / L-103 L-103 L-103 50029 L-103 (P6) / June 18, 2002 99.250° / 5538.99 ft / 5.865 /0.80C NAD27 Alaska State Planes, Zone 4, US Fee1 N 70.35071663, W 149.32371178 N 5978313.000 ftUS, E 583296.300 ftUS +0.63691034° 0.99990788 Geodetic Report Schlumbøruør Minimum Curvature / Lubinski 86.220° N 0.000 ft, E 0.000 ft KB 77.5 ft relative to MSL 44.100 ft relative to MSL 25.851° 57500.760 nT 80.776° July 20, 2002 BGGM 2002 True North +25.851° Well Head "-k III Fea51 Survey 1 DLS Computation Method: Vertical Section Azimuth: dy Vertical Section Origin: II1II IIIIIty I . TVD Reference Datum: I st. TVD Reference Elevation: II Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Grid Coordinates Geographic Coordinates MD Incl I Azim TVD VSec N/-S E/.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 70.00 0.00 0.00 0.00 0.00 0.00 5978313.00 583296.30 N 70.35071663 W 149.32371178 300.00 0.00 70.00 300.00 0.00 0.00 0.00 0.00 5978313.00 583296.30 N 70.35071663 W 149.32371178 327.50 0.41 70.00 327.50 0.10 0.03 0.09 1.50 5978313.03 583296.39 N 70.35071671 W 149.32371105 400.00 1.50 70.00 399.99 1.26 0.45 1.23 1.50 5978313.46 583297.52 N 70.35071786 W 149.32370179 500.00 3.00 70.00 499.91 5.03 1.79 4.92 1.50 5978314.84 583301.20 N 70.35072152 W 149.32367184 600.00 4.50 70.00 599.69 11.31 4.03 11.06 1.50 5978317.15 583307.31 N 70.35072764 W 149.32362199 700.00 6.00 70.00 699.27 20.09 7.16 19.66 1.50 5978320.38 583315.88 N 70.35073619 W 149.32355218 800.00 7.50 70.00 798.57 31.38 11.18 30.71 1.50 5978324.52 583326.88 N 70.35074717 W 149.32346247 900.00 9.00 70.00 897.54 45.16 16.08 44.19 1.50 5978329.57 583340.30 N 70.35076056 W 149.32335304 ~ 930.36 9.46 70.00 927.50 49.83 17.75 48.77 1.50 5978331.29 583344.87 N 70.35076512 W 149.32331586 1000.00 10.50 70.00 996.09 61.42 21.88 60.10 1.50 5978335.54 583356.15 N 70.35077641 W 149.32322388 1100.00 12.00 70.00 1094.16 80.15 28.55 78.44 1.50 5978342.42 583374.41 N 70.35079463 W 149.32307499 1200.00 13.50 70.00 1191.70 101.34 36.10 99.17 1.50 5978350.20 583395.05 N 70.35081525 W 149.32290670 1300.00 15.00 70.00 1288.62 124.97 44.52 122.30 1.50 5978358.87 583418.09 N 70.35083825 W 149.32271893 1400.00 16.50 70.00 1384.86 151.04 53.80 147.81 1.50 5978368.43 583443.49 N 70.35086360 W 149.32251184 1500.00 18.00 70.00 1480.36 179.51 63.94 175.68 1.50 5978378.88 583471.24 N 70.35089130 W 149.32228558 1581.40 19.22 70.00 1557.50 204.45 72.83 200.09 1.50 5978388.04 583495.55 N 70.35091559 W 149.32208741 1600.00 19.50 70.00 1575.05 210.37 74.93 205.88 1.50 5978390.21 583501.32 N 70.35092133 W 149.32204041 Station ID L-103 (P6) report.xls Page 1 of 3 6/18/2002-2:21 PM Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azim I TVD I VSec I N/.S E/.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1700.00 21.00 70.00 1668.86 243.61 86.77 238.40 1.50 5978402.41 583533.70 N 70.35095367 W 149.32177640 SV4 1719.98 21.30 70.00 1687.50 250.53 89.24 245.18 1.50 5978404.95 583540.45 N 70.35096042 W 149.32172136 End Sid 1736.67 21.55 70.00 1703.03 256.38 91.32 250.91 1.50 5978407.09 583546.16 N 70.35096610 W 149.32167484 Sase Permafrost 1784.48 21.55 70.00 1747.50 273.24 97.33 267.41 0.00 5978413.29 583562.59 N 70.35098252 W 149.32154089 Sid 2/100 1789.85 21.55 70.00 1752.50 275.14 98.00 269.26 0.00 5978413.98 583564.43 N 70.35098435 W 149.32152587 1800.00 21.75 70.00 1761.93 278.73 99.28 272.78 2.00 5978415.30 583567.93 N 70.35098784 W 149.32149730 Cry 3.5/100 1889.85 23.55 70.00 1844.85 311.96 111.12 305.30 2.00 5978427.50 583600.32 N 70.35102018 W 149.32123329 1900.00 23.90 69.86 1854.14 315.88 112.52 309.13 3.50 5978428.94 583604.13 N 70.35102401 W 149.32120220 2000.00 27.36 68.65 1944.29 357.24 127.87 349.57 3.50 5978444.74 583644.39 N 70.35106594 W 149.32087389 ..-,." 2100.00 30.83 67.70 2031.65 403.46 145.96 394.69 3.50 5978463.32 583689.31 N 70.35111535 W 149.32050759 SV3 2124.38 31.68 67.49 2052.50 415.45 150.78 406.39 3.50 5978468.27 583700.95 N 70.35112852 W 149.32041260 2200.00 34.31 66.92 2115.92 454.37 166.74 444.34 3.50 5978484.65 583738.72 N 70.35117211 W 149.32010451 2300.00 37.78 66.27 2196.76 509.78 190.12 498.33 3.50 5978508.63 583792.44 N 70.35123598 W 149.31966619 SV2 2326.41 38.70 66.11 2217.50 525.14 196.72 513.29 3.50 5978515.39 583807.32 N 70.35125400 W 149.31954473 2400.00 41.27 65.71 2273.88 569.48 216.02 556.45 3.50 5978535.17 583850.26 N 70.35130672 W 149.31919434 2500.00 44.75 65.23 2347.00 633.26 244.34 618.49 3.50 5978564.18 583911.98 N 70.35138408 W 149.31869066 2600.00 48.24 64.80 2415.83 700.86 274.98 684.22 3.50 5978595.54 583977.36 N 70.35146777 W 149.31815701 2700.00 51.73 64.42 2480.12 772.05 307.82 753.40 3.50 5978629.15 584046.16 N 70.35155746 W 149.31759536 End Sid 2767.07 54.06 64.18 2520.58 821.67 331.01 801.59 3.50 5978652.87 584094.09 N 70.35162080 W 149.31720411 SV1 2812.94 54.06 64.18 2547.50 856.10 347.19 835.03 0.00 5978669.42 584127.34 N 70.35166500 W 149.31693261 9-5/8" Csg pt 2864.06 54.06 64.18 2577.50 894.46 365.22 872.28 0.00 5978687.86 584164.38 N 70.35171424 W 149.31663018 UG4A 3383.77 54.06 64.18 2882.50 1284.51 548.48 1251.08 0.00 5978875.30 584541.09 N 70.35221474 W 149.31355465 UG3 4014.23 54.06 64.18 3252.50 1757.69 770.81 1710.60 0.00 5979102.70 584998.07 N 70.35282188 W 149.30982354 Cry 4/100 4676.44 54.06 64.18 3641.13 2254.69 1004.33 2193.25 0.00 5979341.55 585478.05 N 70.35345949 W 149.30590439 4700.00 53.80 65.30 3655.00 2272.41 1012.45 2210.47 4.00 5979349.86 585495.17 N 70.35348166 W 149.30576456 ~. 4800.00 52.81 70.13 3714.78 2348.40 1042.86 2284.62 4.00 5979381.09 585568.97 N 70.35356468 W 149.30516244 4900.00 52.01 75.08 3775.80 2425.37 1066.55 2360.19 4.00 5979405.62 585644.27 N 70.35362933 W 149.30454881 UG1 4943.25 51.74 77.25 3802.50 2458.87 1074.69 2393.22 4.00 5979414.12 585677.20 N 70.35365154 W 149.30428062 5000.00 51.43 80.12 3837.77 2502.94 1083.41 2436.82 4.00 5979423.33 585720.70 N 70.35367532 W 149.30392659 5100.00 51.07 85.23 3900.38 2580.74 1093.35 2514.13 4.00 5979434.12 585797.89 N 70.35370241 W 149.30329887 5200.00 50.93 90.38 3963.34 2658.37 1096.33 2591.74 4.00 5979437.97 585875.45 N 70.35371048 W 149.30266872 Ma 5238.33 50.94 92.35 3987.50 2688.01 1095.62 2621.49 4.00 5979437.59 585905.20 N 70.35370851 W 149.30242717 End Cry 5289.79 51.00 95.00 4019.91 2727.64 1093.06 2661.37 4.00 5979435.47 585945.11 N 70.35370148 W 149.30210338 Na 5548.15 51.00 95.00 4182.50 2926.07 1075.56 2861.39 0.00 5979420.20 586145.29 N 70.35365347 W 149.30047942 Oa 5842.12 51.00 95.00 4367.50 3151.85 1055.65 3088.98 0.00 5979402.82 586373.06 N 70.35359883 W 149.29863163 L-103 (P6) report.xls Page 2 of3 6/18/2002-2:21 PM Grid Coordinates Geographic Coordinates I Station ID MD Incl I Azim TVD VSec N/.S E/.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) L-103 Sch Tgt 5889.79 51.00 95.00 4397.50 3188.47 1052.42 3125.88 0.00 5979400.00 586410.00 N 70.35358996 W 149.29833204 Obf Base 6477.72 51.00 95.00 4767.50 3640.02 1012.60 3581.06 0.00 5979365.25 586865.55 N 70.35348062 W 149.29463648 Crv 4/100 6533.34 51.00 95.00 4802.50 3682.74 1008.83 3624.11 0.00 5979361.95 586908.63 N 70.35347027 W 149.29428697 6600.00 48.93 97.20 4845.38 3733.01 1003.42 3674.86 4.00 5979357.11 586959.43 N 70.35345542 W 149.29387494 6700.00 45.92 100.77 4913.04 3804.82 991.98 3747.57 4.00 5979346.48 587032.26 N 70.35342407 W 149.29328464 6800.00 43.02 104.71 4984.41 3871.96 976.60 3815.88 4.00 5979331.86 587100.73 N 70.35338196 W 149.29273009 6900.00 40.28 109.10 5059.14 3934.12 957.35 3879.45 4.00 5979313.32 587164.50 N 70.35332928 W 149.29221403 CM2 6910.94 39.99 109.61 5067.50 3940.61 955.02 3886.10 4.00 5979311.06 587171.18 N 70.35332290 W 149.29216005 7000.00 37.72 113.99 5136.86 3991.00 934.33 3937.97 4.00 5979290.95 587223.27 N 70.35326631 W 149.29173900 ~ End Crv 7037.05 36.83 115.94 5166.34 4010.67 924.87 3958.31 4.00 5979281.72 587243.71 N 70.35324043 W 149.29157390 Fit Tgt Crv 4/100 7513.24 36.83 115.94 5547.50 4258.57 800.00 4215.00 0.00 5979159.72 587501.75 N 70.35289892 W 149.28949038 End Crv 7521.14 37.13 116.11 5553.81 4262.69 797.92 4219.27 4.00 5979157.69 587506.04 N 70.35289323 W 149.28945572 CM1 7707.64 37.13 116.11 5702.50 4360.30 748.38 4320.36 0.00 5979109.28 587607.67 N 70.35275773 W 149.28863521 Top HRZ 8248.23 37.13 116.11 6133.50 4643.21 604.79 4613.37 0.00 5978968.97 587902.23 N 70.35236498 W 149.28625701 Base HRZ 8485.29 37.13 116.11 6322.50 4767.27 541.82 4741.86 0.00 5978907.44 588031.40 N 70.35219273 W 149.28521416 K-1 8579.36 37.13 116.11 6397.50 4816.50 516.83 4792.85 0.00 5978883.02 588082.66 N 70.35212438 W 149.28480032 Top Kuparuk 8591.89 37.13 116.11 6407.49 4823.06 513.50 4799.65 0.00 5978879.77 588089.49 N 70.35211527 W 149.28474513 Kuparuk Target 8629.53 37.13 116.11 6437.50 4842.76 503.50 4820.05 0.00 5978870.00 588110.00 N 70.35208791 W 149.28457956 KupC 8633.29 37.13 116.11 6440.50 4844.73 502.50 4822.09 0.00 5978869.02 588112.05 N 70.35208518 W 149.28456300 LCU 8823.94 37.13 116.11 6592.50 4944.50 451.86 4925.42 0.00 5978819.54 588215.93 N 70.35194665 W 149.28372438 KupA 8993.27 37.13 116.11 6727.50 5033.11 406.89 5017.20 0.00 5978775.59 588308.20 N 70.35182363 W 149.28297950 TMLV 9093.62 37.13 116.11 6807.51 5085.63 380.23 5071.60 0.00 5978749.54 588362.88 N 70.35175070 W 149.28253800 TD / 7" Csg Pt 9243.61 37.13 116.11 6927.09 5164.13 340.39 5152.90 0.00 5978710.61 588444.61 N 70.35164171 W 149.28187819 LeQal Description: /-." NorthinQ (y) rftUSl EastinQ (X) rftUSl Surface: 2590 FSL 3618 FEL S34 T12N R11E UM 5978313.00 583296.30 L-1 03 Sch Tgt: 3642 FSL 490 FEL S34 T12N R11 E UM 5979400.00 586410.00 Kuparuk Target: 3092 FSL 4077 FEL S35 T12N R 11 E UM 5978870.00 588110.00 BHL: 2928 FSL 3744 FEL S35 T12N R11 E UM 5978710.61 588444.61 L-103 (P6) report.xls Page 3 of 3 6/18/2002-2:21 PM VERTICAL SECTION VIEW Client: Well: BP Exploration Alaska L-103 (P6) Schlumberger Field: Prudhoe Bay Unit - WOA Structure: L-Pad Section At: 86.22 deg Date: June 18, 2002 1 ! ! ! . 1 Bid 1.51100 300"10 300 TVD "'1~'(¡:OÖö""iÖ:ÕÖ'''äpdëPä¡:¡¡¡re'''''''' - - - ~ - G1328MD323TVD -+ ~ - - ~ - - - - ~ -EndBld1737~D-17õ3TVï5 ""~"" '" ",,21,',55. ;~;.~~..¡.az~;:,~e~a,;~;3"TVr.>" '"'' . s'ÿi3 930 MiS 92;3 T'>lÖ "T 21.550 ¡ 70.00° az 275 departure ""1 ..... ! cn! 3.51100 1890 MD 1845 TVD - ì ~ 23 ¡;so 7000. az 312 departure - - -. - - - - - ::::: :::::1 ::::: ::::: =.:=. ;: ;: ;: =.:=. ¡ ;om ~ 2000 =;: ;:;,; ;:-:~~=~,,~ Th~ ;: ; ; ;::~~~-~~:.'":,,,i~~~9~_:'5I"~8f":~c:~s"'g~Pt"~22;864:~~~M::::Drë~2':'$i",;'7"'8'~TV:""D;~ ~ = ----- --- - :: :: :: :: - - - - - .0:::::: . ;,W2 2:>;;>6¥D Z21!.f'lVD"[' "I ~ . ¡ > - - - + - šV,,: 2813MD2548TVD-+-,:" ~ ~ 540606418° 894deøart ~ (J) - - - - - - :.: = "''' ~""" "" = J.: = = = = q~4!~OO~6~; ~84;TV~ = II .,g "',, Ü,3éA"33s<n"Ö"286'3'TV$ 1 54,06. 641.. az 2255 departure c: CO - - - ~ í - EndC.!j5290MD 4020TVD _I - - - - - -' - - -- - - -" -, S 8 - (18:, 4ô14MD325:f1V[í - - - Hoid Angle-S4.06° - - 51.00" 19~~~3~C~~:I::rt~~ :98JD - , J:: ~ "',, "","""" ."" '"'' ...¡, ì,"'¡ 5.~:OO:.",95:,()Q. ":z. 31,8.8 cu.:p'a~~.~~ ""'"'' +-Ie. t- 4000 -,. - . - ..~.,-" ~" ...:94:!<1D..::80':;"TV.l -- ,---], . "-i-",--_",Çv¡5"L,O,4/0,,~1QQ_9"5~,Q..0?az~3"68..4ß._~.',9d.3.lYe""'''rtIL!!-re' "-- ",,-, ",-, "'-, ",-" ,- ,,- -" - ,-" - , _.. 1- T - ;:"'523& MD~::Tì~¿r'-" u un . =- - - - - - - (J) ""--'" ë)" 4:j6STvD"i" '"'' - - -r - - "", - - 1 0 ~ i 15ý' Radius CO .. . Vbia-s~&i7¡ff.,1D47i3mV() - - - - - - - - - - - - .~ ~ - - - T,,, - \II CM2 "691 T'MCï"ð06ij"rvQ" ~o:: > > (J) (J) :JW s.... ..... 0-". ....~.-.. ¡ ¡ "r" ---..------ , , , ' . ' -¡ - - - - - - -¡- - - - - --j , ' - - - - - -, - - -- - - - -. mt ....;.. iï.d 'CN iÕ3Ú,iþ '516S"ivö'" ~ ~.8~ 1:!.:.9~F ~01~e~ur~ - - -\ - - -- - - - -\ Fit Tgt C~ 411007513 MD 5548 TVD . . ""'*',83. "1~5,94" az"'4259 departur-e "" End Cry 7521 MD 5554 TVD ~ 37,13. 11þ,11.az 4263departure ! , ~~.P.ar~,~ T'!r.ge~~,630..t!lD",§43,UVP,,: 37,13. 116,11.az 4843 departure , /~ .,¡,. 'CM ¡ "7l0S"M1:f"?>"t;):rT'ý"9" "'1- : : 6000 _. '" ........""'....."""!."'".,,"'u..w"'w"'....,,,, ,+, ",..""-"''''--,,,,,, , ",'-:::t-tQId.::An.gt~u~3.7;::t3:i"-~:::'. ~ ;.; ;.; ¡ ~ i,:~!c:;¿;;';;;ti~T~':~~"~:I&!¡;"':':",..:,:.~~'~'~~'~ ,:~ =,T3,:,,:..~,:,p~pa~,' ~92~D ~07;jD~ = = ~ ~ = x - , - -, - - - - - - - - - - ~ - - ~, - ì,:-~ ------ ------~------~-- ! . i ì ..... '-"', n..' ..m - -: -- .m. .n.,- ..... '..., mO- m., ..00. m" ...... - - - - _: .-.. m.. ..... ..,.. ..".. ..... ..... ..." ..... .... ..... m.,. - - - _. ..... .... ,,,.. ....., ..... .....; ....." n..- --:--- m', ..m. ..... ..: ..... - - - ~: - ..... ".., ...., ..... ..... .....: ~ -- ..- ~. -.- .-- TD ;7" Csg PI 92414 MD 6927 TVD 37,13. 116,11.az 516,4 departure 8000 -, ...~.....m~_...._.._....---. ....--...t....-..... . I I -4000 I -2000 I 0 I 2000 I 4000 I 6000 I 8000 T , 10000 Vertical Section Departure at 86.22 deQ from (0.0, 0.0). (1 in = 2000 feet) Client: Well: Field: Structure: Scale: Date: -1000 0 1000 I True North Mag Dee ( E 25.85° ) 2000 - ~ ^ ^ ^ I r- a:: 0 z ~ ¡ fõ~,'\ , rd\~\)~ . y..?\Ò__,nnnn_- 1000--) ..- o-~! 9-5IS" Csg PI End Bid ;:~~D64~~S:D 1737 MD 1703 TVD 365 N 872 E ~:'~5°2:10~00~az: ~: Bid 1.51100 I Þ : 300MD 300TVD; ~ ' :~',:'OO.,,~ i-4 ----.17\,~ r~iM~';.. Bid 2IIQO. 1890 MD 1845~OI N S02 E 1790 M~ 1753 TVD 23,55' 70,00'.k 21,550 70,00' az 111 N 305 E ; 9SN 2~9E I r- :::> 0 en V V V -1 000 _n~i . , _W_'..m.._.........~.~....~.- . '-_.-"'._-,,".,-.__w..-oW. . PLAN VIEW BP Exploration Alaska L-103 (P6) Prudhoe Bay Unit - WOA Schlumbørgør L-pad 1 in = 1000 ft 18-Jun-2002 2000 3000 I 4000 5000 6000 I - 3000 -, .." EndCrv Azimuth 95.00° 5l~(O MC' 4('20 rvD 51,00' 95,00',az L-103 Sch Igl 1093N 2661 ~ ~~0~~5~~~8:D , j ~¡ 1052 N 3126 E ~~;t~ 4803 TVD , :" 51.oar,'... 95,00' az FII Ig1 Cry 4I10d ! / 1009 ~ 3624 E 7513 MD 5548 TvD ¡ ! 36,830 115,94' ~ ! 800 N 4215 E! Kuparuk Targel \-;:0 ~:~U$ ~~":,~%,,,i-!;;t~; ~ , 36,83' 115,94' az , 'TD 17" Csg PI , Cry 41100 , 925 N 3958 E ¡ Ij¡ , '<1 9244 MD 6927 TVd :~7~~~4~8~1:~ I DIet '- 37,13' 116,11'az i 1004 N 2193 E ! End Cry i ~/Í1} i V 340 N 5153 E ' , 7521 MD 55541"D (¡II) 1 : ~~, ~ ~7,1}~ w 1. tfJr,,~. "n~~ "'~ .~n~le ' 798N 4219E ¡ . r 1° I .--', - 2000 - 1000 -0 .. _."'..'~.'._._....~-._..- --1000 "--_...'.._.~-w.w--_......._. .- I -2000 I I I I I I I I -2000 -1000 0 1000 2000 3000 4000 5000 6000 «< WEST EAST »> ( L-103i Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates have been observed in offset wells. These are expected to be encountered near the base of the Permafrost at 1784' and near the TO hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity and yield point is maintained to avoid stuck pipe situations. Production Hole Section: . The production section will be drilled with a recommended mud weight of 10.1 ppg to ensure adequate overbalance in the Kuparuk formation and shale stability in the HRZ shale. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. The two short trips in the production hole has proved problematic if hole cleaning practices are not in place. Back reaming at connections and monitoring excessive annular ECO via the PWD will contribute to favorable hole conditions. . FAULTS: The well trajectory is expected to intersect 3 faults - one in the surface hole, Schrader Sluff and one in the Colville. Losses are unexpected, but if losses are encountered, consult the Lost Circulation Decision Tree for recommended LCM treatments. . KICK TOLERANCE: With 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.3 ppg at the surface casing shoe, and 10.1 ppg mud in the hole, the kick tolerance is 25 bbls. . L-Pad development wells have "kick tolerances" in the 25-50 bbl range. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 ( .,. bp ,,,,.,.,, -.....~ ~.....- ~~- --:....~ .....~ F"'-' .'.'tll'- ". To: Tom MaunderIWinton Aubert, AOGCC Date: June 26, 2002 From: J ames Franks Subject: Dispensation for 20 AAC 25.035 (c) on L-I03i BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the Borealis/Kuparuk wells at L-pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All ten of the surface holes for the Borealis Development were drilled to the shale underlying the SV-1 sands. The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is :t300' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-103i is planned to reach a 9.5 ppg mud weight before TD at -2,500' TVDss. This request is being made based on L-Pad data submitted regarding mud weight, gas monitoring, recent open hole surface logging of L-106 (PEX/Dipole sonic), a meeting between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP), as well as a guarantee to log the surface hole in the future development of the north west comer of the pad.. Your consideration of the waiver is appreciated. Sincerely, J ames Franks GPB Rotary Drilling Engineer 564-4468 Borealis Surface Hole Mud Weight MW (ppg) 9 ( 8 0 8.5 x 500 1000 ~ .c ~ 1500 c > I- "'--" .c 2- 2000 c 2500 3000 1 3500 ~'''^ rt . L-01 II L-116 )( Pore Pressure . L-107 - -- - , L -1 04~~^~'~+===. L -120 L -1 09 (' 9.5 10 '" ..., Iã L-110 ~ L-106 L-102 . L-114 $ L-115 L-119 Borealis Mud Plots 2/4/02 H 206927 DATE INVOICE / CREDIT MEMO OS/23/02 CK052302J - , ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY DESCRIPTION Permit To Drill Fee GROSS DATE CHECK NO. OS/28/02 H206927 VENDOR DISCOUNT NET $100.00 H PIs call Terrie ,Hubble X4628 f) r'" iP" If'.' ~ \ II ~= ~'}. [, ~~,. t ~ \l [,: TOTAL ~ B, P r; ,.. ..,... "1m,, ','í',',Htl ,i'''l ""1' r:¡,tt f f ) ¡ " 'I...' t.. . . .. .:J ..1 If -snlll!' ~~d I dH;! TO THE ORDER OF Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage, AK 99501 " . ¡ \ {<).""" (~O ""':;, ,JU¡\¡ L. f ¿ jUt. AtQ~1'ka OiÄ &: G8S GOW3" e~)nmm~t~!On .' A[chQra2~ ~"b, $100.00 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 206927 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 DATE AMOUNT -'" ***May 28,2002**** *****100.00******* NOT VALID AFTER 120 DAYS 118 2 0 b c¡ 2 ? 118 I: 0... ~ 2 0 3 8 c¡ 5 I: 0 0 8 l, l, ~ c¡ 118 TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORA TION INJECTION WELL ,V' INJECTION WELL RED RILL L-I03 "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SPACING EXCEPTION Rev: 5/6/02 C\jody\templates ~~¡ï Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. - (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ~s YL-Uj!. iLe :;cw<e d,¿v~1er WCl/Ver \/-e.-v b..t'~ t1.- <,. L ~ / Dr; . P~I-e.. / ei ~ ¡L~ fA-J.~ ~~'~ V'~i¡ iõ tvr--e- VJ. WELL PERMIT CHECKLIST COMPANY ßfJY WELL NAME,P&I ¿-Jó~)' PROGRAM: Exp - Dev - Redrll- Se~ X Wellbore seg - Ann. disposal para req- FIELD & POOL ç;~. O/',3()., , ' I,NITCLASS /-Gc/4~J g GEOLAREA ?!ð UNIT# //!:.,("¡'"j ON/OFFSHORE t:!)A) ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. " . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . .. . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N APPR .P~ Tj: 12. Permit can be issued without administrative approval.. . . . . Y N #r' 7/ <f/O? - . 13. Can permit be approved before 15-day wait.. . . . . . . . . . iN if, If .1 ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . N S cI )( 'U? @ ti 0 15. Surface casing protects all known USDWs. . . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . .. N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~' 18. CMT will cover all known productive horizons. . . . . . . . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . .. . ,N . l 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N N~J) 01'$ q I£~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . . At/k 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . ,N, r 24; Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N P I ,AA.., I- t ~~~/f\ DATJF 26. BOPE press rating appropriate; testto <-1000 psig. ,. N M~ ¿ 7 2-..., pÇ¡. ¡vtQ..'K- ~ 'leS c..jCXJ() (J~/ . ~/T 1}1{ 0 /, 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . ~!;l, 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y œ 30. Permit can be issued wlo hydrogen sulfide measures. . . .. JYy N 31. Data presented on potential overpressure zones. . . . . . . Y N ¡t)./) 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y ./ q rJ . A~R 9~1Ji 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N /Y"é T/~CY:? . 34. Contact name/phone for weekly progress reports [exploratory on'- Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A} will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. " to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 MC 25.412. GEOLOGY: ENGINEERlbIG: UIC/Annular: CO RPØ JDH-sJf COT WGA \¡J&I¡- DTS (J7 ( 0 cfO .è~ GEOLOGY APPR DATE /f¿ ) 4/rl Comments/Instructions: G:\geology\permits\checklist. doc